Basic Design and Engineering Package (BDEP), Pipeline Appendix 1

Tri Ocean Document No.

09223-0-DB-GQ-00001.00 Revision No.

0 Client Document No. Page

07-2-LA-7180-0005 1 of 2 Project

Quest CCS Project Title

Design Basis Engineering Package

Appendix A

Acronyms and Abbreviations

Tri Ocean Document No. Revision No.

09223-0-DB-GQ-00001.00 0 Client Document No.

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ALARP As Low as Reasonably Practicable ALC Adjacent Linebreak Closure BCS Basal Cambrian Sand CAPP Canadian Association of Petroleum Producers CCS Carbon Capture and Storage (Sequestration) CRC Calgary Research Centre CSA Canadian Standards Association DBM Design Basis Memorandum DFO Department of Fisheries and Oceans EPP Environmental Protection Plan EPZ Emergency Planning Zone ERCB Energy Resources Conservation Board HAZID Hazard Identification HAZOP Hazard and Operability (Study) HDD Horizontal Directional Drilling HEMP Hazard and Effects Management Process HSSE Health, Safety, Security, and Environment HVP High Vapour Pressure IMP Inspection Management Plan ISBL Inside Battery Limits LBV Line Break Valve LRDF Long Running Ductile Fracture MMSCF Million Standard Cubic Feet MMV Measurement, Monitoring and Verification MOC Management of Change NGO Non-Government Organizations NPS Nominal Pipe Size NSR North Saskatchewan River OR&A Operational Readiness & Assurance OSG Oil Sands Guidelines PDP Project Development Plan QRA Quantitative Risk Analysis SCADA Supervisory Control and Data Acquisition SIL Safety Integrity Level SIMOPS Simultaneous Operations TBA To Be Announced TBC To Be Confirmed TBD To Be Determined TEG Triethylene Glycol WTI Well Tie-In




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Appendix B

Process Flow Scheme




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Appendix C

Process and Instrumentation Diagrams (P&IDs)




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Appendix D

Line Pipe Specifications

Quest CCS Project

Line Pipe Specification

Prepared for Shell Canada Energy

1 2011.07.06 Re-Issued for Quotation KIA MZ MCS

0 2011.06.30 Issued for Purchase KIA MZ KIA

Rev. Date (yyyy.mm.dd) Issue Originator Checker Approver Client

Tri Ocean Document No. 09223-0-SP-PL-00001.00

Client Document No. 07-2-LA-7880-0007

Revision No. 1

Page 1 of 6

90000-1-FM-00012 Rev4 (2010.12.08)


09223-0-SP-PL-00001.00 Revision No.

1 Client Document No.

07-2-LA-7880-0007 Page

2 of 6 Project

Quest CCS Pipeline Project Title


Table of Contents

1. Scope 3

2. Project Information 3

3. Applicable Regulations, Codes, Standards and Specifications 3

4. Design Data 3

5. General Requirements 4 5.1 August 2012 Delivery 4 5.2 March 2013 Delivery 4 5.3 October 2013 Delivery 5

6. Chemical Composition 5

7. Length Tolerances 6

8. Shipping 6

Appendices

Appendix A Shell DEP 31.40.20.37-Gen Appendix B Addendum to Shell DEP 31.40.20.37-Gen; Dated June 21, 2011, Rev. 2




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1. Scope

This specification outlines the requirements of steel line pipe for Quest CCS Pipeline project for Shell Canada Energy.

2. Project Information

Client: Shell Canada Energy

Project description: Shell Quest is a fully integrated Carbon Capture and Sequestration (CCS) project. It will capture up to 1.2 million tones of CO2 per year from the Scotford Upgrader and the CO2 will be transported by pipeline to an injection location near the Scotford Complex and stored approximately 2,300 meters underground in a deep geological formation.

3. Applicable Regulations, Codes, Standards and Specifications

The line pipe shall meet or exceed all of the requirements of the following codes and standards together with additional requirements set forth in this specification.

• CSA Z245.1-07 Steel Pipe

• CSA Z662-07 Oil and Gas Pipeline Systems

• Shell DEP 31.40.20.37-Gen and its Addendum dated June 21, 2011 Rev2

• ISO 3183-2007

• All other Codes and Standards referenced by the above Codes and Standards

In the event of conflict between this specification, Shell DEP 31.40.20.37-Gen and its addendum dated June 21, 2011 Rev2 and CSA code, the Purchaser shall be advised and will decide which document will govern.

4. Design Data

Design Pressure: 14,790 kPa

Minimum Design Metal Temperature: -450C

Maximum Design Temperature: 600C




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5. General Requirements

Process of Pipe Manufacture: HFW/ERW pipe. Only PSL2 pipe shall be supplied, in accordance with Shell DEP 31.40.20.37-Gen and its Addendum dated June 21, 2011 Rev. 2.

Grade and Specification: CSA Z245.1-07 Gr. 386 CAT II. Maximum yield strength shall be 400 MPa.

CVN Impact Test: CVN testing shall be in accordance with ASTM A370. Minimum average absorbed energy for each pipe body test (a set of three test pieces) shall be 60J based upon full-size test pieces with a single minimum value of 52J. The test temperature shall be lower than or equal to -45°C.

Brittle-ductile transition curves shall be provided showing actual absorbed energy values at the temperatures -75°C, -60°C, -20°C, 0°C and +20°C

Drop Weight Test: For each test (a set of two test pieces), the average shear fracture shall be ≥ 85%.

5.1 June 2012 Delivery

Nominal Outside Diameter: 323.9 mm

Specified Wall Thickness: Line Pipe = 12.7 mm

Quantity = 500 m

5.2 March 2013 Delivery



Quantity = 66,000 m

Heavy Wall = 14.3 mm

Heavy Wall Quantity = 1000 m



Quantity =5,000 m




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5.3 October 2013 Delivery



Quantity = 16,000 m



Quantity = 6,000 m

Length Range: See section 7 of this specification

Supplementary Requirements: HFW/ERW pipe produced with a welding current frequency equal to or greater than 100 kHz.

Cut back length shall be 100 mm from pipe ends.

Shell DEP 31.40.20.37-Gen and its Addendum dated June 21, 2011 Rev2.

Service: Dehydrated Dense Carbon Di Oxide to a water content of less than 4 lb/MMSCF.

Physical Properties and Tests: All Mechanical tests (e.g. tensile test), Chemical tests and hardness tests shall be done in accordance with the provisions of Shell DEP 31.40.20.37-Gen and its Addendum dated June 21, 2011 Rev2.

6. Chemical Composition

Chemical composition of the pipe materials shall be as per section 9.2 of Shell DEP 31.40.20.37-Gen and its Addendum dated June 21, 2011 Rev2.

A Sample Product Analysis is to be supplied with the bid. Any deviations must be highlighted and are subject to prior approval.




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7. Length Tolerances

Nominal Length

Shortest Length in Entire Shipment

Longest Length in Entire Shipment

Minimum Average Length in Entire

Shipment

18 m 8.00* 22.0 m 18.3 m

24 m 15.00* 24.5 m 22.0 m

* The shortest length shall be dictated by CSA Z245.1 and the handling capability of the coating mill. The longest length is dictated by transportation regulations and the handling capability of the coating mill and therefore shall be as agreed upon between Tri-Ocean, the manufacturer and the coating applicator. Any finished lengths shorter than the minimums shown in this table must be approved by Tri-Ocean.

8. Shipping

The Manufacturer shall submit, for approval by Tri-Ocean, drawings of their proposed method of stacking and securing pipe for stockpiling and/ or shipping. Any subsequent modifications or revisions to such approved drawings shall be subject to approval by Tri-Ocean.

Care shall be taken to ensure that pipe is stored, loaded and transported in such a manner as to avoid damage. The occurrence of fluctuating stresses that may cause fatigue cracks due to pipe transit shall be avoided.

Cars, Trailers and/or Barges shall be adequately cleaned before loading for shipment.

Mill tallies for each load of pipe shall accompany the pipe.




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Appendix A

Shell DEP 31.40.20.37-Gen

DEP SPECIFICATION

LINE PIPE FOR CRITICAL SERVICE (AMENDMENTS/SUPPLEMENTS TO ISO 3183:2007)

DEP 31.40.20.37-Gen.

February 2011

DESIGN AND ENGINEERING PRACTICE

DEM1

DEP 31.40.20.37-Gen. February 2011

Page 3

TABLE OF CONTENTS

PART I INTRODUCTION ........................................................................................................5 1.1 SCOPE........................................................................................................................5 1.2 DISTRIBUTION, INTENDED USE AND REGULATORY CONSIDERATIONS .........6 1.3 DEFINITIONS .............................................................................................................6 1.4 CROSS-REFERENCES .............................................................................................6 1.5 SUMMARY OF MAIN CHANGES...............................................................................6 1.6 COMMENTS ON THIS DEP.......................................................................................7 1.7 DUAL UNITS...............................................................................................................7 PART II GENERAL REQUIREMENTS ....................................................................................8 1.1 GENERAL...................................................................................................................8 1.2 APPLICATION ............................................................................................................8 1.3 PRINCIPAL'S ACCESS AND ACTIVITIES.................................................................9 1.4 PIPE FOR INDUCTION BENDS.................................................................................9 PART III AMENDMENTS/SUPPLEMENTS TO ISO 3183:2007 ............................................10 1. SCOPE......................................................................................................................10 2.3 COMPLIANCE TO THIS INTERNATIONAL STANDARD ........................................10 3. NORMATIVE REFERENCES...................................................................................10 4. TERMS AND DEFINITIONS.....................................................................................10 4.18 HFW PIPE.................................................................................................................10 4.29 MANUFACTURER....................................................................................................10 5. SYMBOLS AND ABBREVIATED TERMS................................................................10 5.2 ABBREVIATED TERMS ...........................................................................................10 6 PIPE GRADE, STEEL GRADE AND DELIVERY CONDITION................................10 6.1 PIPE GRADE AND STEEL GRADE.........................................................................10 6.2 DELIVERY CONDITION...........................................................................................11 7. INFORMATION TO BE SUPPLIED BY THE PURCHASER ....................................11 7.1 GENERAL INFORMATION.......................................................................................11 7.2 ADDITIONAL INFORMATION ..................................................................................11 8. MANUFACTURING ..................................................................................................12 8.1 PROCESS OF MANUFACTURE..............................................................................12 8.3 STARTING MATERIALS ..........................................................................................13 8.4 TACK WELDS...........................................................................................................13 8.5 WELD SEAMS IN COW PIPE ..................................................................................13 8.6 WELD SEAMS IN SAW PIPE...................................................................................13 8.9 COLD SIZING AND COLD EXPANSION .................................................................13 8.10 STRIP/PLATE END WELDS.....................................................................................13 8.11 JOINTERS ................................................................................................................13 8.12 HEAT TREATMENT .................................................................................................14 8.13 TRACEABILITY ........................................................................................................14 9 ACCEPTANCE CRITERIA........................................................................................14 9.1 GENERAL.................................................................................................................14 9.2 CHEMICAL COMPOSITION.....................................................................................14 9.3 TENSILE PROPERTIES...........................................................................................15 9.4 HYDROSTATIC TEST..............................................................................................15 9.6 FLATTENING TEST .................................................................................................15 9.8 CVN IMPACT TEST FOR PSL2 PIPE......................................................................15 9.9 DWT TEST FOR PSL2 WELDED PIPE ...................................................................16 9.10 SURFACE CONDITIONS, IMPERFECTIONS AND DEFECTS...............................18 9.11 DIMENSIONS, MASS AND TOLERANCES.............................................................18 9.12 FINISH OF PIPE ENDS............................................................................................19 9.13 TOLERANCES FOR THE WELD SEAM..................................................................19 9.14 TOLERANCES FOR MASS......................................................................................20 9.15 WELDABILITY OF PSL2 PIPE .................................................................................20 10 INSPECTION ............................................................................................................20 10.2 SPECIFIC INSPECTION ..........................................................................................20 11 MARKING .................................................................................................................27 11.1 GENERAL.................................................................................................................27


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11.2 PIPE MARKINGS......................................................................................................27 11.3 COUPLING MARKINGS...........................................................................................27 12.2 THREAD PROTECTORS .........................................................................................27 14 PIPE LOADING.........................................................................................................27 ANNEX A SPECIFICATION FOR WELDED JOINTERS ..........................................................28 ANNEX B MANUFACTURING PROCEDURE QUALIFICATION FOR PSL2 PIPE..................28 ANNEX C TREATMENT OF SURFACE IMPERFECTIONS AND DEFECTS ..........................31 ANNEX D REPAIR WELDING PROCEDURE...........................................................................31 ANNEX E NON-DESTRUCTIVE INSPECTION FOR OTHER THAN SOUR SERVICE OR

OFFSHORE SERVICE .............................................................................................32 ANNEX F REQUIREMENTS FOR COUPLINGS (PSL 1 ONLY)..............................................43 ANNEX G PSL 2 PIPE WITH RESISTANCE TO DUCTILE FRACTURE PROPAGATION......43 ANNEX H PSL 2 PIPE ORDERED FOR SOUR SERVICE.......................................................43 ANNEX I PIPE ORDERED AS “THROUGH THE FLOWLINE" (TFL) PIPE ............................46 ANNEX J PSL 2 PIPE ORDERED FOR OFFSHORE SERVICE .............................................46 ANNEX K NON-DESTRUCTIVE INSPECTION PIPE ORDERED FOR S OUR AND/OR

OFFSHORE SERVICE .............................................................................................49 PART IV REFERENCES .........................................................................................................53

APPENDICES

APPENDIX 1 LINEPIPE SUBJECTED TO HIGH STRAIN....................................................55 APPENDIX 2 WELDABILITY OF PSL2 PIPE........................................................................57 APPENDIX 3 LINE PIPE FOR DEE PWATER PROJECTS, INCLUDING STEEL

CATENARY RISERS.......................................................................................58 APPENDIX 4 PROCEDURE REQUIREMENTS FOR NDT...................................................60


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PART I INTRODUCTION

1.1 SCOPE

This DEP specifies requirements and gives recommendations for the manufacture and supply of carbon an d low-alloy steel lin e pipe for use in pipelines where the service h as been evaluated by the Principal as being “Critical”. Guidance on the evaluation of pipeline service criticality and line pipe selection is given in DEP 31.40.00.10-Gen.

This DEP applies to the following applications; see also (Part II, 1.2).

• all offshore pipelines;

• all pipelines designed for sour service;

• all pipelines subject to high strain (more than 1.5%) in installation or service;

• all line pipe ordered with resistance to ductile fracture propagation.

This DEP does not apply when all of the following conditions are satisfied:

• the design pressure does not exceed 40 bar (ga); and,

• the pipeline has been designed with a design factor of 0.5 or lower; and,

• the pipeline is designed for the transportation of category A, B or C fluids (i.e. not for D and E fluids); and,

• the pipeline has a diameter of DN 250 or less; and,

• the minimum pipeline design temperature is 0°C or greater; and,

• The pipeline does not form part of a main transportation infrastructure.

Use of HSAW line pipe may be applied for onshore applications where the diameter and wall thickness requirements are within the manufacturing range for HSAW line pipe. HSAW does not apply when:

• the operating conditions require use of batch inhibition for corrosion control, or

• the seam welds are at risk of corrosion due to water drop out, or

• the use of reliability-based limit state design principles is required to confirm design or operational integrity,or

• in sour service.

This DEP is based on ISO 3183:2007. Part III of this DEP is written in the form of amendments and supplements ISO 3183:2007 (PSL2).

This DEP is appli cable only to grad es L245 up to L555 (X80) as designated in ISO 3183:2007.

The amendments and supplements in this DEP also apply to API 5L, 44th edition (PSL2), which contains the id entical section numbers and content, with the exceptio n of minor deviations listed in Annex N.

This DEP contains mandatory requirements to mitigate process safety risks in accordance with Design Engineering Manual DEM 1 – Application of Technical Standards.

This is a revision of the DEP of the same number dated January 2010; see (1.5) regarding the changes.


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1.2 DISTRIBUTION, INTENDED USE AND REGULATORY CONSIDERATIONS

Unless otherwise authorised by Shell GSI, the distribution of this DEP is confi ned to Shell companies and, where necessary, to Contractors and Manufacturers/Suppliers nominated by them. A ny authorised access to DEPs d oes not for th at reason constitute an authorization to any documents, data or information to which the DEPs may refer.

This DEP is intended for use in facilities related to oil and gas p roduction, gas handling, oil refining, chemical processing, gasification, distribution and supply/marketing. This DEP may also be applied in other similar facilities.

When DEPs are appli ed, a Manag ement of Chang e (MOC) process should be implemented; this is of particular importance when existing facilities are to be modified.

If national and/or local regulations exist in which some of the requirements could be more stringent than in this DEP, the Contra ctor shall determine by careful scrutiny which of the requirements are the more stringent and which combination of requirements will be acceptable with regards to the safety, environ mental, economic and leg al aspects. In all cases the Contractor shall inform the P rincipal of any deviation from the requi rements of this DEP which is considered to be necessary in order to comply with national and/or local regulations. The Principal may then negotiate with the Authorities concerned, the objective being to obtain agreement to follow this DEP as closely as possible.

1.3 DEFINITIONS

1.3.1 General definitions

The Contractor is th e party that carries out all or part of the de sign, engineering, procurement, construction, commissioning or management of a project or operation of a facility. The Principal may undertake all or part of the duties of the Contractor.

The Manufacturer/Supplier is the party that manufactures o r supplies equipment and services to perform the duties specified by the Contractor.

The Principal is the p arty that initiates the project and ultimately pays for it. Th e Principal may also in clude an agent or co nsultant authorised to act for, and on b ehalf of, the Principal.

The word shall indicates a requirement.

The capitalised term SHALL [PS] indicates a process safety requirement.

The word should indicates a recommendation.

1.3.2 Specific definitions

Term Definition

Manufacturer Term used in ISO 3183:2007, which shall be taken to mean the Manufacturer/Supplier.

Purchaser Term used in ISO 3183:2007, which shall be taken to mean the Principal.

1.4 CROSS-REFERENCES

Where cross-references to other pa rts of this DEP are made, the referen ced section number is shown in brackets. Other documents referenced by th is DEP are listed in (Part IV).

1.5 SUMMARY OF MAIN CHANGES

This DEP is a revision of the DEP of the same n umber dated January 2010 which was based on ISO 3183-3.

ISO 3183-1, ISO 3183-2 and ISO 3183-3 were replaced in March 2007 by a consolidated ISO 3183. Due to the fundamental change in overall scope and cla use numbering in ISO 3183 it is impractical to summarise the changes here.


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1.6 COMMENTS ON THIS DEP

Comments on this DEP may be sent to the Administrato r at [email protected], using the DEP F eedback Form. The DEP Feedback Form can be found on the main page of “DEPs on the Web ”, available through the Glo bal Technical Standards web portal http://sww.shell.com/standards and on the main page of the DEPs DVD-ROM.

1.7 DUAL UNITS

In this DEP, the International System of units (SI) shall be understood to prevail over US Customary (USC) units. Where USC units are provided in brackets following the SI units, this is for information only.

mailto:[email protected]

http://sww.shell.com/standards


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PART II GENERAL REQUIREMENTS

1.1 GENERAL

Part III of this DEP is written as amendm ents and supplements to ISO 3183:2007. Wherever reference is made to IS O 3183:2007, it shall b e understood to mean ISO 3183:2007 as amended/supplemented by this DEP.

The amendments and supplements in this DEP sh all also apply to API 5L, 44 th edition (PSL2), which contains the identical section numbers and content, with the exception of minor deviations listed in Annex N.

For ease of reference, the clause numbering of ISO 3183:2007 has been used throughout Part III of this DEP.

Clauses in ISO 3183:2007 which are not mentioned in this DEP shall rema in valid as written.

Tables and figures in this DEP not replacing the corresponding item in ISO 3183:2007 are numbered related to the DEP section they are contained in (e.g. Figure 10.2.5.3).

1.2 APPLICATION

Carbon Steel Line Pipe SHALL [PS] be orde red using this DEP for the followin g applications:

• all offshore pipelines; • all pipelines designed for sour service; • all pipelines subject to high strain (more than 1.5%) in installation or service; • all line pipe ordered with resistance to ductile fracture propagation.

Line Pipe for onshore applications not addressed above may be designated “Line Pipe for Non-Critical Service” (i.e. pipelines designed for non-sour service and where line pipe is not required to be resistant to ductile fracture propagation or high strain) and may be ordered in accordance with ISO 3183 PSL2 without amendment.

To be classified as Line Pipe for Non-Critical Service all of the following conditions shall be satisfied:

• the design pressure does not exceed 40 bar (ga); and, • the pipeline has been designed with a design factor of 0.5 or lower; and, • the pipeline is designed for the transportation of category A, B or C fluids (i.e. not for

D and E fluids); and, • the pipeline has a diameter of DN 250 or less; and, • the minimum pipeline design temperature is 0°C or greater; and, • The pipeline does not form part of a main transportation infrastructure.

Line pipe shall only be ordered in accordance with ISO 3183 PSL1 for non hydrocarbon, non toxic, low pressure (not greater than 20 Barg), and with a minimum design temperature greater than 0 degrees C.

Use of HSAW line pipe should be considered for onshore applications where the diameter and wall thickness requirements are within the manufacturing range for HSAW line pipe. HSAW line pipe shall not be used where:

• the operating conditions require use of batch inhibition for corrosion control, or • the seam welds are at risk of corrosion due to water drop out, or • the use of reliability-based limit state design principles is required to confirm design

or operational integrity,or • in sour service.

Prior to order placement, the pipe mill and all sources of coil shall be evaluated technically and approved.


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1.3 PRINCIPAL'S ACCESS AND ACTIVITIES

Principal’s representatives shall be permitted to witness all che mical testing, mechanical testing, and equipment calibration, and to in spect all pi pe. Sufficient notice (at least 14 days) shall be given of the time at which the production run is to begin.

The Principal’s representatives shall have free entry at all times to all parts of the Manufacturer’s works that will concern the manufacture, testing, inspection, quality control and shipping of the pipe orde red. This incl udes the steel mill and the pip e mill. Th e Manufacturer shall m ake available to t he Principal’s representatives, without charge, all reasonable facilities to inspect, measure, and test the pipe in all stages of production. For example, this includes ultrasonic equipment for wall thickness confirmation.

The Principal’s representative shall hav e the opt ion to examine a ll materials rejected for any reason. The Principal’s representative must be informed of any pipe fractures occurring during hydrostatic testing and of any test specimen failures to meet the requi rements for any reason. All failed material s shall be retai ned until exa mined by th e Principal’s representative.

The Manufacturer shall allow the Principal’s representative to inspect e ach length of pipe after manufacture and testing are completed but prior to loading for shipment.

1.4 PIPE FOR INDUCTION BENDS

The general requirements of ISO 3183:2007 and this DEP apply to pipe in tended for induction bending. However, the composition, mechanical properties and dimensions of such pipe shall be di ctated by the dim ensions and delivery condition of the completed bends, which shall be in accordance with ISO 15590-1 and DEP 31.40.20.33-Gen. The composition, mechanical properties and dimensions of this pipe shall therefore be by agreement between the Manufacturer and the Principal


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PART III AMENDMENTS/SUPPLEMENTS TO ISO 3183:2007

1. SCOPE

Amend first paragraph as follows:

This international standard specifies requirements for the ma nufacture of product specification level PSL 2 of seamless and welded pipe for use in pipeline transportation systems in the petroleum and natural gas industries.

Add the following:

This DEP is applicable only to gra des L245 up to L555 (X 80) as designated in ISO 3183:2007. Intermediate grades shall not be used.

2.3 COMPLIANCE TO THIS INTERNATIONAL STANDARD

Delete existing clause and replace with the following:

The Manufacturer/Supplier SHALL [PS] maintain and operate a quality a ssurance system in a ccordance with ISO 9001 or an alternative standard approved by the Principal.

3. NORMATIVE REFERENCES

Add the following:

See also (Part IV) of this DEP.

4. TERMS AND DEFINITIONS

4.18 HFW PIPE

Amend this clause as follows:

EW pipe produced with a welding current frequency equal to or greater than 100 kHz.

4.29 MANUFACTURER

Add the following:

Where pipe manufacturing and/or heat treatment are subcontracted, the pipe mill and/or the processor shall also be considered to be the Manufacturer/Supplier.

5. SYMBOLS AND ABBREVIATED TERMS

5.2 ABBREVIATED TERMS

Add the following:

AUT Automatic Ultrasonic Testing

FBE Fusion Bonded Epoxy

GMAW Gas Metal Arc Welding

SCR Steel Catenary Riser

ToFD Time of Flight Diffraction

6 PIPE GRADE, STEEL GRADE AND DELIVERY CONDITION

6.1 PIPE GRADE AND STEEL GRADE

6.1.1 Delete this clause


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6.2 DELIVERY CONDITION


Table 1

Delete reference to PSL1 pipe grades

Delete reference to PSL 2 Grades L390N, L415N, L625M, L690M and L830M

NOTE: Pipes fabricated from thermome chanical rolled material are generall y not suitable for hot (induction) bending.

7. INFORMATION TO BE SUPPLIED BY THE PURCHASER

Add the following:

The complete information should be provided at the enq uiry stage of the purcha se order; however, requirements specifically addressed by this DEP need not be repeated.

7.1 GENERAL INFORMATION

Modify the following:

b) Delete PSL1

Add the following

i) Minimum design temperature (for d etermination of CVN, DWT and CTO D test temperature)

j) Intended service, i.e. ga s or oil for determination of need for, resistance to ductile fracture propagation, sour service high strain, and deep water.

7.2 ADDITIONAL INFORMATION

Add the following:

a)10) Diameter and out-of-roundness for pipes with D/t> 75

Information included in this DEP.

a)3), a)4, a)6), a)9)

b)4), b) 6), b)7)

c)6), c)7), c)8), c )9), c)10), c)11), c)12), c)15), c)16), c)22), c)23), c)25), c)26), c)27), c)40), c)42), c)43), c)44), c)46), c)47), c)49), c)51,

Information not applicable to this DEP.

a)1), a)2), a)9)

b)2), b)3), b)5), b)8), b)11) b)12

c)2), c)5), c)7), c)13), c)13), c)17), c)18), c)24), c)38), c)45), c)48), c)52), c)53)


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8. MANUFACTURING

8.1 PROCESS OF MANUFACTURE

8.1 Delete this clause and replace with the following:

Only PSL 2 pipe shall be supplied in accordance with this DEP. Pipe shall be manufactured by one of the following processes:

Table 2 Delete references to PSL1 grades Delete COWL, COWH, Double-seam SAWL and Double-seam COWL Delete Note d and substitute:

Double-seam SAWL may be permitted only for specific applications and where detailed in the Purchase order

Add NOTE g: HFW pipe is generally limited to a maximum wall thickness of 20 mm. Thickness over 20mm may be

considered after detailed evaluation; any approval by the Principal shall be on a project b y project basis.

Delete Table 3 and replace with the following:

Table 3 Acceptable manufacturing routes for PSL 2 pipe

Type of pipe Starting material Pipe forming Pipe heat treatment Delivery condition

Seamless Ingot, bloom or billet Normalising forming (NOTE 1)

N

Normalising N

Hot forming

Quenching and tempering

Q

Hot forming and cold finishing

Normalising N

Quenching and tempering

Q

HFW Normalising rolled strip Cold forming Normalising weld area

N

Thermomechanically rolled strip

Cold forming Heat treating weld area

M

Heat treating weld area and stress relieving (entire pipe)

M

Hot rolled strip Cold forming Normalising (entire pipe)

N

Quenching and tempering (entire pipe)

Q

SAW Normalised or normalising rolled plate or strip

Cold forming N

Thermomechanically rolled plate or strip

Cold forming M

Quenched and tempered plate

Cold forming Q

As rolled, normalised, or normalising rolled plate or strip

Cold forming Quenching and tempering (entire pipe)

Q

NOTE 1: The finishing temperature shall be great er than 780 °C. Pipe finished at a lo wer temperature than 780°C shall be subjected to a further normalising heat treatment.


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8.3 STARTING MATERIALS

8.3.5 Add new clause:

The abutting edges of strip or pl ate to be HF W welded shall be milled or machined. Rotary shearing shall not be considered as machining.

8.4 TACK WELDS

8.4.2 Add the following:

Tack welds shall be made using a continuous single pass unless otherwise agreed with the Principal.

8.5 WELD SEAMS IN COW PIPE

Delete this clause.

8.6 WELD SEAMS IN SAW PIPE

Add the following:

The seam welding of HSAW pipe shall be carried out as a separate process f rom the forming operation (i.e. the welding speed shall be independent of the forming speed)

8.8.1 PSL 1 EW Pipe

Delete this clause

8.8.2 PSL 2 HFW Pipe

Add:

See also Table 3 for acceptable heat treatment routes.

8.9 COLD SIZING AND COLD EXPANSION

8.9.2 Amend this clause as follows:

Cold expansion shall be performed by mechanical means only. The sizing ratio for cold-expanded pipe shall not be less than 0.008 or more than 0.015.

8.10 STRIP/PLATE END WELDS

Replace this clause with the following:

Pipe containing strip end welds shall not be supplied, except for HSAW pip e of above 762 mm OD (30 inch) where strip end welds may be considered subject to the following:

• strip end welds are not within 2 meters from the pipe end;

• welding procedures and NDT procedures to have specific review and approval by the principal;

• These welds to have at least 2 NDT methods applied e.g. UT and RT. NOTE: The Principal shall have the final decision if strip end welds are permitted for any specific

order/project.

8.11 JOINTERS


Jointers shall not be supplied.


Page 14

8.12 HEAT TREATMENT

Add to this clause:

In addition, the Manufacture shall supply the following information concerning the heat treatment facility for approval by the Purchaser:

• Type of furnace (e.g. Batch, Walking Beam, etc.); • Method of heating and fuel (if applicable); • Number, position of thermocouples and controlled heating zones; • Arrangement of pipes with furnace; • Identification and control of individual pipes throughout the heat treatment cycle.

8.13 TRACEABILITY

8.13.1 Delete this clause.

9 ACCEPTANCE CRITERIA

9.1 GENERAL

9.1.2 Delete existing clause and replace with the following:

Pipe manufactured to a specific grade shall not be substituted for pipe ordered as a lower grade.

9.2 CHEMICAL COMPOSITION


9.2.2 Delete existing clause and replace with the following:

Table J1 shall apply for all pipe gra des and for pipe with t ≤ 35mm (other than for sour service where Table H1 shall ap ply) but shall not include G rades L390N, L415N, L625M, L690M and L830M.

The chemical composition limits of pipe with t > 35 mm shall be by ag reement or a s stated in the purchase order.

The Manufacturer/Supplier’s target product analysis shall be sh own in the Manufacturing Procedure Specification. A single value target of CEiiw or CEpcm shall be stated. The range of elements shall be such that the vari ation in th e single value target CEiiw does not exceed ± 0.03 units or CEpcm does not exceed ± 0.02 units with the following additional restrictions:

C 0.03 (HFW and SAW) 0.04 (SMLS)

Mn 0.30 Si 0.25 Ni 0.10 Cu 0.10 V 0.03 Nb 0.02 Al 0.03 Ti 0.015 Mo 0.05 Cr 0.05

NOTE The above figures represent the total range and not a plus or minus tolerance.


Page 15

No changes in the chemical composition (within the tolerances listed above) are permitted from the approved MPS composition. In particular no intentionally added elements shall be increased (beyond the limits above) or removed.

The chemical composition recorded for the pipes used in first-day production testing shall set the datum CE. Whe re any of th e above elements is not intentionally added, the manufacturer may propose maximum values for approval by the Principal. In this case the above ranges shall not apply.

The chemical analysis and reporting in inspection documents shall include all elements covered by the requirements of Table J1.


Table 4

Delete this table.

Table 5

Delete this Table.

9.3 TENSILE PROPERTIES


Table 6

Delete this table.

Table 7

Delete reference to grades L390N, L415N, L625M, L690M and L830M

9.4 HYDROSTATIC TEST


9.6 FLATTENING TEST


No cracks or breaks shall occur in either weld or parent metal during flattening of the test specimen to 50% of the ori ginal OD. The specimen shall be further flattened to 1/3 of original OD without cracks or breaks other than in the weld.

9.8 CVN IMPACT TEST FOR PSL2 PIPE

9.8.2.1 Delete the existing clause and replace with the following:

The minimum average (of a set of three test pie ces) absorbed energy for each pipe body test shall be as given in Table 8, based upon full-size test pieces. The test temperature shall be lower than or equal to that specified in the table below.

Nominal wall thickness, t (mm)

Test Temperature (°C)

Maximum test temperature(°C)

t ≤ 20 Tmin 0

20 < t ≤ 30 Tmin-10 0

30 < t ≤ 40 Tmin-20 0

40 < t To be advised by the Principal

Tmin is the minimum design temperature, which shall be specified in the purchase order. If no minimum design temperature is indicated, it shall be taken as 0°C.

9.8.2.2 Delete this clause


Page 16

9.8.3 Pipe weld and HAZ tests


The absorbed energy requirements for weld and HAZ tests SHALL [PS] be as stated in Table 8.

If any spe cimen displays a value l ess than 6 0% of the value i n table 8 (or a greater value if specified in the specific project requirements), the Ma nufacturer shall fully investigate the cause and advise the Principal. For any value discplayed of less than the value in table 8 (or a greater value for a specific project), 3 further specimens shall be taken in the same area. All 3 specimens shall comply with the minimum value.

No more than 1 specimen with a value less than permitted in table 8 (or hig her figure if specified) shall occur fo r any 5 spe cimen tested, or no more than 2 value s less than permitted in table 8 (or higher figure if specified) in each 9 specimen tested.

For pipelines in rich gas service or CO 2 and pipelines subjected to hi gh strain, the values in table 8 m ay be increased on a project by project basis, this will be stated in project specifications when applicable.

The test temperature shall be as specified for the pipe body.

Table 8

Delete existing table and replace with the following:

Table 8 – CVN absorbed energy requirements for PSL2 pipe

Grade Full-size CVN absorbed energy

Minimum average value (of the set)

J

Pipe body, Weld and HAZ

L245 (B) 40

L290 (X42) 40

L320 (X46) 40

L360 (X52 40

L390 (X56) 40

L415 (X60) 42

L450 (X65) 45

L485 (X70) 48

L555 (X80) 55

9.9 DWT TEST FOR PSL2 WELDED PIPE

9.9.1 Delete this clause and replace with the following

For each test (a set of two test piece s), the average shear fracture shall be ≥ 85%. The test shall be performed at the minimum design temperature specified by the Principal in


Page 17

the purchase order. Where it is not possible to test a full thickn ess specimen, the test temperature shall be adjusted in accordance with API RP3.


Page 18

9.10 SURFACE CONDITIONS, IMPERFECTIONS AND DEFECTS

9.10.5.2 Delete this clause and replace with the following

For dents, the length in any direction shall not exceed 25% of the pipe diameter.

All sharp gouges (with or without dent) of 1mm or greater depth shall be considered a defect.

9.10.5.3 Add new clause

Surface condition – seamless pipe

The external surface of all seamless pipes shall be free from scabs, laps, shells, slivers, burrs, metallurgical tears and sharp e dged discontinuities that may interfere with the application of thin film (e.g. FBE) coatings and multi-layer coatings where FBE forms the first layer.

Prior to ma nufacturing procedure qualification, the man ufacturer shall submit, for approval by the Principal, acceptance criteria for the surface condition of all seamless pipe, together with historic evidence of the successful FBE coating of such pipe without excessive remedial work.

In the absence of such historic data, the Principal may require the blast cleaning and examination of three pipes during manufacturing procedure qualification and one pipe per 10 test units during production.

The pipes shall be selected at random and heated to a minimum of 70°C. Th e outside surface shall be blast cleaned to a surface finish of SA2½ and the pipe then re-heated to 270°C. Each pipe shall be examined visually over its entire surface for imperfections: that could interfere with the FBE coating process.

If this pipe(s) is rejected then the remaining pipes from the test unit, and one pipe from each subsequent test unit, shall be blast cleaned and examined.

9.11 DIMENSIONS, MASS AND TOLERANCES

9.11.3.1 Add to this clause:

Where stated in the proj ect specification or purchase order the diameter a nd out of roundness tolerances of Annex J Table J3 as amended by this DEP, shall also apply to pipe ordered for onshore service.

Table 10 Modify as follows:

For all pipe with specified outside diameter greater than 60.3 mm but with a D/t of less than 75, the pipe end out-of-roundness tolerance shall not exceed 0.0075D or 5 mm, whichever is the less. This tolerance shall apply to the inside diameter. The pipe end out=of roundness tolerances for pipe of D't >75 shall be agreed with the Principal.

Delete footnote "c" of Table 10 and replace with:

For pipe with D ≥ 219.1 mm, the diameter tolerance and out-of-roundness shall be determined using the measured inside diameter.


Page 19

9.11.3.2 Delete this clause and replace with the following

The tolerances for wall thickness shall be as given in Table J4.

Table 12


Table 12 – Tolerance for random length pipe

Random length

designation

m

Minimum length

m

Minimum average length for each

order item

m

Maximum length

m

12 9 11.5 13.70

15 12 14.25 16.70

18 15 17.0 19.80

9.11.3.4 Delete this clause and replace with the following:

a) The total deviation from a straight line, over the entire pipe length, shall be ≤ 0.15% of the pipe length, as shown in Figure 1.

b) The local deviation from a straight line at each end of 1m section shall be ≤ 3.0 mm as shown in Figure 2.

9.12 FINISH OF PIPE ENDS


9.12.2 Threaded ends (PSL1 only)

Delete this clause

9.12.3 Belled ends (PSL1 only)

Delete this clause

9.13 TOLERANCES FOR THE WELD SEAM

9.13.1 Radial offset of strip/plate edges

Delete Table 14 and replace with the following:

Specified wall thickness, T mm

Maximum radial offset mm

T ≤ 10 1.0

10 < T ≤ 20 0.1 T

T > 20 2.0

9.13.2.2 Selection Item e)

The outside weld bead shall be removed by grinding for a distance of at least 150mm from where stated for all pipe ordered for o ffshore service or where st ated on the Purcha se Order. Note: Removal of the outside w eld bead is required wherever AUT is intended to be p erformed on girt h

welds during pipeline installation


Page 20

9.14 TOLERANCES FOR MASS

9.14.1 Delete items a), b) and c), and replace with the following:

For all pipes: +10.0%, -3.5%

9.14.3 Delete items a) and b), and replace with the following:

For all grades: -1.75%

9.15 WELDABILITY OF PSL2 PIPE

Add to this clause:

For all offshore pipelines and for other pipelines where specified in the purchase order, weldability trials shall be carried out. The material sh all be as qualified in the manufacturing procedure qualification (Annex B) , within the limit s specified in Clause B.5. The requirements for weldability testing are given in Appendix 2 of this DEP.

10 INSPECTION

10.1.2 Inspection documents for PSL1 pipe

Delete this clause

10.2 SPECIFIC INSPECTION

10.2.1 Inspection frequency


Table 17

Delete this table

Table 18

Delete the existing table and replace with the following:


Page 21

Table 18 – Inspection frequency for PSL 2 pipe

Type of inspection Type of pipe Frequency of inspection

Heat analysis All pipe One analysis per heat of steel

Product analysis SMLS, HFW, SAWL, SAWH

Two analyses per heat of steel (taken from separate pipes)

Tensile testing of the pipe body SMLS, HFW, SAWL, SAWH

Two tests per test unit(c) of pipe with the same cold expansion ratio(a). One test for heats less than 100 tonne

Tensile testing of longitudinal or helical weld

HFW, SAWL, SAWH

Two tests per test unit of pipe with the same cold expansion ratio(a),(b). One test for heats less than 100 tonne

CVN impact testing of pipe body

SMLS, HFW, SAWL, SAWH

Two tests per test unit of pipe with the same cold expansion ratio(a). One test for heats less than 100 tonne. For test temperature of -20°C or below one test for each 100 pipes.

CVN impact testing of longitudinal weld

HFW Two tests per test unit of pipe with the same cold expansion ratio(a). One test for heats less than 100 tonne. For test temperature of -15°C or below one test for each 100 pipes.

CVN impact of longitudinal or helical weld

SAWL, SAWH Two tests each for weld, fusion line, FL+2, FL+5 locations per test unit of pipe with the same cold expansion ratio(a),(b). One test for heats less than 100 tonne. For test temperature of -15°C or below one test for each 100 pipes.

DWT testing of the pipe body of welded pipe with D ≥ 406.4 mm Applicable to gas pipelines only.

HFW, SAWL, SAWH

Once per test unit with the same cold expansion ratio

Guided-bend testing of the longitudinal or helical seam weld of welded pipe

SAWL, SAWH Two tests per test unit of pipe with the same cold expansion ratio. One test for heats less than 100 tonne

Flattening test of welded pipe HFW 4 tests per coil, plus 2 tests in the case of a weld stop

Hardness test on body and seam weld


One test per test unit

Hardness testing of hard spots in cold-formed welded pipe

HFW, SAWL, SAWH

Any hard spot

CTOD testing SAWL, SAWH Once; for manufacturing procedure qualification only

Hydrostatic testing SMLS, HFW, SAWL, SAWH

Each pipe

Macrographic testing of the longitudinal or helical seam weld of welded pipe

SAWL, SAWH Once per shift or when pipe thickness is changed


Page 22


Metallographic testing of the longitudinal seam weld of welded pipe

HFW (a) Manufacturing procedure qualification test: Each pipe

(b) Production: Once per five coils.

Grit blasting and visual examination of outer surface (if required by the Principal)

SMLS (a) Manufacturing procedure qualification test: Three pipes

(b) Production TBA

Visual inspection SMLS, HFW, SAWL, SAWH

Each pipe

Pipe diameter and out of roundness


One pipe out of every 20 pipes but not less than once per 4 hour operating shift or whenever any change in pipe size occurs.

Wall thickness measurement SMLS, HFW, SAWL, SAWH

Each pipe (see 10.2.8.5)

Other dimensional SMLS, HFW, SAWL, SAWH

One pipe out of every 20 pipes


Each pipe or each lot, with the choice being at the discretion of the manufacturer

Weighing of pipe with D ≥ 141.3 mm


Each pipe

Non-destructive testing SMLS, HFW, SAWL, SAWH

Each pipe

NOTES: a) The cold-expansion ratio is designated by the manufacture (see clause 8.9.3). An increase or decrease in the cold-expansion ratio of more than 0.002 requires the creation of a new test unit

b) In addition, pipe produced by each welding machine shall be tested at least once per week c) “Test unit” is as defined in 4.49

Table 19

Delete this table

Table 20



Page 23

Table 20 Number, orientation and locations of test pieces per sample for mechanical tests

Number, orientation, and location of test pieces per sample(a)

Specified outside diameter D (mm)

Type of pipe Sample location

Type of test

< 219,1 219,1 to < 406,4

≥ 406.4

Tensile 1L(b) 1T(c) 1T(c) CVN 3T(e) 3T(e) 3T(e)

SMLS, not cold-expanded [see Fig 5 a)]

Pipe body

Hardness 1T 1T 1T

Tensile 1L90(b) 1T180(c) 1T180(c) CVN 3T90 3T90 3T90

Pipe body

DWT — — 2T90 Tensile — 1W 1W CVN 3W 3W 3W

Seam weld

Hardness 1T 1T 1T

HFW [see Figure 5 b)]

Pipe body and weld

Flattening As shown in Figure 6

Tensile 1L90(b) 1T180(c) 1T180(c) CVN 3T90(f) 3T90(f) 3T90(f)

Pipe body

DWT — — 2T90 Tensile — 1W 1W CVN 3W and

9HAZ(g) 3W and 9HAZ(g)

3W and 9HAZ(g)

Guided-bend

2W(d) 2W(d) 2W(d)

SAWL [see Figure 5 b)]

Seam weld

Hardness 1T 1T 1T Tensile 1L(b) 1T(c) 1T(c) CVN 3T 3T 3T

Pipe body

DWT — — 2T Tensile — 1W 1W CVN 3W and

9HAZ 3W and 9HAZ

3W and 9HAZ

Guided-bend

2W(d) 2W(d) 2W(d)

SAWH [see Figure 5 c)]

Seam weld

Hardness 1T 1T 1T NOTES: a) See Figure 5 f or an e xplanation of the symbols used to d esignate orientation and

location. b) Full-section longitudinal test pieces may be used at the option of the manufacturer. c) If agreed, annular test pieces may be used for the determination of transverse yield

strength by the hydraulic ring expansion test in accordance with ASTM A370 d) For pipe with t > 19.0 mm, the test pieces ma y be machined to provide a rectangular

cross-section having a thickness of 18.0 mm. e) TBA for wall thicknesses>25.4 mm f) Additional 3T specimens for wall thicknesses > 25.4 m g) Additional 3W and 9HAZ specimens for wall thicknesses >25.4 mm


Page 24

10.2.2 Samples and test pieces for product analysis


Samples shall be take n, and test pi eces prepared in accordance with ISO 14284 or ASTM E1806. Such samples shall be taken from the pipe.

10.2.3.1 Test pieces for the tensile test

Delete first sentence of the second paragraph and replace with the following:

If agreed, round test pieces obtained from non-flattened samples may be used.

10.2.3.3 Test pieces for the CVN impact test

Delete the third paragraph and replace with the following:

For test pieces taken in the weld of SAW pipes, the axis of the notch shall be located on, or as close as possible to the weld centreline. The specimen axis shall be aligned with the intersection points of the internal and external weld beads (see Figure 7).

Delete the fourth paragraph and replace with the following:

For test pieces taken in the HAZ of SAW pipes, the axis of the notch shall be positioned at the fusion line, fusion line + 2mm and fusion line + 5mm. The upper surface of the specimens shall be within 2mm of the outer surface of the pip e. (See Figure 7). Fo r SAW pipe of wall thickness greater than 25.4mm four a dditional sets of impact specimens, from weld centre line, fusion line, fusion line +2mm and fusion line +5mm, as shown in Figure 7 but with the lower surface of the specimen within 2mm of the inner surface of the pipe.

Add paragraphs

For test pieces taken from seamless pipes the specimens axis shall be aligned with the mid-thickness of the pipe.

The impact testing of se amless pipe with wall thickness equal to or gre ater than 25.4 mm shall be as specified in the Purchase Order.

Flattening of coupons prior to removal of specimens is not permitted.

Figure 7

Delete existing figure and replace with the following:

Fusion Line +5mm

Fusion Line

Fusion Line +2mm Weld Metal Centre Line

<2.0 mm-

Last deposited Weld Metal

Figure 7 Location of Charpy test specimens for weld and HAZ tests


Page 25

Add new clause

10.2.3.8 Test pieces for CTOD test

Test pieces shall be taken from the weld metal, the HAZ and the parent metal and shall be prepared in accordance with ISO 1 2135. Test specimens shall be Bx2B through thickness notched specimens. For weld metal test, the notch axis shall be located on the weld centre line. For HAZ specimens, the notch axis located so as to sample the fusion line. The central 50 % po rtion of th e specimen shall sample the HAZ and the outer portions shall sample weld metal.

Add new clauses:

10.2.4.8 Hardness test

Add the following

For all pipe ordered for non- sour service hardness surveys (Vickers) shall be carried out as d etailed in cl ause J.8.3.2 with the ac ceptance criteria specified in J. 4.3. The frequency of testing shall be a s required for i mpact testing by Ta ble J.7. Th e requirements of Annex H shall apply to all pipe ordered for sour service.

10.2.4.9 CTOD test

CTOD testing shall be performed in accordance with ISO 12135. The test temperature shall be the minimum design temperature as stated in the purchase order.

10.2.5 Macrographic and metallographic tests



For HFW pipe, a metallographic examination of the weld seam SHALL [PS] be carried out at a magnification of at least 200 times. The frequency shall be as given below.

(a) Manufacturing Qualification Test:

One specimen shall be taken from each qualification pipe

The manufacturer shall record the following information:

• Width of heat treated zone (unless full body heat treatment carried out);

• Grain size and microstructure of heat treated weld area;

• Deformation angle (i.e. the angle by which the material adjacent to the weld is displaced from the horizontal) or other means of assessment of deformation during welding, as agreed with Principal. (See Figure 10.2.5.3).

The manufacturer shall produce acceptance criteria for approval by the Principal, based on the results of the manufacturing qualification test. These shall be applied in production and shall d emonstrate that the entire weld he at affected zon e has been heat treated over the full wall thickness and is f ree of defects. This shall include assessment of the grain size, and general microstructure. Unless agreed otherwise with the Princi pal, metallographic examination shall also in clude an assessment of the level of deformation achieved during the welding operation (e.g. deformation angle)

(b) Production

Metallographic examination shall be carried out at a frequency of one per five coils according to the criteria agreed with the Principal. All measurements made against these criteria shall be recorded.


Page 26

Figure 10.2.5.3 Deformation angle – HFW pipe

10.2.6.1 Modify this clause:

Test pressures for welded pipe with D less than or equal to 101.6 mm (4 inch) shall be held for not less than 5 seconds. Test pressures for pi pe with D >100.6 mm (4 in ch) shall be held for not less than 10 seconds.




The test pressure for all types and sizes of pipe shall b e such that the h oop stress, calculated on the basis of the minimum specified wall thickness and including stresses from the end loading, is at least 95% of the specified minimum yield strength.

Table 24

Delete this table

Table 25

Delete this table

Table 26

Delete this table


10.2.7 Visual Inspection

10.2.7.1 Amend this clause as follows:

For HFW and SAW pipe s, the inspe ction shall specifically include the inte rnal weld profile. The entire inte rnal surface of SAW pipes of outside diameter greater than 610 mm (24") shall be visually inspected.

10.2.8 Dimensional testing

10.2.8.1 Delete existing clause and replace with the following:

The diameter of the first 10 pipes shall be measured. Thereafter the diameter shall be measured once every 20 pipes but not less than once per 4 hour shift. Unless a specific method is specified in the purchase order, diameter measurements shall be made with a circumferential tape, ring gauge, snap gauge, calliper or optical measuring device.


Page 27

10.2.8..2 Delete existing clause and replace with the following:

The out of ro undness of the first 10 pipes shall be measured. Thereafter the diameter shall be measured once every 20 pipes but not less than once per 4 hour shift. The out of roundness shall be determined as the difference between the largest inside diameter and the smallest inside diameter, as measured in the same cross-sectional plane.

10.2.8.3 Delete this clause.

11 MARKING

11.1 GENERAL


11.2 PIPE MARKINGS

11.2.1 i) Add:

Each pipe shall be uniquely indentified.

11.2.3 Add new item:

d) Die stampings shall be coated with a clear lacquer to prevent corrosion at the location of the markings.

11.3 COUPLING MARKINGS

Delete this clause

12.2 THREAD PROTECTORS

Delete this clause

14 PIPE LOADING

Add:

If required by the Purchase Order, each end of each length of pipe shall be provided with a suitable end protector designed to prevent damage to the machined end. End protector shall not be attache d to the pipe using tape or other connectors. The design shall be submitted to the Princip al and shall b e conducive for u sing crane hooks for lifting. Principal will provide end protector requirements.


Page 28

ANNEX A SPECIFICATION FOR WELDED JOINTERS

Delete this Annex.

ANNEX B MANUFACTURING PROCEDURE QUALIFICATION FOR PSL2 PIPE

B.1 INTRODUCTION

Delete all three sub-clauses and replace with the following:

Manufacturing procedure qualification SHALL [PS] be required for all PSL2 p ipe unless otherwise stated by the Principal. Qualification shall be carried out on each combination of diameter and wall thickness supplied unless otherwise agreed with the Principal.

The qualified manufacturing procedure shall form the ba sis for pipe acceptance. Deviation from the qualified manufacturing procedure shall require full re-qualification in accordance with the requirements of B.5.

The Manufacturer shall i nform the P rincipal within 48 hou rs of any intentional or unintentional manufacturing deviations from the agreed procedures, dimensional tolerances or composition. Informing the Principal of these changes is essential to pipeline construction planning. The M anufacturer shall com municate these changes even if the finished line pipe meets the requirements of this DEP and ISO 3183:2007.

B.2 ADDITIONAL INFORMATION TO BE SUPPLIED BY THE PURCHASER

Delete list items a) and b)

B.3 CHARACTERISTICS OF THE MANUFACTURING PROCEDURE

Add the following to list item a):

Quality plan detailing all i nspection points and te sts performed in accord ance with ISO 10005 using an agreed format. NOTE: Guidance on quality plans is given in DEP 82.00.10.10-Gen.

Amend list item b) 1) as follows:

Strip/plate manufacturing method including details of rolling conditions, accelerated cooling conditions (if applied) and heat treatment method (N or Q) if applicable.

Add the following to list item b) 5):

For HFW pipe, the seam welding procedure shall also include details of the following:

a) methods to be used for heating strip edges and for the control and monitoring of power input in relation to the temperature of the pipe surface and the speed of the pipe;

b) Frequency (in kHz) of the welding power supply;

c) Welding speed

d) Welding Temperature

e) Welding power

f) Compressive force or displacement used in welding.

g) Temperature of in-line normalising (if applied)

h) details of any protective atmosphere used for welding;

i) methods used to accomplish and control the upset welding of the heated pipe edges;

j) Methods used for trimming of the weld bead.


Page 29

For SAW pipe, the seam welding procedure shall also include details of the following:

a) brand name, classification, size and grade of filler metal and flux;

b) speed of welding;

c) number of electrodes and polarity for each electrode;

d) stickout for each wire;

e) welding current for each wire;

f) welding voltage for each wire.

Add new list item d):

d) For sour service pip e, the hydro gen-induced cracking test procedure shall include full details of the exposure test method required by NACE TM0284 and DEP 30.10.02.16-Gen plus full details of the procedure used for metallographic preparation of the exposed test pieces.

B.4 MANUFACTURING PROCEDURE QUALIFICATION TESTS

B.4.1 Add the following to the existing clause:

The following additional test requirements shall apply:

Tensile tests –General

Parent material and all weld metal tensile tests (at ambient and elevated temperature) shall be conducted so as to record the full stress strain curve up to maximum load. This applies to manufacturing procedure qualification testing only.

Elevated temperature tensile tests

Where required in the purchase order, elevated temperature tensile tests shall be taken in both the longitudinal and (for pipes of outside diameter ≥ 219.1mm) the transverse direction. Testing shall be in accordance with EN 10002-5. The testing tem perature and acceptance criteria shall be stated in the purchase order.

All weld tensile tests (SAW only)

All weld tensile tests shall be performed on each of the first-day production test pipes. The tests results shall meet the minimum specified requirements of t he plate with regard to yield, tensile strength and achieve a minimum elongation value of 18%. The test method shall be in accordance with EN 876. Where required in the purchase order, all weld tensile tests shall also be performed at elevated temperature Testing shall be in accordance with EN 10002-5; the test temperature and acceptance criteria shall be stated in the purchase order.

Impact tests

For each of the first-day production pipes, a full impact transition curve shall be determined for all location specified in 10.2.3.3., i.e.

Seamless: Pipe body

HFW: Parent material, weld centre line

SAW: Parent material, weld centre line, fusion line, and fusion line +2mm, fusion line +5mm

At least 12 specimens shall be tested at each position at temperatures range wide enough to obtain upper and lower shelf toughness impact energy values.

CTOD testing (SAW only)


Test pieces shall be taken from both the weld and HAZ and shall be SENB type prepared in accordance with ISO 12135. Weld test specimens shall be through thickness notched, the


Page 30

notch being located at the weld ce ntreline. HAZ specimens shall be surface notched from the outside surface so tha t the fatigue cra ck tip sa mples the HAZ within 0.5 mm of the fusion line. The location of the fatigue crack tip shall be verified by post test sectioning and metallography. Unless ot herwise agreed with th e Principal, through thi ckness notched specimens shall be Bx2B and surface notched specimens BxB.

The minimum CTOD value (from a set of three specimens) taken from each of the pipe, weld and HAZ locations, shall be 0.2 mm, when tested at the minimum design temperature given in the purchase order.

Strain aged testing.

Where required by the p urchase order, tensile charpy impact, fracture toug hness testing and hardness testing shall be carried out in the strain aged condition.

The requirements for testing in the strain aged condition are contained in Appendix 1 of this DEP

Drop Weight Tear tests

In addition to the normal DWTT requirements, a full transition curve shall be established for the parent material on each of the test pipes.

Radiography

The weld seams of all SAW pipes shall be radiographically examined throughout their ful l length in accordance with (D5.5)

PT or MT

The weld seam shall be subjected to liquid penetrant or magnetic particle testing in order to check for surface defects in the weld and adjacent HAZ.

B.4.2 Delete existing clause and replace with the following:

Unless stated otherwise in the p urchase order, the ma nufacturing procedure shall be qualified by t he first-day production tests. This shall be achieved by selecting at random three of the completely finished pipes of the first day’s production. If more than one heat is used in the first-day pro duction pipes, at least two heats shall be represented by the test pipes.

For HFW pipe, the test pipes shall include the pipes made from each end of the first coil of strip.

For orders less than 200 tonne, acceptable data from a previous order for a Shell Gro up company may be acce pted by the Princip al provided the pipe gra de, size an d manufacturing method are similar.

If stated in the purchase order, part or all of the manufacturing procedure qualification shall be carried out prior to first day production.

Add new clauses:

B.5 REQUALIFICATION OF MANUFACTURING PROCEDURE

The following changes to the manufacturing procedure shall require full requalification of the manufacturing procedure:

a) Any change to the steel chemistry which produces a change in the CE of more than +0.03 (see (9.2.2));

b) Any change to the steel de-oxidation practice;

c) A change from ingot casting to continuous casting or vice versa;

d) Any change to the plate or pipe reduction ratio;

e) A change in the finishing temperature during plate or strip rolling outside the approved range;


Page 31

f) A change in the accelerated cooling start temperature outside the approved range;

g) A change in the finishing temperature outside the approved range, for pipe not subject to further heat treatment;

h) A change in the pipe heat treatment soaking temperature and soaking time;

i) Any change to the welding procedure outside the essential variable limits of ISO 9956-3. In addition for SAW pipe, a change in flux brand name and an increase of more than 20 mm in the wire stick-out.

B.6 HFW – PARAMETER ENVELOPE

In addition to the essential variables stated in clause B.5, the Manufacturer shall submit for approval by the Prin cipal, the maximu m ranges of each of the followin g parameters for each pipe diameter, thickness and material grade:

• Welding speed;

• Welding Temperature ;

• Welding Power;

• Compressive force or displacement.

The Manufacturer shall also provide details, for approval by the Principal, on how the se parameters are to be monitored and recorded.

B7 SURFACE OF SEAMLESS PIPE

The manufacturer shall provide historical evidence that the surface fini sh of previous production was suitable for the application of FBE coatings. In the absence of such data, three pipes from the first day's production shall be selected at random and heated to a minimum of 70°C. The outside surface shall be blast cleaned to a surface finish of SA2.5 and the pipe re-heated to 270°C

Each pipe shall be examined visually over its e ntire surface for scabs, slivers, tears an d similar surface defects which would, i n the opi nion of the Princip al, interfere with the application of FBE and other coatings.

Should the pipe fail to meet the required standard of surface finish, the Manufacturer shall submit procedures for remedial action and subsequent testing of the production material to guarantee suitability of the p roduction material for FBE coating, for a pproval by the Principal

ANNEX C TREATMENT OF SURFACE IMPERFECTIONS AND DEFECTS

C2.2 Add the following to existing clause:

All ground areas shall be smoothly contoured at a minimum 3 to 1 slope

C4.5 Delete existing clause and replace with the following:

Weld repairs shall be performed using a welding procedure that is qualified in accordance with Annex D, by a welder qualified in accordance with Annex D.3.

ANNEX D REPAIR WELDING PROCEDURE

D.1.2.b Delete this clause.

D.2.2.a. Welding process

Delete item 1) and replace with the following

A change in the welding process, such as submerged arc welding to shielded metal arc welding.


Page 32

D.2.2.c. Welding materials

Delete items 4) and 5)

D.2.3.4.4.Delete the existing clause and replace with the following;

The minimum average absorbed energy (of a set of three te st pieces) for each repair weld and its associated HAZ, shall not be less than that specified in 9.8.3 for the pipe seam weld and HAZ. The test temperature shall be the same as that required for the weld metal and HAZ.

D.2.5 CTOD test

Add new clause

The qualification of repaired weld shall be subject to the same CTOD testing as required by the additions to clause B.4.1 given in this DEP. In this case surface notched specimens shall be used to sample the weld metal and both HAZs (repair/parent material and repair weld/original weld).

ANNEX E NON-DESTRUCTIVE INSPECTION FOR OTHER THAN SOUR SERVICE OR OFFSHORE SERVICE

E.1 QUALIFICATION OF PERSONNEL

Add the following to this clause:

ISO 9712 and EN 473 are considered to be eq uivalent qualification/ certification systems. ISO 20807 is not considered as equivalent.

E.1.3 Add the following to this clause:

The Manufacturer/ Supplier shall have a NDT UT level 3 available on call during manufacture. All of the Manufacturer/ Supplier NDT specifications and procedures shall clearly state the approval of the NDT Level 3 showing approval date and qualification number and the expiry date of the NDT Level 3 individual.

E.2 STANDARD PRACTICES FOR INSPECTION

Delete existing clause and replace by the following:

Except as specifically modified in this annex, the required non-destructive inspection, other than for su rface inspection (see 10.2.7) and wall-thickness verification, SHALL [PS] be performed in accordance with one of the following standards or an equivalent:

a) electromagnetic (flux leakage): ISO 9402, ISO 9598;

b) electromagnetic (eddy-current): ISO 9304;

c) ultrasonic: ISO 9303, ISO 9305, ISO 10124, ISO 11496, ISO12094, ISO 13663;

d) ultrasonic (weld seam): ISO 9764, ISO 9765;

e) magnetic particle: ISO 13664, ISO 13665;

f) radiographic: ISO 12096;

g) liquid penetrant ISO 12095.

A procedure shall be written for every technique describing the inspection process, with as a minimum the essential variables as stated in Appendix-4


Page 33

E.3 METHODS OF INSPECTION

E.3.1.1 Delete existing clause and replace with the following:

The weld seams of welded pipe shall be inspected using the ultrasonic angle beam shear wave method in accordance with ISO 9764 for HFW pipe (longitudinal imperfection detection using a 450 +/- 30probe) and ISO 9765 for SAW pipe (Longitudinal and transverse imperfection detection), full length (100 %) for the entire thickness, as given in Table E.1.

Acceptance levels: ISO 9764 L2 and ISO 9765 L2

Inspection procedures including the use of ToFD shall only be used with the acceptance of the Principal. Advanced ultrasonic techniques (e.g. phased array, EMAT) may only be permitted by the approval of the Principal on the basis of a specific qualification program approved by the Principal.


All SMLS pipe shall be n on-destructively inspected full length (1 00 %), as given in Table E.2. Applicable code: ISO 9303 (longitudinal imperfections) and ISO 9305 (transverse imperfections).

E.3.1.3b Delete existing clause and replace with the following:

Welded pipe shall be inspected following hydrostatic test.

Table E.1

Delete existing table and replace with the following: Table E.1 Pipe-weld seam non-destructive inspection

Non-destructive inspection method (a) Weld seam type

Electromagnetic Ultrasonic Radiographic

HFW for t < 6 mm

one method or a combination of methods is required

not applicable

HFW for t > 6 mm

not applicable required not applicable

SAW not applicable required if agreed

NOTE (a): The weld seam at the pipe ends may require additional inspection (see E.3.2).

Table E.2


Table E.2 SMLS pipe body non-destructive inspection Non-destructive inspection method

Item Electro-

magnetic Ultrasonic Magnetic particle (circular field)

PSL 2 pipe, any grade Not required unless stated on Purchase Order

required Not required

unless stated on Purchase Order


Page 34

E.3.2 Pipe end inspection — Welded pipe


Pipe end weld seam: If an automated ultrasonic or electromagnetic inspection system is applied to meet the requirements of E.3.1.1, the weld at any pipe ends that are not covered by the automated inspection system shall be inspected for defects by a ma nual or semi-automatic ultrasonic angle beam method, using the same inspection sensitivity and inspection parameters as specified in E.3.1.1. Alternatively, such non-inspected pipe ends shall be cut off.


For SAW pipe, the weld at each pipe end for a minimum distance of 200 mm (8.0 in) shall be inspected by the radiographic method. The results of such radiographic inspection shall be recorded on either film or another imaging medium (See also E.4). The same area shall be inspected by the ultra sonic method, which sha ll be take n as the p rime inspection method.


Ultrasonic inspection in accordance with the method described in ISO 11496 shall be used to verify that the 25 mm wide zone at each pipe end is free of laminar imperfections of ≥ 6.4 mm in the axial and circumferential directions. The ultrasonic inspection may be undertaken from the outside surface if the pi pe end is inspected before weld beveling, if this i s undertaken after weld beveling inspection shall be from the pipe internal surface.

Add new clause:

E.3.2.4 SAW Pipe end circumference:

Ultrasonic inspection using 45° angle beam shear wave p robes and scanning in two circumferential directions shall be used to verify that the 25 mm wide zone at each pipe end is free of axi ally aligned through thickness cracking. An axially aligne d N5 notch is the reference and acceptance level.

E.3.3 PIPE END INSPECTION — SMLS PIPE


E.3.3.1 Pipe end – not te sted portion: If an aut omated ultrasonic or system (combined equipment, operating procedures and personnel) is applied to meet the re quirements of E.3.1.2, the end of the pipe that is not covered by the automated inspection system shall be inspected for defects by the semi-automatic ultrasonic angle beam method using the same inspection sensitivity and insp ection parameters as spe cified in E.3.1.2. Otherwise such non-inspected pipe ends shall be cut off.


Ultrasonic inspection in accordance with the method described in ISO 11496 shall be used to verify that the 25 mm wide zone at each pipe end is free of la minar imperfections ≥ 6.4 mm in both axial and circumferential direction. The examination shall be carried out from the inside surface if the pipe is examined after weld bevel cutting. If examination is befo re bevel cutting, the examination may be undertaken from the outside surface.

E.4 RADIOGRAPHIC INSPECTION OF WELD SEAMS


The radiographic films used sh all be i n accordance with ISO 11699-1:1998, class T2 or class T3, and shall be used with lead screens.


The density of the radiograph shall be between 2.0 and 3.5 in the weld metal.


Page 35

E.4.3 IMAGE QUALITY INDICATORS (IQIS)


ISO wire-type IQIs shall be equal to W 1 FE, W 6 FE o r W 1 0 FE, in a ccordance with ISO 19232-1:2004, and the essential wire diamete rs shall be as given in Table E.3 for the applicable weld thickness.

E.4.3.3 Delete this clause.

Table E.4

Delete Table E.4

E.4.6 DEFECTS FOUND BY RADIOGRAPHIC INSPECTION

Add to existing clause:

Where retesting of suspect areas indicated by UT is perfo rmed with RT, and found to be free of indications, the area shall be subjected to further UT. If the indication is co nfirmed with the repeat UT a nd is not caused by geometrical features or acoustic coupling conditions, then the UT indication shall be classed as a crack and the material rejected.

Add new clause:

E.4.8 Use of Filmless Radiography or Digital Radiography

The radiographic inspection of the body weld se am and the weld sea m at the pipe en ds may be replaced by automatic filmless radiography or Digital Radiography provided that the standard of the automatic filmless radiography is at least equal to the requirements for film radiography specified in this DEP.

The final disposition for suspect areas shall always be made using UT (see clauses E.4.6 and E.5.5.2).

E.5 ULTRASONIC AND ELECTROMAGNETIC INSPECTION

E.5.1.1 Add to existing clause:

Automatic ultrasonic equipment (AUT) SHALL [PS] be used for weld seam and pipe body inspection for detection and sizing of indications. The equipment shall have automatic facilities with the following characteristics:

• registration/ recording of indications on paper and/or on a retrievable medium shall be carried out without any intervention of the ultrasonic operator;

• a device which monitors the effectiveness of the acoustic coupling - a deviation in excess of 10 dB from the good coupling situation indicates a loss of coupling. Loss of coupling shall be recorded and clear automatic acoustic warnings and automatic paint spray shall be activated.

All systems shall be equipped with ruggedised (firm and stable) scanning systems:

For welded pipe, an automated weld tracking system for correct positioning of the probes with respect to the weld centerline shall be used.

The AUT system is considered to be acceptable when the fluctuation of the reference signal between the eight test runs is less than 3-4 dB (+/- 25% of the average value).


Page 36

Acceptance limits for calibration

Manual ultrasonic inspection (MUT) shall only be used to verify the indi cations rejected by AUT and confirm rejection or acceptance, also to inspect areas not inspected by AUT.

E.5.1.2 Performance test of AUT for mill qualification

The performance test shall be carried out during the qualification of the mill to test the AUT system with the pipes as listed below:

• For the wall thickness category >11.9 mm to be qualified

One test pipe in the highest wall thickness category to be qualified

• For the wall thickness category < 11.9 mm to be qualified.

One test pipe with the lowest wall thickness and diameter to be qualified.

The test pipes shall contain the reference reflectors of chapter 7 and two notches or through drilled holes at both pipe ends to mark the border of zones that are not covered by AUT.

The stability tests shall be carried out under the following conditions;

• The reference signals shall be set on 80% screen height (+/- 5%) to be able to see fluctuations in the signal;

• A signal to noise ratio of the reference signals of at least 10dB (to 12 dB, 4x the noise level).

A total of 8 test runs for each test pipe shall be made to confirm the stability of the AUT system. The following listed items shall be reported:

o diameter and wall thickness of the test pipe(s);

o specification of used probes (angles and frequencies);

o drawing of the reference reflectors in the test pipe (above view and cross section);


Page 37

o layout of the probes in combination with the reading channels ;

o printout (paper or digital) of the screen from the individual scans and reference signals marked on the first scan;

o Actual values of the reference signals;

o Actual values of the signal to noise ratio.

The AUT system is considered to be acceptable when the fluctuation of the reference signal between eight test runs is less than 4 dB.

E.5.2 ULTRASONIC AND ELECTROMAGNETIC INSPECTION REFERENCE STANDARDS

Table E.7


Table E.7 — Reference indicators

Reference indicators (a)

Notch location Notch orientation Notch dimensions

Diameter of radially drilled

hole (b)

OD ID Longitudinal Transverse Depth (c) Length (d) Width

Item

% (max) mm

(max) mm mm

HFW seam

Table E.7.1 applies Required Not

Required 5,0 (e) 50 1,0 1,6 (e)

SAW seam

Table E.7.2 applies Required Required 5,0 (e) 50 1,0 3.2 (e)

SMLS pipe

Table E.7.3 applies Required Required 5,0 50 1,0 3.2

NOTES: 1. Notches are rectangular or U-shaped. 2. For electromagnetic inspection, the reference standard shall cont ain OD notches, ID notches and a ra dially

drilled hole. (See E.5.3.4.)

NOTES a) It is not necessary to locate reference indicators in the weld (ferritic, fine grained weld). b) Drilled hole diameters are based upon standard drill-bit sizes.

A hole is not required if a notch is used to establish the reject threshold. c) Depth is expressed as a percentage of the specified wall thickness. It is not necessary for the depth to be less

than 0.3 mm (0.012 in). The depth tolerance is ± 15 % of the specified notch depth or ± 0.05 mm (0.002 in), whichever is greater.

d) Length at full depth. e) Table 7.1 and Table 7.2 apply (see Table 7.Table E.8 for applicable acceptance limits).

E.5.1.2 Weld repair

Add to this clause: Repair of HF W pipe weld seams by g rinding and rewelding is not permitted. Surface repair of extern al and internal HFW weld seam by dressing only by grinding is permitted and if applied, wall thickness is required to be checked after grinding.


Page 38

Add new table:

Table E.7.1 HFW - Number of Probes for zone of weld for different wall thickness/ reference reflector

Number of probes for zone of weld/ type of reference reflector

(at both sides of the longitudinal weld)

Wall thickness range inner zone Embedded outer zone

≤ 11.9 mm one Not required One

12.0 mm to 17.9 mm one

One pair in tandem, centered at mid-wall thickness. (1)

One

18.0 mm to 23.9 mm one Two pairs in tandem, centred at

40 % and 60 % of thickness(1) One

mode of operation pulse echo in tandem (2) pulse echo

Reference reflector

N5 notch/ longitudinal 3.0 mm flat-bottom hole(2) N5 notch/

longitudinal

NOTES: 1. The use of a direct irradiation method (pulse echo) is allowed provided the main axis of the ultrasonic beam hits the corresponding reference reflector perpendicular within ± 30

2. The flat-bottomed hole shall be located at the mid-thickness of the weld and be p erpendicular to the fusion line of the weld.


Page 39

Add new tables

Table E.7.2a SAW - Number of probes for zone of weld for different wall thickness/ reference reflector

Longitudinal imperfection detection Number of probes for zone of weld / type of reference reflector

(at both sides of the longitudinal weld)

Wall thickness range inner zone Embedded outer zone

≤ 11.9 mm One not required One

12.0 mm to 17.9 mm One

One, centred at mid-wall position See Fig E1 (a) and (b) for typical

configuration One

18.0 mm to 23.9 mm One Two centred at 40% and 60% of

thickness. See Figures A and B One


Three, centred at 30%, 50% and 70% of thickness. See Figure E1 (a)

and (b) for typical configuration One


Four, centred at 25%, 42%, 58% and 75% of thickness. See Figure E1 (a)

and (b) for typical configuration One

mode of operation (pulse echo) See note (1); pulse-echo or tandem pulse echo

reference reflector

Radially Drilled Hole

3.2 mm equals 0 dB

Acceptance shall be at

–10 dB

3.0 mm flat-bottom hole (FBH) located at the original weld bevel

position at a depth (through thickness) related to the zone to be

inspected. For example of the location of the reference reflector

and transducer set-up, see Figures A and B

Radially Drilled Hole 3.2 mm equals 0 dB

Acceptance shall be at –10 dB

See Note (5)

NOTES: 1. The angle of the probes for embedded zones shall be perpendicular to the original weld bevel ±3°. If the weld bevel is less than 15° (half aperture) the probes shall be used in the tandem arrangement.

2. for longitudinal imperfection detection: transducer angle between 50° and 70° 3. notch type reflectors (N5) at the toes of the weld (ID and OD) may be used to verify start and end of

monitoring gates, not to adjust sensitivity settings. The echo of notch type reflectors shall exceed the recording threshold level. If not the reference sensitivity level shall be adjusted to above 100% FSH. The reject level remains the original 33 % FSH.

4. Alternative numbers and configurations of probes may be used, subject to demonstration of reliable responses from the reference indicators for each zone and the approval of the Principal

5. A 1.6mm diameter radially drill hole may also be used. In this case the acceptance level shall be 0 dB (100% of reference level)

6. Crack like indications is not permitted in the centre of any weld bead (weld pass -particularly for SAW welding)). The gate setting for the weld bevel inspection shall include the weld pass centre line.


Page 40

Table 7.2b SAW

Transverse imperfection detection / type of reference reflector

With X or K-transmission: probe angles between 50° and 70°

• for thickness up to 12 mm, one set of probes;

• for thickness in excess of 12 mm, two sets of probes one aimed at the inner surface and one at the outer surface.

Reference reflectors - transverse notches N 5 ID and OD

Alternatively “on bead scanning may be applied with a tandem set of transducers. In this case the probe angle shall be 45° ± 3°.

Reference reflectors - transverse notches N 5 ID and OD

Add new figures:

Figure E1(a) Example of transducer set-up and FBH location at 30% and 70% of wall

thickness for one side of the weld

Figure E1(b) Example of tandem transducer set-up and FBH location at 50% of the pipe wall

thickness for one side of the weld (tandem required if the (half) bevel angle is less than 15°)


Page 41

Add new table:

Table E.7.3 SMLS Ultrasonic examination of seamless pipe: probes and reference reflector

Probe angles Probe angle in steel shall be 45° ± 3° (defined in steel at outer surface) See Note 1

Viewing direction Four, opposite directions (Up- and Downstream, Clock- and Counter clockwise)

Coverage Full coverage shall be achieved at the examination sensitivity over the whole volume at all scanning speeds

Longitudinal imperfection detection using N5 notches ID and OD Reference reflectors

Transverse imperfection detection using N5 notches ID and OD

Alternative option

Obliquely oriented imperfections

The longitudinal and transverse imperfection detection systems may be replaced by imperfection detection systems oriented parallel and perpendicular to the helix line along the manufacturing rolling is carried out

The N5 ID and OD notches shall be oriented accordingly

NOTE 1. Other probe angles may be ap proved by the Principal based o n the demonstra tion of repeatable detection of reference indicators on the calibration pipe

E.5.5 ACCEPTANCE LIMITS

E.5.5.2 Add new item to this clause:

d) Where retesting of suspect areas indicated by UT is performed with RT, and found to be free of in dications, the area shall be subjected to further UT. If the indica tion is confirmed with the repeat UT and is not caused by geometrical features or acoustic coupling conditions, then the UT indi cation shall be classed as a crack and the material rejected.


Page 42

Table E.8


Table E.8 Acceptance limit

Notch type

Side drilled hole size

Flat bottom hole size

Acceptance limit(a)

Item Diameter

mm Diameter mm (maximum) %

N5 3.0 100 SAW,

3,2(b) 33 (-10 dB)

HFW N5 3.0 100

SMLS pipe N5 100

NOTES: a) Expressed as a percentage of the indication produced by the reference indicator. The reject thr eshold (see E.5.3) shall not exceed the applicable acceptance limit.

b) A side drilled hole of 1.6 mm may also be used. In this case the acceptance limit shall be 100 % (0 dB)

E.7 RESIDUAL MAGNETISM

E.7.4 Delete existing clause and replace with the following

Measurements shall be made on each end of a pi pe, selected at least three times per 4 h per operating shift.

E.7.6 Delete existing clause and replace with the following

Four readings shall be taken approximately 90° apart around the circumference of each end of the pi pe. The average of the four re adings shall be ≤ 2.0 mT (20 Gs), with no one reading shall be greater than 2.5 mT (25 Gs).

E.8 LAMINAR IMPERFECTIONS IN THE PIPE BODY OF HFW AND SAW PIPES

E.8.1 Delete existing clause and replace with the following:

For HFW pipe, ultrasonic inspection shall be use d to verify that the pipe bod y is free of laminar imperfections. Inspection shall be performed in accordance with:

a) ISO 12094:1994, if such inspection is done prior to pipe forming; or

b) ISO 10124:1994, if such inspection is done after seam welding.

Acceptance criteria shall be in accordance with Table K.1 of this DEP. The coverage of inspection shall be at least 50% of the total strip/plate or pipe body.

E.8.2 Delete existing clause and replace with the following:

For SAW pipe, ultrasonic inspection shall be used to verify that the st rip/plate or the pipe body is free of l aminar imperfections. Inspection shall be in accordance with ISO 12094:1994. Coverage of the inspection shall be at least 50% of the total plate/pipe.

Acceptance criteria shall be in accordance with Table K.1 of this DEP.

E.9 LAMINAR IMPERFECTIONS ALONG THE STRIP/PLATE EDGES OR PIPE WELD SEAM OF HFW AND SAW PIPES



Page 43

For HFW and SAW pipes, ultrasonic inspection shall be used to verify that the 25 mm wide zone along each of the strip/plate edges or along each side of the pipe weld seam is free of laminar imperfections. Acceptance criteria shall be as follows:

a) ISO 12094:1994, acceptance level E2, if such inspection is done prior to pipe forming; or

b) ISO 13663:1995, acceptance level E2, if such inspection is done after seam welding.

Add new clause:

E.11 LAMINAR IMPERFECTIONS IN THE PIPE BODY OF SMLS PIPES

For SMLS pipe, ultrasonic inspection shall be used to verify that the pipe body is free of laminar imperfections greater than those permitted by ISO 10124, acceptance level B2. The coverage shall be sufficient to detect the minimum defect size as specified in ISO 10124, level B2.

Add new clause:

E.12 THICKNESS MEASUREMENTS FOR SMLS PIPES

For SMLS pipe, ultraso nic thickness measurements shall be carried out. Coverage shall be at least 25% of pipe surface.

ANNEX F REQUIREMENTS FOR COUPLINGS (PSL 1 ONLY)

Delete this Annex.

ANNEX G PSL 2 PIPE WITH RESISTANCE TO DUCTILE FRACTURE PROPAGATION

Delete this Annex and replace with the following:

G.1 GENERAL

The Charpy test re quirements given in clause 9.8 are based on crack initiation principles. For rich gas transmission and two phase pipe lines, higher absorbed energy requirements may be specified to avoid the risk of ru nning fractures. In this case, the Battelle Two Curve method will be used to det ermine the required absorbed energy. The calculation shall be performed by the Purchaser and the requirements included in the purchase order.

When specified, this additional Charpy impact testing shall be performed on the pipe body only and shall be conducted at the minimum design temperature provided in the purchase order. If the required absorbed energy values are obtained at the te st temperature prescribed for fracture initiation, section 9.8.2.1 of this DEP, the additional tests need not be performed.

ANNEX H PSL 2 PIPE ORDERED FOR SOUR SERVICE

H.2 ADDITIONAL INFORMATION TO BE SUPPLIED BY THE PURCHASER

Delete the following items:

Information included in this DEP

b) f) g) h) i) j) k) l)

Information not applicable to this DEP

c), d),


Page 44

H.3 MANUFACTURING

H.3.3.2.4 Amend this clause as follows:

Strip and plate shall be inspected ultrasonically for lamina r imperfections or mechani cal damage in accordance with Annex K, ei ther before or after cutting the strip or plate, or the completed pipe shall be subjected to full-body inspection, including ultrasonic inspection.

H.3.3.2.5 Delete this clause. Strip/plate end welds are not permitted.

Add new clause:

H.3.3.2.6 Unless otherwise specified by the Principal HSAW pipe shall not be used for sour service.

H.4 ACCEPTANCE CRITERIA

H.4.1.1 Modify this clause as follows:

Table H1 shall apply for all pipe grades and for pipe with t ≤ 35mm.

The Manufacturer/Supplier’s target p roduct analysis shall be shown in the Manufacturing Procedure Specification. A single value target CEiiw or CEpcm, shall be stated. The range of elements shall be such that the variat ion in the sin gle value target CE iiw does not exce ed ± 0.03 units or CEpcm does not exceed ± 0.02 units with the following additional restrictions:

C 0.03 (HFW and SAW)0.04 (SMLS)

Mn 0.30

Si 0.25

Ni 0.10

Cu 0.10

V 0.03

Nb 0.02

Al 0.03

Ti 0.015

Mo 0.05

Cr 0.05


No changes in the chemical composition (within the tolerances listed above) a re permitted from the approved WPS composition. In particular no intentionally added elements shall be increased beyond the limits above or removed.

The chemical composition recorded for the pipes used in first-day production testing shall set the datu m CE. Whe re any of the above elements are not intentionally added, the manufacturer may propose maximum values for approval by the Principal. In this case the above ranges shall not apply.

All elements listed in Table H1 shall be reported.

H.4.1.2 Modify this clause as follows.

For pipe with t > 35 mm the chemical composition shall be agreed with the Principal, with the requirements given in Table H.1 being amended as appropriate.

Table H.2

Delete notes a) and c). Intermediate grades shall not be supplied


Page 45

H.4.4 Hardness test

Modify this clause as follows:

The maximum hardness of the pipe body shall not exceed 240HV10 at the inner surface, centerline and outer surface.

Note for specific orders the hardness limits may be reduced from that specified above.

First paragraph: Delete (22 HRC)

Second paragraph: Delete (26 HRC)

H.7 INSPECTION

Table H.3


Table H.3 Inspection frequency


Hardness testing of pipe SMLS, HFW, SAWL, SAWH

Two tests per test unit of pipe with the same cold expansion ratio(a). One test for heats less than 100 tonne

Hardness testing of longitudinal or helical-seam weld of welded pipe

HFW, SAWL, SAWH


Hardness testing of hard spots in welded pipe

HFW, SAWL, SAWH

Each hard spot found on the internal or external surface of the pipe

Non-destructive inspection SMLS, HFW, SAWL, SAWH

In accordance with Annex K

HIC test SMLS, HFW, SAWL, SAWH

One test for each of the first three heats applied; thereafter, one test for each test unit of not more than 10 heats of steel

If required, SSC test SMLS, HFW, SAWL,

One test for each pipe provided for manufacturing procedure qualification

NOTE: a) The cold-expansion ratio is designated by the manufacture (see 8.9.3). An increase or decrease in the cold-expansion ratio of more than 0.002 requires the creation of a new test unit

Table H.4

Delete reference to strip/plate end weld

Delete note c.

H.7.3 Test Methods

H.7.3.1.1 Delete this clause and replace with the following:

HIC/SWC tests shall be carried out and reported in accordance with NACE TM0284 and DEP 30.10.02.16-Gen (Amendments/supplements to NACE TM0284) with the exception that the required testing frequency shall be as specified in Table H3


Page 46

H.7.3.1.4 Delete second sentence and replace with the following:

Photographs of any reportable crack shall be provided with the report.

Add:

For tests on HFW pip e, sections containing the weld sea m shall be metallogra phically examined at magnifications of at least 100X for any evidence of cracking at the weld line in the through-thickness direction. All such indications shall be reported. Indications on the weld line with an aggregate length greater than 0.5mm through thickness are unacceptable.

H.7.3.2.1 Delete this clause and replace with the following:

Sulfide stress cracking tests are required for manufacturing procedure qualification of each pipe thickness. For welded pipe three specimens shall be ta ken transverse to the wel d Testing shall be carried out at 90% of the actual yield of the parent material using the 4 point bend method (internal surface in tension) as described in EFC 16, Appe ndix 2. Test solution A, EFC 16 An nex A3, shall be used adjusted to a starting pH of 3.5. 1 bara (pure) H2S shall be used. The distan ce between the inner supports shall be equal to, or greate r than, the width of the weld plus 50 mm (25 mm each side of the weld ). Unless otherwise agreed with the Principal the specimen thickness shall be t or 15 mm, whichever is the less, and the specimen width shall be ≥ 20mm. The applied strain shall be verified by the direct application of strain gauges.

In addition, all SSC test specim ens which meet the acceptance criteria of ISO 3183:2007 are to be evaluated for resi stance to SOHI C in a ccordance with ISO 15156-2, Clause B.4.2.3: Two longitudinal metallographic sections shall be taken from each SSC specimen. No ladder-like HIC featu res or cracks exceeding a length of 0.5 mm in the thro ugh thickness direction are to be permitted.

H.7.3.3.1 Delete first two paragraphs and replace with the following:

Hardness testing shall be performed using the Vickers test in accordance with ISO 6507-1.

Figure H1

Amend note b) as follows:

0.50 mm from fusion line

ANNEX I PIPE ORDERED AS “THROUGH THE FLOWLINE" (TFL) PIPE

Deleted

ANNEX J PSL 2 PIPE ORDERED FOR OFFSHORE SERVICE

J.2 ADDITIONAL INFORMATION TO BE SUPPLIED BY THE PURCHASER

Delete the following List items:

Information included in this DEP

b), e), g), m), n), p)

Information not applicable to this DEP

c), d)

Add:

q) more stringent tolerances on pipe end out-of-roundness and internal diameter.

r) recording pipe end out of roundness and internal diameter for each pipe end


Page 47

J.3 MANUFACTURING

J.3.3.2.4 Amend this clause as follows:

Strip and plate shall be inspected ultrasonically for lamina r imperfections or mechani cal damage in accordance with Annex K, ei ther before or after cutting the strip or plate, or the completed pipe shall be subjected to full-body inspection, including ultrasonic inspection.

J.3.3.2.5 Delete this clause. Strip end welds are not permitted.

J.4 ACCEPTANCE CRITERIA

Table J1 (non sour service) shall apply for all pipe grades and for pipe with t ≤ 35 mm but shall not include Grades L625M, L690M and L830M.

The Manufacturer/Supplier’s target p roduct analysis shall be shown in the Manufacturing Procedure Specification. A single value target of CE iiw or CEpcm shall be stated. The range of elements shall be such that the variation in the single value target CEiiw does not exceed ± 0.03 units or CEpcm does not exceed ± 0.02 units with the following additional restrictions:

C 0.03 (HFW and SAW) 0.04 (SMLS)

Mn 0.30

Si 0.25

Ni 0.10

Cu 0.10

V 0.03

Nb 0.02

Al 0.03

Ti 0.015

Mo 0.05

Cr 0.05


No changes in the chemical composition (within the tolerances listed above) a re permitted from the approved WPS composition. In particular, no intentionally added elements shall be increased beyond the limits above or removed.

The chemical composition recorded for the pipes used in first-day production testing shall set the datum CE. Whe re any of th e above elements is not intentionally added, the manufacturer may propose maximum values for approval by the Principal. In this case the above ranges shall not apply.

All elements listed in Table H1 shall be reported.

J.4.1.2 Modify this clause as follows.

For pipe with t > 35 mm the chemical composition shall be agreed with the Principal, with the requirements given in Table H.1 being amended as appropriate


Page 48

J.6 TOLERANCES FOR DIAMETER, WALL THICKNESS, LENGTH AND STRAIGHTNESS

Table J.2

Delete notes a) and e). Intermediate grades shall not be supplied.

Table J.3

Modify as follows:

The pipe end out-of-roundness for pipe > 610 mm diameter and with D/t < 75 shall be 0.0075D with a maximum of 5 mm. NOTE: Where required by the purchase order, tighter tolerances on pipe end out -of-roundness and internal

diameter may apply to specific items.

Delete Note c) and substitute:

For pipe with D ≥ 219.1 mm, the diameter tolerance and out of roundness shall be determined using the measured inside diameter.

Add new clause:

J.6.5 Surface condition of pipe ends.

The outer surface of the pipe, for a distance of 200 mm from each pipe end, shall be such as to permit the effective use of AUT examination of circumferential joints during pipeline installation. There shall be no pitting in these areas greater than 0.25mm in depth and the surface finish shall be evaluated during the MPS and this shall be the agreed surface finish for all production pipes.

J.7.1 Radial offset of strip/plate edges


The radial offset of strip/plate edges shall be in accordance with section 9.13.1 of this DEP.

J.8 INSPECTION

J.8.1 Specific inspection

Add.

The test unit for mechanical tests shall be fu rther limited to 100 pipes for diameters less than 508 mm and 50 pipes for diameters greater than 508 mm. NOTE: Where required by the purchase order, the pipe e nd out of roundn ess and internal diameter shall be

measured and recorded for each pipe end.

Table J.7

Add note: Where stated in the Purchase Order, higher frequencies of inspection for pipe end internal diameter and out-of roundness may be required.

J.8.2.2 Test pieces for CTOD test

Delete existing clause and replace with the following.

Test pieces shall be taken in accordance with section 10.2.3.8 of this DEP.

Table J.8

Modify this table as follows:

For pipe of D ≥ 219.1 mm longitudinal and transverse pipe body tensile tests are required at the frequency of testing given for transverse pipe body tests (as modified by J8.1, above)

The acceptance criteria for longitudinal pipe body tensile tests shall be as for the transverse tests, as given in Table J2.


Page 49

J.8.3 TEST METHODS

J.8.3.2.1 Delete first two paragraphs and replace with the following:

Hardness testing shall be performed using the Vickers test in accordance with ISO 6507-1.

J.8.3.1 CTOD test



The minimum CTOD value (from a set of three specimens) taken from each of the pipe, weld and HAZ locations, shall be 0.2 mm, when tested at the minimum design temperature given in the purchase order.

Figure J1

Amend note b) as follows:

0.50 mm from fusion line

ANNEX K NON-DESTRUCTIVE INSPECTION PIPE ORDERED FOR SOUR AND/OR OFFSHORE SERVICE

K.2 GENERAL NON-DESTRUCTIVE INSPECTION REQUIREMENTS AND ACCEPTANCE CRITERIA

K.2.1.2 For pipe with t ≥ W 5.0 mm (0.197 in), ultrasonic inspection in accordance with ISO 11496 shall be used to verify that the 100 mm (4.0 in) wide zone at each pipe end is free of such laminar defects. This ca n be undertaken from the outside surface if the pipe end is in spected before weld beveling, if ins pection is after weld beveling this sh all be undertaken from the pipe internal surface.

K.2.1.3 Delete this clause.

K.2.1.4 Amend this clause as follows:

Unless specifically agreed otherwise by the Principal on a project by project basis, the end face/bevel at each pipe end shall be magnetic particle inspected for the detection of laminar imperfections in accordance with ISO 13664.

Laminar imperfections > 6.25 mm in the circumferential direction shall be classified as defects.

K.2.2.4 Delete existing clause and replace with the following:

Where dressing is carried out, complete removal of defects shall be verified by local visual inspection and by an appropriate NDT method. Imperfections should have been completely removed, and that the remaining wall thickness is within the specified tolerances.

K.3 NON-DESTRUCTIVE INSPECTION OF SMLS PIPE

K.3.1 Ultrasonic inspection for longitudinal imperfections


K.3.1 Ultrasonic inspection for longitudinal and transverse imperfections

All SMLS pi pe shall be non-destructively inspected full l ength (100 %), as given in Table E.2. Applicable code: ISO 9303 (longitudinal imperfections) and ISO 9305 (transverse imperfections), with the acceptance limits being in accordance with Table E.8 of this DEP.


Page 50

K.3.2 Laminar imperfections in the pipe body


For sour service, individual laminations and/or lamination densities exceeding the acceptance limits for sour service given in Table K.1 shall be classified as defects. Compliance with such requirements shall be verified by ultrasonic inspection in accordance with ISO 10124:1994 (except 4.2).

The coverage during automatic inspection shall be 100% of the pipe surface


For offshore service, individual laminations and/or lamination densities exceeding the acceptance limits for offsh ore service given in Table K.1 shall b e classified as defects. If agreed, compliance with such requirements shall be verified b y ultrasonic inspection in accordance with ISO 10124:1994 (except 4.2. The coverage d uring automatic inspection shall be ≥ 50 % of the pipe surface).

K.3.4 SUPPLEMENTARY NON-DESTRUCTIVE INSPECTION OF SMLS PIPE

K.3.4.1 Amend this clause as follows:

SMLS pipe shall be ultrasonically inspected for the detection of transverse imperfections in accordance with ISO 9305:1989, acceptance level L2/C.

Table K.1

Replace this table with the following:

Table K.1 Acceptance criteria for laminar imperfections

Maximum individualimperfection

Minimum imperfection size considered

Maximum population density(a)

Area Length Area Length Width Service Condition

mm2 mm mm2 mm mm

Pipe body (or strip/plate body)

Non-sour 1 000 300 35 8 (0.3) 10

[per 1,0 m x 1,0 m square](b)

Sour 100

Not specified

30 5 5 5

[per 500 mm x 500 mmsquare](c)

Strip/plate edges or areas adjacent to the weld seam d

Sour or offshore

100 (0.16) 20 (0.8) — 10 — 3

[per 1,0 m length]

NOTES 1. For an imperfection to be larger than the minimum imperfection size, the minimum area, minimum length and minimum width given for the pipe body (or strip/plate body) all have to be exceeded.

2. For the purpose of determining the extent of suspect area, adjacent suspect areas separated by less than the smaller of two minor axes of the imperfections shall be considered as one imperfection.

NOTES: a) Number of imperfections smaller than the maximum and greater than the minimum imperfection size.

b) For pipe with D < 323,9 mm or strip/plate widths less than 1 000 mm, the maximum population density is referred to 1,0 m2 .

c) For pipe with D < 168,3 mm or strip/plate widths less than 500 mm, the maximum population density is referred to 0,25 m2 .

d) The maximum imperfection area of edges is the product of the maximum imperfection length, where length is the dimension parallel to the material edge and the transverse dimension. An imperfection is considered to be larger than the maximum imperfection size if either the length or the transverse dimension is exceeded.


Page 51

K.4 NON-DESTRUCTIVE INSPECTION OF HFW PIPE

K.4.1 Non-destructive inspection of the weld seam


The full leng th of the we ld seam shall be ultra sonically inspected for the d etection of longitudinal imperfections, with the acceptance limits being in accordance with Table E.8 of this DEP. The probe per weld distribution shall be in accordance with Table E.7.1 of this DEP.

K.4.2 Laminar imperfections in the pipe body


The pipe o r strip/plate b ody shall be u ltrasonically inspected for the detection of laminar imperfections in accordance with ISO 10124:1994 (except 4.2) or ISO 12094, respectively, to acceptance limits for the relevant application as given in Table K.1.

For sour surface applications:

For strip/plate and pipe examination the coverage during automatic inspection shall be 100% of the pipe surface.

For offshore, non sour, applications:

The required levels of coverage are ≥ 50% of the pipe or plate/strip surface.

K.4.3 Laminar imperfections on the strip/plate edges or areas adjacent to the weld seam


The strip/plate edges or the areas adjacent to the weld sea m shall be ultrasonically inspected over a width of 25 mm for the detectio n of laminar imp erfections, in accordance with ISO 12094 or ISO 13663. The acceptance limits shall be as given in Table K.1.

K.4.3 Supplementary non-destructive inspection

Delete this clause.

K.5 NON-DESTRUCTIVE INSPECTION OF SAW PIPE


The full length of th e weld seams of SAW pipe shall be ultrasonically inspected for the detection of longitudinal and transverse imperfections in accordance with ISO 9765:1990, acceptance level L2, with the following modifications:

a) The notch depth shall be ≤ 2.0 mm (0.080 in). b) The use of internal and external longitudinal notches located on the centre of the

weld seam for equipment standardization purposes is not permitted. The sensitivity of the longi tudinal imperfection detection probes shall be adjusted on the radially drilled hole, Table E.7.2.

c) As an alternative to the use of the reference hole for equipment calibration for the detection of transverse imperfections, it is permissible to use acceptance level L2 internal and external notches, lying at right angles to, and cente red over, the weld seam. In this case, the Manufacturer may elect to grind both the internal and external weld reinforcements to match the pipe contour in the immediate area and on both sides of the reference notches. The notches shall b e sufficiently separated from each other in the longitud inal direction and (if gro und flush) from any remaining reinforcement, to give cle arly identifiable separate ultrasonic signal responses. The full si gnal amplitude f rom each of such notches shall be used to set the trigger/alarm level of the equipment.

d) The manufacturer may apply the provisions of K.5.3 to retest the suspect areas.

The probe per weld zone distribution shall be in line with Table E.7.2 of this DEP.


Page 52

K.5.1.2 Delete this clause. Strip end welds are not permitted.

K.5.1.3 Delete this clause. Jointers are not permitted.

K.5.2 LAMINAR IMPERFECTIONS IN THE PIPE BODY AND ON THE STRIP/PLATE EDGES

K.5.2.1 Delete this clause and replace with the following:

The pipe o r strip/plate b ody shall be u ltrasonically inspected for the detection of laminar imperfections in accordance with ISO 12094 to acceptance limits for the relevant service conditions as given in Table K.1 with the following coverage requirements:

For sour surface applications:

For strip/plate and pipe examination the coverage during automatic inspection shall be 100 % of the pipe surface.

For offshore, non-sour applications:

The required levels of coverage for plate/strip and pipe shall be ≥ 50% of the pipe surface.


The strip/plate edges or the areas adjacent to the weld seam shall be ultrasonically inspected over a width of 25 mm for the detection of laminar imperfections, in accordance with ISO 12094 or ISO 13663. The acceptance limits shall be as given in Table K.1.

K.5.3 NON-DESTRUCTIVE INSPECTION OF THE WELD SEAM AT THE PIPE ENDS/REPAIRED AREAS


The length of weld seam at pipe ends that cannot be inspected by the automatic ultrasonic equipment and repaired areas of the weld seam (see Clause C.4), shall be subjected to the following:

a) For the detection of longitudinal imperfections semi-automatic or manual ultrasonic inspection using the same inspection sensitivity and inspection parameters as is specified in K.5.1.1 and radiographic inspection in accordance with Clause E.4. Note: Manual ultrasonic inspection may be approved by the Principal as an interim measure, but the manufacturer shall plan to install an automatic or semi automatic system within an agreed time frame.

b) For the detection of transverse imperfections, automatic or semi-automatic ultrasonic inspection using the same inspection sensitivity and parameters as is specified in K.5.1.1 and radiographic inspection in accordance with Clause E.4. Note: Manual ultrasonic inspection may be approved by the Principal as an interim measure, but the manufacturer shall plan to install an automatic or semi automatic system within an agreed time frame.

For manual ultrasonic inspection, the maximum scanning speed shall be 150 mm/s.

Where testing of a reas performed with both UT a nd RT, and found to be free of RT indications, the area shall be subjected to further UT. If the indication is confirmed with the repeat UT and is not caused by geometrical features or acoustic coupling conditions, then the UT indication shall be classed as a crack and the material rejected

K.5.4 SUPPLEMENTARY NON-DESTRUCTIVE INSPECTION OPERATION


Each pipe shall be tested over the final 25 mm at each end with UT using a 45° shear wave probe to disclose axially aligned, through-thickness cracks. The manufacturer may perform this examination on the ends of the plate ends prior to forming/welding. Cracks are not permitted and if found, cracked areas shall be cut-off and the pipe end re-tested.


Page 53

PART IV REFERENCES

In this DEP, reference is made to the following publications: NOTES: 1. Unless specifically designated by date, the latest edition of each publication shall be used,

together with any amendments/supplements/revisions thereto.

2. The DEPs and most referenced external standards are available to Shell staff on the SWW (Shell Wide Web) at http://sww.shell.com/standards/.

SHELL STANDARDS

Pipeline engineering (amendments/supplements to ISO 13623)

DEP 31.40.00.10-Gen.

Welding of pipelines and related facilities (amendments/supplements to ANSI/API STD 1104)

DEP 61.40.20.30-Gen

Line pipe induction bends (amendments/supplements to ISO 15590-1)

DEP 31.40.20.33-Gen

Welding of Deepwater Pipelines, Flowlines, and Steel Catenary Risers (based on API 1104)

DEP 37.81.40.31-Gen

Hydrogen induced cracking sensitivity test (amendments/supplements to NACE TM0284) Project Quality Assurance

DEP 30.10.02.16-Gen DEP 82.00.10.10-Gen

AMERICAN STANDARDS

Standard practice for measuring thickness by manual ultrasonic pulse-echo contact method

ASTM E 797

Issued by: American Society for Testing and Materials 1916 Race Street, Philadelphia Pa 19103 USA

EUROPEAN STANDARDS Non-destructive testing – Qualification and certification of personnel

EN 473

Destructive tests on welds in metallic materials – longitudinal tensile test on weld metal in fusion welded joints

EN 876

metallic materials – Tensile testing – Part 5: Method of testing at elevated temperature

EN 10002-5

Issued by: CEN Rue de Stassart 36 B-1050 Brussels Belgium

Copies can also be obtained from national standards organizations

INTERNATIONAL STANDARDS

Quality systems - Model for quality assurance in design, development, production, installation and servicing

ISO 9001

Non-destructive testing – Qualification and certification of personnel.

ISO 9712

Quality assurance requirements for measuring equipment – Part 1: Metrological confirmation system for measuring equipment

ISO 10012-1

Seamless and welded steel tubes for pressure vessels – Ultrasonic testing for detection of laminar imperfections

ISO 10124

Steel tubes for pressure purposes – Qualification and certification of non-destructive testing (NDT) personnel

ISO 11484


Page 54

Submerged arc-welded steel tubes for pressure purposes - Radiographic testing of the weld seam for the detection of imperfections

ISO 12096

Induction bends, fittings and flanges for pipeline transportation systems – Part 1, Induction bends

ISO 15590-1

Non-destructive testing – Qualification of personnel for limited application of non-destructive testing

ISO 20807

Issued by: ISO Central Secretariat 1, ch. de la Voie-Creuse Case postale 56 CH-1211 Genève 20, Switzerland

Copies can also be obtained from national standards organizations.

NORWEGIAN STANDARDS

Offshore standard, Submarine pipeline systems DNV OS-F101 Issued by: Det Norske Veritas Industri Norge AS Veritasveien 1 1322 Høvik Norway

EUROPEAN FEDERATION OF CORROSION Guidelines on materials requirements for carbon and low alloy steels for H2S-containing environments in oil and gas production

EFC 16

Issued by: Maney Publishing on behalf of the Institute of Materials 1 Carlton House Terrace London SW1Y 5DB


Page 55

APPENDIX 1 LINEPIPE SUBJECTED TO HIGH STRAIN

A1.1 GENERAL

The following requirements are additio nal to those spe cified for PSL 2 pipe ordered for offshore service by ISO 3183:2007 (Annex J) and this DEP. Applicable to pipe for pipelines subject to a single event nominal strain (elastic + plastic), in any direction > 1.0 % or accumulated strain > 2 %, during i nstallation or operation. These conditions apply to all pipelines subjected to high strain, whether onshore or offshore, at pipe grades up to and including L450.

For pipe proposed for installation by reeling, reelability data shall be provided for the pipe proposed (previous data for pipe in terms of the same pipe gra de, dimensions, manufacturing process, chemical composition, and heat treatment etc). The data shall be provided for both before and after reeling trials/simulations including but not limited to: stress/strain curves, fatigue, toughness, yield/tensile including ratios, etc.

A1.2 MECHANICAL PROPERTIES

The results of all longitudinal tensile te sts shall conform to the requirements of Table J2 to the following modifications:

• Tensile specimens shall be of the prop ortional type, in accordance with ISO 6892. The gauge length shall be equal to 5.65S0, where S0 is the original cross-sectional area of the specimen;

• The yield strength sh all not exceed th e specified minimum value by more than 120 MPa. or vary more than 100 MPa from the agreed MPS value;

• The ratio of yield to tensile strength shall not exceed 90%;

• The elongation shall not be less than 20%.

One set of longitudinal Charpy impact specimens shall be taken at a frequency of one set per test unit from the pipe body. The specimens shall be through-thickness notched and located at mid-thickness. The minimum Charpy impact energy for these tests shall be 100 J (average) 80 J (individual). The testing temperature shall be as given in Table 8.

For the m anufacturing procedure qualification test, the longitud inal tensile and Charpy impact tests shall be carried out in both the as-received condition and after a heat treatment simulating thin-film coatin g. This sh all consist of holdin g at 250° C for a minimum of 10 minutes, or as specified in the purchase order. The Principal may require all production longitudinal tensile and Charpy impact test to receive the sam e heat treatm ent prior to testing, subject to the results of the manufacturing qualification test.

A1.3 SPECIFIC REQUIREMENTS, HFW PIPE

HFW pipe shall be subject to the following heat treatment:

(a) Full body quench and temper;

Or

(b) Weld seam online quench followed by full body temper.

A1.4 STRAIN AGED PROPERTIES

The following shall form p art of the manufa cturing procedure qualification test for each combination of diameter and wall thickness. .

Samples of pipe body shall be subject to a longitudinal, uni-axial strain of 3.0% (or greater if stated in the purchase order). A sufficient number of strain gauges shall be used to verify even straining. (Refer DNV F101 – Appendix B: A1200)


Page 56

Samples of the longitu dinal seam weld (SAW and HFW pipe) shall be similarly subject to uni-axial straining to 3.0% strain (or lesser value if stated in the purchase order) transverse to the seam.

After straining, the samples shall be aged at 250 C for one hour. The following mechanical tests shall be performed:

Pipe body:

• Two longitudinal tensile tests;

• One set of three longitudinal Charpy impact tests ;

• One through thickness hardness survey (HV10), per Fig J.1.a).

Weld seam:

• One all-weld tensile test (SAW only);

• Four sets of charpy impact tests at weld, fusion line, fusion line+2 mm and fusion line +5 mm in accordance with 10.2.3.3;

• One hardness survey (HV10) per Fig J1 b) or c).

The impact test temperature shall be as specified for the unstrained tests.

The acceptance criteria for all mecha nical tests shall be as specifie d for the unst rained tests.

Where required by the Pu rchase order for SSC te sting, as specified in cl ause H.7.3.2.1, shall be performed on sa mples of the longitudinal seam weld strain -aged as specified above.

A1.5 SSC TESTS AT HIGH STRAIN

Where required be the pu rchase order, high strain SSC tests sh all be conducted on the parent material as part of the manufacturing procedure qualification. Three specimens shall be taken from the parent material in the longitudinal direction. Testing shall be carried out using the 4 point bend method (inte rnal surface in tension) as described in EFC 16, Appendix 2. The distance between the inner supports shall be equal to, or greater than, the width of the weld plus 50 mm (25 mm each side of the weld). Unless otherwise agreed with the Principal the specimen thickness shall be t o r 15 mm, whichever is the less, and the specimen width shall be ≥ 20 mm. The applied strain, solution starting pH and H2S partial pressure shall be as stated in th e purchase order and shall be verified by the di rect application of strain gauges.

In addition, all SSC test specim ens which meet the acceptance criteria of ISO 3183:2007 are to be evaluated for resi stance to SOHI C in a ccordance with ISO 15156-2, Clause B.4.2.3: Two longitudinal metallographic sections shall be taken from each SSC specimen. No ladder-like HIC featu res or cracks exceeding a length of 0.5 mm in the thro ugh thickness direction are to be permitted.

Testing shall be applied to each combination of diameter and wall thickness and within the essential variables stated in B.5. These test s shall be in additio n to the trans-weld SSC tests, carried out at 90 % of actual yield that may be required under clause H 7.3.2.1. NOTE It is unlikely that high in-service strains will be permitted un der severe sour se rvice and the te st

conditions required by the purchase order should represent the anticipated process conditions.


Page 57

APPENDIX 2 WELDABILITY OF PSL2 PIPE

A2.1 GENERAL

For all offshore pipelines and for other pipelines where specified in the pu rchase order, weldability trials S HALL [PS] be carri ed out. Th e material shall be as qualified in the manufacturing procedure qualification (Annex B), within the limits spe cified in Clause B.5, as modified by this DEP.

One trial each shall be carried out for the maximum and minimum wall thicknesses to be produced, or as agreed with the Principal.

Data from previous weldability tr ials may be accepted, in whole or part, in lieu of testing by the Principal. The materi al used in th e previous trials shall be identical in grade, and manufacturing procedure to the pipe to be supplied and shall be of similar diameter, wall thickness and similar in chemical composition (within the limits of Annex H table H1).

A2.2 WELDING

Girth welds shall be carried out in accordance with welding procedure specifications representative of those used by installation contractors and approved by the Principal. The production of these welds and subsequent testing shall be in accordance with DEP 61.40.20.30-Gen (Modifying ISO 13847)

Typically, welds shall be produced by the mechanised/automatic GMAW process with arc energies for each weld pass in the range 0.6-1.0 KJ/mm. Alternative welding processes and parameters shall be as stated in the purchase order.

At least one full butt weld shall be produced for each trial and sufficient weld length shall be produced to extract all the required test specimens.

Additional welds may be required to be supplied for testing conducted by the Principal. The number and dimensions of these weld test pieces shall be stated in the purchase order.

A2.3 MECHANICAL AND CORROSION TESTING

Mechanical testing of the welds shall be ca rried out in acco rdance with section 5.4.3. of DEP 61.40.20.30-Gen. (critical service) with the following modifications

Fracture toughness testing shall be carried out for the fusion line/HAZ only as follows:

For elastic design:

SENB CTOD specimens shall be used. A minim um CTOD value of 0.25 mm shall be achieved in all tests.

For SCR pipe: Minimum allowable CTOD shall be 0.51 mm For high strain (Appendix 1 applies)

At least 6 CTOD specimens (SENB or SENT, as stated in the Purcha se order) shall be tested in accordance with the requirements of DEP 61.40.20.30-Gen to develop a R-curve for the HAZ. The required R-curve shall be defined in the Purchase Order.

The design temperature relevant to CTOD and impact testing shall be stated in th e purchase order.

The acceptance criteria for ten sile, hardness and impact testi ng shall be as stated in section 5.4.3 of DEP 61.40.20.30-Gen.

Where required by the purcha se order, corrosion (SSC) testing shall be carried out in accordance with section 5.4.3.9 of DEP 61.40.20.30-Gen. The specimen thickness shall be t or 15mm, whichever is the less. Specimens not exhibiting surface cracking after testing are to b e evaluated for resistance to SO HIC in a ccordance with ISO 15156-2, Clause B.4.2.3: Two lo ngitudinal metallographic sections shall be taken from each SSC specimen. No ladde r-like HIC feature s or cracks exceeding a length of 0.5 mm in the through thickness direction are to be permitted


Page 58

APPENDIX 3 LINE PIPE FOR DEEPWATER PROJECTS, INCLUDING STEEL CATENARY RISERS

A3.1 SCOPE

This appendix, when stated on the purchase order or project documentation, specifies the requirements for line pipe used on deepwater projects. These requirements are in addition to those stated in this DEP, ISO 3183:2007 and API Spec 5L 44th Edition. NOTE: The requirements of Annex J an d Appendices 1 and 2 shall apply to all pipes for deepwater projects

unless specifically stated otherwise on purchase orders for specifc projects.

When specified in the purchase order or project documentation for sour service the requirements of Annex H, as modified by this DEP, shall also apply.

A3.2 GENERAL

For seamless pipe all billets and slabs shall be scarfed or peeled prior to rolling or forming. Continuous cast rounds shall be conditioned to the Manufacturer’s specifications.

Pipe straightness and length shall be measured and recorded for ea ch pipe. Unless otherwise stated by Principal, 85% of pipe sh all be in the range 11.9 m to 12.5 m (39 ft to 41 ft) with the remaining 15% in the range of 11.6 m to 12.8 m (38 ft to 42 ft).

The wall thickness negative tolerance shall be -5 %. The wall thi ckness positive tolerance for seamless pipe shall be +15 %.

A3.3 ADDITIONAL TESTING FOR SAW PIPE

During first day produ ction manufacturer shall perform circumferential compressive stress tests. A compressive stress-strain curve shall be developed. The units used on each axis of each compressive stress-strain curve shall be clearly identified. The compressive stress-strain curves shall cover a range of at least –2.0 % strain.

During first day production manufacturer shall perform ring splitting residual stress tests. If residual stresses are large, greater than 25 % of SMYS, the Pri ncipal shall be informed immediately in order to have the pipe collapse tested.

A3.4 WELDABILITY TEST

Weldability testing shall be in accordance with (Appendix 2) of this DEP, ho wever unless otherwise stated in the purchase order DEP 37.81.40.31-EPP shall be used instead of DEP 61.40.20.30-Gen for the production, testing and inspection of the welds.

CTOD requirements shall be as follows: For SCR pipe: Minimum allowable CTOD shall be 0.51 mm For flowlines and high strain testing: minimum allowable CTOD shall be 0.25 mm The charpy impact test temperature shall be a minimum of -18°C and CTOD at a minimum of 0°C.

A3.5 PIPE ENDS

Pipe ends shall be either bevelled or square cut, as required by the purchase order. When a bevel angl e is spe cified the plus or minus tole rance shall be 2 1/2°, unless otherwi se specified. Root face shall b e as described by Clau se 9.12.5.2 of ISO 3183:2007/API Spec 5L 44th edition, except there shall be no internal bevel resulting from removal of the internal burr.

The inside diameter of each end of each pipe for a distance of 4 in (102 mm) from the end, shall be as specified in Table J.3, but shall not be more than 1.6 mm larger, nor more than 1.6 mm smaller than specified, as measured with inside calipers, inside micrometers, a rod gauge, or similar device. For SCR applications the inside diameter of each end of each pipe for a di stance of 4 in (102 mm) from the end, shall not be mo re than 1.6 mm larger, nor more than 1.6 mm smaller than specified.


Page 59

The inside diameter at the ends may be machined, on the condition that the termination of the machining is pa rallel over 20 0 mm (8 in ) of the pipe, a nd that all wall thickness tolerances are maintained.

If end ma chining is required to m eet these tolerances and the Manufacturer has end machining capabilities that meet the requirements of the Deepwater Projects Addendum, then the Deepwater Projects Addendum shall apply. Manufacturer may submit a proposal to Principal to meet the requirements of the Deepwater Projects Addendum.

If the inside diameter at the end s is machined, a minimum distance for machining of 200 mm from the pipe end shall be required, unless specifically approved by the Principal. Any end-machining required to meet these tolerances shall be approved by the Principal.

A3.6 NON-DESTRUCTIVE INSPECTION

After all manufacturing and heat treatment procedures have been completed on seamless pipe, the e ntire steel volume of ea ch length of pi pe (100%) shall be in spected by both ultrasonic and electromagnetic methods in accordance with this DEP and Annexes E & K of ISO 3183:2007/API Spec 5L 44th edition, and the additional requirements herein.

Prior to edge preparation and forming, all plate (100%) for SAW pipe shall be subjected to an ultrasonic examination in a ccordance with this DEP and Annexes E and K of ISO 3183:2007/API Spec 5L 44th edition to detect discontinuities parallel to the rolled surfaces. At the option of the manufacturer, this inspection may be performed after the pipe fabrication is complete.

All weld se ams for SA W pipe shal l be inspe cted full length (100% ) by ultrasonic examination in accordance with this DEP and Annexes E and K of ISO 3183:2007/API Spec 5L 44th edition.

For Steel Ca tenary Riser pipe the ultrasonic testing equipment requires qualification and approval in accordance with Shell Q uality Services’ TC 11.1 Rev. 1 (16 August 2001) “Quality Services’ Process for Performing UT/EMI System Capability Study”.

Each length of pipe shall be measured along the full length for wall thickness. Each bidder shall submit with their quotation all details of their proposed inspection and the amount of coverage.

There shall be no laminations within 150 mm (6 in) of the pipe ends.

A3.7 WORKMANSHIP

The pipe shall contain no dents that affect both the outside surface and the inside surface, and the pipe shall contain no dent on th e outside surface with a d epth exceeding 1.6 mm for seamless pipe and 0.8 mm for S AW pipe. Pounding out or j acking out dents is prohibited.

For the whole order no more than 0.5% of the pi pe welds may be repaired. No individual repair can be attempted more than once.

A3.8 MARKING AND COATING

Any additional marking requirements, if applicable, will be i ncluded in the purchase order (including the requirement for marking in US units and conformance to US anti-dumping regulations).


Page 60

APPENDIX 4 PROCEDURE REQUIREMENTS FOR NDT A procedure shall be present for every technique describing the inspection process, with as a minimum the essential variables as mentioned below in the different tables

Ultrasonics

chapter Essential variables

scope Diameter- and thickness range

Personnel • qualification and performance if requirements

Inspection Technique(s) • straight beam, angle beam, contact, and/or immersion Scanning (manual or automatic)

equipment • Type and supplier ultrasonic instrument(s). specifications (warning signals, marker etc)

• probe type(s), frequency(ies), and element size(s) shape(s) angle(s) suppliers

• computerized program identification and revision, when used

calibration a) calibration pipe identification b) Dimensions of the calibration pipe (diameter and thickness) and

reference reflectors c) drawing of the reference reflectors in the test pipe (above view

and cross section) d) layout of the probes in combination with the reading channels e) parameters of the inspection (guiding principle, gate settings,

inspection speed etc)

Acceptance criteria • Acceptance criteria for the inspection and decision tree

Reporting

Reporting shall include at least the following items: a) procedure identification and revision; b) instrument reference level gain and, if used, damping; c) identification of the pipe; d) wall thickness and diameter of the pipe; e) position, depth and size of the defect(s) at reporting level (50%

of the reference level); f) date and time of inspection; g) responsible operator.


Page 61

Liquid penetrant


scope Material to be inspected


Inspection Technique(s) • Method of applying penetrant • Method of removing excess surface penetrant • Method of applying developer

equipment • materials including developers, emulsifiers, etc

General a) Surface preparation (finishing and cleaning) b) Minimum and maximum time periods between steps and drying

aids c) Decrease in penetrant dwell time d) Increase in developer dwell time (Interpretation Time) Minimum

light intensity e) Surface temperature outside: 5°C to 52°C

Acceptance criteria • Acceptance criteria for the inspection

Magnetic particle


scope Material to be inspected


Inspection Technique(s) a) Magnetizing technique b) Magnetizing current type or amperage c) Magnetic particles (fluorescent/visible, color, particle size,

wet/dry d) Method of particle application e) Method of excess particle removal f) Methods of identifying flaw indications and discriminating

between flaw indications and false or non-relevant indications

equipment • Supplier of the equipment

General • Surface preparation

• Minimum light intensity surface temperature

• Instructions for identification and confirmation of suspected flaw indications



Page 62

Eddy Current


scope thickness range


Inspection Technique(s) • Mode of inspection: differential or absolute • Scanning mode: manual, mechanized probe driver, remote

controlled fixture

equipment • Manufacturer and model of eddy current equipment • Probe type and size • Probe manufacturer, part number, and description • Length of probe cable and probe extension cables

calibration • Identity of calibration reference standard(s)

• Examination frequencies, drive voltage, and gain settings

• Minimum digitization rate

• Maximum scanning speed during data recording

Acceptance criteria • Acceptance criteria for the inspection and decision tree

Reporting

Reporting shall include at least the following items • procedure identification and revision • Scanning direction during data recording, i.e., push or pull • date and time of inspection • responsible operator


Page 63

Radiography


scope thickness range


Inspection Technique(s) • conventional or digital • single wall / double wall

equipment a) isotope or maximum X-ray voltage used b) manufacturer and model no. of digitizing system if used c) film brand and designation d) image quality indicators (IQI) e) Intensifying Screens if used

general a) radioscopic parameters b) image processing parameters c) image display parameters d) image archiving e) manipulation system


Reporting The radioscopic examination system shall, as a minimum, include the following:

• film number and result of the inspection: accept or reject




07-2-LA-7880-0007 Page

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Appendix B

Addendum to Shell DEP 31.40.20.37-Gen; Dated June 21, 2011, Rev. 2

June 21, 2011-Rev2 Prepared by Irina Ward

1

Additional Specification CSA Z662 specification to DEP 31.40.20.37 Line Pipe for Critical Service- QUEST CO2 Sequestration project PART I INTRODUCTION 1.1 SCOPE

This standard is an integral part of DEP 31.40.20.37 Line Pipe for Critical Service (Amendments

/Supplements to ISO 3183) issued on February 2011.

The additional specifications listed in this document cover CSA Z662 requirements for line pipe for CO2 service pertaining to the Quest Pipeline project.

PART II GENERAL REQUIREMENTS

1.4 PIPE FOR INDUCTION BENDS

(add)

Additional, project specific requirements for induction bends are included in the overlay to the DEP

31.40.20.33-Quest.

PART III AMENDMENTS/SUPPLEMENTS TO ISO 3183:2007

1. SCOPE

(Delete)

Add the following: This DEP is applicable only to grades L245 up to L555 (X80) as designated in ISO 3183:2007. Intermediate grades shall not be used.

(Add)

Add the following: This DEP is applicable only to grades L245 up to L415 (X60) as designated in ISO 3183:2007. Intermediate grades shall not be

3. NORMATIVE REFERENCES

(Add)

CSA Z662, Oil and Gas Pipeline Systems;

CSA Z245.1 Line pipe

ERCB directive 56,

Alberta Pipeline Act and Regulations;

Shell STD. 3-1.12, Pipe, Valves and Fittings - Piping Classes, (Upstream Field Facilities).

DNV RP-J202 “ Recommended Practice- Design and Operation of CO2 Pipelines”, rev 04, 2010

4. TERMS AND DEFINITIONS (add)

Carbon dioxide (CO2) pipeline system — a pipeline system conveying carbon dioxide or


2

predominantly carbon dioxide mixtures in the liquid or quasi-liquid state at pressures above 7.4 MPa.

Dense phase - Collective term for CO2 in its liquid or supercritical phases

Ductile running fracture-A running ductile fracture is defined as a pipeline rupture,

extending more than one pipeline joint.

6 PIPE GRADE, STEEL GRADE AND DELIVERY CONDITION

Table 1

(Delete)

Delete reference to PSL 2 Grades L390N, L415N, L625M, L690M and L830M

(Delete reference to all PSL 2 Grades having the suffix M)

8 Manufacturing 8.1 Process of manufacture

(Add)

Table 2

(Delete reference to PSL2 Grade L555)

(Add)

Table 3

Delete all entries with delivery condition ―M‖ (thermomechanically rolled). 8.8.2

(Add)

The weld zone of electric-welded pipe shall receive a normalizing heat treatment or a continuous in-line

heat treatment, with a minimum temperature of 620 'C, that will control the structure so that the mechanical properties in the heat-affected zone approximate those of the parent metal.

8.10 STRIP/PLATE END WELDS

(Replace entire clause with)

Strip plate ends shall not be used

9.2 CHEMICAL COMPOSITION

(Delete)- Use Appendix H

9.3 Tensile properties


3

(Delete reference to PSL2 Grade L555)

(Add)

The tensile strength shall not exceed 625 MPa for Grades 390 (X56) and lower, 650 MPa for grades

higher than Grade 390 (X56) but lower than Grade 485 (X70). Grades higher then Grade 485 (X70) are

outside the scope of this specification

9.7 Guided-bend test

(Add)

9.7.3 Root guided bend test for HFW pipe

Root guided-bend test specimens shall be in accordance with the dimensional requirements of Fig 8 and shall be bent cold approximately 180' in a jig in accordance with the requirements of Figure 9. The test specimens shall be accepted per specification in 9.7.1.

Note: The specimen orientation will be such that the HFW root is loaded in tension during the bend test

(Add) 9.7.3.1 Electric welded pipe produced in single lengths For each end of electric-welded pipe produced in single lengths, one root guided-bend test shall be conducted. 9.7.3.2 Electric welded pipe produced from coiled skelp For electric-welded pipe produced in multiple lengths and subsequently cut into single lengths, one root guided-bend test shall be conducted for the leading end of the first pipe and the trailing end of the last pipe of each multiple length

9.8 CVN IMPACT TEST FOR PSL2 PIPE 9.8.2.1 (Delete the existing clause and replace with the following) The minimum average (of a set of three test pieces) absorbed energy for each pipe body test shall be as given in Table 8, based upon full-size test pieces. The test temperature shall be lower than or equal to -45degC 9.8.3 Pipe weld and HAZ tests (Delete existing Table 8 and replace with)

Table 8

Grade Full-size CVN absorbed energy Minimum average value (of the set) J

Pipe body, Weld and HAZ


4

L245 (B) 60

L290 (X42) 60

L320 (X46) 60

L360 (X52) 60

L390 (X56) 60

L415 (X60) 60

(Add)

A transition curve shall be provided by the manufacturer capturing the CVN absorbed energy at the

temperatures specified in section B.4.1.

9.9 DWT TEST FOR PSL2 WELDED PIPE 9.9.1 (Delete this clause and replace with the following)

For each test (a set of two test pieces), the average shear fracture shall be ≥ 85%.

9.11.3 Tolerances for diameter, wall thickness, length and straightness

9.11.3.2 Add

The minus tolerance for wall thickness shal be – 0.08t, where t = wall thickness in millimeters

9.15 WELDABILITY OF PSL2 PIPE (Delete) Add to this clause: For all offshore pipelines and for other pipelines where specified in the purchase order, weldability trials shall be carried out. The material shall be as qualified in the manufacturing procedure qualification (Annex B), within the limits specified in Clause B.5. The requirements for weldability testing are given in Appendix 2 of this DEP.

(Add)

10.2 SPECIFIC INSPECTION 10.2.1 Inspection frequency (Add to Table 18)


Root guided bend testing of weld HFW Two tests per test unit of pipe with the same cold expansion ratio. One test for heats less than 100 tone

ANNEX B MANUFACTURING PROCEDURE QUALIFICATION FOR PSL2 PIPE


5

B.4.1 Impact tests (Add the following to the existing clause:)

The transition curve provided by the manufacturer shall capture the CVN absorbed energy at the

following temperatures:

-75C,. -60C, -45C, -20C. 0C, +20C

ANNEX G PSL 2 PIPE WITH RESISTANCE TO DUCTILE FRACTURE PROPAGATION G.1 GENERAL (Delete second paragraph and replace with) When specified, this additional Charpy impact testing shall be performed on the pipe body only and shall be conducted at the minimum design temperature provided in the purchase order. If the required absorbed energy values are obtained at the test temperature prescribed for fracture initiation, section 9.8.2.1 of this DEP, the additional tests need not be performed. When specified, additional Charpy impact testing shall be performed on the pipe body and the weld of welded pipe and shall be conducted at the minimum design temperature provided in the purchase order as specified in section 9.8 of this specification. ANNEX H PSL 2 PIPE ORDERED FOR SOUR SERVICE H 3.2 Steel making H 3.2.3 (Add)

The maximum ASTM grain size shall be 9 and the manufacturer should aim for a grain size of 10.9 H.4 ACCEPTANCE CRITERIA H.4.1.1 (Add to chemical restrictions table)

B 0.001

H.4.2 Tensile properties Table H.2 — Requirements for the results of tensile tests (Modify Table H2 as follows) The tensile strength shall not exceed 625 MPa for Grades 390 (X56) and lower, 650 MPa for grades higher than Grade 390 (H56) but lower than Grade 485 (X70), and 665 MPa for Grade 485 (X70). H.4.4 Hardness test (Delete second paragraph) The maximum acceptable hardness of an unexposed weld cap and external surface HAZ and base metal may be 275 HV10 or 26 HRC (73,0 HR 15N) where the equipment user agrees to the alternative weld cap hardness limit, the parent pipe wall thickness is greater than 9 mm, the weld cap is not exposed directly to the sour environment and the escape of hydrogen is not impeded, e.g. by cathodic protection.


6

(Add)

The microhardness at any location in the weld zone of HFW pipe and in the deposited weld metal and heat-affected zones of other welds shall not exceed 248 HV 500 gf. The welding procedure qualification test for the pipe weld shall be microhardness tested at the hardest-appearing microstructure; the microhardness at any location therein shall not exceed 248 HV 500 gf. H.5 Surface conditions, imperfections and defects (Delete) b) 275 HV10, 27 HRC or 260 HBW on the external surface of the pipe or repair to external seam weld bead. Table H3 (Add)


Microhardness of longitudinal or helical-seam weld of welded pipe

HFW, SAWL, SAWH


H.7.3 Test Methods H.7.3.2.1 Delete this clause and replace with the following: Sulfide stress cracking tests are required for manufacturing procedure qualification of each pipe thickness. For welded pipe three specimens shall be taken transverse to the weld Testing shall be carried out at 90% of the actual yield of the parent material using the 4 point bend method (internal surface in tension) as described in EFC 16, Appendix 2. Test solution A, EFC 16 Annex A3, shall be used adjusted to a starting pH of 3.5. 1 bara (pure) H2S shall be used. The distance between the inner supports shall be equal to, or greater than, the width of the weld plus 50 mm (25 mm each side of the weld). Unless otherwise agreed with the Principal the specimen thickness shall be t or 15 mm, whichever is the less,

and the specimen width shall be ≥ 20mm. The applied strain shall be verified by the direct

application of strain gauges. In addition, all SSC test specimens which meet the acceptance criteria of ISO 3183:2007 are to be evaluated for resistance to SOHIC in accordance with ISO 15156-2, Clause B.4.2.3: Two longitudinal metallographic sections shall be taken from each SSC specimen. No ladder-like HIC features or cracks exceeding a length of 0.5 mm in the through thickness direction are to be permitted. Sulfide stress cracking tests if required shall accompany the manufacturing procedure qualification of each pipe thickness. A four-point bend test piece in accordance with ISO 7539-2 or ASTM G 39 shall be used and the test duration shall be 720 h. Testing shall be carried out at 90% of the actual yield of the parent material using the 4 point bend method (internal surface in tension) as described in EFC 16, Appendix 2. The applied strain shall be verified by the direct application of strain gauges.


7

Test solution A, EFC 16 Annex A3, shall be used adjusted to a starting pH of 3.5. 1 bara (pure) H2S shall be used. For welded pipe three four point bent test specimens shall be taken transverse to the weld. The distance between the inner supports shall be equal to, or greater than, the width of the weld plus 50 mm (25 mm each side of the weld). Unless otherwise agreed with the Principal the specimen thickness shall be t or 15

mm, whichever is the less, and the specimen width shall be ≥ 20mm.




07-2-LA-7180-0005 1 of 54 Project



Appendix E

Piping Material Specifications

Quest CCS Project

Piping Materials Specification


A 2011.07.04 Issued for Design AR MZ KIA


Tri Ocean Document No. 09223-0-SP-PQ-00001.00

Client Document No. 249.0311.000.035.001

Revision No. A

Page 1 of 4

90000-1-FM-00012 Rev4 (2010.12.08)


09223-0-SP-PQ-00001.00 Revision No.

A Client Document No.

249.0311.000.035.001 Page

2 of 4 Project



Table of Contents

1. Introduction 3

2. Background 3

3. References 4

Tables

Table 2.1-1 Piping Classes Summary 3

Appendices

Appendix A Piping Classes Appendix B Valve Data Sheets Appendix C Wall Thickness Calculations




249.0311.000.035.001 Page

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1. Introduction

This document outlines piping classes that will be used on Quest CCS project for pipelines, LBV valve stations and wellsites. These piping classes are currently not contained within Shell ESTG 3-1.02 Pipe, Valves and Fittings – Piping Classes (Upstream Plant Facilities) and Shell ESTG 3-1.12 Pipe, Valves and Fittings – Piping Classes (Upstream Field Facilities), but shall be read in conjunction with ESTG 3-1.02 and ESTG 3-1.12, and all its associated documentation.

2. Background

Two piping specifications, namely C02Z and C6, are generated for Quest CCS project. Table 2.1-1 provides a brief summary of these two classes.

Table 2.1-1

Piping Classes Summary

Piping Rating Temp.(°C)

Design Code

Basic Material

Facility Type Service

C02Z PN 150 -45 to 60

CSA Z662-07

Z245.1 Carbon Steel

Pipeline/ Wellsite

Dense Phase CO2

C6 CL 900 -101 to 150

ASME B31.3 304 SS

LBV station and

Wellsite

Dense Phase CO2

The pipe specification C02Z has been written based on CSA Z662-07. This specification is more stringent than the requirements of CSA Z662-07 Section 5.2.2 in that the notch toughness requirements are more stringent to meet the criteria set forth by Shell to mitigate long running ductile failure during depressurization of CO2. This Piping class has been rated at 14,790 MPa(g) maximum. This piping class uses the Class 2 locations factors specified in Table 4.2 as pertaining to CO2 service.

The pipe specification C6 has been written based on ASME B31.3. This piping class will be used for the flare/vent piping at LBV stations where Joule-Thompson effect can produce lower temperatures than MDMT of most of the commercially available carbon steels.




249.0311.000.035.001 Page

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3. References

Shell Standards

• Shell Std. 3-1.02, Pipe, Valves and Fittings – Piping Classes (Upstream Plant Facilities).

• Shell Std. 3-1.12, Pipe, Valves and Fittings – Piping Classes (Upstream Field Facilities).

• Shell GS.10.52923 Fracture Toughness Requirements for Quest Pipeline

Industry Standards

• CSA Z662-07, Oil and Gas Pipeline Systems

• ASME B31.3, Process Piping

Project Documents

• 09223-0-DG-BB-00020.01 to 00023.01 Material Selection Diagram Rev A

• 09223-0-DB-GQ-00001.00 Design Basis Engineering Package Rev B

• 09223-1-DB-BQ-00001.00 Process Design Basis Rev B




249.0311.000.035.001 Page

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Appendix A

Piping Classes

1

Project Quest Pipeline Piping Material Class C02Z

Client Shell Energy Canada Rev Date June 27/11 Rev B

Service Dense phase (HVP) CO2

Design Standard CSA Z662-07 Class 2 (Design Factors: F=0.8; L=0.8, J=1; T=1)

Pressure Class PN 150 (Rated to 14790 kPag at -45°C to 60°C)

Nominal Pipe Material CSA Z245.1 Gr. 386 Cat II

Flange Material Group N/A

Corrosion Allowance (mm) 1.3

Branch Table B-1

GENERAL NOTES

A ALL BUTTWELD JOINTS TO BE SUBJECT TO 100% RADIOGRAPHY

B PREHEAT AND PWHT TO CSA Z662 AND APPLICABLE WELDING PROCEDURES

C FOR BRANCH CONNECTION REQUIREMENTS, SEE BRANCH TABLE B-1

D IN ADDITION TO CSA Z662-07, ALL PIPING COMPONENTS SHALL COMPLY WITH ESTG 3-2.11

E ALL UNDERGROUND PIPE AND FIELD JOINT EXTERNALS SHALL BE FUSION BONDED EPOXY COATED WITH BREDERO SHAW FBE COATING

F ALL UNDERGROUND PIPING SHALL BE IMPRESSED CURRENT CATHODICALLY PROTECTED

G ALL BUTT-WELDED COMPONENT THICKNESS SHALL MATCH PIPE THICKNESSES

H THIS PIPING CLASS SHALL NOT BE USED WITHIN COMPRESSOR STATIONS AND PUMP STATIONS.

MAX DESIGN PRESSURE AT TEMPERATURE

Pressure (kPa) 14790 14790 14790 14790

Temperature (Deg. C) -45 38 50 60

PIPE DIAMETERS AND WALL THICKNESSES

ND (inch) 3/4 1 1 1/2 2 3 4 6 8 10 12 14 16

WT tol (%) -8.0 -8.0 -8.0 -8.0 -8.0 -8.0 -8.0 -8.0 -8.0 -8.0 -8.0 -8.0

Pipe THK (mm) 3.9 4.5 5.1 4.8 4.8 5.6 7.9 9.5 11.1 12.7 14.3 15.9

SCH 80 80 80

PIPING COMPONENT SPECIFICATION

COMPONENT SIZE RANGE END CONN MATERIAL STD. CL/SCH GEOMETRIC STANDARD

DS NOTES

from to #1 #2

PIPE

Pipe 3/4 1 1/2 PE PE CSA Z245.1 Gr. 386 ERW Cat II CSA Z245.1 MDS-01,

MDS-04 1

2



DS NOTES

from to #1 #2

Pipe 2 16 BE BE CSA Z245.1 Gr. 386 ERW Cat II CSA Z245.1 MDS-01

Pipe Bends 2 16 BE BE CSA Z245.1 Gr. 386 ERW Cat II CSA Z245.1 MDS-02 2

Pipe Transition Piece 2 18 BE BE CSA Z245.1 Gr. 386 ERW Cat II CSA Z245.1 MDS-01

Nipple 3/4 1 1/2 PE PE CSA Z245.1 Gr. 386 Cat II CSA Z245.1, CSA

Z245.11 MDS-01, MDS-04 1

FLANGES

Flange 2 2 RF WN CSA Z245.12 Gr. 386 ERW Cat II PN250 CSA Z245.12 MDS-03

Flange 3 16 RF WN CSA Z245.12 Gr. 386 ERW Cat II PN150 CSA Z245.12 MDS-03

Blind Flange 2 2 RF CSA Z245.12 Gr. 386 ERW Cat II PN250 CSA Z245.12 MDS-03

Blind Flange 3 16 RF CSA Z245.12 Gr. 386 ERW Cat II PN150 CSA Z245.12 MDS-03

BOLTS

Stud Bolt c/w Nuts 2 2 ASTM A320 Gr L7 Studs; ASTM A194 2H Nuts

CL 1500 ASME B16.5


CL 900 ASME B16.5

GASKETS

Gasket – Spiral Wound 2 2 RF RF

304 SS Spiral Wound 1/8” thk, w/ Flex. Grafoil Filler, CS outer ring, CS inner ring

CL 1500 ASME B16.20


304 SS Spiral Wound 1/8” thk, w/ Flex. Grafoil Filler, CS outer ring, CS inner ring

CL 900 ASME B16.20

FITTINGS

Concentric Reducer 2 16 BW BW CSA Z245.11 Gr. 386 ERW Cat II CSA Z245.11 MDS-04

Elbow 45 Deg 2 16 BW BW CSA Z245.11 Gr. 386 ERW Cat II CSA Z245.11 MDS-04

Elbow 90 Deg 2 16 BW BW CSA Z245.11 Gr. 386 ERW Cat II CSA Z245.11 MDS-04

Straight Tee 2 16 BW BW CSA Z245.11 Gr. 386 ERW Cat II CSA Z245.11 MDS-04

Reducing Tee 2 16 BW BW CSA Z245.11 Gr. 386 ERW Cat II CSA Z245.11 MDS-04

3



DS NOTES

from to #1 #2

Weldolet 2 16 BW BW CSA Z245.11 Gr. 386 ERW Cat II CSA Z245.11, MSS

SP-97 MDS-04

COMPONENT SIZE RANGE END CONN CL/SCH

GEOMETRIC STANDARD

VALVE TAG DS NOTES

from To #1 #2

VALVES

BALL VALVES

Ball Valve 2 2 RF RF PN 250 Z245.15 VO 1564-LZ2 3

Ball Valve 3 16 RF RF PN 150 Z245.15 VO 964-LZ2 3

GATE VALVES

Gate Valve 2 2 RF RF PN 250 Z245.15 VG 1504-LZ2

Gate Valve 3 16 RF RF PN 150 Z245.15 VG 904-LZ2

Gate Valve 2 2 RF RF PN 250 Z245.15 VG 1534-LZ2 4

Gate Valve 3 16 RF RF PN 150 Z245.15 VG 934-LZ2 4

Gate Valve 3/4 1 1/2 SW SW CL 1500 API 602 VG 1501-L2

Gate Valve 3/4 1 1/2 SW THRD CL 1500 API 602 VG 1503-L2

CHECK VALVES

Check Valve 2 2 RF RF PN 250 Z245.15 VC 1504-LZ2

Check Valve 3 16 RF RF PN 150 Z245.15 VC 904-LZ2

Check Valve 3/4 1 1/2 SW SW CL 1500 API 602 VC 1541-L2

GLOBE VALVES

Globe Valve 2 2 RF RF PN 250 Z245.15 VO 1504-LZ2

Globe Valve 3 16 RF RF PN 150 Z245.15 VO 904-LZ2

Globe Valve 3/4 1 1/2 SW SW CL 1500 API 602 VO 1501-L2

GAUGE AND NEEDLE VALVES

Gauge Valve 3/4 1 1/2 THRD THRD 6000 CWP VN 6059-C

Needle Valve 3/4 1 1/2 THRD THRD 6000 CWP VN 6019-C

NOTES

1 SEAMLESS PIPE MANUFACTURED TO ASTM A333 Gr. 6 THAT CAN BE DUAL CERTIFIED TO CSA Z245.1 GR 359 CAT II AND MEETS THE IMPACT TEST REQUIREMENTS AS PER MDS-01 CAN BE ACCEPTED.

2 PIPELINE STRESS ENGINEER SHALL BE CONSULTED TO VERIFY THAT WALL THICKNESS STATED IN THE PIPE SPEC ARE ADEQUATE TO WITHSTAND BENDING AND COMBINDED STRESSES FOR BUIRED PIPE.

3 METAL SEATED ORBIT VALVES WILL BE USED AS LINE BLOCK VALVES AT LBV SITES, FULL PORT.

4 FULL PORT PIGGABLE SLAB GATE VALVE

4

BRANCH TABLE B-1

HEADER

0.75 1 1.5 2 3 4 6 8 10 12 14 16

B

R

A

N

C

H

0.75

USE NPS 2 FLANGED CONNECTION 1

1.5

2 T T T

3 T T T WELDOLET

4 T T T

6 T T T T

8 T T T T T

10 T T T T

12 T T T

14 T T

16 T

BRANCH TABLE NOTES:

1) TEES TO BE EQUAL OR REDUCING. 2) MINIMUM BRANCH SIZE ON NPS 2 AND GREATER TO BE NPS 2.

.

5

MATERIAL DATA SHEET: MDS-01 Rev. 0 TYPE OF MATERIAL: Carbon Steel Page 1 of 1 PRODUCT STANDARD GRADE CATEGORY SUPPL. REQ. Seamless or ERW pipe CSA Z245.1-07 386 II - 1. SCOPE This MDS specifies additional requirements which shall be added or supersede the

corresponding requirements in the referred standard.

2. ADDITIONAL MATERIAL REQUIRMENTS AS PER PROJECT DOCUMENTS

A. Charpy V-notch testing in accordance with ASTM A 370 at - 45°C is required. Full size specimens are required. The minimum absorbed energy for the average of 3 full size specimens shall be 60J, with a single minimum value of 52J. B. Brittle-ductile transition curves shall be provided, via the Manufacturer, showing actual absorbed energy values over a minimum of 4 temperature ranges from - 70°C to 20°C (full size specimens). C. Fracture appearance shear area shall be ≥ 85%. D. Minimum wall thickness variation shall be limited to - 8%. E. Maximum yield strength of pipe shall be 400 MPa.

3. ADDITIONAL MATERIAL REQUIRMENTS AS PER ESTG 3-2.11 Appendix B

In addition to the requirements of CSA Z662-07, pipeline bends shall meet the requirements of ESTG 3-2.11 Appendix B

6

MATERIAL DATA SHEET: MDS-02 Rev. 0 TYPE OF MATERIAL: Carbon Steel Page 1 of 1 PRODUCT STANDARD GRADE CATEGORY SUPPL. REQ. Pipe Bend CSA Z245.11-09 386 II - 1. SCOPE This MDS specifies additional requirements which shall be added or supersede the



A. Charpy V-notch testing in accordance with ASTM A 370 at - 45°C is required. Full size specimens are required. The minimum absorbed energy for the average of 3 full sized specimens shall be 60J, with a single minimum value of 52J. B. Brittle-ductile transition curves shall be provided, via the Manufacturer, showing actual absorbed energy values over a minimum of 4 temperature ranges from - 70°C to 20°C (full size specimens). C. Fracture appearance shear area shall be ≥ 85%. D. Minimum wall thickness variation shall be limited to - 8%. E. Maximum yield strength of pipe shall be 400 MPa.

3. ADDITIONAL MATERIAL REQUIRMENTS AS PER ESTG 3-2.11 Appendix B

In addition to the requirements of CSA Z662-07, pipeline bends shall meet the requirements of ESTG 3-2.11 Appendix B All pipes for bending shall be manufactured in accordance with CSA Z245.1-07.

7

MATERIAL DATA SHEET: MDS-03 Rev. 0 TYPE OF MATERIAL: Carbon Steel Page 1 of 1 PRODUCT STANDARD GRADE CATEGORY SUPPL. REQ. Steel Flanges CSA Z245.12-09 386 II - 1. SCOPE This MDS specifies additional requirements which shall be added or supersede the



A. Charpy V-notch testing for flanges shall be in accordance with ASTM A 370 at -45°C. Full size specimens are required. The minimum absorbed energy for the average of 3 full sized specimens shall be 60J, with a single minimum value of 52J. B. Fracture appearance shear area shall be ≥ 85%.

8

MATERIAL DATA SHEET: MDS-04 Rev. 0 TYPE OF MATERIAL: Carbon Steel Page 1 of 1 PRODUCT STANDARD GRADE CATEGORY SUPPL. REQ. Steel Fittings CSA Z245.11-09 386 II - 1. SCOPE This MDS specifies additional requirements which shall be added or supersede the



A. Charpy V-notch testing for body and welds of fittings shall be in accordance with ASTM A 370 at - 45°C. Full size specimens are required. The minimum absorbed energy for the average of 3 full size specimens shall be 60J, with a single minimum value of 52J. B. Fracture appearance shear area shall be ≥ 85%.

3. ADDITIONAL MATERIAL REQUIRMENTS AS PER PROJECT SPECIFICATION ESTG 3-2.11, APPENDIX A (Refer to referenced clauses of the spec)

2.2.2. Fittings such as tees, elbows and crosses shall not be manufactured from bar stock. Weld fabricated tees, elbows and crosses require Engineering approval. 2.2.3. The hardness requirements of any buttwelding fittings manufactured by welding shall include the weld and heat-affected zone of the welding seam(s). 2.2.7. All nipples and swages (except as noted in sub-section 2.2.8) shall be manufactured from seamless pipe.

4. MARKINGS (As per ESTG 3-2.11, Appendix A, Section 7.0)

The required markings listed in CSA Z245.11 shall apply to all fittings. In addition, on each end the Manufacturer shall use an indelible marking method (e.g., paint stencil) to show: - the identity of the pipe Manufacturer; and, - the pipe Manufacturer's heat number, coil number if applicable, and / or pipe number traceable to pertinent mill certificates, test reports and inspection reports. Cold die stamping is not permitted.

1

Project Quest Pipeline Piping Material Class C6

Client Shell Energy Canada Rev Date June 26/11 Rev B

Service Dense phase (HVP) CO2

Design Standard ASME B31.3

Pressure Class Class 900 (Rated to 14350 kPag at 38°C)

Nominal Pipe Material ASTM A312 TP 304/304L

Flange Material Group 2.1

Corrosion Allowance (mm) 0

Branch Table B-2

GENERAL NOTES

A ALL BUTTWELD JOINTS TO BE SUBJECT TO 100% RADIOGRAPHY

B PREHEAT AND PWHT TO ASME B31.3 AND APPLICABLE WELDING PROCEDURES

C FOR BRANCH CONNECTION REQUIREMENTS, SEE BRANCH TABLE B-2

D IN ADDITION TO B31.3, ALL PIPING COMPONENTS SHALL COMPLY WITH SHELL ESTG 3-2.01

E ALL BUTT-WELDED COMPONENT THICKNESS SHALL MATCH PIPE THICKNESSES

F 316/316L PIPE AND PIPING COMPONENTS CAN BE SUBSTITUTED FOR 304/304L PIPE AND PIPING COMPONENTS

MAX DESIGN PRESSURE AT TEMPERATURE

Pressure (kPa) 14890 14890 14350 13930 12260 11100

Temperature (Deg. C) -101 38 50 60 100 150

PIPE DIAMETERS AND WALL THICKNESSES

ND (inch) 0.75 1 1.5 2 3 4 6 8

WT tol (%) -12.5 -12.5 -12.5 -12.5 -12.5 -12.5 -12.5 -12.5

Pipe THK (mm) 3.91 4.55 5.08 5.54 7.62 8.56 10.97 15.09

SCH 80S 80S 80S 80S 80S 80S 80S 100



DS NOTES

From to #1 #2

PIPE

Pipe 3/4 1 1/2 PE PE ASTM A312 TP 304/304L, SMLS ASME B36.19

Pipe 2 8 BE BE ASTM A312 TP 304/304L, SMLS ASME B36.19

2



DS NOTES

From to #1 #2

Nipple 3/4 1 1/2 PE PE ASTM A312 TP 304/304L, SMLS ASME B36.19

FLANGES

Flange 1/2 1-1/2 RF SW ASTM A182 F304/304L CL1500 ASME B16.5

Flange 2 2 RF WN ASTM A182 F304/304L CL 1500 ASME B16.5

Flange 3 8 RF WN ASTM A182 F304/304L CL 900 ASME B16.5

Blind Flange 2 2 RF ASTM A182 F304/304L CL 1500 ASME B16.5

Blind Flange 3 8 RF ASTM A182 F304/304L CL 900 ASME B16.5

BOLTS

Stud Bolt c/w Nuts 3/4 2 ASTM A320 Gr L7 Studs; ASTM A194 2H Nuts

CL 1500 ASME B16.5


CL 900 ASME B16.5

GASKETS

Gasket – Spiral Wound 3/4 2 RF RF

304 SS Spiral Wound 1/8” thk, w/ Flex. Grafoil Filler, SS outer ring, SS inner ring

CL 1500 ASME B16.20


304 SS Spiral Wound 1/8” thk, w/ Flex. Grafoil Filler, SS outer ring, SS inner ring

CL 900 ASME B16.20

FITTINGS

Concentric Reducer 2 8 BW BW ASTM A403 WP 304/304L-S ASME B16.9

Elbow 45 Deg 1/2 1-1/2 SW SW ASTM A182 F304/304L CL 3000 ASME B16.11

Elbow 45 Deg 2 8 BW BW ASTM A403 WP 304/304L-S ASME B16.9

Elbow 90 Deg 1/2 1-1/2 SW SW ASTM A182 F304/304L CL 3000 ASME B16.11

Elbow 90 Deg 2 8 BW BW ASTM A403 WP 304/304L-S ASME B16.9

Straight Tee 1/2 1-1/2 SW SW ASTM A182 F304/304L CL 3000 ASME B16.11

Straight Tee 2 8 BW BW ASTM A403 WP 304/304L-S ASME B16.9

3



DS NOTES

From to #1 #2

Reducing Tee 3/4 1-1/2 SW SW ASTM A182 F304/304L CL 3000 ASME B16.11

Reducing Tee 2 8 BW BW ASTM A403 WP 304/304L-S ASME B16.9

Weldolet 2 3 BW ASTM A182 F304/304L MSS-97

Sockolet 1/2 1-1/2 SW ASTM A182 F304/304L CL 3000 MSS-97

COMPONENT SIZE RANGE END CONN CL/SCH

GEOMETRIC STANDARD

DESCRIPTION DS NOTES

from to #1 #2

VALVES

GATE VALVES

Gate Valve 2 2 RF RF CL 1500 API 603 VG 1544-CT

Gate Valve 3 8 RF RF CL 900 API 603 VG 944-CT

Gate Valve 3/4 1 1/2 SW SW CL 1500 API 603 VG 1541-CT

Gate Valve 3/4 1 1/2 SW THRD CL 1500 API 603 VG 1543-CT

CHECK VALVES

Check Valve 2 2 RF RF CL 1500 API 603 VC 1504-C

Check Valve 3 8 RF RF CL 900 API 603 VC 904-C

Check Valve 3/4 1 1/2 SW SW CL 1500 API 603 VC 1541-C

GLOBE VALVES

Globe Valve 2 2 RF RF CL 1500 API 603 VO 1544-CT

Globe Valve 3 8 RF RF CL 900 API 603 VO 944-CT

Globe Valve 3/4 1 1/2 SW SW CL 1500 API 603 VO 1541-CT

GAUGE AND NEEDLE VALVES

Gauge Valve 3/4 1 1/2 THRD THRD 6000 CWP VN 6059-C

Needle Valve 3/4 1 1/2 THRD THRD 6000 CWP VN 6019-C

NOTES

4

BRANCH TABLE B-2

HEADER

0.75 1 1.5 2 3 4 6 8

B

R

A

N

C

H

0.75 T T T

1 T T T SOCKOLET

1.5 T T T

2 T T T WOL

3 T T T

4 T T T

6 T T

8 T

BRANCH TABLE NOTES:

1) TEES TO BE EQUAL OR REDUCING. 2) MINIMUM BRANCH SIZE ON NPS 2 AND GREATER TO BE NPS 1-1/2.




249.0311.000.035.001 Page

1 of 25 Project



Appendix B

Valve Data Sheets

VALVE SPECIFICATION DATA SHEET VALVE TAG

VC 904-C

DESIGN

Temperature Range:Specification:

Design Std.:Other Applicable Stds.:Size RangePressure Rating:End Type:End Std:Valve Style:Port Opening:Operator:

MATERIALS

Body:Bonnet:Cover:Ball / Plug:Body Seat Ring or Seat:

Seat Ring Insert:Wedge or Disc Face:Stem / Hinge Pin:Back Seat Bush:Trim No.:Bolting:PackingGaskets:Seals:

OTHER

Service:

Notes:

-101 ºC to 150 ºCASME 900 Class Swing Check Valve per Shell STD.3-2.01 Piping Components - Manufacturing, Appendix GAPI 600, ASME B16.34API 598 NPS 3 to 8CLASS 900

Swing Check, Bolted CoverASME B16.5Flanged RF

316SS, HFS or Monel ®

316SS

ASTM A351 Gr. CF8M

ASTM A351 Gr. CF8M

316SS

316SS304 or 316 SS

DENSE PHASE CO2


VC 904-LZ2

DESIGN



MATERIALS



OTHER

Service:

Notes:

-45 ºC to 60 ºCPN 150 Class Swing Check Valve per Shell STD.3-2.11 Pipeline Components - Manufacturing, Appendix ECSA Z245.15API 598 NPS 3 to 16PN 150

Swing Check, Bolted CoverCSA Z245.12Flanged RF


316SS

ASTM A352 GR LCC

ASTM A352 GR LCC

316SS

316SSASTM A193-L7

DENSE PHASE CO2

A. Charpy V-notch testing in accordance with ASTM A 370 at - 45°C is required. Full size specimens are required. The minimum absorbed energy for the average of 3 full size specimens shall be 60 J, with a single minimum value of 52 J.B. Brittle-ductile transition curves shall be provided, via the Manufacturer, showing actual absorbed energy values over a minimum of 4 temperature ranges from - 70°C to 20°C (full size specimens).C. Fracture appearance shear area shall be ≥ 85%.


VC 1504-C

DESIGN



MATERIALS



OTHER

Service:

Notes:

-101 ºC to 150 ºCASME 1500 Class Swing Check Valve per Shell STD.3-2.01 Piping Components - Manufacturing, Appendix GAPI 600, ASME B16.34API 598 NPS 2 to 2CLASS 1500

Swing Check, Bolted CoverASME B16.5Flanged RF


316SS

ASTM A351 Gr. CF8M

ASTM A351 Gr. CF8M

316SS

316SS304 or 316 SS

DENSE PHASE CO2


VC 1504-LZ2

DESIGN



MATERIALS



OTHER

Service:

Notes:

-45 ºC to 60 ºCPN 250 Class Swing Check Valve per Shell STD.3-2.11 Pipeline Components - Manufacturing, Appendix ECSA Z245.15API 598 NPS 2 to 2PN 250

Swing Check, Bolted CoverCSA Z245.12Flanged RF


316SS

ASTM A352 GR LCC

ASTM A352 GR LCC

316SS

316SSASTM A193-L7

DENSE PHASE CO2



VC 1541-L2

DESIGN



MATERIALS



OTHER

Service:

Notes:

-45 ºC to 60 ºC1500 Class Check Valve to API 602 and Shell Std 3-2.01 Piping Components - Manufacturing, Appendix FAPI 602, ASME 16.34API 598 NPS 3/4 to 1.5CLASS 1500

Horizontal Type, Piston Lift, Bolted CoverASME B16.11SW

316SS316SS, HFS or Monel ®

ASTM A350 GR LF2 CL1

ASTM A350 GR LF2 CL1

316SSASTM A193-L7

DENSE PHASE CO2



VC 1541-C

DESIGN



MATERIALS



OTHER

Service:

Notes:

-101 ºC to 150 ºC1500 Class Check Valve to API 602 and Shell Std 3-2.01 Piping Components - Manufacturing, Appendix FAPI 602, ASME 16.34API 598 NPS 3/4 to 1.5CLASS 1500

Horizontal Type, Piston Lift, Bolted CoverASME B16.11SW

316SS316SS, HFS or Monel ®

ASTM A182 F316 or ASTM A351 Gr. CF8M

ASTM A182 F316 or ASTM A351 Gr. CF8M

316SS304 or 316 SS

DENSE PHASE CO2


VG 904-LZ2

DESIGN



MATERIALS



OTHER

Service:

Notes:

-45 ºC to 60 ºCPN 150 Gate Valve per Shell STD.3-2.11 Pipeline Components - Manufacturing, Appendix ECSA Z245.15API 598

Handwheel up to NPS 4. Gear operator for valves larger than NPS 6

NPS 3 to 16PN 150

OS&Y, Bolted BonnetRegular Port

CSA Z245.12Flanged RF


316SS

ASTM A352 GR LCCASTM A352 GR LCC

Inner Rings: Grafoil ® ; Outer Ring: Braided Graphite

316SS316SS316SSASTM A193-L7

DENSE PHASE CO2

A. Charpy V-notch testing in accordance with ASTM A 370 at - 45°C is required. Full size specimens are required. The minimum absorbed energy for the average of 3 full size specimens shall be 60 J, with a single minimum value of 52 J.B. Brittle-ductile transition curves shall be provided, via the Manufacturer, showing actual absorbed energy values over a minimum of 4 temperature ranges from - 70°C to 20°C (full size specimens).C. Fracture appearance shear area shall be ≥ 85%.D. 17-4PH steam shall have a design stress of less than 40% of SMYS.


VG 934-LZ2

DESIGN



MATERIALS



OTHER

Service:

Notes:

-45 ºC to 60 ºCPN 150 Gate Valve per API 6D and Shell STD.3-2.11 Pipeline Components - Manufacturing, Appendix ECSA Z245.15, API 6DAPI 598


NPS 3 to 16PN 150

Slab Gate, Bolted Bonnet Full Port


316SS OR CS WITH ENC OR HFS

316SS OR CF8M


TEFLON

PTFE

316SS316SS316SS OR CF8MASTM A193-L7

DENSE PHASE CO2

A. Charpy V-notch testing in accordance with ASTM A 370 at - 45°C is required. Full size specimens are required. The minimum absorbed energy for the average of 3 full size specimens shall be 60 J, with a single minimum value of 52 J.B. Brittle-ductile transition curves shall be provided, via the Manufacturer, showing actual absorbed energy values over a minimum of 4 temperature ranges from - 70°C to 20°C (full size specimens).C. Fracture appearance shear area shall be ≥ 85%.D. Vendor to advise the compatbility of seal materials with dense phase CO2. Use high durometer (>90) elastomer sealsE. 17-4PH steam shall have a design stress of less than 40% of SMYS.


VG 944-CT

DESIGN



MATERIALS



OTHER

Service:

Notes:

-101 ºC to 150 ºC900 Class Gate Valve per API 603 and ASME B16.34

API 600, ASME B16.34API 598


NPS 3 to 8CLASS 900

OS&Y, Bolted Bonnet, With Extended Bonnet Regular Port

ASME B16.5Flanged RF

Integral or Insert

316SS

ASTM A351 Gr. CF8MASTM A351 Gr. CF8M

Braided Teflon

316SS

316SS304 or 316 SS

DENSE PHASE CO2


VG 1501-L2

DESIGN



MATERIALS



OTHER

Service:

Notes:

-45 ºC to 60 ºC1500 Class Gate Valve to API 602 and Shell Std 3-2.01 Piping Components - Manufacturing, Appendix FAPI 602, ASME 16.34API 598

Handwheel

NPS 3/4 to 1.5CLASS 1500


ASME B16.11SW


316SS

ASTM A350 GR LF2 CL1ASTM A350 GR LF2 CL1


316SS

316SSASTM A193-L7

DENSE PHASE CO2



VG 1503-L2

DESIGN



MATERIALS



OTHER

Service:

Notes:

-45 ºC to 60 ºC1500 Class Gate Valve to API 602 and Shell Std 3-2.01 Piping Components - Manufacturing, Appendix FAPI 602, ASME 16.34API 598

Handwheel



ASME B16.11SW/THRD


316SS



316SS

316SSASTM A193-L7

DENSE PHASE CO2



VG 1504-LZ2

DESIGN



MATERIALS



OTHER

Service:

Notes:

-45 ºC to 60 ºCPN 250 Gate Valve per Shell STD.3-2.11 Pipeline Components - Manufacturing, Appendix ECSA Z245.15API 598


NPS 2 to 2PN 250

OS&Y, Bolted BonnetReduced Port



316SS



316SS316SS316SSASTM A193-L7

DENSE PHASE CO2



VG 1534-LZ2

DESIGN



MATERIALS



OTHER

Service:

Notes:

-45 ºC to 60 ºCPN 250 Gate Valve per API 6D and Shell STD.3-2.11 Pipeline Components - Manufacturing, Appendix ECSA Z245.15, API 6DAPI 598


NPS 2 to 2PN 250

Slab Gate, Bolted Bonnet Regular Port


316SS OR CS WITH ENC OR HFS

316SS OR CF8M


TEFLON

PTFE

316SS316SS316SS OR CF8MASTM A193-L7

DENSE PHASE CO2

A. Charpy V-notch testing in accordance with ASTM A 370 at - 45°C is required. Full size specimens are required. The minimum absorbed energy for the average of 3 full size specimens shall be 60 J, with a single minimum value of 52 J.B. Brittle-ductile transition curves shall be provided, via the Manufacturer, showing actual absorbed energy values over a minimum of 4 temperature ranges from - 70°C to 20°C (full size specimens).C. Fracture appearance shear area shall be ≥ 85%.D. Vendor to advise the compatbility of seal materials with dense phase CO2. Use high durometer (>90) elastomer sealsE. 17-4PH steam shall have a design stress of less than 40% of SMYS.


VG 1541-CT

DESIGN



MATERIALS



OTHER

Service:

Notes:


API 602, ASME 16.34API 598

Handwheel

NPS 3/4 to 1-1/2CLASS 1500


ASME B16.11SW

Integral or Insert

316SS

A182 F316A182 F316

Braided Teflon

316SS

316SS304 or 316 SS

DENSE PHASE CO2


VG 1543-CT

DESIGN



MATERIALS



OTHER

Service:

Notes:


API 602, ASME 16.34API 598

Handwheel

NPS 3/4 to 1-1/2CLASS 1500


ASME B16.11SW/THRD

Integral or Insert

316SS

A182 F316A182 F316

Braided Teflon

316SS

316SS304 or 316 SS

DENSE PHASE CO2


VG 1544-CT

DESIGN



MATERIALS



OTHER

Service:

Notes:




NPS 2 to 2CLASS 1500



Integral or Insert

316SS

ASTM A351 Gr. CF8MASTM A351 Gr. CF8M

Braided Teflon

316SS

316SS304 or 316 SS

DENSE PHASE CO2


VO 904-LZ2

DESIGN



MATERIALS



OTHER

Service:

Notes:

-45 ºC to 60 ºCPN 150 Globe Valve per Shell STD.3-2.11 Pipeline Components - Manufacturing, Appendix ECSA Z245.15API 598


NPS 3 to 16PN 150




316SS


Braided Teflon

316SS

316SSASTM A193-L7

DENSE PHASE CO2



VO 944-CT

DESIGN



MATERIALS



OTHER

Service:

Notes:

-101 ºC to 150 ºC900 Class Globe Valve per API 603 and ASME B16.34



NPS 3 to 8CLASS 900



Integral or Insert

316SS

A351 Gr. CF8MA351 Gr. CF8M

Braided Teflon

316SS

316SS304 or 316 SS

DENSE PHASE CO2


VO 1501-L2

DESIGN



MATERIALS



OTHER

Service:

Notes:

-45 ºC to 60 ºCAPI 1500 Class Globe Valve per Shell STD.3-2.01 Piping Components - Manufacturing, Appendix FAPI 602, ASME 16.34API 598

Handwheel



ASME B16.11SW


316SS


Braided Teflon

316SS

316SSASTM A193-L7

DENSE PHASE CO2



VO 1504-LZ2

DESIGN



MATERIALS



OTHER

Service:

Notes:

-45 ºC to 60 ºCPN 250 Globe Valve per Shell STD.3-2.11 Pipeline Components - Manufacturing, Appendix ECSA Z245.15API 598


NPS 2 to 2PN 250




316SS


Braided Teflon

316SS

316SSASTM A193-L7

DENSE PHASE CO2



VO 1541-CT

DESIGN



MATERIALS



OTHER

Service:

Notes:


API 602, ASME 16.34API 598

Handwheel

NPS 3/4 to 1-1/2CLASS 1500


B16.11SW

Integral or Insert

316SS

A182 F316A182 F316

Braided Teflon

316SS

316SS304 or 316 SS

DENSE PHASE CO2


VO 1544-CT

DESIGN



MATERIALS



OTHER

Service:

Notes:




NPS 2 to 2CLASS 1500



Integral or Insert

316SS

A351 Gr. CF8MA351 Gr. CF8M

Braided Teflon

316SS

316SS304 or 316 SS

DENSE PHASE CO2

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Text Box

6000 CWP

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle

AdeelRaza

Rectangle




249.0311.000.035.001 Page

1 of 11 Project



Appendix C

Wall Thickness Calculations

09223-0-SP-PQ-00001.00

Piping Class Rating Service Design Factor

Size Linepipe P OD Max Op S F L J T CA Tth t t min. nom. t(min) CSA Z662 t (actual)NPS Material (MPa) (mm) Temp (C) (Mpa) - - - - (mm) (mm) (mm) (mm) Table 4.5 ( note 3) (mm)1/2 CSA Z245.1 Gr. 386 Cat. II 14.790 21.3 60 386 0.8 0.8 1 1.00 1.3 1.45 0.6 3.4 3.7 3.73 80 13/4 CSA Z245.1 Gr. 386 Cat. II 14.790 26.7 60 386 0.8 0.8 1 1.00 1.3 1.45 0.8 3.5 3.9 3.91 80 11 CSA Z245.1 Gr. 386 Cat. II 14.790 33.4 60 386 0.8 0.8 1 1.00 1.3 1.78 1.0 4.1 4.5 4.55 80 1

1 1/2 CSA Z245.1 Gr. 386 Cat. II 14.790 48.3 60 386 0.8 0.8 1 1.00 1.3 1.78 1.4 4.5 5.1 5.10 80 11/2 CSA Z245.1 Gr. 386 Cat. II 14.790 21.3 60 386 0.8 0.8 1 1.00 1.3 0 0.6 1.9 3.7 3.73 80 23/4 CSA Z245.1 Gr. 386 Cat. II 14.790 26.7 60 386 0.8 0.8 1 1.00 1.3 0 0.8 2.1 3.9 3.91 80 21 CSA Z245.1 Gr. 386 Cat. II 14.790 33.4 60 386 0.8 0.8 1 1.00 1.3 0 1.0 2.3 4.5 4.55 80 2

1 1/2 CSA Z245.1 Gr. 386 Cat. II 14.790 48.3 60 386 0.8 0.8 1 1.00 1.3 0 1.4 2.7 5.1 5.10 80 22 CSA Z245.1 Gr. 386 Cat. II 14.790 60.3 60 386 0.8 0.8 1 1.00 1.3 0 1.8 3.1 5.5 4.80 43 CSA Z245.1 Gr. 386 Cat. II 14.790 88.9 60 386 0.8 0.8 1 1.00 1.3 0 2.7 4.0 5.5 4.80 44 CSA Z245.1 Gr. 386 Cat. II 14.790 114.3 60 386 0.8 0.8 1 1.00 1.3 0 3.4 4.7 6.0 5.60 46 CSA Z245.1 Gr. 386 Cat. II 14.790 168.3 60 386 0.8 0.8 1 1.00 1.3 0 5.0 6.3 6.4 7.908 CSA Z245.1 Gr. 386 Cat. II 14.790 219.1 60 386 0.8 0.8 1 1.00 1.3 0 6.6 7.9 6.4 9.5010 CSA Z245.1 Gr. 386 Cat. II 14.790 273.1 60 386 0.8 0.8 1 1.00 1.3 0 8.2 9.5 6.4 11.1012 CSA Z245.1 Gr. 386 Cat. II 14.790 323.9 60 386 0.8 0.8 1 1.00 1.3 0 9.7 11.0 6.4 12.7014 CSA Z245.1 Gr. 386 Cat. II 14.790 355.6 60 386 0.8 0.8 1 1.00 1.3 0 10.6 11.9 6.4 14.3016 CSA Z245.1 Gr. 386 Cat. II 14.790 406.4 60 386 0.8 0.8 1 1.00 1.3 0 12.2 13.5 6.4 15.90

where : P = Design Pressure"Max Op Temp" = Design TemperatureS = Minimum Specified Yield StrengthF = Design factor per CSA Z662-07 para 4.3.6L = Location factor per CSA Z662-07 Table 4.2, for HVP(non-sour service) and CO2, General, Class 2J = Joint factor per CSA Z662-07 Table 4.3T = Temperature factor per CSA Z662-07 Table 4.4CA = Corrosion Allowance

Notes: 1) Wall thickness calculation based on Thrd Pipe / Thrd. Fittings.2) Wall thickness calculation based on SW pipe/SW fittings.

Sch Notes

0.64Dense phase (HVP) CO2 PN 150C02Z

WALL THICKNESS CALCULATION FOR ABOVEGROUND PIPING

09223-0-SP-PQ-00001.00

Design Code Piping Class Rating Service

NPS Pipe Material D Design Pr. Design S E W Y c t tm Mill Notes(mm) P (Mpa) Temp ( oC ) (Mpa) (mm) (mm) (mm) Sch. ts (mm) Tol (%) tsm (mm) Pa (MPa) Acceptable?

0.5 A312 TP304/304L 21.3 14.79 38 137.895 1 1 0.4 1.45 1.10 2.55 80S 3.73 12.5 1.81 25.20 Yes 10.75 A312 TP304/304L 26.7 14.79 38 137.895 1 1 0.4 1.45 1.37 2.82 80S 3.91 12.5 1.97 21.64 Yes 1

1 A312 TP304/304L 33.4 14.79 38 137.895 1 1 0.4 1.78 1.72 3.50 80S 4.55 12.5 2.20 19.19 Yes 11.5 A312 TP304/304L 48.3 14.79 38 137.895 1 1 0.4 1.78 2.48 4.26 80S 5.08 12.5 2.67 15.92 Yes 10.5 A312 TP304/304L 21.3 14.79 38 137.895 1 1 0.4 0 1.10 1.10 80S 3.73 12.5 3.26 48.16 Yes 2

0.75 A312 TP304/304L 26.7 14.79 38 137.895 1 1 0.4 0 1.37 1.37 80S 3.91 12.5 3.42 39.38 Yes 21 A312 TP304/304L 33.4 14.79 38 137.895 1 1 0.4 0 1.72 1.72 80S 4.55 12.5 3.98 36.34 Yes 2

1.5 A312 TP304/304L 48.3 14.79 38 137.895 1 1 0.4 0 2.48 2.48 80S 5.08 12.5 4.45 27.40 Yes 22 A312 TP304/304L 60.3 14.79 38 137.895 1 1 0.4 0 3.10 3.10 80S 5.54 12.5 4.85 23.69 Yes3 A312 TP304/304L 88.9 14.79 38 137.895 1 1 0.4 0 4.57 4.57 80S 7.62 12.5 6.67 22.00 Yes4 A312 TP304/304L 114.3 14.79 38 137.895 1 1 0.4 0 5.88 5.88 80S 8.56 12.5 7.49 19.07 Yes6 A312 TP304/304L 168.3 14.79 38 137.895 1 1 0.4 0 8.65 8.65 80S 10.97 12.5 9.60 16.48 Yes8 A312 TP304/304L 219.1 14.79 38 137.895 1 1 0.4 0 11.27 11.27 100 15.09 12.5 13.20 17.46 Yes

10 A312 TP304/304L 273.0 14.79 38 137.895 1 1 0.4 0 14.04 14.04 100 18.26 12.5 15.98 16.93 Yes12 A312 TP304/304L 323.8 14.79 38 137.895 1 1 0.4 0 16.65 16.65 100 21.44 12.5 18.76 16.76 Yes14 A312 TP304/304L 355.6 14.79 38 137.895 1 1 0.4 0 18.29 18.29 100 23.83 13.5 20.61 16.76 Yes16 A312 TP304/304L 406.4 14.79 38 137.895 1 1 0.4 0 20.90 20.90 100 26.20 14.5 22.40 15.90 Yes

Where: tm = Minimum required wall thickness, mmt = Pressure design thickness, mmP = Internal design gage pressure, MPaD = Outside pipe diameter, mmS = Material allowable stress value, MPa (Table A-1,of ASME B31.3-2010 at ambient temperature)Y = Coefficient value (Table 304.1.1) for t<D/6E = Quality factor (Table A-1A/B, ASME B31.3-2010)W= Weld Joint strength reduction factor as per Table 302.3.5, ASME B31.3, 2010c = Sum of allowances (corrosion, mechanical, etc..)

Notes: 1) Wall thickness calculation based on Thrd Pipe / Thrd. Fittings2) Wall thickness calculation based on Plain Pipe / Socket Weld Fittings

Selected Pressure Verification

Dense phase (HVP) CO2 CLASS 900C6B31.3

Size Linepipe Design Pressure C.A. Calc W.T.* Selected WT Hoop Stress StressNPS Material (kPag) (mm) (mm) mm (kPa) Level

4 CSA Z245.1 GR 386 CAT II 14,790 1.3 5.30 5.60 150937 39%6 CSA Z245.1 GR 386 CAT II 14,790 1.3 7.20 7.90 157542 41%8 CSA Z245.1 GR 386 CAT II 14,790 1.3 9.00 9.50 170552 44%

10 CSA Z245.1 GR 386 CAT II 14,790 1.3 10.90 11.10 181944 47%12 CSA Z245.1 GR 386 CAT II 14,790 1.3 12.60 12.70 188602 49%14 CSA Z245.1 GR 386 CAT II 14,790 1.3 13.70 14.30 183892 48%16 CSA Z245.1 GR 386 CAT II 14,790 1.3 15.50 15.90 189014 49%

PIPE WALL THICKNESS CALCULATIONS SUMMARY FOR

BURIED PIPELINE (CSA Z662-07)

* calculated wall thickness required also include consideration for combined stress(es) for straight sections of buried line pipe.

03200_0_SP_PQ_00003.00_Rev1_AppB Page 2 of 2

Client: Line Number:Project #: Fluid:Project Name: NPS:SECTION 1: Calculation Criteria

Unrestrained - AG Sour ServiceUnrestrained - BG x Sweet Service

X Restrained - BG

SECTION 2: Pressure Design for Steel Line Pipe (Paragraph 4.3.3)

Formula =

where: 14,790 kPa386 MPa

114.3 mm0.8000.8001.0001.000

3.4 mm 0.000 inches1.3 mm 0.051 inches0.0 mm 0.000 inches0.0 mm 0.000 inches

4.7 mm 0.000 inches

5.6 mm 0.220 inches

4.3 mm 0.000 inches

SECTION 3: Hoop Stress (Paragraph 4.6.5)

Formula =

197 MPaCalculated Hoop Stress (Sh)

Min Required Wall Thickness (tmin)

Selected Wall Thickness

Actual W.T. less Allowances (tn) (for calcs)

Corrosion Allowance (tc)Thread Allowance (tth)Inspection Allowance t(i)

Minimum Required Wall Thickness (tmin) tmin = t + tc + tth + ti

Joint Factor (J) See Table 4.3Temperature Factor (T) See Table 4.4

Design Wall Thickness (t)

Design Pressure / MOP (P)Specified Mininimum Yield Strength (S)Outside Pipe Diameter (D)Design Factor (F) See paragraph 4.3.6Location Factor (L) See Table 4.2

Required by AR 122/87 Section 13

Refer to Paragraph 4.6.2 regarding Above Ground Restrained piping

Quest CCS Project 4

ALBERTA CSA Z662-07 Wall Thickness Calculation - Rev. 1Shell Canada Energy N/A

09223 Dense phase (HVP) CO2

TJLF1000D

tS2P ⋅⋅⋅⋅⋅⋅⋅

=

1000t2DPS

nh ⋅⋅

⋅=

14,790 kPa4.3 mm

114.3 mm51%

SECTION 4: Longitudinal Compression Stress (Paragraph 4.7.1)Formula =

(139.7) MPa1.20 E-05 C-1

0.30196.6 MPa

207,000 MPa60 C

-20 C

SECTION 5: Combined Stress (Paragraph 4.7.1)Formula =

347.4 MPa336.3 MPa

97%(139.7) MPa196.6 MPa

1.0

SECTION 6: SUMMARY

Doc. No.: 09223-0-SP-PQ-00001.00

AEUB sour service BELOW ground piping 60% N/AAEUB sour service ABOVE ground piping 50% N/A

RESULT OF WALL THICKNESS CALC. (Section 3) PASS

RESULT OF COMBINED STRESS CALC. (Section 5) PASS

Maximum Allowable Stress Calculated Combined Stress Percentage of Allowable (%)Longitudinal Stress (Sl) Hoop Stress (Sh)Temperature Factor (T)

Hoop Stress (Sh)Modulus of Elasticity of Steel (Ec)Max. Operating Temp. (T2)Ambient Temp.at time of Restraint (T1)

Alberta Regulaton 91/2005 Sec 16

Calculated Longitudinal Stress (Sl) Coefficient of Thermal Expansion (α)Poisson's Ratio (ν)

p ( h)Design Pressure (P)Nominal Pipe Thickness, less allowances (tn)Outside Pipe Diameter (D)Design Stress Level (% SMYS)

( )12chl TTESS −α⋅−⋅ν=

TS90.0SS lh ⋅⋅≤−



X Restrained - BG


Formula =


168.3 mm0.8000.8001.0001.000


6.3 mm 0.000 inches

7.9 mm 0.311 inches

6.6 mm 0.000 inches


Formula =












Quest CCS Project 6



TJLF1000D

tS2P ⋅⋅⋅⋅⋅⋅⋅

=

1000t2DPS

nh ⋅⋅

⋅=

14,790 kPa6.6 mm

168.3 mm49%


(142.1) MPa1.20 E-05 C-1

0.30188.6 MPa

207,000 MPa60 C

-20 C


347.4 MPa330.7 MPa

95%(142.1) MPa188.6 MPa

1.0

SECTION 6: SUMMARY

Doc. No.: 09223-0-SP-PQ-00001.00










TS90.0SS lh ⋅⋅≤−



X Restrained - BG


Formula =


219.1 mm0.8000.8001.0001.000


7.9 mm 0.000 inches

9.5 mm 0.374 inches

8.2 mm 0.000 inches


Formula =












Quest CCS Project 8



TJLF1000D

tS2P ⋅⋅⋅⋅⋅⋅⋅

=

1000t2DPS

nh ⋅⋅

⋅=

14,790 kPa8.2 mm

219.1 mm51%


(139.4) MPa1.20 E-05 C-1

0.30197.6 MPa

207,000 MPa60 C

-20 C


347.4 MPa337.0 MPa

97%(139.4) MPa197.6 MPa

1.0

SECTION 6: SUMMARY

Doc. No.: 09223-0-SP-PQ-00001.00










TS90.0SS lh ⋅⋅≤−



X Restrained - BG


Formula =


273.0 mm0.8000.8001.0001.000


9.5 mm 0.000 inches

11.1 mm 0.437 inches

9.8 mm 0.000 inches


Formula =












Quest CCS Project 10



TJLF1000D

tS2P ⋅⋅⋅⋅⋅⋅⋅

=

1000t2DPS

nh ⋅⋅

⋅=

14,790 kPa9.8 mm

273.0 mm53%


(136.9) MPa1.20 E-05 C-1

0.30206.0 MPa

207,000 MPa60 C

-20 C


347.4 MPa342.9 MPa

99%(136.9) MPa206.0 MPa

1.0

SECTION 6: SUMMARY

Doc. No.: 09223-0-SP-PQ-00001.00










TS90.0SS lh ⋅⋅≤−



X Restrained - BG


Formula =


323.8 mm0.8000.8001.0001.000






Formula =

210 MPa

Design Pressure / MOP (P)Specified Mininimum Yield Strength (S)Outside Pipe Diameter (D)Design Factor (F)Location Factor (L)Joint Factor (J)Temperature Factor (T)


ALBERTA CSA Z662-07 Wall Thickness Calculation - Rev. 1

Inspection Allowance t(i)

Minimum Required Wall Thickness (tmin)Min Required Wall Thickness (tmin)

Corrosion Allowance (tc)Thread Allowance (tth)

Calculated Hoop Stress (Sh)



See Table 4.2See Table 4.3See Table 4.4

tmin = t + tc + tth + ti



See paragraph 4.3.6

Shell Canada Energy09223

Quest CCS Project

N/ADense phase (HVP) CO2

12

TJLF1000D

tS2P ⋅⋅⋅⋅⋅⋅⋅

=

1000t2DPS

nh ⋅⋅

⋅=

14,790 kPa11.4 mm

323.8 mm54%


(135.7) MPa1.20 E-05 C-1

0.30210.0 MPa

207,000 MPa60 C

-20 C


347.4 MPa345.8 MPa100%

(135.7) MPa210.0 MPa

1.0

SECTION 6: SUMMARY

Doc. No.:

AEUB sour service BELOW ground piping 60%

09223-0-SP-PQ-00001.00

RESULT OF COMBINED STRESS CALC. (Section 5)

p ( h)Design Pressure (P)


Nominal Pipe Thickness, less allowances (tn)Outside Pipe Diameter (D)Design Stress Level (% SMYS)

Temperature Factor (T)

Hoop Stress (Sh)

Longitudinal Stress (Sl) Hoop Stress (Sh)

Maximum Allowable Stress Calculated Combined Stress


AEUB sour service ABOVE ground piping 50%

RESULT OF WALL THICKNESS CALC. (Section 3)

Percentage of Allowable (%)

Modulus of Elasticity of Steel (Ec)Max. Operating Temp. (T2)Ambient Temp.at time of Restraint (T1)

N/A

PASS

N/A

PASS


TS90.0SS lh ⋅⋅≤−



X Restrained - BG


Formula =


355.6 mm0.8000.8001.0001.000






Formula =















TJLF1000D

tS2P ⋅⋅⋅⋅⋅⋅⋅

=

1000t2DPS

nh ⋅⋅

⋅=

14,790 kPa13.0 mm

355.6 mm52%


(138.0) MPa1.20 E-05 C-1

0.30202.3 MPa

207,000 MPa60 C

-20 C


347.4 MPa340.3 MPa

98%(138.0) MPa202.3 MPa

1.0

SECTION 6: SUMMARY

Doc. No.: 09223-0-SP-PQ-00001.00










TS90.0SS lh ⋅⋅≤−



X Restrained - BG


Formula =


406.4 mm0.8000.8001.0001.000






Formula =















TJLF1000D

tS2P ⋅⋅⋅⋅⋅⋅⋅

=

1000t2DPS

nh ⋅⋅

⋅=

14,790 kPa14.6 mm

406.4 mm53%


(137.0) MPa1.20 E-05 C-1

0.30205.8 MPa

207,000 MPa60 C

-20 C


347.4 MPa342.8 MPa

99%(137.0) MPa205.8 MPa

1.0

SECTION 6: SUMMARY

Doc. No.: 09223-0-SP-PQ-00001.00










TS90.0SS lh ⋅⋅≤−




07-2-LA-7180-0005 1 of 31 Project



Appendix F

Coating Specifications

90000-1-FM-00012 Rev4 (2010.12.08)

Quest CCS Project

Line Pipe Coating Specification


1 2011.07.14 Re-Issued for Purchase MZ KIA KIA

0 2011.07.05 Issued for Purchase MZ KIA KIA


Tri Ocean Document No. 09223-0-SP-PQ-00002.00

Client Document No. 07-2-LA-7880-0008

Revision No. 1

Page 1 of 6




07-2-LA-7880-0008 Page

2 of 6 Project



Table of Contents

1. Scope 3

2. Project Information 3

3. Applicable Regulations, Codes, Standards and Specifications 3

4. Coating Design Conditions 3

5. Coating Qualification Testing Requirements 4

6. General Requirements 4

Appendices

Appendix A Excerpt for Line Pipe Coating Specifications Appendix B ESTG 19-2.11 External Shop Coating for Pipe for Underground Service




07-2-LA-7880-0008 Page

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1. Scope

This specification outlines the requirements of steel line pipe coating for Quest CCS Pipeline project for Shell Canada.

2. Project Information

Project description: Shell Quest is a fully integrated Carbon Capture and Sequestration (CCS) project. It will capture up to 1.2 million tones of CO2 per year from the Scotford Upgrader and the CO2 will be transported in dense phase by pipeline to an injection location near the Scotford Complex and stored approximately 2,300 meters underground in a deep geological formation.

3. Applicable Regulations, Codes, Standards and Specifications

The line pipe coating shall meet or exceed all of the requirements of the following codes and standards together with additional requirements set forth in this specification.

CSA Z662-07 Oil and Gas Pipeline Systems

CSA Z245-20 Specification for coating qualification and testing

Shell ESTG 19-2.11 External Shop Coating for Pipe for Underground Service

All other Codes and Standards referenced by the above Codes and Standards

In the event of conflict between this specification, Shell ESTG 19-2-11 and CSA code, the Purchaser shall be advised and will decide which document will govern.

4. Coating Design Conditions

The Quest pipeline has two segments consisting of a 323.9 mm ERW pipe of 12.7 mm wall thickness and 168.3 mm ERW pipe of 7.9 mm wall thickness. The pipeline will transport CO2 in dense phase. There is a possibility that during normal operating conditions involving line de-pressurization, the metal temperature of the pipeline will drop from to a minimum of -70°C. This temperature drop may be associated with a differential in thermal expansion/contraction in the pipe versus coating.




07-2-LA-7880-0008 Page

4 of 6 Project



MDMT is -45°C with excursions to -60°C

Design temp is +60°C

The NPS 12 pipe wall thickness is 12.7 mm and 14.3 mm for heavy wall portion and the pipe grade is CSA Z245.1-07 Grade 386 CAT II.

The NPS 6 pipe wall thickness is 7.9 mm and the pipe grade is CSA Z245.1-07 Grade 386 CAT II.

5. Coating Qualification Testing Requirements

The coating needs to meet the minimum requirements for adhesion strength and cathodic disbondment stipulated in CSA Z245-20.

In addition to the minimum coating requirements specified in ESTG 19-2.11, the following testing is required:

1. Adhesion test carried out at -70°C using the knife procedure

2. Thermal cycle from -70°C to +45°C followed by adhesion testing

6. General Requirements

Line pipe specification: CSA Z245.1-07 Grade 386 CAT II

The following coating shall be used for the line pipes:

a) Line Pipe Coating – Fusion Bonded Epoxy

Powder Manufacturer: 3M

Applicator: Shaw Pipe

Coatings: 3M Sktochkote 134 or 3M 6233 as per manufacturer’s specifications.

i) Nominal Outside Diameter: 323.9 mm


Quantity = 81500 m




07-2-LA-7880-0008 Page

5 of 6 Project



ii) Nominal Outside Diameter: 168.3 mm


Quantity =11,000 m

b) Horizontal Directional Drilling Pipe Coating – Dual layer Fusion Bonded Epoxy

Same 3M powder for line pipe coating shall be applied in dual layer with additional qualification testing for dual layer.

i) Nominal Outside Diameter: 323.9 mm


Quantity = 1000 m

ii) Nominal Outside Diameter: 323.9 mm


Quantity = 1000 m

c) Induction Bends Coating and Girth Welds – Liquid Epoxy

Manufacturer: Canusa CPS

Applicator: ShawCor CPS

Coatings: HBE 95 spray grade and brush grade for girth welds as per manufacturer’s specifications.

i) 323.9 mm OD 12.7 mm WT 20D 900 Induction Bend ERW

Quantity = 33 Nos.

ii) 323.9 mm OD 12.7 mm WT 20D 980 Induction Bend ERW

Quantity = 1 No.

iii) 323.9 mm OD 12.7 mm WT 20D 750 Induction Bend ERW

Quantity = 2 Nos.




07-2-LA-7880-0008 Page

6 of 6 Project



iv) 323.9 mm OD 12.7 mm WT 20D 650 Induction Bend ERW

Quantity = 8 Nos.

v) 323.9 mm OD 12.7 mm WT 20D 550 Induction Bend ERW

Quantity = 5 Nos.

vi) 323.9 mm OD 12.7 mm WT 20D 500 Induction Bend ERW

Quantity = 2 Nos.

vii) 323.9 mm OD 12.7 mm WT 20D 450 Induction Bend ERW

Quantity = 5 Nos.

viii) 168.3 mm OD 7.9 mm WT 20D 900 Induction Bend ERW

Quantity = 4 Nos.

ix) 168.3 mm OD 7.9 mm WT 20D 600 Induction Bend ERW

Quantity = 2 Nos.

x) 168.3 mm OD 7.9 mm WT 20D 500 Induction Bend ERW

Quantity = 1 No.

xi) 168.3 mm OD 7.9 mm WT 20D 450 Induction Bend ERW

Quantity = 12 Nos.




07-2-LA-7880-0008 Page

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Appendix A

Excerpt for Line Pipe Coating Specifications

Irina Ward May18,2011‐ DRAFT

Quest Project Pipeline Coating Specifications:

Governing Specifications External Coating specifications the Quest Pipeline shall follow ESTG 19‐2‐11 Shop applied pipeline coatings and 19‐3.11 Field applied pipeline coatings for girthwelds . These specifications are based on CSA Z662 code and follow CSA Z245‐20 specification for coating qualification and testing.

Coating Design Conditions

The Quest pipeline is a 12inch ERW pipe of 12.7mm wall thickness and transports CO2 in dense phase. There is a possibility that during normal operating conditions involving line de‐pressurization, the metal temperature of the pipeline will drop from to a minimum of – 70 deg C. This temperature drop may be associated with a differential in thermal expansion/contraction in the pipe versus coating.

• MDMT is ‐45degC with excursions to – 60 degC • Design temp is +43C • The pipe thickness will likely by 12.7mm and the pipe grade may be CSA Z2451 grade

359 OR (more likely) grade 386.

The pipeline is composed of straight sections as well as bends and horizontal directional drilled sections which will need different types of coatings. It is understood that the straight pipeline sections as well as the horizontal direction drilled ones will only see minimum and maximum temperatures associated with the operating conditions . The bends however may be exposed to the maxium temperatures encountered by pipeline risers in the summer/winter months. The design conditions captured above are conservative in capturing the minimum coatig requirements.

Coating Qualification Testing Requirements

The coating needs to meet the minimum requirements for adhesion strength and cathodic disbondment stipulated in CSA Z245‐20.

Unless already covered by the product documentation and in addition to the minimum coating requirements specified in ESTG 19‐2.11, the following testing is required and needs to be specified in the purchasing documents:

1. Adhesion test carried out at ‐70 degC using the knife procedure 2. Thermal cycle from ‐70 degC to +45degC followed by adhesion testing

Coating Recommendations For the project the following coating systems are required:

A. Linepipe Coating‐ Fusion Bond Epoxy Powder manufacturer: 3M Applicator: Shaw Pipe Coatings: 3M Sktochkote 134 or

3M 6233 as per attached specifications

3M 6233 Data Sheet.pdf

skotchkote 134.pdf

B. Induction bends Coating and Girth Welds – Liquid Epoxy Manufacturer: Canusa Applicator: ShawCor CSI Coatings: HBE 95 spray grade and brush grade for the girthwelds

HBE-95 spray grade,PDS.pdf

Test Report HBE-95 at -70C adhesion test

C. Horizontal Direction Drilling Pipe Coating‐ Dual Layer Fusion Bond Epoxy

Still under review‐ looking at the same 3M powder applied in dual layer but need qualification testing.




07-2-LA-7880-0008 Page

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Appendix B

ESTG 19-2.11 External Shop Coating for Pipe for Underground Service




07-2-LA-7180-0005 1 of 18 Project



Appendix G

Control Narrative

Quest CCS Project

Control Narrative


D 2011.07.20 Re-Issued for HAZOP SJD JGL MCS

C 2011.04.21 Issued for Client Review SJD NES MCS

B 2011.04.13 Issued for HAZOP SJD NES MCS

A 2011.03.29 Issued for Internal Review SJD JGC MCS


Tri Ocean Document No. 09223-0-PH-JQ-00001.00

Client Document No. 249.1611.000.012.001

Revision No. D

Page 1 of 17


09223-0-PH-JQ-00001.00 Revision No.

D Client Document No.

249.1611.000.012.001 Page

2 of 17 Project


Control Narrative

Table of Contents

1. Introduction 3 1.1 Abbreviations 3 1.2 Project Background 3

2. Project Scope 4

3. Control System Overview 5 3.1 Wellsite Packages 5

3.1.1 Wellsite Control and Shutdown Functionality 9 3.2 Measurement, Mitigation and Verification (MMV Data) 11 3.3 Pipeline Leak Detection 11 3.4 Pipeline LBV Packages 12

3.4.1 LBV Control and Shutdown Functionality 14 3.5 CO2 Metering (Capture Facility and Well Sites) 15 3.6 SCADA PLC and CO2 Facility Interface 16

4. Control System Commissioning 16

5. Reference Documents 17 5.1 Process Design Basis 17 5.2 P&ID 17 5.3 Instrument Index 17 5.4 Shutdown Key 17

Tables

Table 3.1-1 Well Site Instruments 8 Table 3.2-1 LBV Site Instruments 14 Table 3.3-1 Metering Locations 15




249.1611.000.012.001 Page

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Control Narrative

1. Introduction

This document describes the Control Philosophy & Design for the Shell Quest CCS Pipeline and Well Tie-ins. The project schedule has identified that construction for this site is to begin in February 2012.

1.1 Abbreviations

The following abbreviations are used in this document:

CCR Central Control Room

CCS Carbon Capture and Sequestration

CSA Canadian Standards Association

DCS Distributed Control System

ESD Emergency Shutdown

LBV Line Break Valve

PLC Programmable Logic Control

RTU Remote Terminal Unit

SCADA Supervisory Control and Data Acquisition

SDK Shutdown Key

SMR Steam Methane Reformer

1.2 Project Background

Shell Quest is a fully integrated Carbon Capture and Sequestration (CCS) project. It will capture and store up to 1.2 million tonnes of CO2 per year from the Scotford Upgrader and the Scotford Upgrader Expansion.

The CO2 will be captured from the Scotford steam methane reformer (SMR) units. The CO2 is then compressed, cooled and sent for transportation by pipeline to injection wells located near the Scotford Complex. The CO2 is injected into an aquifer at a depth of approximately 2,300 meters underground.




249.1611.000.012.001 Page

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Control Narrative

The CO2 produced by the Scotford facility will be metered as it leaves the compressor but before it is cooled (the CO2 will be in a single phase and will be easier to measure) and at each of the well sites. The high accuracy metering will be used for leak detection, production accounting and allocation. All process and equipment status data will be passed between Scotford, the CO2 pipeline and the injection well sites via SCADA network. This information will be made available to operations through the DCS.

Note: the actual amount of data to be passed from each facility has not yet been determined so development will proceed based on a standard wellsite data requirement.

2. Project Scope

Tri Ocean Engineering scope of work consists of the following:

Design and installation of a buried high pressure pipeline that will be used to transport dehydrated, compressed, liquid/dense phase CO2.

The development of five (5) CO2 injection well sites in the CO2 storage area near Radway and Thorhild, Alberta.

Design, develop and supply pigging facilities for the pipeline.

Design, develop and supply Line Break Valve packages which will include the associated monitoring and control for the LBV valves.

Design and installation of a new pipeline and wellsite SCADA system that includes a local RTU at each well site and all the associated site instrumentation (see instrument index) for monitoring, control and shutdown. This system function is to include the collection and transmission of data from the pipeline and well sites back to the capture facility (Scotford) control room.

Design and development of a new water wells around the CO2 injection well sites shall require monitoring to confirm that the injection site is stable. Actual monitoring requirements to be determined during Detailed Design phase of project.




249.1611.000.012.001 Page

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Control Narrative

The CO2 capture facility, constructed within the Scotford Plant battery limit, will be executed by others. This facility will require both hardwired and a communication interface with the master SCADA PLC. These interfaces will transfer process data from the capture facility (i.e. the local metering skid, the CO2 compressor, etc.) for control and shutdown of the pipeline. The metering skid will be used as an integral part of the leak detection on the pipeline system.

3. Control System Overview

The Quest CCS pipeline control system design has a limited I/O requirement but requires process measurement and control that is spread over the length of the pipeline. The SCADA control system is comprised of five (5) segments:

1) Wellsite packages (5 total); these packages will include reservoir monitoring for each of the well sites.

2) Pipeline LBV packages (7 total)

3) CO2 Metering (capture facility and well sites)

4) SCADA Master PLC and CO2 capture facility – control and shut down interface

5) Water well sites (used for CO2 injection monitoring)

3.1 Wellsite Packages

A preliminary total of five (5) well sites are positioned near the end of the main CO2 distribution pipeline. Each of the well sites will be supplied with a local RTU and the associated field and injection well instrumentation. This instrumentation will consist of the following:

RTU-702x00 – control and shutdown equipment will be used to monitor site conditions and provide both control and shutdown functionality. The wellsite RTU provides I/O for the site instrumentation, control and shutdown logic, and transfers data between the well site and Scotford. The RTU is housed in a dedicated enclosure and is supplied with ancillary equipment (i.e. radio, antenna, mast, solar panels and batteries).




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Control Narrative

PDIT-702x02 – this differential pressure transmitter measures the D/P across the CO2 Particulate Filter (S-70201) and alarms on a high differential pressure. The measurement is recorded and may initiate alarms only (no shutdown will occur from this measurement).

PSV-702x01 – this pressure relief valve is mounted on the CO2 particulate filter (S-70201) to protect the filter from overpressure. The PSV is sized for thermo relief case.

TIT-702x03 – this temperature transmitter is installed to monitor the temperature upstream of the flow control valve (FCV-702x04). This measurement is used detect any abnormal temperature conditions within the process. The measurement is recorded and may initiate alarms only (no shutdown will occur from this measurement).

FIT-702x04 – this coriolis type flow meter will monitor CO2 flow (kg/hr) to the well. The flow data will be totalized in the RTU, sent to the host for the mass balance calculation. The flow rate (kg/hr) will also be used as the process variable for flow controller (FIC-702x04). The measurement is recorded and may initiate alarms only (no shutdown will occur from this measurement).

FCV-702x04 – this control valve is used to control the CO2 flow rate to the injection well. Control of this valve shall be determined by the status of a number of process variables:

a) (PIC-702x03) pressures upstream of the flow control valve

b) (FIC-702x04) injection flow rate

c) (PIC-702x05) pressure at the wellhead

d) (TIC-702x05) temperature at the wellhead

e) (DIC-702x05) density of the process (calculated variable based on pressure and temperature measurements – may be removed)

The PID controllers shall monitor the wellsite process conditions and the controller outputs are connected to low select function blocks. The lowest controller output will control the position of the valve. The control valve actuator may use N2 or O2 as the instrument gas.




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PIT-702x05 – this pressure transmitter is installed to monitor the pressure at the wellhead. This measurement provides the process variable for the direct acting pressure controller (PIC-702x05). The measurement is recorded and may initiate alarms only (no shutdown will occur from this measurement).

PIT-702x07 – this pressure transmitter is installed to monitor the pressure at the wellhead casing pressure. This measurement is used detect any abnormal pressure conditions within the well casing. The measurement is recorded and may initiate alarms only (no shutdown will occur from this measurement).

PIT-702x08 – this pressure transmitter is installed to monitor the downhole / reservoir pressure. The measurement is recorded and may initiate alarms only (no shutdown will occur from this measurement). Note, as a control option, PIT-702x08 may be selected as a process variable for the pressure controller (PIC-702x05). This function is an operator select function enabled with a DCS selector switch (PHS-702-x05).

TIT-702x08 – this temperature transmitter is installed to monitor the downhole / reservoir temperature. The measurement is recorded and may initiate alarms only (no shutdown will occur from this measurement). Note, as a control option, TIT-702x08 may be selected as a process variable for the pressure controller (TIC-702x05). This function is an operator select function enabled with a DCS selector switch (THS-702-x05).

UV-702x06 – the wellsite ESD valve (UV-702x06) function is to isolate the well in the event of an abnormal condition (trips are identified in SDK 09223-0-DG-BD-00001.01). This fire rated 900# ANSI stainless steel ball valve is line size and is supplied with a metal seated full port ball and a self-contained hydraulic actuator assembly.

The shutdown of this valve is initiated from the RTU for either a local control action or remote signal (via SCADA) to the site. To open the valve (for an initial start-up or after a shutdown), all shutdowns need to be cleared or bypassed and then a local manual reset by operations is required, an automatic reset function is not available. Position switches on the valve (ZSC/ZSO-702x06) provide status of valve position to the RTU.




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Control Narrative

SSSV-702x09 – the function of this sub surface valve is to isolate the well down hole in the event where an abnormal condition has occurred. This valve will mirror the action of the site ESD valve. The local SSSV hydraulic panel will shutdown this valve. The shutdown is initiated from either local control actions or remote signal (via SCADA) and is connected to the valve hydraulic panel for the trip. Opening the valve after a trip will require a manual reset by operations, automatic reset is not available.

Table 3.1-1

Well Site Instruments

Tag # Well #1 Well #2 Well #3 Well #4 Well #5

RTU 702100 702200 702300 702400 702500

PSV 702101 702201 702301 702401 702501

DPIT 702102 702202 702302 702402 702502

TIT 702103 702203 702303 702403 702503

PIT 702103 702203 702303 702403 702503

FIT 702104 702204 702304 702404 702504

FV 702104 702204 702304 702404 702504

PIT 702105 702205 702305 702405 702505

TIT 702105 702205 702305 702405 702505

UV 702106 702206 702306 702406 702506

PIT 702107 702207 702307 702407 702507

PIT 702108 702208 702308 702408 702508

TIT 702108 702208 702308 702408 702508

SSSV 702109 702209 702309 702409 702509




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Control Narrative 3.1.1 Wellsite Control and Shutdown Functionality

CO2 is delivered to the well sites by the pipeline. Flow measurement of the CO2 to each well site is accomplished with a coriolis meter. Note: two phase flow is a difficult process to measure accurately. CO2 at steady state conditions will be in a dense phase and will allow accurate measurement of the flow to the well sites. Each flow transmitter will provide process information (i.e. mass flow (kg/hr), density (kg/m3), etc.) for the flow control loop (as process variable). The measurement shall also be used with the mass balance calculation of the pipeline and to assist in monitoring and determination of a pipeline leak. Flow totalization for each site will occur within the RTU.

Each well site has a number of transmitters to monitor process variables within the piping, wellhead casing and within the reservoir. Some of the transmitters provide a process variable for a PID controller while the others are for indication and alarming.

3.1.1.1 Control Functions

The flow control valves (FV-702x04) is the only final automated control element at each site. This valve has a number of PID controllers that have the potential to control its actions. In normal operating conditions, the flow controller (FIC-702x04) will be the primary control for the valve. If abnormal conditions appear, selection of the controlling PID is performed by logic within the RTU. The control variables that could control valve actions are as follows:

PIC-702x03 – this direct acting controller monitors the pressure upstream of the flow control valve. The setpoint (sent to the RTU from the DCS via the SCADA interface) for the controller is set lower that the normal operating pressure. In normal operating conditions, the controller output will be high because the measured process pressure is higher that the setpoint. The RTU low select logic will not select this controller output for the valve. In the event were the measured pressure drops below the setpoint (i.e. LBV trips, pipeline leak, etc.) that controller output will start to drop, once it is less that the other controller output, it will now control valve action and cause the valve to close.




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Control Narrative

FIC-702x04 - this reverse acting controller monitors the CO2 flow rate to the injection well. The setpoint (sent to the RTU from the DCS via the SCADA interface) for the flow control is based on storage allocations for each well injection flow rate. The flow controller is the primary controller at the well site to maintain the CO2 flow rate to the well. If, in the event an abnormal condition is occurring, one of the other site controllers may adjust to the condition so that their output is selected by the RTU low select logic.

PIC-702x05 - this reverse acting controller monitors the pressure at the wellhead or the reservoir. The setpoint (sent to the RTU from the DCS via the SCADA interface) for the controller is set higher that the normal operating pressure. Selection of the process variable for this controller is made by operations with the DCS selector switch (PHS-702x05) which will allow selection between the wellhead or the reservoir pressures. In normal operating conditions, the controller output will be high because the measured process pressure is lower that the setpoint. The RTU low select logic will not select this controller output for the valve. In the event were the measured pressure raises above the setpoint (i.e. well or reservoir plugging, etc.) that controller output will start to drop, once it is less that the other controller outputs, it will now control valve action and cause the valve to close.

TIC-702x05 - this direct acting controller monitors the temperature at the wellhead or the reservoir. The setpoint (sent to the RTU from the DCS via the SCADA interface) for the controller is set lower that the normal operating temperature. Selection of the process variable for this controller is made by operations with the DCS selector switch (THS-702x05) which will allow selection between the wellhead or the reservoir temperature. In normal operating conditions, the controller output will be high because the measured process temperature is higher that the setpoint. The RTU low select logic will not select this controller output for the valve. In the event were the measured temperature drops below the setpoint (i.e. well or reservoir upset, etc.) that controller output will start to drop, once it is less that the other controller outputs, it will now control valve action and cause the valve to close.

DIC-702x05 - density of the process at the wellhead or reservoir is a calculated variable based on pressure and temperature measurements. Control action for this controller is still to be determined. This controller may be removed.




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Control Narrative

Each well site has been provided with a CO2 vent which has the ability to vent the pipeline. The vent is located downstream of the flow meter. The venting procedure is a manual operation. This vent may also be used to vent the wellsite piping.

3.1.1.2 Shutdown Functions

The well sites have a shutdown valve (UV-702-x06) on the piping to the wellhead and a SSSV (UV-702x09) which is located downhole. When shutdown signal is received by the RTU, trip signals will be sent to the shutdown valves to isolate the well. The instrumentation (i.e. transmitters, etc.) at the site provide only monitoring and alarms, they do not cause any shutdowns.

3.2 Measurement, Mitigation and Verification (MMV Data)

Each well site shall have a number of monitoring wells surrounding the injection well which will be continuously monitored to provide reservoir data. This monitoring shall include line of site CO2 measurement with laser detection, video surveillance and a number of measure technologies for the reservoir and surrounding areas. This section is still in development and identification and technology selections are made.

3.3 Pipeline Leak Detection

The CO2 pipeline and well sites shall be continuously monitored. This monitoring shall be used for the detection of a pipeline leak. The leak detection shall use an internally based leak detection system. It shall be based upon the principles indentified in CSA Z662 Oil and Gas Pipeline Systems – Annex E “Recommended practise for liquid hydrocarbon pipeline system leak detection”. Any leak that is detected by the system shall initiate a procedure for the isolation of the affected area. This isolation includes a procedure which closes all the LBV and wellsite shutdown valves.

The internal based leak detection system shall utilize the field instrumentation, located at various locations throughout the length of the pipeline, to monitor the pipeline conditions (i.e. flows, pressures, and temperatures). Multiple methods for detection are planned for this project:




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Control Narrative

a) Leak detection using the pressure measurement – pressure transmitters located upstream and downstream of the LBVs shall supply pipeline pressure data which is used to determine if abnormal condition are present in the pipeline. If pressures reading at the same location differ greater that a pre-determined differential, an alarm is generated to notify operations of the abnormal condition. Operations will then review and determine the cause for the alarm and this may initiate a shutdown of the pipeline.

b) Leak detection using flow metering (coriolis meters) – comparing the mass flow of CO2 with the Scotford coriolis meter (custody transfer meter) to the sum of the mass flows from the coriolis meters (custody transfer meters) at the individual CO2 injection wells. The material balance calculation will consider all uncertainties associated with pipeline transmission of the CO2. If the mass flow reading differs greater than a pre-determine differential, an alarm is generated to notify operations of the abnormal condition. Operations will then review and determine the cause for the alarm and this may initiate a shutdown of the pipeline.

c) Leak detection using mass or material balance – this method uses mathematical formulas that are based on laws of conservation of mass/matter “states that the mass of a closed system will remain constant over time”. This procedure will utilize many factors in determining if a leak in the pipeline is occurring. Details of this system shall be developed during Detailed Design phase of the project. A detailed leak detection manual shall be prepared which will provide system mapping (detailed descriptions of each of the pipeline sections, a summary of the production specifications, a description of each of the measurement devices and how the data is gathered, etc.).

3.4 Pipeline LBV Packages

The CO2 pipeline has protection from a line rupture and equipment to reduce the impact from loss of containment. The 12” pipeline will have Line Break Valves (LBV) packages located throughout the pipeline, starting with the first valve at the inlet to the pipeline (at Scotford), and then located at intervals of approximately every 10-15 km (also at each side of the North Saskatchewan River crossing). The LBV packages will contain the following equipment:




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Control Narrative

RTU-249x00 – this equipment will be used to monitor the conditions at the LBV site and provide both shutdown functionality for this site and the remaining LBV sites (to initiate a total pipeline shutdown, upon determination of a pipeline leak or line break). The LBV RTU will provide the transfer of data between the individual LBV sites and Scotford. The RTU equipment is housed in a weatherproof enclosure and is supplied with ancillary equipment (i.e. radio, antenna, mast, solar panels and batteries).

UV-249x02 – the Line Break Valve (LBV) is a self-contained, hydraulically actuated, stainless steel, ball valve that is line size and has a full port ball. The valve has a single metal seat and is designed for high pressure CO2 service. The speed of closure for the LBVs shall be set at 30 seconds (from the full open position to the full closed position). Limiting the speed at which the valves close will limit the momentum of the CO2 flow to minimize the transient pressure surge.

A LBV shutdown is initiated from the RTU for either a local shutdown action or a remote signal (via SCADA) from Scotford. To open the valve (for an initial start-up or after a shutdown), all shutdowns need to be cleared or bypassed and then a local manual reset by operations is required, an automatic reset function is not available. Position switches on the valve (ZSC/ZSO-702x02) provide status of valve position to the RTU.

PIT-249x01– a pressure transmitter installed to monitor the pressure upstream of the LBV. This measurement is an integral part to the leak detection system and detection of any abnormal line conditions could indicate a leak due to the failure of the pipeline. The leak detection logic will then initiate a shutdown of the pipeline. The measurement is also used as a process variable for PID control (PIC-249x01) provides upstream pressure control for venting or when pressurizing the downstream piping. The measurement is recorded, transmitted, and is used to initiate alarms and a low pressure shutdown.

PIT-249x03– a pressure transmitter installed to monitor the pressure downstream of the LBV. This measurement is an integral part to the leak detection system and detection of any abnormal line conditions could indicate a leak due to the failure of the pipeline. The leak detection logic will then initiate a shutdown of the pipeline. The measurement is also used as a process variable for PID control (PIC-249x03) provides downstream pressure control for venting or when pressurizing the downstream piping. The measurement is recorded, transmitted, and is used to initiate alarms and a low pressure shutdown.




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Control Narrative

PV-249x04 – this pressure control valve has two functions. One function is used to pressurize the pipeline downstream of the LBV if that section has been out of service and is depressurized. The second function of this valve is to regulate the flow of CO2 to the vent stack. The low select (PX-249x04) has three (3) inputs (2 pressure controller outputs and 1 manual setpoint) and the output from the low select controls the valve position.

Table 3.2-1

LBV Site Instruments

Tag # LBV #1 LBV #2 LBV #3 LBV #4 LBV #5 LBV #6 LBV #7

RTU 249100 249200 249300 249400 249500 249600 249700

PIT 249101 249201 249301 249401 249501 249601 249701

UV 249102 249202 249302 249402 249502 249602 249702

PIT 249103 249203 249303 249403 249503 249603 249703

PV 249104 249204 249304 249404 249504 249604 249704

3.4.1 LBV Control and Shutdown Functionality

Each LBV site has two pressure transmitters to monitor process variables within the site piping. The transmitters provide two functions for the site 1) a process variable for a PID controller and 2) process variable for line break logic, alarming and shutdown.

3.4.1.1 Control Functions

Each of the LBV packages can be used to vent the pipeline CO2 from either side of the LBV to the atmosphere. When a trip of the LBV occurs, operations have the ability to vent the pipeline pressure (from either the upstream or downstream sections). The manual vent valves will be set in the correct positions (as per the operations guideline). A pressure control valve (PV-249x04) is then manually opened with the RTU manual controller (HC-249x04). The setpoint will be sent from the DCS to the RTU via the SCADA network. The valve will throttle the flow of the CO2 through vent to the atmosphere. The close position switch on the LBV is interlocked and is required to indicate the LBV is closed before the blowdown can commence.




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Control Narrative

It is recommended that the venting of the CO2 will be done under constant supervision of Shell operations. A number of factors impact the venting procedure, wind direction must be confirmed so that the CO2 plume does not travel towards a nearby residence or towards any livestock. It is also anticipated that the venting will generate a high noise level (similar to a jet engine). Further study is required to mitigate the noise impact.

3.5 CO2 Metering (Capture Facility and Well Sites)

The CO2 produced and captured at Scotford is transported to the storage wells located north of the Facility. This process is measured with the custody transfer coriolis mass flow meter (FIT-247004) prior to entering the pipeline. The coriolis meter provides the mass flow (kg/hr) of the CO2 to calculate a totalized flow (FQI-247004) and the mass balance. In addition, the flow meter data is sent to the master pipeline PLC for monitoring the flow of the CO2 leaving Scotford and compares it to the flows of each of the storage wells. The individual flow values provide data for the mass balance calculation for the pipeline.

Metering locations are shown per Table 3.3-1.

Table 3.3-1 Metering Locations

Well Site LSD Tag Number

Scotford Inside Battery Limit* FIT-249004

1 NW Sec 02, 59-20-W4M* FIT-702104

2 NW Sec 20, 59-20-W4M* FIT-702204

3 SW Sec 01, 60-21-W4M* FIT-702304

4 SW Sec 14, 60-21-W4M* FIT-702404

5 NE Sec 29, 60-21-W4M* FIT-702504

* - To be confirmed – see Fluor P&ID 247.0000.000.041.014

Each well site shall have a coriolis mass flow meter measuring the flow rate (kg/hr) of the CO2 that is being injected into the well reservoir. This meter is connected to the local RTU and provides the process variable for wellhead CO2 flow control (FIC-702x04) and provides the process data that is transmitted back to the master PLC (at Scotford) to provided part of the mass balance calculation.

The CO2 pipeline depressurization philosophy is to provide venting of the pipeline utilizing a vent at the Scotford facility. The vented CO2 is not measured.




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Control Narrative 3.6 SCADA PLC and CO2 Facility Interface

The well site and LBV sites have local control RTUs that will communicate the site data back to Scotford via radio on the new pipeline SCADA network. When there is a requirement to transfer data between sites, the master PLC will poll the sites for data, read and process the data and then write data to the corresponding adjacent site. Also, the master PLC provides an Ethernet link and hardwired I/O for interface with other units (i.e. control and shutdown of the CO2 compressor, etc.) located at Scotford facility. Any shutdowns initiated by the pipeline equipment will be hardwired from I/O in the master PLC (located in the compressor MCC) to the Foxboro I/A.

An accurate measurement of the moisture content in the CO2 process, located in the carbon capture facility at Scotford, is extremely important. This data is passed to the pipeline control system because the CO2, with high moisture content, will increase corrosion rates within carbon steel pipelines, so an accurate measurement will provide assurances that accelerated corrosion to the pipeline is prevented. The moisture analyzer (AIT-247001) is connected to the Scotford control system and provides continuous monitoring (AI-247001) of the process water content. A high moisture alarm (AAH-247001) is generated from this measurement. At present, there is no shutdown (AAHH-247001) action planned for a high moisture measurement in the CO2.

Control and shutdown for the pipeline equipment located at the inlet to the pipeline will be handled by the master PLC (located in the TBD). It is planned to have any equipment (i.e. CO2 compressor, etc.), which is supplied by other, to be hardwired to this system for control and shutdown if there is an impact to the pipeline. Communication to Scotford facility will be by a fibre optic Ethernet link between the master control PLC and the Foxboro DCS.

Note: The final design for the interface of pipeline signals to the compressor logic will be developed during the Detailed Design phase of the project

4. Control System Commissioning

Each of the facilities will be unmanned and will require a reliable communication link to Scotford. This communication will be through a radio link developed in this project. The new SCADA network will incorporate the wellsites (5), the LBV sites (7) on the pipeline and pipeline equipment located within the Scotford battery limits. This interface will allow operations to collect real-time data from each site. This interface shall provide operations the following information:




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Control Narrative

Monitor individual LBV sites and injection well sites for process data values, equipment statuses and alarm conditions

Provide control and shutdown capabilities of individual facilities or a shutdown of entire pipeline and well sites

The process instrumentation and control schemes are defined on the P&IDs, with additional information from the Instrument Index, I/O Schematics and Shutdown Key. These documents shall be used by the Contractor in the development of the RTU programming. Any changes/modification that deviates from the original design will be red-lined on the effected document.

The site specific Instrument Index shall be used to aid in clarifying the scope and shall be used by Shell and the I&E Contractor for a complete instrument listing and to allow a cross reference of all instrument end devices with ranges and setpoints. This information will assist in determining which SCADA values will need to be transmitted.

5. Reference Documents

The following is a list of reference documents:

5.1 Process Design Basis

09223-1-DB-BQ-00001.00

5.2 P&ID

249.0000.000.041.001 – 010 Pipeline P&IDs

702.0000.000.041.001 – 010 Wellsite P&IDs

5.3 Instrument Index

09223-0-LI-JN-00001.00 Instrument Index

5.4 Shutdown Key

09223-0-DG-BD-00001.00 Shutdown Key




07-2-LA-7180-0005 1 of 48 Project



Appendix H

Cause and Effect Diagrams (Shutdown Key)




07-2-LA-7180-0005 1 of 48 Project



Appendix I

Instrument Index