kei-pl-2102t~0_flowline carbon steel spec

Project TERANGSIRASUNB

ATUR FIELD DEVELOPMENT

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KANGEAN ENERGY INDONESIA LTD

Document Number KEI-PL-2102T

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Document Type Specification

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TABULATION OF REVISED PAGES

SHEET REVISIONS SHEET REVISIONS

A A1 B 0 1 2 3 4 A B C 0 1 2 3 4 1 x 51 2 x 52 3 x x 53 4 x x 54 5 x 55 6 x x x 56 7 x 57 8 x x x 58 9 x 59

10 x x 60 11 x x 61 12 x x x 62 13 x 63 14 x x 64 15 x 65 16 x x 66 17 x 67 18 x 68 19 x x 69 20 x x 70 21 x x x 71 22 x x 72 23 x 73 24 x x 74 25 x 75 26 x x x 76 27 x 77 28 x x 78 29 x 79 30 x x 80 31 x 81 32 x 82 33 x x 83 34 x 84 35 x x 85 36 x x 86 37 x x x x 87 38 x x 88 39 x x 89 40 x x 90 41 x x ATTACHMENT APPENDIX 42 x 1 A 43 2 B 44 3 C 45 4 D 46 5 E 47 6 F 48 7 G 49 8 H 50 9 I



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TABLE OF CONTENTS Page

1.0 INTRODUCTION .......................................................................................................................... 5

1.1 Project Description.......................................................................................................... 5

2.0 SCOPE ......................................................................................................................................... 6

2.1 Purchaser Documents .................................................................................................... 6

2.2 Industry Codes and Standards ....................................................................................... 6

3.0 ABBREVIATONS ......................................................................................................................... 7

4.0 DEFINITIONS ............................................................................................................................... 7

5.0 SPECIFICATION FOR HFW AND SAW PIPE .............................................................................. 8

5.1 General ............................................................................................................................. 8

5.2 Process Of Manufacture ................................................................................................. 8

5.2.1 General .................................................................................................................. 8

5.3 Offshore Service ............................................................................................................ 10

5.4 Manufacturing Procedure Qualification (MPQ) ........................................................... 10

5.4.1 Electric Welded Pipe ............................................................................................ 10

5.4.2 Submerged Arc Welded Pipe ............................................................................... 10

5.5 Material Requirements .................................................................................................. 11

5.5.1 Chemical Properties............................................................................................. 11

5.5.2 Chemical Properties for Offshore Service ............................................................ 11

5.6 Material Properties ........................................................................................................ 12

5.6.1 General Testing ................................................................................................... 12

5.6.2 Hardness ............................................................................................................. 14

5.6.3 Charpy Testing HFW Pipe ................................................................................... 14

5.7 Dimensions .................................................................................................................... 14

5.7.1 OD Grinding ......................................................................................................... 15

5.7.2 Dents ................................................................................................................... 16

5.8 Testing and Inspection ................................................................................................. 16

5.8.1 General ................................................................................................................ 16

5.8.2 Electric Welded Pipe ............................................................................................ 17

5.8.3 Submerged Arc Welded Pipe ............................................................................... 17

5.8.4 Automatic GMAW and GTAW for Pipeline Installation ......................................... 17

5.8.5 Charpy Fracture Toughness Test ......................................................................... 17

5.8.6 Tensile Test ......................................................................................................... 18



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5.8.7 Drop Weight Tear Testing .................................................................................... 18

5.8.8 NDI for HFW Pipe ................................................................................................ 19

5.8.9 Test for Surface Condition ................................................................................... 19

5.8.10 Hydrostatic Tests ................................................................................................. 19

5.9 Workmanship, Visual Inspection, Repair of Defects ................................................... 19

5.10 Marking .......................................................................................................................... 20

5.11 Shipping ......................................................................................................................... 20

5.12 Warranty......................................................................................................................... 21

5.13 Agreement Clauses In API 5L ....................................................................................... 21

6.0 SPECIFICATION FOR SEAMLESS PIPE .................................................................................. 26

6.1 Process of Manufacture ................................................................................................ 26

6.2 Material Requirements .................................................................................................. 28

6.2.1 Chemical Properties............................................................................................. 28

6.2.2 Chemical Properties for Offshore Service ............................................................ 29

6.2.3 Mechanical Tests ................................................................................................. 29

6.2.4 Strain Age Embrittlement Test Preparation .......................................................... 29

6.2.5 Hardness ............................................................................................................. 30

6.2.6 Test For Surface Condition .................................................................................. 30

6.3 Dimensions .................................................................................................................... 30

6.3.1 OD Grinding ......................................................................................................... 32

6.3.2 Dents ................................................................................................................... 32

6.4 Testing and Inspection ................................................................................................. 33

6.4.1 General ................................................................................................................ 33

6.4.2 Charpy Fracture Toughness Test ......................................................................... 33

6.4.3 Drop Weight Tear Testing .................................................................................... 34

6.4.4 Automatic GMAW and GTAW for Pipeline Installation ......................................... 35

6.4.5 Tensile Tests ....................................................................................................... 35

6.4.6 Hydrostatic Tests ................................................................................................. 35

6.5 Workmanship, Visual Inspection, Repair of Defects ................................................... 36

6.6 Marking .......................................................................................................................... 36

6.7 Shipping ......................................................................................................................... 36

6.8 Warranty......................................................................................................................... 37

6.9 Agreement Clauses In API 5L ....................................................................................... 37



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1.0 INTRODUCTION

1.1 Project Description

The TerangSirasunBatur (TSB) project consists of the development of four offshore gas fields located in a seismically active area - Terang, Sirasun East, Sirasun West and Batur in the Bali Sea. These fields are located approximately 120 km from Pagerungan Island, Indonesia and water depths vary from approximately 80m to 220m. The TSB field location can be seen in Figure 1.

FIGURE 1 (TSB Field Location)

The TSB development concept consists of the nine (9) subsea wells producing and delivering into a gas gathering flowline system. This gas then flows to a Floating Production Unit (FPU) providing separation, compression, dehydration, and supporting utilities systems. The treated gas will be fiscally metered and exported via an 18 diameter transmission pipeline to East Java Gas Pipeline (EJGP) which delivers the gas to customers. The overall system was designed to meet en average export gas rate at 330 MMscfd.

Kangean Energy Indonesia Limited (KEI) are developing the fields in two phases:

TSB Phase 1: Development of the Terang Field (5 wells). Phase 1 production commenced in May 2012.

TSB Phase 2: Development of the Batur and Sirasun Fields (4 wells). The target date for the first gas of Phase 2 is Q1 2016.



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The current Phase 2 project will develop the subsea facilities required for producing from the Batur and Sirasun wells that will be tied in to the existing TSB Phase 1 subsea facilities. The TSB Phase 2 conceptual layout can be seen in FIGURE 2.

2.0 SCOPE

This specification covers longitudinally welded and seamless API 5L line pipe for the construction of submarine pipelines.This specification states COMPANY's requirements which are in addition to API 5L. Wherever conflicts exist between the requirements of API 5L and this specification, the requirements of this specification shall govern. Items not addressed in this specification shall conform to the requirements of API 5L.

2.1 Purchaser Documents

TS-SS-GN-DBS-2101 Basis of Design TS-SS-PL-DBS-2102 Flowline Design premise TS-SS-PL-EDS-P2101 Flowline System Datasheets

2.2 Industry Codes and Standards

American Petroleum Institute (API)

5L Specification for Line Pipe

RP 5LW Recommended Practice for Transportation of Line Pipe on Barges

andMarine Vessels

American Society of Mechanical Engineers (ASME)

B31.8 Gas Transmission and Distribution Piping Systems.

National Association of Corrosion Engineers (NACE)



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MR0175/ISO 15156 Parts 1 through 3, Materials for Use in H2S-containing

Environments in Oil and Gas Production.

International Organization for Standardization (ISO)

11124-2 Preparation of Steel Substrates before Application of Paints and RelatedProducts - Specifications for Metallic Blast-Cleaning Abrasives - Part 2: Chilled-Iron Grit.

StandarNasional Indonesia (SNI)

3474-2009 Sistempenyalurandandistribusipipa gas.

3.0 ABBREVIATONS

ASNT American Society for Non-destructive Testing

DSAW Double Submerged Arc Welding

EMI Electro-Magnetic Inspection

FDPT First Day Production Testing

GMAW Gas-Metal Arc Welding

GTAW Gas-Tungsten Arc Welding

HFW High Frequency Welding

HIC Hydrogen Induced Cracking

ID Inner Diameter

MPQ Manufacturing Procedure Qualification

MPQT Manufacturing Procedure Qualification Testing

NDI Non-Destructive Inspection

OD Outer Diameter

PSL Product Specification Level

PT Product Testing

PWHT Post Weld Heat Treatment

QCP Quality Control Procedure

SAW Submerged Arc Welding

SMAW Shielded Metal Arc Welding

SMYS Specific Minimum Yield Strength

SSC Sulfide Stress Cracking

UT Ultrasonic Testing

WT Wall Thickness

Y/T Yield to Tensile Ratio

4.0 DEFINITIONS

COMPANY :KANGEAN ENERGY INDONESIA Limited or its appointed agent.



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CONTRACTOR : EPCI Contractor Company.

SUB CONTRACTOR : To be determined by EPCI Contractor.

MANUFACTURER : To be determined by EPCI Contractor.

WORK : The scope of work as specified in the Contract.

5.0 SPECIFICATION FOR HFW AND SAW PIPE

5.1 General

1) This specification supplements API specification 5L, 44th or latest edition, and covers all

sizes of API 5L Product Specification Level (PSL) 2 longitudinally (not helically) welded

line pipe in grades B up toX70 with wall thicknesses up to 50 mm.

2) For mill orders, the mill shall be on the Purchaser-Approved Mill List. Contact Purchaser

Quality Assurance Team assistance with non-approved mills.

3) Pipe shall be manufactured in accordance with the requirements of API 5LPSL 2 and as

supplemented by this specification (including Appendix I)

This specification shall constitute the Purchaser's request for special agreements

where they exceed API 5LPSL 2 requirements.

The Supplier's quotation in conformance with this specification and any supplements

shall constitute their agreement to meet all of the requirements in the specification.

The quotation shall state if the order will be distributed between more than one

Manufacturer. In this case if Supplier is awarded the contract any variations in MPS

and MPQ will be highlighted and the highest carbon and CEs will be identified and

reported to assist girth weld procedure.

If a Manufacturer has more than one mill, the quote shall specify which mill will be

used for this order.

In the event of conflict between this specification and other specifications, applicable

codes and references, written clarification shall be sought from Purchaser before

proceeding with the work.

The requirements of Section A are mandatory for all pipe ordered to this specification. Appendix I of this specification references API 5L clause 7, B.2, G.2, H.2, and J.2 and lists Purchaser's requirements for the Manufacturer/Purchaser agreement clauses

5.2 Process Of Manufacture

5.2.1 General

1) After Purchase Order placement, one month prior to steelmaking and the pre-production

meeting, the Manufacturer shall provide a controlled copy of the Manufacturing Procedure Qualification (MPQ) and a Quality Control Plan (QCP) that is customized to meet the

requirements of the purchase orderand this specification.

This requirement may be waived if the manufacturer has supplied this MPQ and QCP in the past and it is on record with Purchaser's Quality Assurance Team.

However, reference to a controlled numbered copy of the MPQ and QCP documents shall be provided if a waiver is requested.



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2) The MPQ shall meet the requirements of API 5L clause B.3 and shall include the following:

Plan(s) and process flow description/diagram.

Details of inclusion control.

Method for cold expansion or compression/sizing/finishing; target and maximum sizing

ratios.

List of specified mechanical and corrosion testing requirements.

Dimensional control procedures.

Pipe tracking procedure.

Marking, coating, and end protection procedures.

Handling, loading, and shipping procedures.

3) The validity of the MPQ shall be limited to the steelmaking, rolling, and

manufacturing/fabrication facilities where the qualification was performed.

4) Steel shall be continuous cast.

5) No jointers shall be permitted and skelp end welds on ERW pipe used to join coils during

manufacturing shall be cut out of the finished pipe.

6) Pipe supplied shall be supplied to a finished length of not less than 12.0m and not greater

than 12.4m, with an average length for each nominal pipe size of 12.2m.

7) Additional requirements for HFW pipe:

The minimum weld frequency shall be 100 kHz

ERW pipe shall be manufactured from hot-rolled coil.

Inclusion control with respect to content, distribution, and shape shall be performed by

desulfurizing, degassing, calcium injection, and/or rare earth metal treatment.

Strip edges shall be free of any inclusions that would form radial hook inclusions within

the completed weld.

The full thickness of the weld seam including the HAZshall be normalized above the

upper critical temperature of the steel. This temperature shall be listed in the MPQ.

8) Additional requirements for SAW pipe:

Only double submerged arc-welded (DSAW) pipe is acceptable.

API 5L clause 9.13.2.2 e shall be invoked if automatic welding and automatic UT are used for girth welds.

To prevent porosity or delayed hydrogen cracking of the weld seam on SAW pipe, appropriate steps shall be taken to prevent the flux from absorbing moisture. The Vendor shall ensure that the SAW flux control procedures are adequate to provide a maximum allowable weld metal hydrogen content of 7ml per 100g of weld metal as determined by collection over mercury using the IIW method. Pipe shall be allowed to cool slowly in still air after welding.

9) If specified on the purchase order, a test for surface condition shall be performed as detailed in Appendix II of this specification.



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5.3 Offshore Service

1) These requirements are in addition to the requirements of 5.2 above.

2) The manufacturer shall obtain written review and acceptance to use centre slit coils. If centre

slit coils are to be used, the manufacturer must demonstrate that the specifications to their

coil supplier contain adequate quality controls to avoid the presence of centerline

segregation and deleterious inclusions and that they have sufficiently audited and

documented that these controls are in place for their orders such that pipe formed from

centre slit coils shall conform to the requirements of 5.2.1 (6) above.

3) The edges of the coil shall be milled or planed. Shearing is not permissible.

4) An automatically controlled welding process shall be used.

Welding temperature, current, or heat input shall be continuously monitored and recorded.

Records shall show that the data are in agreement with the manufacturer's qualified procedure.

The record shall be available for review by the 3rd party inspector during production and until the order is shipped.

5) A device shall be used to assure that the weld seam heat treating equipment and NDI

systems (both at the welding station and in the final UT inspection areas) are constantly

tracking the weld seam.

This system shall be reviewed and accepted by Purchaser.

The heat treatment temperature shall be continuously monitored and recorded.

The record shall be available for review by the 3rd party inspector during production and

until the order is shipped.

6) Alternate ways of assuring adequate heat treatment (full body normalizing) and seam inspec-

tion may be proposed, but must be reviewed and accepted by Purchaser.

5.4 Manufacturing Procedure Qualification (MPQ)

5.4.1 Electric Welded Pipe 1) A qualification test, according to Annex B.3 and B.4 of API 5L, is required either at the start

of production (FDPT) or on a trial run made prior to the start of production (MPQT).

Testing shall consist of one joint from each of the first three test units.

This may require testing more than three joints if more than one welding line is used.

The mill should make every effort to load coils from three different test units at the beginning of production.

2) Each joint shall be subject to all of the chemistry requirements, mechanical tests, and NDI in this specification.

5.4.2 Submerged Arc Welded Pipe 1) A qualification test, according to Annex B.3 and B.4 of API 5L, is required either at the start

of production (FDPT) or on a trial run made prior to the start of production (MPQT).

Testing shall consist of one joint from each of the first three test units.

This may require testing more than three joints if more than one welding line is used.

The mill should make every effort to load plates from three different test units at the



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beginning of production.

2) Each joint shall be subject to all of the chemistry requirements, mechanical tests, and NDI in this specification.

5.5 Material Requirements

If Section B through Dof this specification apply, the chemical and mechanical properties in those

sections shall supersede this Section.

5.5.1 Chemical Properties 1) The product chemical composition shall meet API 5L table 5 and the following

supplementary requirements shown below in Table 5-1:

Table 5-1 Product Chemistry

Element, % HFW & SAW

Carbon (C) 0.16% max. or per API 5L Table 5, whichever is

less

Silicon (Si) 0.35% max. Sulfur (S) 0.010% max.

Phosphorus (P) 0.020% max. Aluminum (Al) 0.06% max

2) Product analysis shall be performed by the pipe manufacturer

3) Induction bending of pipe with a vanadium content greater than 0.08% shall not be supplied.

Mechanical Tests.The tensile test frequency shall be as given in Table 5-2.

4) Shear values from PSL 2 mandatory impact testing shall be reported for information only.

Table 5-2 Tensile Test Frequency

Pipe Size Grade Grade Pipe Body

Tensile Test

Weld Tensile Tests

Longitudinal Seam Weld

Skelp End Weld

8.625 in.and 12.75 in. ( 219 mm.and 324

mm) All

200 lengths per test unit

200 lengths per test unit (*)

200 lengths per test unit (*)

> 12.75 in. (324 mm) All 100 lengths per

test unit 100 lengths per

test unit (*) 100 lengths per

test unit (*)

(*) In addition, over the duration of the pipe production run, pipe produced by each welding

machine is to be tested at least once per week.

5.5.2 Chemical Properties for Offshore Service

1) The product chemical composition shall meet API 5L Table J.1 except for the requirements for specified wall thicknesses < 25 mm (0.984 in) indicated in Table 5-3.

2) In API 5L, Table J.1, footnotes 'b' and 'h' shall not apply.



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a. In cases where the wall thickness is greater than 25 mm (0.94 inches), a modified chemistry may be

required in order to meet NACEMR0175\IS0 15156 hardness requirements. If so, an aim chemistry

shall be submitted as part of the bid package. b. For grades lower than X60 (e.g. Grade B) alternative compositions may be appropriate and Purchaser

should be consulted. c. See API 5L paragraph 6.1.3.1 for the formula. The PCM is required when the carbon content is less

than or equal to 0.12%.

5.6 Material Properties

5.6.1 General Testing

1) Test frequencies and acceptance criteria shall be as follows in Table 5-4and Table 5-5.

2) Transverse specimens shall be extracted using flattened rectangular specimens or round

bar specimens, provided that the same method is used for all pipe within a given wall

thickness and grade.

Table 5-4: Mechanical Testing Required for First Day Production Testing (FDPT) and Production Testing (PT)

Test

# of Test Units

# of Pipes per Test Unit a

# of Tests per Pipe

FDPT PT FDPT PT FDPT PT

Stress-Strain Curve 3 0 1 0 1L, 1Tb c 0

Pipe Body Tensile Test 3 Entire Order

2 1 Pipe per 50 Lengths per

Test Unit 2L, 2Tc d IL IT b c

Cross-Weld Tensile Test 3 Entire Order

1 Per API 5L Table J.7

2T 2T

All Weld Metal Tensile Tests 3 0 1 0 2L 0

Charpy Impact Test 3 Entire Order


Heat

1L, 1Tb e 1Tb e

Hardness 3 Entire Order


Heat

2 rings f 1 ring g

Table 5-3: Product Chemistry Requirements

ELEMENT a, b Wt.%

Carbon (C) 0.040 - 0.120%

Niobium (Nb) 0.040% max.

Titanium (Ti) 0.0250% max.

Vanadium (V) 0.080% max. or API 5L Table J.1, whichever

is lower

Nb + Ti + V 0.120% max.

Carbon Equivalent (IIW) 0.420% max or Table J.1., whichever is lower

Carbon Equivalent (PCM)c As per API 5L Table J.1



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Strain Age Embrittlement Test (Pipe Body Tensile

Test) 3 0 1 0 1Lb 0

Strain Age Embrittlement Test (Charpy Impact Test)

3 0 1 0 1L, 1Tb e 0

Strain Age Embrittlement Test (Hardness)

3 0 1 0 2 rings f 0

L = Longitudinal; T = Transverse

a. For HFW pipe, also seeSection D 3.3 b. Samples shall be extracted from alternating ends. c. Elongation shall be taken to 8% minimum on the curve. d. One L, one T sample shall be taken from each end. e. One L, one T refer to one set of three test pieces from their respective orientations. f. One ring shall be extracted from each end of the pipe. Hardness profile testing shall be done on

each quadrant on each ring. g. One ring shall be extracted from alternating ends. Hardness profile testing shall be done on each

quadrant on each ring.

Table 5-5:Mechanical Property Requirements for Both Transverse

(if Applicable) and Longitudinal Orientations

Material Property Material NOT Strain Aged Strain Aged Material

Minimum Yield Strength Per API 5L Table J.2 Per API 5L Table J.2

Maximum Yield Strength SMYS + 17.4 ksi (120 MPa) N/A

Maximum Yield Strength Range

< 14.5 ksi (100 MPa) N/A

Minimum/Maximum Tensile Strength

Per API 5L Table J.2 Per API 5L Table J.2

(for SMTS)

Maximum Tensile Strength Range

N/A N/A

Yield to Tensile Ratio More than 80% test results shall have Y/T 85% average shear for the order > 60% average shear for each test

N/A



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Hardness Tests 270 HV10 270 HV10

5) Strain Age Embrittlement Test Sample Preparation

The test procedure shall be submitted to Purchaser for review and acceptance prior to

testing.

Samples shall be extracted from the pipe wall.

The test samples shall be successively deformed by uni-axial tension followed by uni-

axial compression through the neutral point, in steps corresponding to those of the

installation process.

The plastic strain shall be at least equal to that introduced during installation and

service, but not less than 3%. The samples shall then be artificially aged at 482F (250C) for one hour prior to testing.

6) Strain Age Embrittlement Tensile Test

7) One longitudinal specimen using the largest possible round bar specimen from strained and aged pipe shall be tested.

5.6.2 Hardness

1) Hardness survey shall be performed as shown in API 5L Figure J.1. Other locations

shall be determined by Purchaser as appropriate.

2) Hardness tests shall be conducted on all four quadrants of pipe.

3) Hardness Retesting

If any hardness value fails, the pipe shall be rejected and one retest shall be taken

on two other pipes from test unit which failed.If either or both tests fail, the entire

test unit shall be rejected or reprocessed. If both tests pass, entire test unit may be

accepted.

5.6.3 Charpy Testing HFWPipe

For HFW pipe, tensile and Charpy production tests shall be repeated once per every five

joints of pipe in addition to the first day production test frequency listed in Table 5-4.

5.7 Dimensions

1) Dimensional tolerances specified in this specification and in API 5L shall apply regardless

of the pressure used in the mill hydrotest.

2) The pipe length range shall be as specified on the purchase order; or if not specified, it shall

be from 38 to 42 ft. (11.6 to 12.8 m) with an average length not less than 40 ft. (12.2 m).

3) Pipe straightness shall accord with values given in Table 5-7.

4) Bar gage, caliper, or device measuring actual maximum and minimum diameters shall be

used in measuring out-of-roundness of pipe ends. At least three sets of pipe end outside

diameter readings shall be taken on separate planes around the pipe circumference and

averaged to provide a value.



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4) API 5L clause 10.2.8.3 shall apply regardless of size unless otherwise stated on the

purchase order. With reference to API 5L Table J.3 footnote c, the ID shall be measured,

not calculated.

5) The inside diameter tolerance shall be +/- 0.5% around the nominal ID (maximum of +/- 1.0 mm) and shall apply to both ends of each pipe of the order.

6) The nominal ID shall be established with measurements on the first 100 production pipes.

7) Maximum out-of-roundness at the pipe ends shall be 2 mm (0.08 in.).

8) The wall thickness shall be determined along the full length of each pipe by ultrasonic testing, shall comply with Table 5-8.

Table 5-7 Pipe Straightness Tolerances and Measurement Frequency

Deviation Within 6

Inches (15 cm) of the Pipe Ends

Deviation Over Nominal Length

Frequency

Pipe Straightness

< 0.12 in/ft (< 3 mm/m)

Per API 5L Clause J.6.4

3 pipes per shift selected at the beginning, middle, and

end of the shift

Table 5-8 Wall Thickness Tolerances

Wall Thickness Wall Thickness Tolerance

Frequency (min.) (max.)

All thickness Per API 5L Table

J.3 Per API 5L Table

J.3

Checked along the full length of each pipe body by AUT. At both ends,

measured and recorded on 1 pipe in every 10 with thickness gauge.

5.7.1 OD Grinding

1) Grinding shall be performed in accordance with procedures reviewed and accepted by

Purchaser. A maximum of 15% of the pipe order may be repaired by stone wheel

grinding. 2) The ground area shall not exceed more than 45% of the circumference of a cross-

sectional plane. 3) Ground areas shall be smoothly contoured to the surface of the pipe at a minimum 4 to 1

slope.

4) Ground areas shall not exceed an area of 5% of the total surface area of each pipe. The

remaining wall thickness at a ground area shall be greater than the minimum wall

thickness of this specification.

5) Areas ground shall have the final wall thickness measured by ultrasonic testing and shall



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be recorded (i.e. wall thickness, joint number, location on the joint, etc.).

6) These ground areas shall not interfere with non-destructive testing at the pipe mill or

during fabrication/installation (i.e. automated ultrasonic testing of girth welds).

5.7.2 Dents

1) Pipe shall contain no dents that affect both the outside surface and the inside surface. 2) Pipe shall contain no dents on the outside surface with a depth exceeding 0.08 inches

(2 mm) for pipe body or exceeding 1 mm (0.04 inches) for six inches from either pipe end.

3) Pounding out or jacking out dents is prohibited.

4) Pipe ends shall not be internally machined without prior review and acceptance by Purchaser.

5.8 Testing and Inspection

5.8.1 General

1) NDI for final acceptance shall be performed per API 5L Annex E, except where noted

herein. 2) With reference to API 5L clause E.1.3, evaluations of indications shall be performed by

ASNT-TC-1A Level 2 or 3 personnel only. The person responsible for the preparation of inspection procedures and supervision activities shall be qualified to ASNT-TC-1A Level 3.

3) The only acceptable electromagnetic NDI method is one which utilizes diverted flux. In accordance with API 5L clause E.5.3.4, a drilled hole shall be used to establish a rejection threshold.

4) For pipe less than or equal to 0.188 inches (4.7 mm) wall thickness, either an ultrasonic NDI method or an electromagnetic NDI method which utilizes diverted flux is acceptable. For pipe thicker than 0.188 inches (4.7 mm), the only acceptable method is ultrasonics.

5) The NDI reference standard shall contain both longitudinal and transverse notches. Both notches and drilled holes with dimensions in accordance with API 5L Table E.7 shall be required for calibration. API 5LTableE.7 footnote 'g' shall not be invoked.

6) A dynamic standardization (calibration) at production speed using the reference standard is required. If a standardization check shows that the accuracy of the standardization has shifted outside of the acceptable range, all lengths of pipe inspected since the last acceptable standardization shall be re-inspected using the same nondestructive method previously used.

7) No loss of back reflection is permitted.

8) If not previously inspected, pipe ends shall be inspected by using handheld ultrasonic shear wave equipment. Alternatively, un-inspected ends may be cropped. Standardization (calibration) and standardization frequency shall be in the same manner as in item 6, above.

9) For proof of indications, radiography may be used as an additional inspection tool, but final acceptance shall be by UT.

10) All pipe shall be checked for magnetism and shall show a maximum of 15 gauss after completion of all inspection.



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5.8.2 Electric Welded Pipe

NDI shall be completed after hydrotesting.

5.8.3 Submerged Arc Welded Pipe

NDI shall be done after hydrotest and cold expansion

5.8.4 Automatic GMAW and GTAW for Pipeline Installation

If automatic GMAW (gas metal arc welding) or GTAW (gas tungsten arc welding) are to be usedfor pipeline installation, residual magnetism shall be less than or equal to 15 Gauss for any individual reading.

5.8.5 Charpy Fracture Toughness Test

1) API 5L Annex G contains the requirements for shear and energy values specific to enhancing resistance to ductile fracture propagation in gas lines. The temperature for fracture toughness testing shall be as stated in Table 5-9.

2) Charpy impact specimens shall be taken from each test unit or from 100 lengths of heat pro-duced, whichever results in a greater number of impact tests.

3) API 5L Annex G clause G.2.1 item a) shall apply. Shear fracture area of weld metal and HAZ specimens shall be recorded for informational purposes only.

4) In natural gas service (> 97% methane) the averaged absorbed energy values (based on three full size specimens) for Charpy impact testing shall be in accordance with API 5L Table G. 1, G.2, or G.3 for design factors 0.625, 0.72, or 0.80, respectively.

For design factors other than in Tables G.1, G.2, and G.3, use test the table

corresponding to the next higher design factor.

If no table in API 5L Annex G is specified on the data sheet, API 5L Table G3 shall be

used by default.

If Section C, D and/or E of this specification are applicable, the greatest absorbed

energy value shall apply.

5) In rich gas service, the API 5L clause G.9 shall be invoked. Consult Purchaser Material & Corrosion Team for appropriate Charpy impact requirements.

Table 5-9 Temperature for Charpy Testing

Specified Wall Thickness Test Temperature a.b

inch mm F C

Up to 0.800 Up to 20 Tmin or 32c Tmin or 0

c

0.800 up to 1.57 20 up to 40 Tmin- 18 Tmin - 10

Greater than 1.57 Greater than 40 Tmin- 36 Tmin - 20

a. Tmin is the minimum design temperature as specified on the purchase order

b. The test temperatures listed are the maximum allowable for a given wall thickness.Testing is permitted at temperatures below those stated.

c. Whichever temperature is lower.



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5.8.6 Tensile Test

1) If specified on the data sheet, elevated temperature tests shall be run on one longitudinal

and one transverse sample from one pipe from each of the first three test units and the

conditions below.

Transverse yield strength may be determined either using transverse flattened rectangular specimens or round bar specimens, provided that the same method is

used for all pipe within a given wall thickness and grade.

Testing shall be performed at the maximum design temperature.

Longitudinal and transverse yield and tensile requirements shall comply with Table 1-2.

2) In addition to the tensile tests required by API 5L Table J.8, an additional longitudinal tensile test shall be taken at the same frequency as transverse tensile tests. Acceptance shall be per API 5L Table J.2.

3) API 5L Table J.2 shall be amended such that the maximum yield to tensile ratio shall be

0.90 for grades up to X56 and 0.92 for grades X60 and above unless otherwise stated on

the purchase order and/or data sheet.

4) A stress-strain curve shall be produced on one pipe from each of the first five heats for

information purposes. This information shall be submitted as part of the MPQ data

package.

5) The Supplier shall notify the Purchaser if more than 5% strain occurs after final heat

treatment. If so, strain-age embrittlement tensile testing shall be performed per Sections E

of this specification.

5.8.7 Drop Weight Tear Testing

1) For pipe greater than or equal to 20 inches, Charpy testing shall be supplemented with DWTT

2) A pressed notch shall be used unless otherwise specified

3) The test temperature shall conform to Table 5-10.

Table 5-10: Temperature for Drop Weight Tear Testing

DWTT Test Specimen Size

Specified Pipe Wall Thickness mm (in.)

Limited to 0.750 in. (19.0 mm) C (F)

Full Wall Thickness C (F)

< 19.0 (0.75) Samples must be full thickness TMin

22.2 (0.875) to < 28.6 (1.125) TMin - 11 (20) TMin

> 28.6 (1.125) to < 39.7 (1.563) TMin- 17 (30) TMin

> 39.7 (1.563) Consult Purchaser Materials & Corrosion Team

TMin is the minimum design temperature



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5.8.8 NDIfor HFW Pipe

1) For HFW pipe, API 5L Table E.7 shall be amended to an N5 notch and a 1/16 inch (1.5

mm) diameter hole.

2) API 5L clause K.2.1.4 shall be invoked.

5.8.9 Test for Surface Condition

1) The following test for surface condition shall be carried out on the first 10 pipes of the

firstday's production:

Preheat pipe surface to 70C (158F). Blast each pipe to SA 2.5 using steel grit, typically ISO 11124-2 G17 grade or

equivalent. Heat each pipe to 240C (464F) and cool in water to simulate the coating process.

2) Each pipe shall then be visually inspected.

The surface condition of the pipes shall be such that a coating contractor using a single pass grit blasting system can achieve an SA 2.5 finish with a blast profile of 50-100 microns.

The total number of defects should be able to be removed in no more than 3 man-minutes per pipe using a handheld grinder.

Where the pipe manufacturer is contracted or responsible for line pipe coating, this requirement may be omitted.

5.8.10 Hydrostatic Tests

Each joint of pipe shall be hydrostatically tested using the following method:

1) Hoop stress, S, shall be calculated using 90% of specified minimum yield strength (SMYS)

using the specified wall thickness.

2) The acceptance criterion for mill hydrotest shall be no failure.

Pipes that fail the hydrotest shall be quarantined until examined by Purchaser's inspector.

Failed pipes shall be removed from the hydrotest area and quarantined to a location where an investigation to determine the cause of failure can be conducted.

Purchaser shall have access to witness and/or participate in the investigation of the failure.

Results of the failure investigation shall be made available to Purchaser.

5.9 Workmanship, Visual Inspection, Repair of Defects

1) The Manufacturer shall ensure that all mill scale is removed from process rollers, at least four times per shift and whenever scale built-up occurs, to avoid undetected scale penetrating into parent pipe metal.

2) Where the depth of a surface imperfection is not readily apparent, suitable NDI and surface grinding shall be performed to assure that the imperfection is completely removed to a polished finish.When the surface is ground to remove a surface imperfection, complete removal shall be verified by magnetic particle examination and re-inspection by the same method as used to detect the defect.



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3) The remaining wall thickness shall be measured by UT to assure it meets or exceeds the minimum allowable requirements of API 5L Table 11.

4) Manufacturers shall take all reasonable precautions to minimize recurring imperfections, damage, and defects. The Purchaser reserves the right to reject all or part of the order based on recurring defects. This clause shall be invoked if more than 15% of the pipes produced in a 24 hour period are rejected by NDI.

5) In addition to paragraph 1, above, ID grinding only is permissible where ground area can be adequately inspected by MPI or dye penetrant inspection.

6) For all longitudinal welded pipe multiple repairs of the same location are not permitted.

7) ERW shall not be weld repaired.

8) The weld flash on ERW pipe shall be removed except that the maximum allowable depth of the groove on the ID shall be 0.4mm (1/64 inch) and the maximum allowable height on the OD shall be 1.6mm (1/16 inch) with no undercutting permitted. Both inside and outside shall be smooth and free of sharp edges, slivers, burrs and cracks.

9) For ERW pipe confirmed defects shall be cut off or the joint rejected. Defects on the weld seam may be repaired by grinding providing the wall thickness is in accordance with this specification.

10) For SAW pipe repair welding is not permitted outside the weld zone. Single repairs are permitted in the weld zone. Repairs in the weld seam shall not be accepted within 200 mm from the bevel ends and repair welding shall be limited to a maximum total repair length of 5% of the seam length.

11) All repair welding shall be recorded and reported to the Company Representative.

12) A rejection rate in excess of 2 pipe joints in a run of 20, and a rejection rate of 5% or greater in a sample exceeding 20 joints, will be cause for cessation of production until the cause of defect is determined and rectified to the satisfaction of Purchaser. Any indication of a negative trend in quality may be cause for Purchaser to require a cessation of production and the cause of the drop in quality to be determined and rectified prior to resumption of production.

5.10 Marking

1) Marking shall be according to API 5L Clause 11.2.1, 11.2.3, and API monogrammed in

accordance with Annex O.

2) In addition to the marking referenced above, the heat number shall also be included in

the marking

3) Marking shall be on the inner surface for sizes 16" and greater per API 5L clause 11.2.2

b) 2).

4) Location of the ERW welds shall be paint marked internally at each end for a minimum

distance of 200mm at the mill.

5.11 Shipping

1) Pipe shall be bare and free of oil, grease, lacquer, antifreeze (from UT couplant), and



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other contaminants such as chlorides which adversely affect coating adhesion. It is

permissible to apply mill varnish over the stencil identification to minimize deterioration of

this marking.

2) When pipes are stored ready for shipping the pipes shall be stored at an angle to allow

drainage of moisture.

3) Hooks shall not be used. Handling devices that contain copper or copper alloys shall not

be used.

4) No overstowage or deck loads are permitted.

5) Pipe shall not be nested one diameter inside another.

6) If in-transit fatigue cracks are detected after shipment, Purchaser reserves the right to

reject the entire shipment until an absence of fatigue cracking is proven on the entire

shipment by an agreed upon NDI method.

7) Bevel protectors shall be used unless otherwise specified on the purchase order.

8) All pipe shall be handled, loaded, and shipped in accordance with API RP 5L1 and/or API RP 5LW, as applicable.

Suppliers shall submit, with their shipping procedures, a written method to prevent

salt contamination of the pipe at the receiving facility.

For transoceanic shipping, ship's log shall be made available to Purchaser for review

when the pipe is unloaded.

9) The manufacturer shall submit loading instructions and diagrams for review and comment

for all pipe shipped by truck or vessel at least 8 weeks prior to shipment. However, review

and comment of these loading instructions shall not relieve manufacturer of responsibility

for any damage during shipment.

10) All dimensional tolerances and pipe surface conditions specified herein and in API 5L shall apply to the pipe condition as received by Purchaser at the shipping destination.

5.12 Warranty

1) Purchaser shall be reimbursed for replacement costs of any pipe furnished that fails under

field hydrostatic test (which is commonly performed at pressures lower than the mill

hydrotest), for damage to the pipe in transit to the point of delivery, for defects of materials

and/or workmanship, or for lack of compliance with this specification.

2) The replacement costs shall include pipe, labor, and equipment rental for locatiang, cutting

out, replacing and testing the pipeline.

5.13 Agreement Clauses In API 5L

Tables 5-11 until 5-17list the information required by API 5L to be supplied by the Purchaser.

The pipe shall conform to these requirements unless otherwise agreed upon by the Purchaser.

Where API 5L by agreement clause are not addressed, either default requirements apply or the clause does not apply to the product to be purchased.

Table 5-11Agreement Clauses under API 5L Clause 7.1



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API 5L, 44th Edition, Clause

7.1: Information Required

API 5L Clause & Table #

a) Quantity (e.g. total mass or total length of pipe)

b) PSL API 5L Introduction

c) Type of Pipe Table 2

d) Specification API 5L, 44th or latest edition

e) Steel Grade 6.1, H.4.1.1, or J.4.1.1

f) Outside Diameter (OD, size) and Wall Thickness 9.11.1.2

g) Length and Type of Length (randomor approximate) 9.11.1.3, 9.11.3.3, and Table 12

h)

- Confirmation of Applicability of Individual Annexes

- - Delivery date and shipping instructions

- - Inspection or surveillance by 3rd party

-Design Code

API 5L Introduction

Table 5-12 Agreement Clauses under API 5L Clause 7.2 (a)

Item under API 5L, Clause

7.2 (a) Subject to Mandatory Agreement

3) Chemical Composition for Pipe with t > 25.0 mm (0.984 in.)

4) Carbon Equivalent Limits for PSL 2 Pipe in Grade L415N or X60N

Table 5-13: Agreement Clauses under API 5L Clause 7.2 (c) (Sheet 1 of 2)

Item under API 5L, Clause 7.2 (c)

Items that apply, if Agreed API 5L Clause

& Table #

1) Delivery Condition 6.2 and Table 1

4) Supply of double seam SAWL pipe Table 2 Footnote d

7) Supply of Jointers 8.11, H.3.3.3



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8) CNV Impact Test Temperature Lower than 0C (32F) 9.8.2.1, 9.8.2.2,

9.8.3

10) CVN Impact Test of the Longitudinal Seam Weld of PSL 2 HFW Pipe

9.8.3 and Table 18

11) DWT Test of the Pipe Body of PSL 2 Welded Pipe with D > 508 mm (20.00 in.)

9.9.1 and Table 18

12) DWT Test Temperature Lower than 0C (32F) 9.9.1

Table 5-14 Agreement Clauses under API 5L Clause 7.2 (c) (Sheet 2 of 2)



& Table #

14) Special Bevel Configuration 9.12.5.3

15) Removal of Outside Weld Bead at Pipe Ends of SAW or COW Pipe

9.13.2.2 e

16) Weldability Data or Tests for PSL 2 Pipe 9.15

26) Specific Method to be Used for Determining Pipe Diameter

10.2.8.1

27) Use of Inside Diameter Measurements to Determine Diameter and Out-of- Roundness for Non-Expanded Pipe with D > 219.1 mm (8.625 in.)

10.2.8.3, Table 10 Footnote c

28) Specific Method to be Used for Determining Other Pipe Dimensions

10.2.8.6

30) Additional Marking Specified by the Purchaser 11.1.3

31) Specific Surface or Location for Pipe Marking 11.2.2 b) or

11.2.2 c) and 11.2.6 b)

32) Die-stamping or Vibro-etching of Pipe 11.2.3

33) Alternative Location for Marking the Pipe 11.2.4

34) Alternative Format for Pipe Length 11.2.6

36) Temporary External Coating 12.1.2

37) Special Coating 12.1.3

38) Lining 12.1.4

40) Manufacturing Procedure Qualification for PSL 2 Pipe, in which case, Annex B shall apply

Annex B



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& Table #

49)

Application of Annex G to PSL 2 Pipe with resistance in the pipe body to ductile fracture propagation in gas pipelines and where Purchaser shall specify applicable approach and/or impact test temperature and energy values to be required

G.7 to G.11

54) PSL 2 Pipe for Offshore Service in which case, Annex J shall apply

Annex J

55) Any other additional or more stringent requirements

Table 5-15 Agreement Clauses under API 5L Clause B.2

Item under API 5L, Clause B.2

Information Required API 5L Clause

& Table #

a) Qualification in Accordance with Clause B.3 or B.4 or both

B.1.3

b) Frequency and Amount of Testing B.4.2

Table 5-16Agreement Clauses under API 5L Clause G.2

Table 5-17 Agreement Clauses under API 5L Clause H.2 (Sheet 1 of 2)

Item under API 5L, Clause G.2

Information Required API 5L Clause

& Table #

G.2.1 Purchaser must Specify G.2.1 a) or b) G.2.1

G.2.2 a) CVN Impact Test Temperature G.2.2

G.2.2 b) DWT Test Temperature G.2.2

Item under API 5L,

Clause H.2 Information Required

API 5L Clause & Table #

a) Steel Casting Method for Strip of Plate Used for the Manufacture of Welded Pipe

H.3.3.2.1

b) Ultrasonic Inspection of Strip or Plate for Laminar Imperfections

H.3.3.2.4



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Table 5-17 Agreement Clauses under API 5L Clause H.2 (Sheet 2 of 2)

Item under API 5L, Clause H.2

Information Required API 5L Clause & Table #

m)

Magnetic Particle Inspection for Laminar Imperfection at Each Pipe End Face/Bevel

K.2.1.4

q) Acceptance Level L2/C or L2 for NDI of the Weld Seam of HFW Pipe

K.4.1

r) Ultrasonic Inspection of the Pipe Body of HFW Pipe for Laminar Imperfections

K.4.2

e) Chemical Composition for Pipe with Wall Thickness > 25.0 mm (0.984 in.)

H.4.1.2

f) Chemical Composition Limits Table H.1, Footnotes c),

d), e), f), i), j), and k)

g) Frequency of Hardness Testing of the Longitudinal Seam Weld of HFW or SAW pipe

Table H.3

h) SSC Test for Manufacturing Procedure Qualification

Table H.3

i) Alternative HIC/SWC Test Methods and Associated Acceptance Criteria for Manufacturing Procedure Qualifications

H.7.3.1.3

k)

Alternative SSC Test Methods and Associated Acceptance Criteria for Manufacturing Procedure Qualifications

H.7.3.2.2



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6.0 SPECIFICATION FOR SEAMLESS PIPE

1) This specification supplements API Specification 5L, 44th or latest edition, and covers all sizes of API 5L Product Specification Level (PSL) 2 seamless line pipe in grades B up to X70 with wall thickness up to 50 mm.

2) For mill orders, the mill shall be on the Purchaser Approved Mill List. Contact Purchaser

Quality Assurance Team for assistance with non-approved mills.

3) Pipe shall be manufactured in accordance with the requirements of API 5LPSL 2 and as

supplemented by this specification including (Appendix I), other supplementary

appendices, the purchase order.

This specification shall constitute the Purchaser's request for special agreements

where they exceed API 5LPSL 2 requirements.

The Supplier's quotation in conformance with this specification and any supplements

shall constitute their agreement to meet all of the requirements in the specification.

The quotation shall state if the order will be distributed between more than one

manufacturer.

If a manufacturer has more than one mill, the quote shall specify which mill will be used

for this order.

In the event of conflict between this specification and other specifications, applicable

codes and references, written clarification shall be sought from Purchaser before

proceeding with the work.

4) The requirements of Section A shall be mandatory for all pipe ordered to this specification.

If other sections of this specification or other additional requirements are called out on the

purchase order, the most stringent requirements shall be met. Appendix I of this

specification references API 5L clause 7, B.2, G.2, H.2, and J.2 and lists Purchaser's

requirements for the manufacturer/purchaser agreement clauses.

6.1 Process of Manufacture

1) After purchaser order placement, one month prior to steel-making and the pre-production

meeting, the manufacturer shall provide a controlled copy of the Manufacturing Procedure

Qualification (MPQ) and a Quality Control Plan (QCP) that is customized to meet the require-

ments of this specification.

This requirement may be waived if the manufacturer has supplied this MPQ and QCP in

the past and it is on record with Purchaser's Quality Assurance Team.

However, reference to a controlled numbered copy of the MPQ and QCP documents

shall be provided if a waiver is requested.

2) The MPQ shall meet the requirements of API 5L clause B.3 and shall include the following:

Plan(s) and process flow description/diagram.

Method for sizing/finishing; target and maximum sizing ratios.

List of specified mechanical and corrosion testing requirements

Dimensional control procedures.

Pipe tracking procedure.



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Marking, coating, and end protection procedures.

Handling, loading, and shipping procedures.

3) The validity of the MPQ shall be limited to the steelmaking, rolling, and manufacturing/fabri-

cation facilities where the qualification was performed.

4) Steel shall be continuous cast.

5) No jointers shall be permitted.

6) Repair welding of seamless pipe is not permitted.

7) If specified on the purchase order, a test for surface condition shall be performed as detailed in

Appendix II of this specification.

8) The MPQ shall be qualified per API 5L Annex B.3 and B.4 for each pipe diameter, wall thick-

ness, and grade.

9) First day production testing shall be carried out at the frequency in Table 6-1.

10) Test frequencies and acceptance criteria shall be as indicated in Table 6-1and Table 6-2.

11) Transverse specimens shall be extracted using flattened rectangular specimens or round bar

specimens, provided that the same method is used for all pipe within a given wall thickness and

grade.

Table 6-1 Mechanical Testing Required for First Day Production Testing (FDPT)

and Production Testing (PT)

Test # Test Units # Pipes per Test Unit # Tests per Pipe

FDPT PT FDPT PT FDPT PT

Stress Strain Curve 3 0 1 0 1L, 1Ta b 0

Tensile Test 3 Entire

Order 2

1 Pipe per 50 lengths

per Test Unit 2L, 2Tb c 1L, 1Ta b

Charpy Impact Test 3 Entire

Order 2

1 Pipe per 50 Lengths

per Test Unit 1L, 1Ta d 1Ta d

Hardness 3 Entire

Order 1

1 Pipe per 50 Lengths

per Test Unit 2 ringse 1 ringf

Strain Age

Embrittlement Test

(Tensile Test)

3 0 1 0 1La 0

Strain Age

Embrittlement Test

(Charpy Impact Test)

3 0 1 0 1L, 1Ta d 0

Strain Age

Embrittlement Test

(Hardness)

3 0 1 0 2 ringse 0



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a. Samples shall be extracted from alternating ends.

b. Elongation shall be taken to 8% minimum on the curve.

c. One L, one T sample shall be taken from each end.

d. One L, one T refer to one set of three test specimens from the respective orientations.

e. One ring shall be extracted from each pipe end. Hardness profile testing shall be done each quadrant

on each ring.

f. One ring shall be extracted from alternating ends. Hardness profile testing shall be done each

quadrant on each ring.

Table 6-2: Mechanical Property Requirements for Both Transverse

(If Applicable) and Longitudinal Orientations

Material NOT Strain Aged Strain Aged Material

Minimum Yield Strength Per API 5L Table J.2 Per API 5L Table J.2

Maximum Yield Strength SMYS + 17.4 ksi (120 MPa) N/A

Maximum Yield Strength

Range

< 14.5 ksi (100 MPa) N/A

Minimum/Maximum Tensile

Strength Per API 5L Table J.2

Per API 5L Table J.2 (for

SMTS)

Maximum Tensile Strength

Range

N/A N/A

Yield to Tensile Ratio

More than 80% test results

shall have Y/T < 0.85

Remaining (less than 20%)

test results shall have Y/T <

0.87

< 0.97 for all specimens

Elongation 20% 15%

Uniform Elongation 8% N/A

Charpy Impact Toughness

Per API 5L Table 8 (Table

G.1, G.2, G.3, or

Clause G.9 if applicable)

Per API 5L Table 8

(Table G.1, G.2, G.3,

or Clause G.9 if applicable)

Shear Area

> 85% average shear for the

order60% average shear for

each test

N/A

Hardness Tests 270 HV10 270 HV10

6.2 Material Requirements

The chemical and mechanical properties given in this specification shall supersede API 5L.

6.2.1 Chemical Properties

Induction bending of pipe with a vanadium content greater than 0.08% shall not be supplied.



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6.2.2 Chemical Properties for Offshore Service

1) Non-sour service offshore pipe shall meet API 5L Table J.1 except for the following require-

ments for specified wall thicknesses < 25 mm (0.984 in), as shown in Table 6-3.

2) API 5L Table J.1 footnote 'b', 'g', and 'h' shall not apply.

Table 6-3 Product Chemistry Requirements

Element a Wt.%

Carbon (C) As per Table J.1 with a minimum carbon

content of 0.070%

Niobium (Nb)b 0.040% max.

Titanium (Ti) 0.0250% max.

Vanadium (V) 0.080% max. or Table J.1, whichever is

lower. Nb+Ti+V 0.120% max.

Carbon Equivalent (IIW) 0.420% max. or Table J.1, whichever is

lower. Carbon Equivalent (PCM)c As per API 5L Table J.1.

a. In cases where the wall thickness is greater than 25 mm (0.94 inches), a modifiedchemistry may be required in order to meet NACEMR0175/IS0 15156 hardness requirements. If so, aim chemistry shall be submitted as part of the MPQ data package.

b. If the pipe girth welds will undergo PWHT, an aim chemistry shall be submitted as part of the bid package.

c. See API 5L Paragraph 9.2.4 for the formula. The PCM is required when the carbon content is less than or equal to 0.12%.

6.2.3 Mechanical Tests

1) The tensile test frequency shall be as given in Table 6-4.

2) Shear values from PSL 2 mandatory impact testing, shall be reported for information only.

Table6-4: Tensile Test Frequency

Pipe Size Grade Maximum Test Unit Size

< 5.562 in. (< 141 mm) All 400 lengths per test unit

> 5.562 in. and < 12.75 in.

(> 141 mm and < 324 mm) All 200 lengths per test unit

> 12.75 in. (> 324 mm) All 100 lengths per test unit

6.2.4 Strain Age Embrittlement Test Preparation

1) Strain Age Embrittlement Test Sample Preparation

The test procedure shall be submitted to Purchaser for review and acceptance prior to testing.

Samples shall be extracted from the pipe wall.



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The test samples shall be successively deformed by uni-axial tension followed by uni-axial compression through the neutral point, in steps corresponding to those of the installation process.

The plastic strain shall be at least equal to that introduced during installation and service, but not less than 3%.

The samples shall then be artificially aged at 482F (250C) for one hour prior to testing.

2) Strain Age Embrittlement Tensile Test

One longitudinal specimen using the largest possible round bar specimen from strained andaged pipe shall be tested.

6.2.5 Hardness

1) Hardness survey shall be performed as shown in API 5L Figure J.1. Other locations shall

bedetermined by Purchaser as appropriate.

2) Hardness tests shall be conducted on all four quadrants of pipe.

3) Hardness Retesting

If any hardness value fails, the pipe shall be rejected and one retest shall be taken on

two other pipes from test unit which failed.

If either or both tests fail, entire test unit shall be rejected or reprocessed. If both tests

pass, entire test unit may be accepted.

6.2.6 Test For Surface Condition

1) The following test for surface condition shall be carried out on the first 10 pipes of the first

day's production:

Preheat pipe surface to 158F (70C ).

Blast each pipe to SA 2.5 using steel grit, typically ISO 11124-2 G17 grade or

equivalent.

Heat each pipe to 464F (240C) and cool in water to simulate the coating process.

2) Each pipe shall then be visually inspected.

The surface condition of the pipes shall be such that a coating contractor using a

single pass grit blasting system can achieve an SA 2.5 finish with a blast profile of50-

100 microns.

The total number of defects should be able to be removed in no more than 3 man-

minutes per pipe using a handheld grinder.

Where the pipe manufacturer is contracted or responsible for line pipe coating, this

requirement may be omitted.

6.3 Dimensions

1) The inside diameter tolerance shall be +/- 0.5% around the nominal ID (maximum of +/- 1.0

mm) and shall apply to both ends of each pipe of the order.

2) The nominal ID shall be established with measurements on the first 100 production pipes.



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3) Maximum out-of-roundness at the pipe ends shall be 0.75% of the ID or 5 mm, whichever is

less.

4) The wall thickness shall be determined along the full length of each pipe by ultrasonic

testing.

5) Dimensional tolerances specified in this specification and in API 5L shall apply regardless of

the pressure used in the mill hydrotest.

6) The pipe length range shall be as specified on the purchase order; or if not specified, it shall

be from 38 to 42 ft. (11.6 to 12.8 m) with an average length not less than 40 ft. (12.2 m).

7) Bar gage, caliper, or device measuring actual maximum and minimum diameters shall be

used in measuring the out-of-roundness of pipe ends. At least three sets of pipe end outside

diameter readings shall be taken on separate planes around the pipe circumference and

averaged to provide a value.

8) Wall thickness tolerances shall comply with Table 6-5.

9) Pipe straightness shall conform to Table 6-6.

Table 6-5: Wall Thickness Tolerances

Wall Thickness Wall Thickness Tolerance

Frequency (min) (max)

< 25 mm -10% + 12.5% Checked along the full length of each pipe body by AUT. At both ends, measured and recorded on 1 pipe in every 10 with thickness gauge.

> 25 mm

-10% or -3 mm, whichever

is less

12.5% or +3 mm, whichever

is less

Table 6-6 Pipe Straightness Tolerances and Measurement Frequency

Deviation Within 6

Inches (15 cm)

of the Pipe Ends

Deviation Over

Nominal Length Frequency

Pipe

Straightness < 0.12 in/ft (< 3 mm/m)

Per API 5L

clause J.6.4

3 pipes per shift

selected at the

beginning, middle, and

end of the shift

10) Eccentricity

Eccentricity tolerances and measurement frequency for pipe ends shall comply with Table 6-7.

Measurements shall be made on the same cross-sectional plane using calipers.



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Eccentricity within 6 inches of each end shall be defined as follows:

where:

Tmax = maximum wall thickness, inches

Tmin = minimum wall thickness, inches

Table 6-7 Eccentricity Tolerance and Measurement Frequency

Eccentricity Tolerance < 18%

Measurement Frequency Each pipe end in the order

6.3.1 OD Grinding

1) Grinding shall be performed in accordance with procedures reviewed and accepted by

Purchaser. A maximum of 15% of the pipe order may be repaired by stone wheel grinding.

2) The ground area shall not exceed more than 45% of the circumference of a cross-sectional plane.

3) Ground areas shall be smoothly contoured to the surface of the pipe at a minimum 4 to 1 slope and shall be completed with a polished finish.

4) Ground areas shall not exceed an area of 5 percent of the total surface area of each pipe. The remaining wall thickness at a ground area shall be greater than the minimum wall thickness of this specification.

5) Areas ground shall have the final wall thickness measured by Ultrasonic Testing and shall be recorded (i.e. Wall Thickness, Joint Number, Location on the Joint, etc.).

6) All ground areas shall be subject to magnetic particle inspection using an approved method. Any imperfection of unknown depth shall be subjected to exploratory grinding until the extent of the defect is known. No pipe will be accepted where grinding has reduced the wall thickness below the acceptable tolerances.

7) These ground areas shall not interfere with non-destructive testing at the pipe mill or during fabrication/installation (i.e. Automated Ultrasonic Testing of girth welds).

6.3.2 Dents

1) Pipe shall contain no dents that affect both the outside surface and the inside surface

2) Pipe shall contain no dent on outside surface with a depth exceeding 0.08 inches (2 mm) for pipe body exceeding 0.04 inches (1mm) for 6 inches from either pipe end.

3) Pounding out or jacking out dents is prohibited

4) Pipe ends shall not be internally machined without prior acceptance by Purchaser.



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6.4 Testing and Inspection

6.4.1 General

1) NDI for final acceptance shall be performed per API 5L Annex E, except where noted

herein.

2) With reference to API 5L clause E.1.3, evaluations of indications shall be performed by

ASNT-TC-1A Level 2 or 3 personnel only. The person responsible for the preparation of

inspection procedures and supervision activities shall be qualified to ASNT-TC-1A Level 3.

3) The only acceptable electromagnetic NDI method is one which utilizes diverted flux. In

accordance with API 5L clause E.5.3.4, a drilled hole shall be used to establish a rejection

threshold.

4) For pipe less than or equal to 0.188 inches (4.7 mm) wall thickness, either an ultrasonic

NDI method or an electromagnetic NDI method which utilizes diverted flux is acceptable. For pipe thicker than 0.188 inches (4.7 mm), the only acceptable method is ultrasonics.

5) The NDI reference standard shall contain both longitudinal and transverse notches. Both

notches and drilled holes with dimensions in accordance with API 5L Table E.7 shall be

required for calibration. API 5L Table E.7 footnote 'g' shall not be invoked.

6) A dynamic standardization (calibration) at production speed using the reference standard

is required. If a standardization check shows that the accuracy of the standardization has

shifted outside of the acceptable range, all lengths of pipe inspected since the last

acceptable standardization shall be re-inspected using the same nondestructive method

previously used.

7) No loss of back reflection is permitted.

8) If not previously inspected, pipe ends shall be inspected by using handheld ultrasonic

shear wave equipment. Alternatively, un-inspected ends may be cropped. Standardization

(calibration) and standardization frequency shall be in the same manner as in item 5,

above.

9) NDI shall be completed after hydrotesting.

10) Pipe shall be checked for magnetism and shall show a maximum of 15 gauss after

completion of all inspection.

11) All indications of defects detected by automatic equipment shall be marked with paint

spray. Defects shall be confirmed by manual ultrasonic or electromagnetic inspection.

6.4.2 Charpy Fracture Toughness Test

1) API 5L Annex G contains the requirements for shear and energy values specific to enhancing resistance to ductile fracture propagation in gas lines. The temperature for

fracture toughness testing shall be as stated in Table 2-8.



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Table 6-8 Temperature Requirements for Charpy Testing

Specified Wall Thickness Test Temperature a,b

inches mm F C

Up to 0.800 Up to 20 Tmin or 32c Tmin or 0

c

0.800 up to 1.57 20 up to 40 Tmin - 18 Tmin - 10

Greater than 1.57 Greater than 40 Tmin- 36 Tmin - 20

a) Tmin is the minimum design temperature as specified on the purchase order.

b) The test temperatures listed are the maximum allowable for a given wall thickness.

c) Testing is permitted at temperatures below those stated. d) Whichever temperature is lower.

2) Charpy impact specimens shall be taken from each test unit or from 100 lengths of heat produced, whichever results in a greater number of impact tests.

3) API 5L Annex G clause G.2.1 item a) shall apply.

4) In natural gas service (> 97% methane), the averaged absorbed energy values (based on three full size specimens) for Charpy impact testing shall be in accordance with API 5L Table G. 1, G.2, or G.3 for design factors 0.625, 0.72, or 0.80, respectively. For design factors other than in Tables G.1, G.2, and G.3, use the table corresponding

to the next higher design factor.

If no table API 5L Annex G is specified on the data sheet, API 5L Table G.3 shall be used by default.

If Section C, Cand/or Dof this specification are applicable, the greatest absorbed energy value shall apply.

5) In rich gas service, the API 5L clause G.9 shall be invoked. Consult Purchaser Material & Corrosion Team for appropriate Charpy impact requirements.

6.4.3 Drop Weight Tear Testing

1) For pipe greater than or equal to 20 inches, Charpy testing shall be supplemented with

DWTT

2) A pressed notch shall be used unless otherwise specified.

3) The test temperature shall conform to Table 6-9.

Table 6-9 Temperatures for Drop Weight Tear Testing

DWTT Test Specimen Size

Specified Pipe Wall Thickness

in. (mm)

Limited to 0.750 in

(19.0 mm) F (C)

Full Wall Thickness

C (F)

< 0.75 (19.0) Samples must be full thickness TMin

< 0.75 (19.0) to < 0.875 (22.2) TMin- 10 (6) TMin

> 0.875 (22.2) to < 1.125 (28.6) TMin - 20 (11) TMin

> 1.125 (28.6) to < 1.563 (39.7) TMin- 30 (17) TMin

> 1.563 (39.7) Consult Purchaser

Materials & Corrosion Team > 1.563 (39.7)

TMin is the minimum design temperature



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6.4.4 Automatic GMAW and GTAW for Pipeline Installation

If automatic gas metal arc welding (GMAW) or gas tungsten arc welding (GTAW) are to be

usedfor pipeline installation, residual magnetism shall be less than orequal to 15 Gauss.

6.4.5 Tensile Tests

1) If specified on the Purchase Order, elevated temperature tests shall be run on one longitudinal

and one transverse sample from one pipe from each of the first three test units and the condi-

tions below.

Transverse yield strength may be determined either using transverse flattened

rectangular specimens or round bar specimens, provided that the same method is used

for all pipe within a given wall thickness and grade.

Testing shall be performed at the maximum design temperature.

Longitudinal and transverse yield and tensile requirements shall comply with Table 6-4.

2) API 5L Table J.2 shall be amended such that the maximum yield to tensile strength ratio on

the tensile specimens shall be 0.90 for grades up to X56 and 0.92 for grades X60 and above

unless otherwise stated on the purchase order.

3) A stress-strain curve shall be produced on one pipe from each of the first five heats for infor-

mational purposes. This information shall be submitted as part of the MPQ data package.

4) The Supplier shall notify the Purchaser if more than 5% strain occurs after final heat treatment.

If so, strain-age embrittlement tensile testing shall be performed per Section E of this specifi-

cation.

6.4.6 Hydrostatic Tests

Each joint of pipe shall be hydrostatically tested using the following method:

1) Hoop stress, S, shall be calculated using alternative percentages of specified minimum yield strength (SMYS) listed in API 5L Table 26 (see "alternative test pressure" column).

2) If a higher test pressure than the alternative is required, it will be specified on the purchase order, or in Section B, C, D, and/or E (if applicable).

3) End seals used for hydrostatic test shall not extend more than 50mm from the pipe end. In the event that available equipment cannot meet this requirement, a seal extension of no more than 200 mm is acceptable, providing 100% RT, UT and MPI are employed inside and outside this length.

4) In cases where a pressure test is incomplete, the serial number of the pipe under test at the time of failure shall be recorded on the chart and it shall be shown clearly on retest that the pipe has performed its proper test.

5) The dead weight pressure calibration shall be performed at least once per week.

6) The acceptance criterion for mill hydrotest shall be no failure.

Pipes that fail the hydrotest shall be quarantined until examined by Purchaser's inspector.

Failed pipes shall be removed from the hydrotest area and quarantined to a location where an investigation to determine the cause of failure can be conducted.

Purchaser shall have access to witness and/or participate in the investigation of the



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failure.

Results of failure investigation shall be made available to Purchaser.

6.5 Workmanship, Visual Inspection, Repair of Defects

1) Where the depth of a surface imperfection is not readily apparent, suitable NDI and

surface grinding shall be performed to assure that the imperfection is completely

removed.

When the surface is ground to remove a surface imperfection, complete removal

shall be verified by magnetic particle examination and re-inspection by the same

method as used to detect the defect.

The remaining wall thickness shall be measured by UT to assure it meets or exceeds the minimum allowable requirements of API 5L Table 11, or the minimum stated on the purchase order.

2) Manufacturers shall take all reasonable precautions to minimize recurring

imperfections, damage, and defects. The Purchaser reserves the right to reject all or

part of the order based on recurring defects. This clause shall be invoked if more than

15% of the pipes produced in a 24-hour period a

kei-pl-2102t~0_flowline carbon steel spec

Documents

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document number keipl

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project description

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electric welded pipe

submerged arc welded

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