GEN-SU-5209

June 2009 2009 Chevron U.S.A. Inc. All rights reserved. 1 of 45

This document is the confidential property of Chevron U.S.A. Inc. Neitherthe whole nor any part of this document may be disclosed to any thirdparty without the prior written consent of Chevron U.S.A. Inc. Neither thewhole nor any part of this document may be reproduced, stored in anyretrieval system or transmitted in any form or by any means (electronic,mechanical, reprographic, recording or otherwise) without the priorwritten consent of Chevron U.S.A. Inc.

GEN-SU-5209

FLANGE GASKETS AND BOLTING

APPLICATION: ONSHORE, TOPSIDES

Rev Date Description Author Sponsor6/09 GR-800 conversion to CES DREE JROF

Flange Gaskets and Bolting GEN-SU-5209


CONTENTS

1.0 Scope ..........................................................................................................................42.0 References ..................................................................................................................4

2.1 ......Purchaser Documents ......................................................................................42.2 ......Industry Codes and Standards .........................................................................4

3.0 Terminology ................................................................................................................43.1 ......Acronyms .........................................................................................................43.2 ......Definitions .........................................................................................................5

4.0 General ........................................................................................................................65.0 Inspection and Repair Flanges .................................................................................6

5.1 ......General .............................................................................................................65.2 ......Gasket Surface Inspection ...............................................................................65.3 ......Warped Flanges and Gasket Surfaces ............................................................75.4 ......Gasket Surface Repairs ...................................................................................8

6.0 Installation of Gaskets ...............................................................................................97.0 Gasket Applicability ...................................................................................................9

7.1 ......Corrugated Gasket Graphite Covered (CGG) Gaskets ....................................97.2 ......Kamprofile Gaskets ........................................................................................107.3 ......Spiral Wound Gaskets with Inner and Outer Rings ........................................107.4 ......Octagonal Ring Joint (ORJ) ...........................................................................117.5 ......Solid Metal Gaskets with Nubbins ..................................................................117.6 ......Other Applications ..........................................................................................117.7 ......Gasket Specifications and Acceptable Brands ...............................................12

8.0 Bolting Up .................................................................................................................128.1 ......General ...........................................................................................................128.2 ......Stud Material ..................................................................................................138.3 ......Spring Washers ..............................................................................................138.4 ......Hardened Washers ........................................................................................138.5 ......Stud Loads .....................................................................................................148.6 ......Stud Length ....................................................................................................158.7 ......Lubrication ......................................................................................................158.8 ......Studs Exposed to Steam or Boiler Feed Water ..............................................178.9 ......Piping Flange Assembly .................................................................................178.10 ....Piping Flange Alignment ................................................................................178.11 ....Stud Tightening Practice ................................................................................188.12 ....Cold Pull Alignment ........................................................................................188.13 ....Hot Bolting or Single Stud Replacement ........................................................198.14 ....Flange Joints in Vibrating Service (Including Liquid Packed Pressure Relief

Devices) .........................................................................................................19



9.0 Torqued Joints .........................................................................................................209.1 ......General ...........................................................................................................209.2 ......Joints to be Torqued .......................................................................................219.3 ......Calculating Torque Values .............................................................................219.4 ......Piping and Pressure Vessels .........................................................................229.5 ......Shell and Tube Heat Exchanger Body Flange Joints .....................................229.6 ......Torquing Hard to Reach Nuts .........................................................................229.7 ......Hot Torquing Shell and Tube Exchanger Body Flange Joints ........................229.8 ......Shell and Tube Heat Exchanger Leaks on Startup or on the Run .................23

10.0 Tensioned Joints ......................................................................................................2510.1 ....General ...........................................................................................................2510.2 ....Joints to Be Tensioned ...................................................................................2510.3 ....Tensioning Procedure ....................................................................................2510.4 ....Hot Tensioning of Heat Exchanger Joints ......................................................2610.5 ....Tensioning Hard to Reach Nuts .....................................................................26

11.0 Boiler Manways and Hand Holes ............................................................................2611.1 ....General ...........................................................................................................2611.2 ....Procedure .......................................................................................................26

12.0 Flange Insulation ......................................................................................................2712.1 ....General ...........................................................................................................2712.2 ....Inclement Weather .........................................................................................2712.3 ....Assembly ........................................................................................................2712.4 ....Tags ...............................................................................................................2712.5 ....Fixed Equipment, Rotating Equipment, and Valve Bonnet Flanges ...............2812.6 ....Temperatures Between 700F and 850F (370C and 455C) ......................2812.7 ....Temperatures Above 850F (455C) ..............................................................2812.8 ....Under Insulation Corrosion Protection ...........................................................28

Appendix A Piping ............................................................................................................29Appendix B Shell and Tube Exchangers (Existing) .......................................................39



1.0 SCOPE1. This specification defines practices for selection, inspection, repair, and torquing/tensioning of

flanged joints.2. This specification is applicable to existing ASME flanges, shell and tube heat exchangers, and

air cooled heat exchangers. 3. This specification does not cover specialty equipment and piping systems with full-faced

gaskets, hub-type connectors, such as Grayloc, Reflange, LTS, and Taperloc, or specialty equipment, such as hair-pin or double-pipe exchangers that require equipment specific sealing materials and assembly procedures. Recommended general bolting practices in this specification do apply.

4. The following are not covered by this specification:a. Small utility, lubrication, and skid mounted heat exchangers that use a sheet type gasket

material.b. Air cooler plugs and gaskets. This service will be addressed on an individual basis.c. API 6B and API 17D flanges, although the practices in this specification may be applied.

2.0 REFERENCES1. The following documents are referenced herein and are considered part of this specification.2. Use the edition of each referenced document in effect on the date of the publication of this

specification

2.1 Purchaser DocumentsEXH-SU-2583 Shell and Tube Heat Exchangers for General Refinery ServiceException to

API 660, 8th EditionEXH-SU-5150 Graphite-Covered Corrugated Metal CGG-Style GasketsEXH-SU-5151 Kamprofile Graphite Covered KAG Style GasketsGEN-DG-5209 Design Guide for Flange Closure Design Calculation SpreadsheetGEN-DS-5209 Data Sheets for Flange Gasket and Bolting

Purchaser DrawingsGD-L1264 Gasket Specifications and Acceptable BrandsGF-C87280 Standard Manholes and Covers for Pressure Vessels

2.2 Industry Codes and StandardsAmerican Petroleum Institute (API)Std 660 Shell-and-Tube Heat Exchangers, Eighth Edition

3.0 TERMINOLOGY

3.1 AcronymsCGGCorrugated gasket graphite cover made specifically to EXH-SU-5150

CMGCorrugated metal graphite (gaskets - generalized industry term for a CGG)



ETGISEvaluation, torquing, gaskets, installation, studs (Purchaser sealing program)

EWOEngineering work order

HFHydrofluoric acid used in Alkylation plants

IDInside diameter

KAGKamprofile gasket graphite covered made specifically to EXH-SU-5151

KAMSerrated gasket sealing surface covered with graphite (such as a KAG gasket)in accordance with EXH-SU-5151

MAWPMaximum allowable working pressure

MOCManagement of change

MPTMinimum pressurizing temperature

NBICNational Board Inspection Code

ODOutside diameter

OEMOriginal equipment manufacturer

ORJOctagonal ring joint

PEGPressure energized gasket (mostly used in reactor heads)

PRDPressure relief device

RADRegulated air drive (air driven torquing tool)

RFRaised face

RMSRoot mean square (refers to surface finish)

RTJRing tongue and groove joint

SCCStress corrosion cracking

SGASheet gasket aramid fiber (also called paper gasket in the field)

SSCSulfide stress cracking

SWSpiral wound (gasket)

T&GTongue and groove

VOCVolatile organic compound

3.2 DefinitionsGrip LengthThe load carrying length of a fastener, from the center of one nut to the center of the opposing nut. For studs in blind holes, the length from the flange face to the top of the nut.

Heat ExchangersWhere used in this document and all attachments the term refers to shell and tube heat exchangers.

Hot Bolting1.) Removal of every other stud on live (pressurized) equipment, prior to a shutdown, in preparation for opening equipment or 2.) Installation of only half of the flange studs prior to a pressure test.

Screw Plug Exchanger (also referred to as a Breech Lock) High pressure heat exchanger with a screw plug closure.



Single Stud Replacement1.) Removal, lubrication, and reinstallation of a single stud on live equipment, prior to a shutdown, in preparation for opening equipment or 2.) Single stud replacement on live equipment.

4.0 GENERALGaskets for raised face and flat face flanges, as well as recessed exchanger flanges, shall always be self-centering.

5.0 INSPECTION AND REPAIR FLANGES

5.1 GeneralThis section outlines post construction inspection and repair procedures for exchanger, piping, boiler, and vessel manway flanges and shall apply to all types of flanges, i.e.; flat face, raised face, ring joint, and tongue and groove, as outlined in Section 5.2 through Section 6.0.

5.2 Gasket Surface Inspection

5.2.1 General1. Flange gasket seating surfaces shall be cleaned.2. Gasket surfaces shall be inspected for the following:

a. Gasket surface finish to verify proper flange finish.b. If needed, a surface finish gauge comparator shall be used to determine gasket

surface finish to achieve pipe flange and exchanger gasket seating surface finish of 125 root mean square (RMS) to 250 RMS.

c. Cracks, corrosion, erosion, mechanical damage, or other defects remaining after cleaning. Minor damage (scratches, pits, etc.) shall not extend more than 50 percent across the radial width of the gasket landing area.

d. Ring Joints1) Amount of coining (lip or ridge) at the bottom of the groove shall be minimal. 2) Amount of coining shall generally be determined by visual inspection and

noting depth using fingernail. 3) Sealing surfaces shall not have any deep pits, gouge marks, corrosion damage,

or sufficient coining to hang a fingernail.4) If there is any concern regarding the condition of the groove, a machinist

bluing compound shall be used to check the contact between the groove and a new gasket. Contact shall be continuous around the circumference of both inner and outer sealing surfaces and at least 70 percent of the height of the sealing surface.

5.2.2 Nubbins1. Nubbins have been used in conjunction with solid metal and jacketed gaskets and are

no longer recommended in ANY application other than some Alkylation Unit Contactors (Reactors) (refer to Section 7.5).

2. Nubbins shall not be used with corrugated gasket graphite covered (CGG) or Kamprofile graphite covered (KAG) gaskets.



3. Nubbins shall be removed and CGG or KAG style gaskets installed when equipment is opened.

4. A temporary management of change (MOC) shall be required if nubbins are to be left in place until the nubbin can be removed at the next opportunity. Contact a sealing subject matter expert for possible gasketing after the MOC has been completed.

5.2.3 Tongue and Groove Flanges1. For tongue and groove flanges, the old gasket material shall be removed each time the

flange is opened. 2. Gasket surfaces on tongue and groove flanges shall be 125 RMS to 250 RMS and free

of pits and defects. If not, they shall be repaired or replaced. Graphite (Thermiculite or Teflon for oxidizing services) covered KAG (with a 1/16 inch [0.063 inch, 1.6 mm] thick core) or CGG style gaskets shall be used.

5.3 Warped Flanges and Gasket Surfaces

5.3.1 General1. Flanges shall be inspected and checked for visual warpage and damage, especially

after any stress relieving process or repair is performed.2. Laying a straight edge across the gasket surface or setting up a field milling machine

with a dial indicator are the two most common ways for checking flanges for flatness.3. Flanges that are warped shall be repaired if the warpage exceeds API Standard 660

requirements included in Appendix B. 4. Gasket surfaces shall be flat and parallel in the circumferential and radial directions to

ensure even seating across the gasket. 5. Unless directed by the work order, gasket surfaces for raised face piping flanges are

not typically dial indicated.6. Refer to GEN-DS-5209 WAR for required readings and instructions.

5.3.2 Exchanger Body Flanges (Existing)1. General

a. Exchanger flanges shall be checked for warpage by performing dial indication readings across the flange and gasket surface as directed by the work order.

b. A dial check shall be mandatory for exchanger and large diameter flanges after welding or stress relieving.

c. A dial check may also be required if there has been an indication of leakage after converting to evaluation, torquing, gaskets, installation, studs (ETGIS) process and installing CGG/KAG gaskets.

d. Refer to GEN-DS-5209 WAR for required readings and instructions.2. Exchangers with CGG/KAG Gaskets

a. The following do not have to be dial indicated unless directed by the work order:1) Exchangers previously converted to CGG/KAG gaskets using the ETGIS

process or this specification that have operated leak free.



2) Small utility exchangers.3) Small exchangers that are part of an equipment skid.4) Exchangers that have provided leak free service with non CGG or KAG

gaskets. b. If gasket surface repairs are performed, gasket surfaces shall be dial indicated.

3. Chronic Leaking Heat Exchangers a. Chronic leaking exchangers shall be checked by performing dial indication

readings radially and circumferentially in accordance with GEN-DS-5209 WAR. b. Guidelines/tolerances for these readings are in Appendix B.

Note Chronic leaking exchangers are ones that have a history of leaks or ones that are leaking at the time of conversion.

5.3.3 Warpage Form1. Dial indication readings on exchanger flanges shall be recorded using

GEN-DS-5209 WAR. 2. If warpage exceeds tolerances shown in Appendix B the surfaces shall be machined. 3. To support the work flow, a completed warpage form shall be completed. 4. Copies of the required warpage forms shall be forwarded to the engineer, inspector,

and/or the person responsible for directing repair work.

5.3.4 Weld Buildup1. Depending on flange thickness, the warped flange may require weld buildup before

machining to maintain the minimum code required flange thickness. 2. Flange thickness shall comply with ASME Code requirements after machining.3. Surfaces shall be machined if the final flange dimensions will be less than the original

equipment manufacturer (OEM) drawing shows.4. An authorized inspector shall be consulted to determine if flange thickness that is less

than original is considered an alteration.

5.4 Gasket Surface Repairs

5.4.1 General1. Flange gasket surfaces may be repaired by weld buildup and remachining. 2. Weld repairs on any flange shall be performed in accordance with an ASME qualified

weld procedure. 3. Piping flanges may be easier to replace rather than repair.

5.4.2 Flange Refacing1. In some cases, the flange can be refaced without weld metal buildup. 2. Flange thickness shall be verified as thick enough to meet code requirements after

machining. (Flange strength is based on the thickness that does not include the raised face.)



3. OEM flange dimensions shall preferably be maintained on all equipment. Flange minimum thickness calculations shall be completed prior to opening the heat exchanger vessel or piping if OEM dimensions are not going to be maintained prior to machining.

4. Actual dimensions shall be verified in the field before performing any machining.5. Repair of gasket surfaces may be subject to a variety of purchaser, local, state,

country, ASME code, and national board requirements. Some repairs will require a National Board R-symbol stamp. To ensure that all requirements are properly met, the Authorized Inspector (AI) or an appropriate subject matter expert shall be consulted.

5.4.3 Routine Repairs1. Routine repairs as defined in the National Board Inspection Code (NBIC) are not

recognized in California. 2. In California, inspector involvement and stamping, shall be required for gasket

surface weld repairs on Code vessels and Code piping.

6.0 INSTALLATION OF GASKETS 1. Gaskets for existing heat exchangers shall be installed in accordance with Appendix

Section B.2. 2. Pipe flange gaskets shall be installed in accordance with Appendix Section A.1.3. Gasket specification and acceptable brands shall comply with GD-L1264. 4. Pipe flange torque values for standard ASME RF, RTJ, and tongue and grove (T&G) flanges

shall comply with Appendix Table A-1. 5. Torque values for non ASME/specially designed flanges, such as large diameter low pressure

knife gate flanges, shall be provided in the work order or by the person responsible for the work.

6. For graphite covered gaskets, if the graphite is damaged to the point where the core is exposed, the area shall be repaired by covering it with adhesive backed APX-2 graphite tape. Only the minimum amount of tape needed for the repair shall be used, and edges shall not be overlapped by more than 1/16 inch (0.063 inch, 1.6 mm).

7.0 GASKET APPLICABILITY

7.1 Corrugated Gasket Graphite Covered (CGG) Gaskets 1. CGG gaskets shall be used in process heat exchangers, including cooling water and screw plug

exchangers, in accordance with the following:a. In nonoxidizing services 800F (425C) and below design if one edge of the gasket is

exposed to air. (Inside columns, in air free nonoxidizing service, the temperature limit is higher.)

b. Radial gasket widths of 1/2 inch (12.7 mm) and greater.c. T&G flanges that use a 1/2 inch (12.7 mm) or wider gasket and coke drum transition spool

flanges.2. CGG gaskets may also be used in other special closure designs but are generally not

recommended for pipe flanges.



7.2 Kamprofile Gaskets KAG Kamprofile gaskets shall be used in the following applications:1. Process heat exchangers, including cooling water and screw plug exchangers, in accordance

with the following:a. In nonoxidizing services 800F (425C) and below.b. Radial gasket widths of less than 1/2 inch (12.7 mm).c. Where a thicker gasket is required to prevent body flange faces from touching.

2. Raised face piping flanges in class 150 and class 300 nonoxidizing services unless there is a technical reason to use Spiral Wound.

3. Raised face piping flanges in class 600 and higher that are:a. Chronic leakers.b. Approved for use.

4. KAG gaskets shall be considered for any raised face (RF) piping flange over 24 inches if either:a. There is concern over the possibility of windings popping out of spiral wound (SW) gasket

guide rings.b. The windings cannot be kept loaded.

5. Any other closure designs, such as furnace tube closure blinds, in nonoxidizing services 800F (425C) and below.

6. Vessel manways.7. T&G flanges, if a 1/16 (0.063 inch, 1.6 mm) inch core is used.8. KAG gaskets can be used above 800F (425C) if specially designed with a mica barrier on the

outside diameter ([OD], and inside diameter [ID], if needed) to protect the graphite from high temperature oxidation, where one edge of the gasket is exposed to air.

7.3 Spiral Wound Gaskets with Inner and Outer Rings SW gaskets with inner and outer rings shall be used in the following applications:1. Raised face piping flanges in services 800F (425C) and below for class 600, class 900, and

class 1500. For large SW gaskets, tape (including graphite tape) shall not be used to hold the windings in place. The tape will prevent the windings from being properly loaded.

2. Raised face piping flanges in class 150 and class 300, if volatile organic compound (VOC) emissions are not a concern, KAG gaskets are not available, or there is a technical reason to use this gasket to over a KAG.

3. Raised face piping flanges in 150 and 300 class lube and seal oil service, if there is concern of contaminating oil system with small graphite pieces.

4. Hydrofluoric Acid (HF) Alkylation Units that have successfully used SW gaskets with Monel windings and inner rings and either Teflon or graphite filler may stay with this gasket design for HF service. (KAG gaskets are a recommended upgrade.)



7.4 Octagonal Ring Joint (ORJ)1. ORJ (oval rings are not recommended) and KAM-ORJ gaskets shall be used in the following

applications:a. Ring joint piping flanges in class 2500.b. Ring joint piping flanges for service temperatures above 800F (425C).c. Existing ring joint piping flanges in class 300, 600, class 900, and class 1500.

2. ORJ gaskets shall be used in flanges with ring joint grooves that are in as new condition and have no history of leaks. ORJ gaskets shall be replaced each time the flange is opened.

3. KAM-ORJ gaskets shall be used in:a. Flanges with ring grooves that are slightly damaged.b. Flanges that are broken apart at a frequency greater than once every five (5) years.c. Flanges with a history of leaking (such as reactor companion flanges on the top and

bottom ells).4. For KAM-ORJ gaskets in service temperatures above 800F (425C), a mica based or

Thermiculite covering shall be specified in lieu of APX-2 graphite on the gasket edge that is exposed to air. See GD-L1264 for a complete list of approved materials.

7.5 Solid Metal Gaskets with Nubbins 1. Solid metal gaskets and nubbins are approved for use in Alkylation Unit Contractors

(Reactors) if:a. Contractors operate at ambient temperature or below.b. The Contractors were originally built with this sealing system.

2. Nubbins and solid metal or clad gaskets shall not be allowed on equipment operated at elevated temperatures.

7.6 Other Applications

7.6.1 Metal Jacketed (Clad) Gaskets Metal jacketed (clad) gaskets and solid flat metal gaskets (except air cooler plug gaskets) shall not be used except as discussed in Section 7.5.

7.6.2 Reactor Pressure Energized Gaskets (PEGs) and Screw Plug Heat Exchangers 1. Reactor PEGs and screw plug heat exchangers are covered by specific instructions

that pertain to the individual piece of equipment. 2. Sections of this specification regarding gasket selection and bolting technique are

consistent with specifications specific to this equipment.

7.6.3 Heat Exchangers That Do Not Use CGG or KAG GasketsHeat exchangers that comply with service, code, and temperature requirements but do not currently use CGG or KAG gaskets shall be converted using the conversion process as covered by this specification.



7.6.4 Glass Reinforced Epoxy (GRE) Gaskets for Electrical IsolationGRE gaskets are no longer recommended for use. For Electrical isolation of flanges, use coated metal core gasket only such as Pikotek VCS or VCDFS (firesafe); or equal.

7.7 Gasket Specifications and Acceptable Brands1. Refer to drawing GD-L1264 for gasket specifications and acceptable brands information. 2. Sheet gaskets in accordance with gasket code sheet gasket aramid fiber (SGA) shall be

acceptable for temporary isolation blinds. 3. The same sheet material and temporary flat plate isolation blinds used in raised face flanges

may also be used in ORJ flanges. 4. ALL gaskets used in columns shall be rated for the maximum temperature of the column.

Generally, SGA gaskets are not to be used in columns and should be replaced by KAG, SWG, or SGG materials. Refer to GD L1264 for additional guidance.

5. EXH-SU-5150 contains the complete specification for CGG (CMG) gasket style, andEXH-SU-5151 contains the complete specification for Kamprofile (KAG) gasket style.

8.0 BOLTING UP

8.1 General1. This specification generally applies to the bolting up of all flanged piping, exchanger, and

other pressure vessel connections. Bolting is a generic term that describes the use of either a threaded fastener with a fixed head (a bolt) or a stud (a threaded rod), on which one or two nuts are used to retain the load.

2. The ideal choice for ensuring the accuracy of stud loads is to replace the studs and nuts in kind with new ones each time the connection is opened and torque the nuts to a desired stud load that will achieve the required gasket stress.

3. Studs that are tensioned (the stud is stretched with a tensioning head) do not need to be replaced, as long as the nut can be turned by hand, and the stud can still carry the load.

4. In the case of special alloys, studs that are threaded into blind holes and are difficult to remove (e.g., reactor studs) or specially made fasteners (e.g., screw plug jacking screws), it may be more economical to recondition the threads and reuse the fastener.

5. The following options (in order of effectiveness) shall be acceptable for reconditioned threads as long as the result allows the threads to run freely over each other using only the fingers and the load carrying requirements of the fastener have not been reduced:a. Recondition studs and nuts using taps and dies. This approach is the most effective at

protecting the load carrying ability of the existing threads as the taps and dies generally just remove surface contamination on the threads. In some cases, it may be easier to use dies on the stud threads and replace the nuts.

b. Recondition studs and nuts using a light bead blast. A close check for corrosion or mechanical damage shall be required after blasting. In some cases, additional reconditioning with taps and dies may be required. If the bead blast results in metal loss that increases the clearance between male and female threads, the threaded component(s) shall be replaced.

6. Threads on studs and nuts that are to be retorqued shall not be reconditioned by wire brushing. Wiring brushing may be used on studs that are to be tensioned, as the frictional differences



between studs will not affect the accuracy of the final load. The tensioner puller bar and nuts must run freely on the stud. If not, a tap and die nut shall be used to correct the problem or the components shall be replaced.

7. For special closures (screw plug exchangers, reactor heads, the packed glands on exchanger distance pieces, etc.), the equipment specific procedures and instructions included in the work order shall be followed.

8.2 Stud Material1. If the stud metallurgy is not adequate to withstand environmental or process conditions, a

review shall be performed and the metallurgy changed to a more suitable material. 2. A change in metallurgy may require a code review and calculations, along with a review of the

operating gasket stress for leak tight operation, e.g., changing from SA-193 B7 in a floating head application to SA-193 B8 stud material, which has a lower yield strength.

3. For a listing of available bolting material, yield strength, temperature limits, and applications, refer to Appendix Table A-2.

8.3 Spring WashersInstallation of spring washers (Belleville washers) shall not be allowed for flanged joints because they:1. Do not provide an advantage on a heat exchanger or piping joints.2. Are susceptible to hydrogen stress corrosion cracking from contact with water (if they are

made from high strength carbon steel).3. Are expensive.4. Are susceptible to cracking. 5. Are difficult to reinstall in the right configuration (cup to cup or cone to cone).6. Usually require use of multiple washers (three to five or more) to gain any advantage.

8.4 Hardened Washers

8.4.1 General1. Hardened washers shall be installed under nuts to be torqued on all exchanger body

flange joints that use SA-193-B7 or B16 stud material. 2. Washers shall be ASTM F-436 class 1 specification. 3. Washer thickness shall be at least 1/8 inch (3.17 mm) and compatible with the stud

size. 4. Hardened washer, if reused, shall not have any galling, grooving, or burrs. 5. Pipe flange studs being wrench tightened shall not require hardened washers, if the

nuts contain an integral washer that is installed face down against the bearing surface. 6. Washers are optional on manways and pipe flanges that have to be torqued, provided

that the bearing surface is in reasonably good shape. 7. Washers shall be used on manways and pipe flanges if the bearing surface is badly

worn, galled, or if the corners of the nuts are in danger of hitting the flange face due to an excessively deep pocket that has been worn into the flange.



8. Glass reinforced epoxy washers (G10) are no longer recommended for electrical isolation of flange joints. Use coated metal core washers only such as Pikotek HCS or equal.

8.4.2 Materials1. Changes in washer material or use of hardened washers with stud materials other than

SA-193-B7 or B16 shall be reviewed by a material engineer or other qualified person. 2. In some cases, standard washers cannot be used (e.g., with fine thread floating head

studs, as the washer will protrude past the flange OD).

8.4.3 Placement of Washers1. For safety considerations, if the nut is accessible from either end of the stud, the

hardened washer shall be installed under the appropriate nut to be torqued such that the torque wrench will be pulled in a downward direction during the torquing operation.

2. For exchanger channel cover flanges, washers shall be placed on the channel cover. 3. For other exchanger body flanges, washers shall be placed on the flange to the left

when facing the connection from either side of the exchanger. For channel to shell connections, this will result in washers being place on the channel flange on the right side of the exchanger (when facing the front of the exchanger) and on the shell flange on the left side of the exchanger.

4. For vertical reboilers, on which studs are initially tightened in the horizontal position and hot torqued in the vertical positions, washers can be placed under both nuts. (Some facilities do this on all exchangers to simplify washer placements.)

8.5 Stud Loads

8.5.1 Shell and Tube Heat Exchangers1. Stud loads for heat exchangers shall generally range from 50 percent to 90 percent of

the minimum code yield strength of 105,000 psi (724 Mp, 7,240 Bar) (for B7 and B16 stud material, 52,500 psi (362 Mp, 3,620 Bar) to 94,500 psi (652 Mp, 6,516 Bar).

2. Stud loads shall be adjusted to obtain a targeted gasket stresses of 20,000 psi (138 Mp, 1,379 Bar), with a maximum of 40,000 psi (276 Mp, 2,758 Bar) and a minimum of 10,000 psi (69 Mp, 689 Bar).

3. If a gasket stress is to too high, the radial width of the gasket shall be increased by reducing the ID (making the gasket wider and increasing the contact area) to reduce the gasket stress. This is usually required for gaskets on the low pressure side of tubesheets that have a differential pressure that is 300 psi (2 Mp, 20.68 Bar) or higher.

4. If the gasket stress is too low, the radial width shall be reduced. If the radial width is less than 1/2 inch (12.7 mm), a KAG gasket shall be used. KAG gaskets are not recommended with radial widths below 3/8 inch (9.5 mm) but have been used down to a 1/4 inch (6.35 mm) radial width if no other option is available.

5. To calculate a torque value, a nut or K factor of 0.17 shall be used. 6. GEN-DS-5209 FCD shall be used to calculate gasket stresses and torque values for

heat exchangers. For more on GEN-DS-5209 FCD please see GEN-DG-5209.



8.5.2 Pipe Flanges1. Stud loads for pipe flanges shall be set to obtain an approximate 25,000 psi (172 Mp,

1.724 Bar) gasket stress. A summary of pipe flange torque values are found in Appendix Table A-1.

2. Gasket stresses and torque values for ASME pipe flanges have been calculated using the GEN-DS-5209 FTS for both RF and RTJ flanges. This document also contains the maximum stud load that can be used with each flange size and class.

3. For flanges over 24 inches, the GEN-DS-5209 LGF shall be used. 4. To calculating a torque value, a nut or K factor of 0.15 shall be used.

8.6 Stud Length1. Studs shall be long enough to ensure that all threads in the nuts are fully engaged. 2. Studs shall be flushed with the nut, with a maximum of two threads exposed past the nut that

should break first during disassembly. 3. Extra stud length may extend past the non-breaking nut. 4. Studs shall not be butterflied where extra threads are distributed evenly past both nuts.

8.7 Lubrication

8.7.1 General1. Stud threads shall be thoroughly lubricated on both ends during final assembly. 2. Bearing surfaces between the nut and hardened washer or the nut and flange on the

end that will be torqued shall be lubricated to ensure that the proper torque load is applied. This can easily be accomplished by filling the threads with antiseize in the area where the nut will rest and then allow the antiseize to squeeze out as the nut makes contact.

3. Studs may be lubricated only on one end for flanges that are being blinded during a shutdown.

4. The antiseize on the complete assembly shall be easily visible.

8.7.2 Lubricants1. Only Jet-Lube 550 antiseize lubricant shall be used for flange temperatures up to

600F. 2. For blind stud holes and temperatures above 600F (516C) (i.e., reactor heads and

coker drums, delta valves), Jet-Lube Riser and Superior Plant Services Molly- B are approved. If Hot Torquing is required, see Section 8.7.3.

3. These products are molybdenum disulfide based. 4. Substitutions shall not be allowed, unless approved in writing by the person

responsible for the job.

8.7.3 Hot Torquing1. If hot torquing is required after using Molly-B or Jet-Lube Riser, a new temperature

based torque value shall be calculated, as the friction factor drops substantially when the temperature rises. (Refer to Figure 1 and Figure 2) This can cause the studs to be



over loaded if the torque value is not reduced to compensate for the change in temperature.

2. Figure 1 shows Jet-Lube 550 (MO2) is fairly temperature stable. The nut or K factor changes little with temperature, so the original torque value can be used for the hot torque.

3. Figure 2 shows the significant change in nut or K factor, with the change in temperature for Molly-B and Jet-Lube Riser.

Figure 1: Nut Factor Results - MO2 (This graph comes from original product testing on nut factors at the TTRL Laboratory in Montreal and is published with permission from the author, Dr. Warren Brown.)

Figure 2: Nut Factor Results - MO1 (This graph comes from original product testing on nut factors at the TTRL Laboratory in Montreal and is published with permission from the author, Dr. Warren Brown.)

Average 95% Percentile5% Percentile Range (% of Average)

0.05

0.07

0.09

0.11

0.13

0.15

0.17

0.19

0.21

0.23

0.25

25C 100C 200CTest Temperature (C)

K F

acto

r

0

4

8

12

16

20

24

28

32

36

4075F 210F 390F

Ran

ge (

% o

f A

vera

ge)



8.7.4 Gasket SurfacesAnti-seize lubricant shall not be applied to the gasket surface.

8.8 Studs Exposed to Steam or Boiler Feed WaterStuds in flanges that have leaked boiler feed water, steam, condensate, or caustic over an extended period of time shall be replaced when the flange leak is repaired and gasket replaced. Studs in these conditions are prone to failure due to caustic embrittlement where caustic is sometimes used to treat boiler feedwater and condensate systems.

8.9 Piping Flange Assembly 1. Also refer to Appendix A. 2. Flat faced or raised face piping flanges shall be assembled as follows:

a. Flanges shall be faced together.b. Studs shall be installed in half of the flange to help center the gasket.c. The gasket and remaining studs shall then be installed.

3. On tongue and groove and ring joint flanges, the gasket shall be inserted before the flanges are faced together. If the tongue and groove gasket will not stay in place while facing the flanges together, several dabs of heavy grease or 3M Super 77 spray adhesive may be used on the seating surface to hold the gasket in position.

4. When assembling cast iron flanges or RFP (fiberglass), flange faces shall be full faced and not mated to RF flanges. Only full faced gaskets shall be used when assembling these flanges.

5. Flat face flanges made of ductile iron, carbon steel or stainless steel can be mated with raised face flanges. The appropriate raised face ring gaskets shall be used for these applications.

8.10 Piping Flange Alignment

8.10.1 General1. Pipe flanges shall be properly aligned before bolting. 2. If alignment cannot be corrected by loosening adjacent flanges and shifting the ends

of connecting pipe spools, the piping shall be cut and fit up properly.

8.10.2 After Final Assembly1. After final assembly, RF and RTJ flanges less than 24 inches in diameter shall be less

than 1/32 inch of an inch (0.032, 0.813 mm) of parallel (cocked) as measured across any flange outside diameter.

2. The flange gap shall be checked after final assembly of all flanges.

8.10.3 Small Gaps1. Small gaps, up to 1/16 inch, due to unparallel piping flange faces, may be tightened by

pulling up on the studs at the widest flange separation point and then tightening all the studs.

2. The pipe shall have enough flexibility to allow the flanges to pull together.



8.10.4 Alignment Procedure1. Flanges shall be aligned by inserting a spud wrench bar in an open bolt hole and

installing two studs opposite each other to hold the flanges in position. 2. Excessive force, if required to align the flanges, shall be corrected. 3. Forces shall be considered excessive if either:

a. Come alongs, cranes, hoists, or jacks are needed to align the flanges.b. Bolting is needed to pull the flanges together, i.e., excessive gap between the

flanges. 4. The piping shall be inspected to determine if it needs to be redesigned to reduce forces

in the piping and/or equipment. 5. A stress analysis may need to be performed.

8.11 Stud Tightening Practice1. Studs shall be hand tightened and torqued in the specified pattern around the flange until all

the studs have the same tension. Refer to Appendix Section A.3 for piping joint torque patterns.

2. Persuaders or handle extensions shall not be used on wrenches. This practice can result in broken wrenches, bent flanges, and personal injury.

3. Short Stiff Manifoldsa. On short stiff manifolds, such as at pumps, equipment nozzles, compressors, turbines,

control and valves, flanges shall fit squarely without cold pull or line strain. b. Custom Made Spacers

1) In some cases, a custom made spacer may be used to correct misalignment. 2) These spacers shall be constructed with a tab welded to the spacer. 3) The tab shall stick out past the flanges and insulation. 4) The location of the spacer shall be etched on the tab, e.g., P 8400C suction piping

spacer.5) Metallurgy and design details of the spacer shall be consistent with the piping

specification.4. Bending piping spools into alignment by heating and pulling into place with the studs is not

recommended, as residual line stresses remain after heating. The root cause of the problem shall be determined and corrected.

8.12 Cold Pull Alignment1. Review

a. If flanges are in alignment but require cold pull to make up the gap between the flanges, the installation shall be reviewed to determine if modifications are required.

b. Cold spring or pull shall not normally be used in a refinery to compensate for line expansion.

c. If cold spring or pull is noted, checks shall be performed to see whether:1) Piping is properly anchored.2) Piping has moved or shifted on the pipe supports due to repeated thermal expansion.



3) A pipe shoe slipped off the pipe support and is hung up on a support holding the line.4) There are other line restraints holding the line.

2. If the line cannot be made up without cold spring, a stress analysis shall be performed on the line to determine whether the line can either:a. Be pulled into place.b. Needs to be redesigned to fit up without line strain.

3. Misalignment from Cold Stress Movementa. In some cases, in high temperature applications, such as reactor inlet and outlet piping,

flanges may be misaligned due to cold stress movement.

Note Cutting and rewelding of flanges will not resolve this issue, as flanges will return to normal alignment when operating temperature is reached.

b. In these cases, flanges shall be aligned and squared using a come along and high side bolting to square flange before making contact with gasket. After the line is in service, the studs should be retightened. Outside flange and nut temperatures above 250F may be too hot for hydraulic torque equipment to perform this operation.

8.13 Hot Bolting or Single Stud Replacement

8.13.1 General

Note Hot bolting (using only half the studs for a pressure or hydrotest or removing studs in operating equipment prior to a shutdown) and single stud replacement on operating equipment shall not be allowed, unless the procedure outlined in Section 8.13.2 is followed.

8.13.2 Procedure1. Hot bolting of any equipment may only proceed after completing the MOC process,

including a job safety review, an engineering review, and issuance of a written operating procedure specifying allowable temperature and pressure limits. An example is when feed has been pulled and plant is being steamed out to relief with less than 15 psig pressure buildup and flange temperature is below 200F (93C).

2. Single stud replacement shall be subject to the same approval process as hot bolting in Section 8.13.1.

8.14 Flange Joints in Vibrating Service (Including Liquid Packed Pressure Relief Devices)

1. Equipment reliability can be significantly affected if it is subjected to constant or high levels of vibration.

2. Immediate operational changes should be made to eliminate unexpected vibration that suddenly develops in equipment.

3. Engineering analysis shall be performed on lines subject to vibration to define the extent of the problem, and design changes or plant modifications shall be made to reduce the level of vibration to safe levels.

4. Piping sections that are allowed to vibrate may potentially lead to the following:a. Flange leaks



b. External thinning of piping rubbing on supportsc. Fatigue failure, depending on frequency and amplitude of displacement

5. Typical locations where piping vibration may occur are in the vicinity of the following:a. Reciprocating compressorsb. Reciprocating pumpsc. Control valve manifoldsd. Let down stationse. Power recovery turbinesf. Pressure relief device (PRD)

6. Observed Vibration of Piping Sectionsa. Piping sections in the plant that exhibit vibration shall be brought to the attention

of the responsible engineer. b. Such piping sections shall be reviewed to determine whether they have previously

been analyzed and all corrective actions completed. c. For piping sections not previously analyzed, a dynamic stress analysis study can

be performed and in most cases relocation of supports can reduce vibration intensity.

7. Check for Missing or Loose Nuts on Flangesa. Piping sections continually exposed to vibration for which analysis has shown are

within allowable stresses shall be walked down periodically or at least once a year to check for missing or loose nuts on flanges.

b. Missing or loose nuts that are discovered shall be reported to the responsible engineer, as they may indicate a system wide problem and a precursor to one or more potential flange leaks.

c. This is especially true for relief systems that are liquid packed if the PRD has a tendency to lift and close repeatedly (chatter) or systems subject to cavitation due to change in fluid phase.

d. A plan of action shall be determined and, as a minimum, the studs and nuts at the missing or loose nut locations shall be replaced before retightening.

e. Piping sections that continue to experience vibration, even after mitigation attempts are performed, shall be flagged for replacement of gaskets and studs in flanges during planned turnarounds at 10-year intervals.

f. Gasket and stud replacement on vibrating PRD piping sections shall be coordinated during PRD removal for repair and recertification.

9.0 TORQUED JOINTS

9.1 General1. Many joints, depending on service and size, shall require torquing to ensure even stud loading

and prevent leaks.



2. Joints that are to be torqued shall be subject to the following:a. For shell and tube heat exchangers, studs shall be new or reconditioned (using taps and

dies) and hardened washer shall be placed under the nut that is to be torqued.b. For pipe flanges, the nuts shall run freely with the fingers, or the stud and nut shall be

replaced. Hardened washers are only required under the nut that is being tightened if the flange face is galled (such that there is not a smooth surface for the nut to tighten against) or if the flange is worn to the point where the corners of the nut are contacting the flange face.

c. Both ends of the studs shall be lubricated with antiseize. 3. Tensioning is also an option and may be required if studs are reused. See Section 10.0.

9.2 Joints to be TorquedThe following joints shall be torqued:1. All shell and tube exchanger body flange connections.2. Piping and equipment flanges that require 200 ft-lb (270 Nms) of torque or more.3. Reactor top and bottom manways that use standard octagonal ring (ORJ/RTJ) or KAM/ORJ

gaskets.

9.3 Calculating Torque Values1. Stud loads shall be calculated first to achieve the targeted gasket stress under operating

conditions for the specific gasket material that is being used. 2. Torque values and gasket stresses for all shell and tube exchangers stress shall be calculated

using the GEN-DS-5209 FCD.3. Torque values and gasket stresses for all pipe flanges up to 24 inches were calculated using the

GEN-DS-5209 FTS.4. Torque values and gasket stresses for all API and MSS flanges from 26 inches to 60 inches

(66 cm153 cm) shall be calculated using the GEN-DS-5209 LGF on a case by case basis to reflect operating pressure.

Studs in Tapped Holes1. For studs threaded into tapped holes, torque values shall be limited by the weakest set of

threads. While tapped holes are usually in materials with lower yield strengths than B7 or B16 stud material, additional thread length can offsets this discrepancy. See the Stud Stuff tab in the GEN-DS-5209 FCD spreadsheet for calculating stripping loads.

2. If some of the tapped hole threads are damaged, the length of thread engagement in the calculation shall be reduced by the percent of damaged threads (e.g., if the threaded hole was 2-inches deep and 50 percent of the threads damaged, 1.0 inch of thread engagement can be used for the calculation).

3. To calculate thread stripping loads, the Stud Stuff tab in GEN-DS-5209 FCD can be used.



9.4 Piping and Pressure Vessels

9.4.1 General1. For piping and vessel manway flanges that are either a standard ASME ring joint or a

standard ASME raised face flange, torque values supplied in Appendix Table A-1 and torque procedure in Appendix Section A.3 shall be used.

2. If manway flanges are a different type, such as GF-C87280, the gasket stress and torque shall be calculated using the appropriate spreadsheet.

9.4.2 Leaks1. If a torqued joint leaks after using the proper assembly procedure, lubrication and

torquing value, the connection shall be retorqued back to the original torque value. (Do NOT increase the torque value at this point.)

2. If the joint continues to leak, the feasibility of using a higher torque value shall be determined after using the proper spreadsheet and evaluating the impact of higher stud loads on gasket stress and flange strength.

3. Torque shall not be increased without approval following a technical review.

9.5 Shell and Tube Heat Exchanger Body Flange Joints1. Heat exchanger joints (body flanges, floating heads, cover plates, etc.) shall be torqued using

the torque values and procedure supplied in the work order or approved data base. 2. The procedure in Appendix Section A.3 (for less than 24 studs) or Appendix Section B.3

(24 studs or more) shall be followed. 3. If the connection leaks during the hydrotest, studs shall be retorqued to their original target

load in accordance with the applicable procedure. 4. If the joint continues to leak, the requirements in Section 9.4.2 above shall be followed.

9.6 Torquing Hard to Reach NutsIf torque wrench access to nuts is blocked by equipment nozzles or other obstructions, the following procedure shall be used: 1. After all the accessible studs have been torqued to their final load, start by backing off one nut

that is easy to reach and then hand tighten. 2. Mark one of the corners on the nut against the flange and then count the number of flats the nut

is moved by the time it is fully torqued. 3. Use a slug wrench or other appropriate tool to move the hard to reach nut(s) the same number

of flats after they have been hand tightened. Remember to hold the slug wrench with a device and not your hands.

9.7 Hot Torquing Shell and Tube Exchanger Body Flange Joints

9.7.1 General1. Exchanger body flanges shall be hot torqued during startup to reload the gasket to the

proper seating stress. 2. Hot torquing shall be performed in a circular pattern and typically requires one pass,

plus the four studs that are past the point where the torque pattern was started.



3. In hot torquing, each nut shall move or be broken loose to apply the correct torque value. (Torque is measured on a rotating fastener, not a stationary one.)

4. Studs and nuts tend to stick together (thread embedment) after sitting for awhile, and additional torque may be required to overcome this added friction. Contact Engineering before increasing torque values.

5. Refer to Appendix B Section B.2 for additional information.

9.7.2 Before Startup1. Before startup, the joint shall be retorqued to the original specified torque value if the

joint has been pressure tested with hot water or steam or heated in any way.2. For new exchangers, all studs shall be torqued before startup to recover any gasket

relaxation that might have occurred while the exchanger was in storage or transit.

9.7.3 After Startup1. After startup, the joint shall be retorqued to the specified torque value when the cooler

of the two mating flanges is between 250F and 400F (120C and 205C) on the coolest part of the flange.

2. If the exchanger flange does not reach 250F (120C), hot torque shall be performed after the exchanger has been in service for 3 days.

3. If some exchangers have a section of the flange that will remain below the 250F (120C) minimum hot torque temperature (this is often a problem on steam generators):a. Hot torque the rest of the flange if minimum temperature of either mating flange is

over 250F (120C).b. Come back after three (3) days and hot torque the section of the flange that was

below 250F (120C). The torque pattern shall extend far enough past the studs that were previously hot torqued such that no nut movement is observed.

4. Exchanger flange temperature at time of the hot torque shall be verified with a temperature gun or magnetic thermometer 360 around the perimeter of the flange, and all safety concerns shall be addressed.

5. The order in which the exchangers will heat up shall be identified by operations. This order shall be followed for hot torquing.

6. If there is a concern that the hot torque might have been done too soon, additional hot torques can be performed with no impact on gasket performance.

9.7.4 Shell and Tube Body Flange Temperatures Over 400F (205C)Hot torquing shall preferably not be performed at temperatures over 400F (205C) as the stud and nut friction factor increase substantially as the lubricant burns off. This reduces the accuracy of the stud loads.



9.8 Shell and Tube Heat Exchanger Leaks on Startup or on the Run

9.8.1 General1. This step shall require approval before proceeding with retorquing a leaking joint

during startup or on the run. 2. After approval, exchanger joints that leak during startup or on the run shall be hot

torqued in accordance with Section 9.8.2.

9.8.2 Procedure1. Lower temperatures where the grease in the antiseize has not burned off the threads

a. If the grease in the antiseize has not burned off, the joint shall be retorqued using a circular pattern, plus four studs past the starting point. Use the original specified torque values and wait long enough to determine if this stops the leak.

b. Original specified torque value shall not be exceeded without completing a technical review in accordance with Section 9.4.2.

2. Higher temperatures where the grease in the antiseize has burned off the threadsa. If the grease in the antiseize has burned off the turn of the nut method shall be

used. (e.g.,turn each nut the same amount.) b. An engineering work order shall be issued outlining when to use the turn of the

nut method and how far each nut should be turned. c. The extent to which the nut should be moved shall be calculated as a small amount

of movement can increase the stud load significantly. See the formula below.

To calculate the change in stud stress per one full flat of nut rotation:

Stud Stress, psi = 1 / (threads per inch) / (6, total flats on a hex nut) (Modulus of Elasticity, psi) / (Grip Length, inches)

To calculate the change in stud length:

Change in Length = (Stud Stress, psi) (Grip Length, inches) / (Modulus of Elasticity, psi)Modulus of Elasticity for B7 Studs = 29,700,000 psi

d. For shell and tube heat exchangers, turning nuts one half flat can add up to approximately 15,000 psi additional stud load, assuming 8 threads per inch and a grip length of 20 inches. Note that this also equals 0.010 inches of stud stretch. Since some of the mechanical movement can go into flange rotation, some into gasket relaxation (depending on how long the gasket has been in service) and some goes into additional stud load, it is difficult to say exactly how much load will actually go into the stud. Field data shows that in some cases (e.g. new gaskets during original assembly) as little as 50 percent of nut rotation actually transfers into higher stud load.

However, experience has shown that when flange leaks develop, these are usually the result of low gasket stress (and thus low stud stress). The 15,000 psi of additional stud stress is enough to add sufficient gasket stress to reseal the gasket reliably without having a detrimental effect on the flanges function or reliability. If there is concern about the level the gasket stress might increase as the stud load is raised, the gasket stress shall be recalculated with the new targeted stud stress using the appropriate spreadsheet.



All bolted connections relax when heated, and if the connection is leaking, it is an indication that the gasket and stud stresses are below what is required to maintain the seal. Adding 15,000 psi stud stress will raise gasket stresses above the minimum values needed to seal usually without approaching flange yield values. Even if we assume that the flange does yield, using the example above the entire amount of flange roll at the bolt circle would be limited to the amount that the nut is moved, or 0.010 of an inch. This is insignificant.

If the connection continues to leak after the 15,000 psi stud stress has been added, additional analysis to find and correct the root cause shall be performed, the connection clamped or the gasket replaced.

e. Start by marking the location of one of the nut corners against the flange surface and then turn the nut the prescribed number of flats as directed by the work order.

10.0 TENSIONED JOINTS

10.1 General1. Tensioning the studs is always an option. 2. Tensioning shall be employed if very accurate stud loads are required or if studs are going to

be reused (such as reactor and coke drum transition spool flange studs). 3. Only specific pieces of equipment shall require tensioning (as specified in the work order),

including some pipe flanges, such as reactor companion flanges.4. At least one stud diameter shall extend above the nut for tensioning to be performed.5. Tensioning shall be performed in accordance with the procedure that will be included with the

work order.

10.2 Joints to Be TensionedThe following shall be tensioned:1. All reactor inlet and outlet connections with PEG gaskets, regardless of stud size.2. Coke drum top and bottom transition spool flanges.3. Applications in which studs are threaded into blind holes and going to be reused, such as

reactor heads and manways.

10.3 Tensioning Procedure1. At least one fourth of all the studs shall be tensioned simultaneously. Preferably, half of the

studs should be tensioned at one time if enough tensioning heads are available.2. Studs have to be pulled to a stud load that is in excess of the final desired load to compensate

for strain loss when the load is transferred from the tensioning device to the nut. Some companies over pull by 25 percent to compensate for this strain loss, but it is recommended that the additional load requirement be calculated based on the stud grip length for the specific connection.

3. Tensioning shall be performed by outside contractors that specialize in tensioning operations. The Supplier usually provides all the equipment. Tensioning can also be done by specially trained company mechanics if a facility already owns the equipment.



4. General written tensioning procedures shall be included in the work order that cover routine tensioning work. Special equipment specific written instructions shall be provided if necessary.

10.4 Hot Tensioning of Heat Exchanger Joints1. After careful review, hot tensioning on heat exchanger flanges over 250F (122C) shall be

performed only by qualified personnel.2. Multiple heads shall be used and rotated in and out of service, or the heads shall be cooled

between tensioning passes such that the internal seals will not over heat and fail.3. The O-ring seals in tensioning heads are rated for approximately 250F (120C) and may fail

due to overheating and leaking hydraulic fluid on to hot flange surfaces.

10.5 Tensioning Hard to Reach NutsIf access to nuts with tensioning heads is blocked by equipment nozzles or other obstructions, the following procedure shall be used: 1. After all accessible studs have been tensioned to their final load, start by backing off one nut

that is easy to reach and then hand tighten.

2. Mark one of the corners on the nut against the flange, and then, count the number of flats the nut is moved by the time it has been fully retensioned.

3. Tighten the hard to reach nut by hand, and then use a slug wrench or other appropriate tool to move the nut(s) the same number of flats. Use a device to hold the slug wrench in place and not your hands.

11.0 BOILER MANWAYS AND HAND HOLES

11.1 GeneralMost oval boiler manways and hand inspection holes use boiler pressure to help seat the gasket as the pressure pushes the cover against the gasket. 1. Oval shaped CGG (1/2 inch (12.7 mm) or greater radial width) or KAG (any radial width)

style gaskets shall be used in these applications. 2. Gasket stress shall be calculated to ensure that proper gasket seating loads are achieved.3. The GEN-DS-5209 FCD Oval Gaskets tab, can be used to calculate oval gasket stresses.

11.2 ProcedureBased on experience, to properly seat oval gaskets and prevent leakage, the following procedure shall be employed:1. Tighten the strong back up to the calculated torque value.2. Check and retighten the strong back, if necessary, during hydrotest.3. Check and retighten the strong back before starting up the equipment to recover any gasket

relaxation. 4. Monitor the manways and hand holes for 1 to 2 weeks for leakage. If the joint leaks, it is

unlikely that the strong back will provide enough load to seal the connection, given that the internal pressure is providing most of the gasket stress. The unit may have to come down for repairs.



12.0 FLANGE INSULATION

12.1 General1. In general, flange joints shall not be insulated.

Insulating flange joints may cause a joint to leak during a thermal upset. 2. For personnel protection, a perforated steel enclosure shall be placed around flanges that pose

a safety concern.3. Exceptions to the not insulating flange rule are specified in Section 12.2 through

Section 12.6.

12.2 Inclement Weather1. At some facility locations, inclement weather can have a direct impact on plant operation in

certain piping systems with un-insulated flanges. In such cases, an analysis or energy audit shall be performed to identify the reason and justify the cost and risk for insulting the flanges.

2. The insulation plan shall be subject to approval. The additional risk that comes with the insulation of pipe flanges shall be considered.

3. The report shall be signed and kept in the inspection files for the identified system. 4. Insulated flanges shall be checked by operations for leaks when the plant is back online after a

significant plant upset which results in a sudden drop in temperature.

12.3 Assembly1. Flanges can be insulated only if assembled in accordance with this specification. 2. If flanges in piping system are to be insulated, all flanges shall be broken apart during a

turnaround and all aspects of this specification followed, including visual inspection of flange faces, proper assembly, alignment, proper selection of stud and gasket materials, and torquing to the right stud load.

3. A tag in accordance with Section 12.4 shall be attached as soon as the flange has been assembled and the QA/QC operation has been completed.

12.4 Tags1. Flanges in piping systems designated for insulation and assembled in accordance with this

specification shall be identified with a permanent steel tag stating that the flange has been assembled in accordance with this specification and is approved for insulation.

2. Tags shall not be attached unless the person performing the QA/QC step can verify compliance with this specification.

3. Flanges without tags shall not be insulated. 4. The following is a sample of the required tag:

5. The tag shall be affixed to the insulation jacket next to the associated flange such that it is visible after the flange is insulated.

Assembled per GEN-SU-5209 (date) QA/QC performed by: _____________

Approved for Insulation



12.5 Fixed Equipment, Rotating Equipment, and Valve Bonnet Flanges1. Fixed equipment, rotating equipment, and valve bonnet flanges shall not be insulated, unless:

a. Gasket seating stress calculations are performed.b. Gasket target loads have been met.c. Flanges are broken apart, and all aspects of this specification are followed.

2. A tag in accordance with Section 12.4 shall be attached as soon as the flange has been assembled and QA/QC operation has been completed.

12.6 Temperatures Between 700F and 850F (370C and 455C)Flanges subject to process service temperatures between 700F and 850F (370C and 455C) may be insulated only if:1. ASTM A193 Gr. B16 stud bolting with ASTM A194 Gr.7 nuts are used.2. Flanges comply with Section 12.2 and Section 12.3.

12.7 Temperatures Above 850F (455C)1. Flanges used in process service temperatures above 850F (455C) shall never be insulated.2. Flanges can be covered with weather shields to minimize weather impact.

12.8 Under Insulation Corrosion ProtectionFlanges shall be coated or have some method of protection for the following service conditions:1. Stainless steel piping and flanges if process service temperatures are less than 400F (205C).2. All other piping and flanges if process service temperatures are less than 300F (150C).



APPENDIX A

PIPING

A.1 GeneralPipe flange joints shall be assembled in accordance with this entire appendix.

A.2 Pipe Flange Inspection and Assembly Procedure1. General Instructions

a. Select the right gasket for the flange class and process conditions in accordance with this specification, drawing GD-L1264, and piping class requirements. If there is a conflict, this specification and drawing GD-L1264 shall govern.

b. For hydrotesting or general flange makeup, all the studs shall be installed and correctly loaded in accordance with Table A.1 and Table A.2

c. For hydrotesting, the gasket style intended for final assembly shall be used. WRI-RJ gaskets may be used to test ring joint flanges.

d. Gaskets shall be replaced each time a connection is opened. Exceptions can be made for gaskets that have a graphite covering which can be replaced, such as some KAG, Kam/PEG, and Kam/ORJ gaskets, but not SW gaskets.

e. Gaskets for raised face and flat face flanges shall always be self centering.2. Inspection

a. Cleaning1) Clean the gasket surfaces with a suitable scraper or wire wheel/brush, as required, to

remove rust/corrosion products, old gasket material, etc. 2) Wipe the surface clean. 3) Some graphite remaining in flange face serrations after scraping and wiping clean

shall be acceptable. b. Inspect flanges visually to ensure that they are free of mechanical damage, radial tool

marks, scratches, corrosion products, pitting, scale, etc. c. Report any damage. A work order may be issued that outlines further measurements or

machining of the flange and gasket surfaces that might be required by the shop or in plant machining company to repair damaged surfaces.

3. Assemblya. Check flange alignment in accordance with Section 8.10.b. Lubrication and Cleaning of Threads

1) Lubricate the threads (using Jet-Lube 550) on both ends of the studs and between the nut and bearing surface.

2) Well lubricated used studs and nuts in good condition can be installed on piping flanges.

3) If the nuts do not run down easily on both ends of the stud by using only the fingers, clean the threads using a tap and/or die to fix the problem or replace the stud or nut.



4) Loose material can be removed from the threads with a wire brush, but this procedure shall not be used for removing galling or restoring the friction between the nut and stud back to like new condition because it is ineffective.

c. Hardened Washer1) Install an ASTM F-436 washer under the nut to be tightened if the flange area under

the nut has evidence of galling, grooving, or the nut does not have an integral washer built in.

2) Install the washer under the nut on the side of the flange such that the torque wrench can be pulled in a down direction during torquing.

3) Ensure that the integral washer side of nut is face down and raised letters are faced up.4) Install half the studs around one side of the flange and insert the gasket.

Note DO NOT coat gaskets with antiseize. Install the remaining studs and pull the flanges down evenly.

d. Tightening Tolerances1) Tighten the studs either with hand wrenches, Regulated Air Drive (RAD) tools, or air

impacts to snug to hold the components in place. 2) Measure the gap around the flange with a flange gap tool or caliper. 3) After final assembly, RF and Tongue and Groove and Ring Joint (RTJ) flanges less

than 24 inches in diameter shall be less than 1/32 inch of parallel (cocked) as measured across any flange outside diameter.

e. Tightening Pattern1) Tighten the studs using a star pattern with a hand wrench, RAD torque gun (air

regulated impact gun), or air impact. Use as many passes as needed to keep the flanges parallel.

2) Do not exceed the final targeted stud load. 3) For flanges with studs that require a torque value of 200 ft-lb (270 Nms) or more, a

calibrated torque wrench shall be required on the final pass to obtain the specified torque value.

4) Use hydraulic torque equipment on stud loads over 1,000 ft-lb (1350 Nm). 5) Refer to Appendix Table A-1 and Appendix Table A-2 for pipe flange torque values

and Appendix Section A.3 for details on the tightening pattern.

Note Torque multipliers shall not be allowed due to decrease in accuracy.



f. Final Pass1) The final pass with the torque wrench shall be made in a circular pattern, provided that

at least 80 percent of the final stud load has already been applied. 2) If a nut has been over tightened and will not turn while using the torque wrench, back

off slightly on the nut and retighten it to the specified torque value.4. Complete GEN-DS-5209 PPV for torqued flanges and sign off on the appropriate steps.

a. Send this data sheet to the QA/QC group or the work order originator, if a QA/QC group is not being used, or the EWO originator.

b. Approved Supplier QA/QC process sign-off and documentation for tightening flanges may be used in place of GEN-DS-5209 PPV, as long as information required in GEN-DS-5209 PPV is included in Contractor documentation.

5. Hot TorqueHot torque shall not be required on pipe flanges, unless specified in the work order.

A.3 Star Pattern Torquing Procedure for PipingThe following torque pattern is intended for all piping connection types, including piping connections to vessels, regardless of the gasket used:1. For initial tightening, the star pattern in Figure A-1 shall be used. As long as the flanges are

taken up evenly, working from one side to the other in a rotating pattern around the flange, the actual pattern or direction around the flange does not matter.

2. After at least 80 percent of the final load has been set, the final load can be set in a circular pattern. The nuts should move on this pass. If the nuts do not move, use a calibrated torque wrench to check the final load reached. Record and report the loads.

3. Tighten the studs to 100 percent of the specified torque value in a circular pattern. For flanges tightened to 200 ft-lb (270 Nm) and higher, a calibrated torque wrench shall be used to set the final required load, and hydraulic torque wrenches or tensioners shall be used for studs requiring ASME Pipe Flange Torque Values 1,000 ft-lb (1350 Nm) or more. If the nuts move on this pass, make additional passes until the nuts stop turning.



Figure A-1:Traditional Star Pattern

TRADITIONAL STAR PATTERN

S e q u e n t i a l O r d e r

R o t a t i o n a l O r d e r

1 - 2 1 23 - 4 9 1 05 - 6 1 7 1 8 7 - 8 5 6

9 - 1 0 1 3 1 4 1 1 - 1 2 2 1 2 2 1 3 - 1 4 3 4 1 5 - 1 6 1 1 1 2 1 7 - 1 8 1 9 2 0 1 9 - 2 0 7 8 2 1 - 2 2 1 5 1 6 2 3 - 2 4 2 3 2 4

Flange Gaskets and B

oltingG

EN-SU

-5209

June 2009

2009 Chevron U

.S.A. Inc. A

ll rights reserved.33 of 45

Table A-1: Pipe Flange Torque Values (1 of 5)

PIPE FLANGE TORQUE VALUES

Pipe Size Qty Dia. Length Slip Bld Qty Dia. Length Slip Bld Qty Dia. Length Slip Bld3/4 4 1/2 2 1/2 3 40 40 4 5/8 4 4 1/2 50 4 3/4 4 1/2 5 1/2 60

1 4 1/2 3 3 1/2 50 50 4 5/8 4 4 1/2 70 4 7/8 5 6 1001 1/2 4 1/2 3 3 1/2 60 60 4 3/4 4 1/2 5 130 4 1 5 1/2 6 1/2 2502 4 5/8 3 1/2 4 130 100 8 5/8 4 1/2 5 80 8 7/8 6 7 1803 4 5/8 4 4 1/2 130 130 8 3/4 5 6 150 8 1 1/8 7 1/2 8 1/2 3504 8 5/8 4 4 1/2 120 80 8 7/8 6 7 330 8 1 1/4 8 9 1/2 6005 8 3/4 4 5 200 160 8 1 6 1/2 7 1/2 480 8 1 1/2 10 11 1/2 9406 8 3/4 4 5 220 220 12 1 7 8 470 12 1 3/8 10 1/2 12 7508 8 3/4 4 1/2 5 220 220 12 1 1/8 8 9 700 12 1 5/8 12 13 1/2 1,280

10 12 7/8 5 5 1/2 350 290 16 1 1/4 8 1/2 10 840 12 1 7/8 13 1/2 15 1/2 2,03012 12 7/8 5 6 350 310 20 1 1/4 9 10 1/2 840 16 2 15 17 2,10014 12 1 5 1/2 6 1/2 530 430 20 1 3/8 9 1/2 11 940 16 2 1/4 16 1/2 18 1/2 2,48016 16 1 5 1/2 6 1/2 480 360 20 1 1/2 10 12 1,290 16 2 1/2 18 20 1/2 3,98018 16 1 1/8 6 7 750 590 20 1 5/8 11 12 1/2 1,990 16 2 3/4 19 1/2 22 1/2 5,63020 20 1 1/8 6 1/2 7 1/2 750 540 24 1 5/8 11 1/2 13 1/2 1,970 16 3 21 1/2 24 1/2 7,13024 20 1 1/4 7 8 1/2 1,130 760 24 1 7/8 13 15 2,630 16 3 1/2 24 1/2 28 11,250

1/2 7/8Pipe Size Qty Dia. Length Slip Bld Qty Dia. Length Slip Bld Qty Dia. Length Slip Bld 5/8 1-1/16

3/4 4 5/8 3 4 50 50 4 3/4 5 6 70 3/4 1-1/41 4 5/8 3 1/2 4 70 70 4 7/8 5 1/2 6 1/2 110 7/8 1-7/161 1/2 4 3/4 4 4 1/2 130 130 4 1 1/8 7 8 300 1 1-5/82 8 5/8 3 1/2 4 1/2 70 70 8 1 7 8 200 1-1/8 1-13/163 8 3/4 4 1/2 5 140 140 8 7/8 6 7 250 8 1 1/4 9 10 1/2 450 1-1/4 24 8 3/4 4 1/2 5 1/2 220 190 8 1 1/8 7 8 450 8 1 1/2 10 1/2 12 750 1-3/8 2-3/165 8 3/4 5 5 1/2 220 220 8 1 1/4 7 1/2 9 840 8 1 3/4 13 1/2 14 1,280 1-1/2 2-3/86 12 3/4 5 6 200 190 12 1 1/8 8 9 530 8 2 14 16 1,880 1-5/8 2-9/168 12 7/8 5 1/2 6 1/2 330 310 12 1 3/8 9 10 1/2 840 12 2 15 1/2 17 1/2 1,880 1-3/4 2-3/4

10 16 1 6 1/2 7 1/2 420 420 16 1 3/8 9 1/2 11 840 12 2 1/2 19 1/2 22 3,080 1-7/8 2-15/1612 16 1 1/8 7 8 630 630 20 1 3/8 10 1/2 11 1/2 990 12 2 3/4 21 1/2 24 4,950 2 3-1/814 20 1 1/8 7 1/2 8 1/2 500 480 20 1 1/2 11 12 1/2 1,280 2-1/4 3-1/216 20 1 1/4 8 9 710 710 20 1 5/8 11 1/2 13 1,580 2-1/2 3-7/818 24 1 1/4 8 9 1/2 880 840 20 1 7/8 13 15 2,590 2-3/4 4-1/420 24 1 1/4 8 1/2 9 1/2 880 840 20 2 14 16 2,850 3 4-5/824 24 1 1/2 9 1/2 11 1,310 1,310 20 2 1/2 17 1/2 20 4,650 3-1/2 5-3/8

Slip Blind for Turnaround Isolation - No hydrotestTorque Fp's SS

Use Washers if flange is galled or badly warn.Hydraulic Torque RequiredASME SA-105 CS Flanges, B7 & B7M Studs Hand Tighten Must be Torqued

Note separate Torque Values for 300 Series SS flanges!

Torque Fp's

150 RAISED FACE

Torque Fp's

Torque Fp's

600 RAISED FACE

2500 RAISED FACE

1500 RAISED FACE

Dimensions in Inches

Studs recommended for 125/150 FF Flg's. Do not mate FF Cast Iron with RF Carbon Steel.

M

F

G

-

7

3

0

4

(

1

2

/

0

8

)

Torque Fp's

Torque Fp's

Chevron Bolting and Torque Card

Torque in Foot Pounds

(Fp's)

Hvy Hex Nuts

Wrench Size

300 RAISED FACE Torque Fp's

Not made. Use 1500 class flanges Information

900 RAISED FACE Torque Fp's SS


oltingG

EN-SU

-5209

June 2009

2009 Chevron U

.S.A. Inc. A



Pipe Size Ring # Qty Dia. Length Slip Bld Ring # Qty Dia. Length Slip Bld Ring # Qty Dia. Length Slip Bld3/4 R-13 4 5/8 3 1/2 4 1/2 80 80 R-16 4 3/4 5 6 110

1 R-16 4 5/8 3 1/2 4 1/2 80 80 R-18 4 7/8 5 1/2 6 1/2 1501 1/2 R-20 4 3/4 4 1/2 5 130 130 R-23 4 1 1/8 7 8 3402 R-23 8 5/8 4 1/2 5 90 70 R-26 8 1 7 1/2 8 1/2 2003 R-31 8 3/4 5 6 160 150 R-31 8 7/8 6 7 200 R-32 8 1 1/4 9 1/2 10 1/2 4004 R-37 8 3/4 5 1/2 6 200 190 R-37 8 1 1/8 7 8 1/2 330 R-38 8 1 1/2 10 1/2 12 8105 R-41 8 3/4 5 1/2 6 1/2 230 230 R-41 8 1 1/4 8 9 470 R-42 8 1 3/4 12 1/2 14 1/2 1,4306 R-45 12 3/4 6 6 1/2 200 190 R-45 12 1 1/8 8 9 350 R-47 8 2 14 1/2 16 1/2 2,0408 R-49 12 7/8 6 1/2 7 1/2 300 300 R-49 12 1 3/8 9 10 1/2 580 R-51 12 2 16 18 1,990

10 R-53 16 1 7 8 300 300 R-53 16 1 3/8 9 1/2 11 580 R-55 12 2 1/2 20 1/2 23 3,68012 R-57 16 1 1/8 7 1/2 9 430 430 R-57 20 1 3/8 10 1/2 12 580 R-60 12 2 3/4 22 1/2 25 1/2 5,40014 R-61 20 1 1/8 8 9 400 400 R-62 20 1 1/2 11 1/2 13 97016 R-65 20 1 1/4 8 1/2 10 510 510 R-66 20 1 5/8 12 13 1/2 1,28018 R-69 24 1 1/4 8 1/2 10 490 490 R-70 20 1 7/8 13 1/2 15 1/2 2,03020 R-73 24 1 1/4 9 10 1/2 640 640 R-74 20 2 14 1/2 16 1/2 2,40024 R-77 24 1 1/2 10 1/2 12 1,200 1,200 R-78 20 2 1/2 18 1/2 21 4,350

Pipe Size Ring # Qty Dia. Length Slip Bld Ring # Qty Dia. Length Slip Bld Pipe Size Qty Dia. Length Slip Bld3/4 R-13 4 5/8 3 1/2 4 1/2 80 R-14 4 3/4 4 1/2 5 1/2 100 3/4 4 1/2 2 1/2 3 70

1 R-16 4 5/8 4 4 1/2 90 R-16 4 7/8 5 6 130 1 4 1/2 2 1/2 3 701 1/2 R-20 4 3/4 4 1/2 5 140 R-20 4 1 5 1/2 6 1/2 200 1 1/2 4 1/2 3 3 1/2 702 R-23 8 5/8 4 1/2 5 90 R-24 8 7/8 6 7 150 2 4 5/8 3 4 1303 R-31 8 3/4 5 1/2 6 160 R-35 8 1 1/8 7 1/2 8 1/2 300 3 4 5/8 3 1/2 4 1304 R-37 8 7/8 6 7 240 R-39 8 1 1/4 8 9 1/2 460 4 8 5/8 3 1/2 4 1/2 1305 R-41 8 1 7 8 350 R-44 8 1 1/2 10 11 1/2 650 5 8 3/4 4 4 1/2 2306 R-45 12 1 7 8 280 R-46 12 1 3/8 11 12 530 6 8 3/4 4 5 2308 R-49 12 1 1/8 8 9 420 R-50 12 1 5/8 12 14 1,090 8 8 3/4 4 1/2 5 230

10 R-53 16 1 1/4 9 10 450 R-54 12 1 7/8 14 16 1,630 10 12 7/8 4 1/2 5 1/2 38012 R-57 20 1 1/4 9 10 1/2 450 R-58 16 2 16 18 2,030 12 12 7/8 5 5 1/2 38014 R-61 20 1 3/8 9 1/2 11 600 R-63 16 2 1/4 17 19 1/2 2,850 14 12 1 5 1/2 6 1/2 57016 R-65 20 1 1/2 10 1/2 12 750 R-67 16 2 1/2 19 21 1/2 3,980 16 16 1 5 1/2 6 1/2 57018 R-69 20 1 5/8 11 13 980 R-71 16 2 3/4 21 23 1/2 5,180 18 16 1 1/8 6 7 1/2 83020 R-73 24 1 5/8 12 13 1/2 1,050 R-75 16 3 23 26 6,750 20 20 1 1/8 6 1/2 7 1/2 83024 R-77 24 1 7/8 13 1/2 15 1/2 1,800 R-79 16 3 1/2 26 29 1/2 10,500 24 20 1 1/4 7 8 1/2 1,160

Note separate Torque Values for 300 Series SS flanges! Use Washers if flange is galled or badly warn.Slip Blind for Turnaround Isolation - No hydrotest Contact your local bolting SME for help or David Reeves at 310-941-8827

ASME SA-105 CS Flanges, B7 & B7M Studs Hand Tighten Must be Torqued Hydraulic Torque RequiredDimensions in Inches

Torque FP's

Torque FP's

Not made. Use 1500 class flanges Information

125/150 FULL FACE (Stud Bolts)

Torque FP's

900 RTJ 2500 RTJ

Torque FP's

Torque FP's

Torque FP's

Torque Fp's SS

300 RTJ

600 RTJ 1500 RTJ


oltingG

EN-SU

-5209

June 2009

2009 Chevron U

.S.A. Inc. A



Pipe Size Qty Dia. Length Slip Bld Qty Dia. Length Slip Bld Qty Dia. Length Slip Bld3/4 4 1/2 2 1/2 3 50 50 4 5/8 4 4 1/2 70 4 3/4 4 1/2 5 1/2 80

1 4 1/2 3 3 1/2 70 70 4 5/8 4 4 1/2 90 4 7/8 5 6 1301 1/2 4 1/2 3 3 1/2 80 80 4 3/4 4 1/2 5 180 4 1 5 1/2 6 1/2 3402 4 5/8 3 1/2 4 180 130 8 5/8 4 1/2 5 110 8 7/8 6 7 2403 4 5/8 4 4 1/2 180 180 8 3/4 5 6 200 8 1 1/8 7 1/2 8 1/2 4704 8 5/8 4 4 1/2 160 110 8 7/8 6 7 440 8 1 1/4 8 9 1/2 8105 8 3/4 4 5 270 220 8 1 6 1/2 7 1/2 650 8 1 1/2 10 11 1/2 1,2706 8 3/4 4 5 300 300 12 1 7 8 630 12 1 3/8 10 1/2 12 1,0108 8 3/4 4 1/2 5 300 300 12 1 1/8 8 9 940 12 1 5/8 12 13 1/2 1,720

10 12 7/8 5 5 1/2 470 390 16 1 1/4 8 1/2 10 1,130 12 1 7/8 13 1/2 15 1/2 2,73012 12 7/8 5 6 470 420 20 1 1/4 9 10 1/2 1,130 16 2 15 17 2,83014 12 1 5 1/2 6 1/2 710 580 20 1 3/8 9 1/2 11 1,270 16 2 1/4 16 1/2 18 1/2 3,34016 16 1 5 1/2 6 1/2 650 480 20 1 1/2 10 12 1,740 16 2 1/2 18 20 1/2 5,36018 16 1 1/8 6 7 1,010 790 20 1 5/8 11 12 1/2 2,680 16 2 3/4 19 1/2 22 1/2 7,58020 20 1 1/8 6 1/2 7 1/2 1,010 730 24 1 5/8 11 1/2 13 1/2 2,650 16 3 21 1/2 24 1/2 9,60024 20 1 1/4 7 8 1/2 1,520 1,020 24 1 7/8 13 15 3,540 16 3 1/2 24 1/2 28 15,150

1/2 7/8Pipe Size Qty Dia. Length Slip Bld Qty Dia. Length Slip Bld Qty Dia. Length Slip Bld 5/8 1-1/16

3/4 4 5/8 3 4 70 70 4 3/4 5 6 90 3/4 1-1/41 4 5/8 3 1/2 4 90 90 4 7/8 5 1/2 6 1/2 150 7/8 1-7/161 1/2 4 3/4 4 4 1/2 180 180 4 1 1/8 7 8 400 1 1-5/82 8 5/8 3 1/2 4 1/2 90 90 8 1 7 8 270 1-1/8 1-13/163 8 3/4 4 1/2 5 190 190 8 7/8 6 7 340 8 1 1/4 9 10 1/2 610 1-1/4 24 8 3/4 4 1/2 5 1/2 300 260 8 1 1/8 7 8 610 8 1 1/2 10 1/2 12 1,010 1-3/8 2-3/165 8 3/4 5 5 1/2 300 300 8 1 1/4 7 1/2 9 1,130 8 1 3/4 13 1/2 14 1,720 1-1/2 2-3/86 12 3/4 5 6 270 260 12 1 1/8 8 9 710 8 2 14 16 2,530 1-5/8 2-9/168 12 7/8 5 1/2 6 1/2 440 420 12 1 3/8 9 10 1/2 1,130 12 2 15 1/2 17 1/2 2,530 1-3/4 2-3/4

10 16 1 6 1/2 7 1/2 570 570 16 1 3/8 9 1/2 11 1,130 12 2 1/2 19 1/2 22 4,150 1-7/8 2-15/1612 16 1 1/8 7 8 850 850 20 1 3/8 10 1/2 11 1/2 1,330 12 2 3/4 21 1/2 24 6,660 2 3-1/814 20 1 1/8 7 1/2 8 1/2 670 650 20 1 1/2 11 12 1/2 1,720 2-1/4 3-1/216 20 1 1/4 8 9 960 960 20 1 5/8 11 1/2 13 2,130 2-1/2 3-7/818 24 1 1/4 8 9 1/2 1,180 1,130 20 1 7/8 13 15 3,490 2-3/4 4-1/420 24 1 1/4 8 1/2 9 1/2 1,180 1,130 20 2 14 16 3,840 3 4-5/824 24 1 1/2 9 1/2 11 1,7

GEN-SU-5209

Documents

jrofflange gaskets

cgg gaskets

installation of gaskets

kamprofile gaskets

spiral wound gaskets

solid metal gaskets

gasket surfaces

gasket surface inspection