Drilling & Work Over Manual-2014

8/10/2019 Drilling & Work Over Manual-2014

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DRILLING AND WORKOVER WELL CONTROL MANUAL

VOLUME I

5 th EDITION, June, 2014

SAUDI ARAMCO

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Saudi Aramco

Well Control Manual Volume I, 5 th Edition

INTRODUCTION AND DOCUMENT CONTROLCHAPTER A EQUIPMENT REQUIREMENTS

CHAPTER B BOP SYSTEMS

CHAPTER C MAINTENANCE, TESTING AND RECERTIFICATION

CHAPTER D WELL CONTROLLED POLICIES

CHAPTER E WELL CONTROL DRILLS

CHAPTER F SUPPLEMENTAL REFERENCES


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WELL CONTROL MANUAL: 5 TH EDITION VOLUME I Drilling & Workover

INTRODUCTION AND DOCUMENT CONTROL

Current Revision: JUNE, 2014 INT - 1Previous Revision: MAY, 2010

1.0 INTRODUCTION

The 5 th edition of the Well Control Manual has some significant changes from the 4 th Edition. It is theresponsibility of the authorized users of this manual to familiarize themselves with the specificationsand instructions in its entirety.

2.0 REVISIONS

The Well Control Manual (WCM) will undergo a full review and revision every three (3) years. The WCM willbe reviewed by the Well Control Committee (WCC), endorsed by the General Manager of Drilling andapproved by the Vice President of Drilling and Workover.

Document Control:The Well Control Manual (WCM) is subject to constant review, revision and updates by the Well ControlCommittee (WCC). The timely implementation of the policies contained in this document is critical and stepsmust be taken to ensure that the latest revision including published errata and amendments is available toDrilling and Workover Rigs and Management.

Revisio ns and Updates will be control led as follo ws:1 The WCM will be fully reviewed and reissued after three (3) years.2 Interim revisions and updates will be issued as errata or amendments as required.3 A revision log will be maintained at the beginning of the WCM that will list and summarize any

changes

To ensure that the document is available to all concerned parties there will be two (2) versions of the manualavailable, Electronic and Printed.

Electronic Version:The Electronic version will reside on the Drilling Information Highway. This document is available for viewingby all authorized DIH users. If a page or section is printed from DIH, it is considered uncontrolled as of theprint date.

Printed Version:Printed copies will be issued as follows:

V.P. D&WO General Manager, Drilling All D&WO Managers All Drilling and Workover Rig Superintendents All Members of the Well Control Committee. All rigs operating under Drilling and Workover will have one copy in the Foremans Office. Each Drilling or Workover Rig Contractors local head office. D&WO Contracts Administration Division

Updates and Revisions to printed copies will be controlled as follows:1. When errata or an amendment is issued a notification will be sent to all D&WO personnel. The

master electronic copy on the DIH will have the errata and amendments placed at the beginningof the file.


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WELL CONTROL MANUAL: 5 TH EDITION

Drilling & Workover VOLUME I

CHAPTER A - EQUIPMENT SPECIFICATIONS AND REQUIREMENTS

Current Revision: JUNE, 2014 A - 1Previous Revision: MAY, 2010

CHAPTER A: EQUIPMENT SPECIFICATIONS AND REQUIREMENTS

TABLE OF CONTENTS

1.0 PRIMARY WELL CONTROL EQUIPMENT REQUIREMENTS1.1 General Requirements A-3

1.2 Annular Units and Diverters A-5

1.3 Fixed Ram Preventers and Elastomers A-5

1.4 Variable Bore Ram Preventer Blocks and Elastomers A-6

1.5 Shear Blind Ram (SBR) Blocks and Elastomers A-6

1.6 Valve Removal Plugs and Blind Flanges on BOP Side Outlets A-8

1.7 Drilling Spools A-8

2.0 REQUIREMENTS FOR KILL, EMERGENCY KILL, CHOKE LINES AND CHOKES2.1 Minimum Bore Size for Lines: A-9

2.2 Material and Fabrication A-9

2.3 Requirements for Drilling Chokes A-11

2.4 Requirements for Valves A-11

2.5 Requirements for Cup Testers A-12

3.0 ACCESSORY BOP EQUIPMENT REQUIREMENTS3.1 Pit Volume Totalizers A-12

3.2 Mud Flow Indicators A-12

3.3 Gas Busters A-12

3.4 Full Opening Safety Valves A-17

3.5 Inside BOP A-17

3.6 Trip Tank A-18

3.7 Bowl Protectors (Wear Bushings) A-19

3.8 Valve Removal Plugs A-19

3.9 Drillpipe Float Valves A-19


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Current Revision: JUNE, 2014 A - 2Previous Revision: MAY, 2010

3.10 Weco Connections A-19

3.11 Chiksans A-19

3.12 Accumulator Closing Units A-20

3.13 Stroke Counters A-22

3.14 Gas Detectors A-22

3.15 Drill Rate Recorders A-22

3.16 Pump Lines for Existing Offshore Well Kill A-23


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Current Revision: JUNE, 2014 A - 3 Copyright 2014, Saudi Aramco Previous Revision: MAY, 2010 MBG

1.0 WELL CONTROL EQUIPMENT SPECIFICATIONS ANDREQUIREMENTS

This Chapter of the Well Control Manual sets forth the specifications and requirements for Blow Out PreventionEquipment (BOPE) and systems for use in Drilling and Workover Operations. Variations or deviations of BOPE,specifications, arrangement, pressure rating or requirements from this standard requires endorsement of theWell Control Committee, and approval by the Vice President of Drilling and Workover. The enforcement of theseequipment standards shall be the responsibility of the Drilling or Workover Rig Superintendent. The RigForeman shall ensure that the proper equipment is available and correctly installed. If not specified in thesestandards all BOP equipment shall comply with API Specifications and Recommended Practices.

1.1 General Requirement s:

All Drilling and Workover Well Control Equipment shall meet the following requirements:

1.1.1 All BOPE (Annulars, Ram Type, Valves, Chokes, Crosses Flexible Lines, Hard Lines and etc.)shall be of forged material, Monogrammed to API Specification 6A, 16A, 16C, 17D or otherapplicable API Specification as appropriate.

1) All equipment in service in Saudi Aramco D&WO Operations must be API Monogrammed.This includes equipment transferred from other regions whether or not it is on a rigalready. Monogram and markings MUST be clearly visible through the painted coating ofthe equipment. Care should be taken to preserve this monogram on the equipmentnameplate, flange or body to prevent it being obliterated or destroyed during handlingmaintenance and use. Additionally, documentation must be available at the rig sitereflecting the equipment Serial Number and API Monogram Status.

2) Any exceptions to this monogram policy (e.g.; 30" 1,000 psi annulars) are noted in thesection detailing that specific equipment.

1.1.2 All major BOPE components including, but not limited to, ram BOPs, annular BOPs, drillingspools, ram blocks, valves, choke and kill lines, choke manifolds, gas busters etc. will have anunique serial or asset identification number assigned at time of manufacture by the ORIGINALEQUIPMENT MANUFACTURER (OEM). The number must be permanently marked in themetal of the component body and should be paint stenciled in a prominent and visiblelocation on the equipment. This number must be referenced on all accompanyingcertification and recertification documents. Repair numbers are not acceptable for thisrequirement.

1.1.3 Only OEM parts are acceptable when repairing or redressing the BOP, valves, chokes, andclosing units. Documentation (e.g.; PO, invoice, certificate of compliance etc.) must bemaintained for all parts verifying that they are OEM.

1.1.4 Maintenance and testing requirements may be found in Chapter C "Maintenance Testing andCertification Requirements of this manual.

1.1.5 A drilling spool is preferred for primary choke and kill line installation. However in special cases,such as space limitation, preventer side outlets may be used in lieu of a drilling spool. Thediameter of all preventer side outlets must be at least as large as the choke manifold lines.

NOTE: Side outlets are used for installation of the lower choke and kill lines on 10K/15K BOPs.


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1.1.6 The through-bore size of the preventer stack, tubing head, and any adapters used in the BOPhook-up shall be large enough for the maximum size bit, scraper, liner hanger, packer, plug, cuptester, bowl protector or any other large diameter down-hole tools to be run in the well.

1.1.7 The pressure rating of all pressure control equipment (BOP, Valves, Lines etc.) must be greaterthan the MASP (Maximum Anticipated Surface Pressure).

1.1.8 The inboard manual valves on the choke and kill lines are considered master valves andnormally would not, except for pressure testing, be closed unless the outside valve (HCR) hasfailed.

1.1.9 Check valves must be installed on normal kill lines but shall not be used on emergency kill lines.

1.1.10 The kill line, emergency kill line and choke lines should be flushed and washed out frequently toprevent mud solids settling.

1.1.11 BOP assemblies will be dismantled between wells to inspect for internal corrosion, erosion andto check flange bolts. Refer to Chapter C for maintenance procedures and requirements.

1.1.12 All Rigs shall maintain a logbook of BOP schematics detailing the components installed. Thelogbooks shall contain the part number, size, description, serial number (if applicable) andinstallation date of ram blocks, top seals, ram and annular packers and bonnet or door seals.This is be witnessed and co-signed by the Toolpusher and the Saudi Aramco Representative(see form #1 in Chapter C) of this manual).

1.1.13 All ram preventers must be equipped with manual or automatic locking devices, which must be

locked whenever the rams are used to control the well. Hand crank, wrench or hand wheelsystems are acceptable manual locking devices.

1.1.14 All preventers and associated equipment must meet NACE MR-0175/ISO 15156, APISpecification 6A, 16A or 16C for sour service.

1.1.15 A full OEM certification or recertification of the BOP, choke manifold (including chokes) and allrelated equipment must be performed at the start of the contract and least once every threeyears thereafter. The recertification must be in accordance with the relevant APISpecification for repair/remanufacture. The documentation package shall be kept with theequipment and must be available for inspection at the rig site by Saudi Aramco personnel. Thisincludes, but is not limited to:

Ram preventers. Annular preventers. Valves on the kill, emergency kill, choke line and choke manifold. Drilling chokes. Kill, emergency kill and choke lines (and line components) including both hard line and

flexible hoses. Drilling spools.

NOTE: Recertification can only be performed by the OEM or their licensee facility. If recertifiedby a licensee, the document package shall include a copy of the license issued by theOEM. In-field recertif ication i s not acceptable.


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NOTE: New equipment shall be accompanied by the manufacturer's certificate of complianceand a full documentation package including inspection and test reports.

1.1.16 All BOPE including, but not limited to, annulars, ram type, valves, spools, crosses, tees andother end and outlet connections with working pressures of 3,000 psi and above shall haveflanged, welded, integral, or hubbed connections only. Threaded connections and threadedconnections that have been seal welded are not permitted.

1.1.17 All Ram Type BOP cavities MUST CONTAIN a Ram. Vacant Ram cavities during operationsare not permitted.

1.2 Annular Units and Diverters:

1.2.1 All annular units must comply with the following in addition to the requirements in Section 1.1.

1.2.2 The minimum acceptable ratings for H 2S and temperature are as follows,

2,000 psi and less 2.5% H 2S and 0-170F3,000 psi equipment 2.5% H 2S and 0-180F5,000 psi equipment 2.5% H 2S and 0-180F

10,000 psi equipment 2.5% H 2S and 0-180F

1.2.3 The acceptable annular manufacturers are Cameron, GE-Hydril and NOV-Shaffer.

1.2.4 GE Vetco KFDJ and Dril-Quip MD diverters are acceptable for offshore 500, 1,000 and 2,000

psi service. Dril-Quip, is currently the only approved design, for the 500 psi onshorediverter.

NOTE: The Dril-Quip onshore diverter is not eligible for API Monogram and is not subject to the3-year recertification requirement. Only repair after each nipple-up is required.

1.2.5 If a rotary diverter system is utilized on an offshore rig, the diverter lines must have thecapability of discharging below the bottom of the hull due to H 2S concerns.

1.2.6 Bolted, latched and screwed top annulars are acceptable.

1.2.7 30 inch 1,000 psi annulars may not be monogrammed under API specification 16A. Theseannulars are exempt from the monogram requirement.

1.3 Fixed Ram Preventer Bloc ks and Elastomers:

1.3.1 All fixed ram preventers must comply with the following in addition to the requirements inSection 1.1 above.

1.3.2 Only fixed size rams are acceptable as the master pipe ram (bottom ram) on all BOP stacks.

1.3.3 The minimum acceptable ratings for H 2S and temperature for ram assemblies are:

3,000 psi stack 5.0% H 2S and 0-250F5,000 psi stack 10.0% H 2S and 0-250F


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1.3.4 Cameron, NOV-Shaffer and GE-Hydril are acceptable manufacturers for ram preventers. Allram assemblies shall meet NACE Standard MR-01-75-2000 for sour service.

NOTE : Fixed size ram preventers CANNOT CLOSE on TOOL JOINTS

1.3.5 All ram preventers shall be equipped with manual or automatic locking devices which must belocked whenever the rams are closed to control the well. A hand crank/wrench or handwheelsystem are acceptable manual devices. Automatic devices (e.g.: Shaffer Posilocks) are alsoacceptable.

1.4 Variable Bore Ram Preventer Block s and Elastomers:

1.4.1 All variable bore ram preventers must comply with the following in addition to the requirementsin Section 1.1 above.

1.4.2 Variable bore rams (VBR) are optional for tapered drill string applications on Class A stacks.In all cases the master pipe ram (bottom ram) must be a fixed ram.

1.4.3 The minimum acceptable ratings for H 2S and temperature for VBR's are:


1.4.4 The Cameron Extended Range High Temperature VBR-II Packer (3-1/2 to 5-7/8 pipe sizes)for the Cameron 13-5/8 U Type blowout prevented is acceptable for 3,000 and 5,000 psiapplications ONLY. This VBR was successfully tested to 250 oF with a CAMLAST elastomerrated for 20% H2S.

NOTE: The Cameron ER-HT VBR-II, described above, is approved for use in 3M and 5M Class'A' BOPs. This is the ONLY APPROVED VBR.

1.5 Shear Blind Ram (SBR) Block s and Elastomers:

1.5.1 SBR's are required on:

Close Proximity Wells (All Wells in Populated Areas) Gas Cap Wells (Either 3,000 or 5,000 Class A Stacks) Onshore Class A 5,000 psi stacks (Expl./Dev. Wells >10 % H2S) Smart Well Completions and Downhole monitoring systems where more than one (1) line is

run on the OD of the tubing. ESP Completions in areas where the well can flow naturally Offshore Class A 5,000 psi stacks (Offshore Wells) Class A 10,000 psi stacks (Deep Gas Exploration and Development Wells) Class 'A' 15,000 psi stacks (Deep Gas Exploration and Development Wells)


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1.5.2 The minimum acceptable ratings for H 2S and temperature for SBR's are:3,000 psi stack 5.0% H 2S and 0-250F5,000 psi stack 10.0% H 2S and 0-250F


1.5.3 Approved Shear Blind Rams are as follows:

Cameron Shearing Blind Rams Shaffer V-Shear, T-72 and LFS (Low Force Shear) Rams Hydril Blind/Shear Rams

1.5.4 All rigs utilizing SBR in 3,000 and 5,000 psi BOP equipment shall have a 3 emergency kill line.This will provide additional kill line capacity in case the SBR does not make a proper seal aftercutting the pipe. If the wellhead spool outlet is 2, then the inboard manual valve shall be 2 withDSA back to 3. Rigs with 10,000 psi and higher BOP equipment shall have dual choke and killlines as specified in Chapter B.

1.5.5 Shear Blind Rams are normally installed in Class A BOP stacks. When installed they will be inthe position immediately above the drilling cross as detailed in the individual stackconfigurations shown in this manual. They may be used on Class B BOP stacks on closeproximity wells to allow the utilization of smaller rigs. When installed in Class B stacks, theconfiguration must be a fixed pipe ram in the bottom position, a drilling cross above that, theSBR and then the annular.

NOTE: Double rams may not be used in conjunction with SBRs on a Class B stack.

NOTE: SBRs are only to be used during testing and a well control incident. They shall not beused to close the well when out of the hole. A steel hole cover (minimum thick withlocating pins) should be available on the rig floor to cover the rotary when pipe is out ofthe hole.

1.5.6 The tables below indicate the shear capability of SBR for different BOP manufacturers, sizesand pressure applications.

NOTE: Shear Blind Rams CANNOT BE CLOSED ON TOOL JOINTS.

SHEAR BLIND RAM CAPABIL ITY10,000 - 15,000 PSI SERVICE

BOPSERVICE

BOPESIZE - WPCLASS

MFG. DRILL PIPESHEARCAPABILITY

REQUIREDSHEARBLIND RAMTYPE

OPERATORREQUIREDSIZE

SIDE PACKER

TEMP(0F)

H2S,(%)

DEEP GASEXPL/ DEV.

13-5/8" 10MCLASS 'A'

CAMERON(1)

ALL SIZES TO5-1/2" 24.7# G-105

'SBR' YES/ LBT (2) 0-300 20

SHAFFER (1) ALL SIZES TO5-1/2" 24.7# G-105

'V' 14"/10" (3) 0-300 20

11" 10MCLASS 'A'

CAMERON(1)

ALL SIZES TO5" 19.5# G-105

'SBR' YES/ LBT (2) 0-300 20

SHAFFER (1) ALL SIZES TO5" 25.6# G-105

'T-72' 14"/10" (3) 0-250 20


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NOTE : (1) CAMERON, HYDRIL AND SHAFFER ARE APPROVED MANUFACTURERS. (2) CAMERON - LBT REFERS TO LARGE BORE SHEAR BONNETS WITH TANDEM BOOSTERS.(3) NOV SHAFFER - 14" OPERATOR WITH 10" BOOSTER IS REQUIRED.

3,000 - 5,000 PSI SERVICEBOPSERVICE

BOPESIZE - WPCLASS

MFG. DRILL PIPESHEARCAPABILITY

REQUIREDSHEARBLINDRAM TYPE

OPERATORREQUIREDSIZE

SIDEPACKER

TEMP(0F)

TEMP(0F)

OFFSHOREONSHOREEXPL/DEV. w/ H 2S >10%

GAS CAP WELLPOPULATED AREAS

13-5/8" 3-5MCLASS 'A'

CAMERON (1) ALL SIZES TO5-1/2" 24.7# G-105

'SBR' YES/ LBT (2) 0-250 20

DUAL TUBINGSTRINGS

SHAFFER (1) ALL SIZES TO5-1/2" 24.7# G-105

'V'14"/10" (3)

0-250 20

11" 3-5MCLASS 'A'

CAMERON (1) ALL SIZES TO5" 19.5# G-105

'SBR' YES/ LBT (2) 0-250 20

SHAFFER (1) ALL SIZES TO5" 25.6# G-105

'T-72' 14"/10" (3) 0-250 20

NOTE : (1) CAMERON, HYDRIL AND SHAFFER ARE APPROVED MANUFACTURERS. (2) CAMERON - LBT REFERS TO LARGE BORE SHEAR BONNETS WITH TANDEM BOOSTERS.(3) SHAFFER - 14" OPERATOR WITH 10" BOOSTER IS REQUIRED.

1.6 Side Outlets, Valve Removal Plugs and Blind Flanges

1.6.1 Two side outlets are required below each ram on a BOP. Therefore, a single ram body willhave two (2) outlets and a double ram body will have four (4).

1.6.2 Valve Removal (VR) plugs are not required on BOP side outlets, however they may be used.The following conditions apply to the blind flanges installed on side outlets:

Flanges installed on the side outlets of ram preventers that do not have VR plugs installed shallbe blind with no penetrations.

Flanges installed on the side outlets of ram preventers that have VR plugs installed shall have a inch NPT or an Autoclave tap (depending on the pressure rating) and have a plug installed.

1.7 Drilling Spools:

1.7.1 All Drilling Spools shall comply with the following requirements:

Monogrammed to API Specification 6A or 16A PSL-2 (5,000 psi working pressure or lower) PSL-2 with PSL-3 Gas Test (10,000 psi working pressure or higher) PR-1 (or better) MR-DD (or better) TR-U (5,000 psi working pressure or lower) TR-X Suitable for 350 oF service (10,000 psi working pressure or higher) Forged bodies


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2.0 REQUIREMENTS FOR KILL, EMERGENCY KILL, CHOKE LINES ANDCHOKES

All Kill, Emergency Kill and Choke lines shall comply with the following in addition to Section 1.1.

2.1 The Minimum Bore Size for Kill, Emergency Kill and Choke Lines Shall Be As Follows :

KILL LINENominal Size/Bore (in) Working Pressure (psi)

2-1/16" 3,000 and 5,0002-1/16" 10,0003-1/16" 15,000

EMERGENCY KILL LINENominal Size/Bore (in) Working Pressure (psi)

2-1/16" 3,000 and 5,0003-1/8" (with SBR) 3,0003-1/8" (with SBR) 5,000

2-1/16" 10,0003-1/16" 15,000

CHOKE LINENominal Size/Bore (in) Working Pressure (psi)

3-1/8" 3,0003-1/8" 5,000

4-1/16" 10,000 and 15,000

2.1.2 The complete piping system, valves, chokes and choke manifold will be the full workingpressure of the BOP through the block valves downstream of the chokes and the ChokeManifold Buffer Chamber.

2.2 Material and Fabricatio n:

2.2.1 The lines from the BOP stack to the choke manifold shall have the same working pressure (orgreater) as the BOP stack. All lines shall meet Sour Service requirements for APISpecifications 6A and 16C.

2.2.2 Choke lines for 3M and 5M applications shall be either steel pipe, flexible hose or a combination

of these.

2.2.3 Choke lines for 10M and higher applications shall be either steel pipe or a combination of hardline and flexible hose.

2.2.4 Flexible steel hose if used in combination flanged hard line may be used for the choke, kill andemergency kill lines on 3M through 15M applications provided the following requirements aresatisfied:

Made by an approved manufacturer as listed in section 2.2.7 below.


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All components of the hose and end fittings in possible contact with wellbore fluids meetSour Service NACE MR-01-75/ISO 15156 (latest revision)

2.2.5 All lines and end connections shall be pressure tested and Monogrammed as per APIspecification 6A, 16C or 17D as appropriate.

2.2.6 Steel line material shall meet the requirements of API specification 6A or 16C for H 2S service.

2.2.7 Flexible choke and kill lines shall be monogrammed to API Specification 16C. The onlyapproved flexible choke and kill lines are:

Technip/Coflexip (coflon lined) Continental Contetich-Thermo plastic lined (only allowed in 5,000 psi and lower service) Phoenix HNBR (only allowed in 5,000 psi and lower service)

NOTE: The Phoenix HNBR hose has the following limitations in chemical compatibility:

Product comp atibilit y of HNBR lined Phoenix Rubber hoses(choke and kill hoses acc. to API Spec. 16C 07 C draft &hoses c\w st. st. internal carcass acc. to API Spec. 17K)

0oF 75 oF 150 oF 200 oF 250 oFMedium Concentration -18 oC 24 oC 66 oC 93 oC 121 oC

Hydrochloric acid HCl 15% + + - - -Hydrofluoric acid HF 0.6% + + - - -Xylene C6H4 (CH3)2 25% + + + L L

Methanol CH3OH 100% + + L L LZinc bromide ZnBr2 Saturated + + L L L

Calcium bromide CaBr2 Saturated + + L L LCalcium chloride CaCl2 Saturated + + L L L

Diesel 100% + + + + -Sea water --- + + + - -

Sodium hydroxide NaOH 50% L L - - -Hydrogen sulfide H2S 20% + + + + +

(+) Suitable, (-) Not Suitable, (L) Limited Service

2.2.8 Field welding is not permitted on choke and kill lines. These must be welded in an API licensedshop to a qualified welding procedure and must, at a minimum, pass hardness tests (HRC 22 orless) and radiography of the welds.

2.2.9 All choke and kill lines shall be as straight as possible with targeted, block tees at turns. The

tees will be lead targeted with renewable target flanges. Welded or threaded tees are notacceptable.

NOTE: Threaded tees that are seal welded are NOT ALLOWED in any service.

NOTE: Chiksans are not acceptable for kill line, emergency kill line or choke line.

2.2.10 All kill, emergency kill, choke and choke manifold connections should be flanged, API licensedfactory welded, integral or hubbed and shall be monogrammed to API Specification 6A.


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2.3 Requirements for Drilling Chokes:

2.3.1 A remote controlled hydraulic choke(s) shall be installed on each manifold. All chokes used inSaudi Aramco service must be from one of the approved models listed below. Acceptablemodels are:

SWACO 'Super Choke' Cameron Drilling Choke NOV Shaffer Drilling Choke

NOTE: Choke makes and models not listed above will not be accepted.

2.3.2 All Chokes, regardless of make and model, shall comply with the following specifications:

Monogrammed to API Specification 6A or 16C PSL-2 (or better) (With PSL-3 Gas Test) PR-1 (or better) MR-DD (or better) TR-U (5,000 psi working pressure or lower) TR-X Suitable for 0-350 oF service (10,000 psi working pressure or higher) Forged bodies and bonnets Alloy 625 or better, inlaid ring grooves

2.4 Requirements for Manual Gate Valves, Hydraul ic Gate Valves and Check Valves:

2.4.1 Manual Gate Valves shall be non-rising stem, single slab floating gate valves with one-pieceseat design (Body Bushings Not Allowed). Split gates or valves with floating or two-piece seatsthat can pressure lock are not acceptable. Nitrile/Buna Elastomer Seals are not allowed.PTFE/PEEK Based Seals are acceptable. Manufacturers are not specified for contractor ownedmanual gate valves, however, it should be noted that each valve must be re-certified by theOEM at contract start-up and every three (3) years thereafter. Hydraulic Controlled Remote(HCR) Gate Valves will be required to meet the same specification with the exception of theStem. HCR Gate Valves are allowed to incorporate a rising stem and a balance stem on thebottom of the valve body.

Approved Hydraulic Valve Manufacturers: Cameron (all sizes), Axon (7-1/16 only).

2.4.2 All Gate Valves shall comply with the following specifications (in addition to Section 1.1):

Monogrammed to API Specification 6A PSL-2 (or better) with PSL-3 Gas Test (10,000 psi and higher) PSL-2 (or better) (5,000 psi and lower) PR-1 (or better) MR-DD (or better) TR-U (5,000 psi working pressure or lower) TR-X suitable for 0-350 oF service (10,000 psi working pressure or higher) Forged bodies and bonnets

2.4.3 All Check Valves shall comply with the following specifications (in addition to Section 1.1):

Monogrammed to API Specification 6A PSL-2 (or better) with PSL-3 Gas Test (10,000 psi and higher)


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PSL-2 (or better) (5,000 psi and lower) PR-1 (or better) MR-DD (or better) TR-U (5,000 psi working pressure or lower) TR-X suitable for 0-350 oF service (10,000 psi working pressure or higher) Forged bodies and bonnets Top entry valves only, no bottom body penetrations. Metal to metal seal valves only.

2.5 Requirements for Cup Testers:

2.5.1 Cameron Type F cup testers are the only approved model. All elastomers and other partsmust be OEM.

3.0 ACCESSORY BOP EQUIPMENT REQUIREMENTS

3.1 Pit Volume Totalizers:

3.1.1 All rigs shall have a pit volume totalizer installed. These should be kept on at all times, evenwhen out of the hole, changing bits or logging.

3.1.2 Charts and, or, warning devices (horn, lights etc.) should be installed at the Drill Floor, MudLogging unit and the Toolpushers or Drilling Representative's office.

3.2 Mud Flow Indicators:

3.2.1 All rigs shall have a mud flow indicator installed. These should be kept on at all times, evenwhen out of the hole, changing bits or logging.

3.2.2 Electrical Differential and the Flow Sensor types are approved.

3.3 Gas Busters:

3.3.1 Gas busters (poor boy degassers) shall be installed on every rig.

3.3.2 The vent lines must meet the following requirements:

Lines will be 8 minimum OD flanged or clamped steel line (minimum of 240 in length, fromthe gas buster)

Same pressure rating (or greater) than that of the gas buster. Shall terminate in a flare pit, positioned 50 beyond the edge of the reserve/waste pits toprevent ignition of any waste hydrocarbons while circulating gas from the wellbore.

3.3.3 The gas buster design for deep gas rigs is shown in Figure A-3.1 The minimum internalcapacity for Gas Rig gas busters is 35 barrels.

3.3.4 The gas buster design for oil development rigs is shown in Figure A-3.2 The minimum internalcapacity for Oil Rig gas busters is 17.5 barrels.

3.3.5 Gas busters should be cleaned out periodically.


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3.3.6 Never circulate cement returns through a gas buster.

3.3.7 Gas busters have a tendency to shake and rattle when they are in use. They should besecurely anchored.

3.3.8 All gas busters shall be built in compliance to ASME Boiler and Pressure Vessel Code, SectionVIII, Division I, with all materials meeting requirements of NACE Standard MR-01-75/ISO15156(Latest Revision). All welding on the vessel shall meet ASME requirements. New gas bustersshall be hydrostatically tested to 190 psi to give a maximum working pressure of 150 psi, as per

ASME.

INTENTIONALLY LEFT BLANK


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FIGURE A-3.1: Mud Gas Separators for Gas Service

3.3.9 There should be a by-pass line upstream of the separator directly to the flare line and a valve onthe separator inlet line to protect the separator from high pressure.

3.3.10 The mud discharge line from the separator must have a vacuum breaker stacked vent line if thedischarge line outlet is lower than the bottom of the separator. This is to prevent siphoning gasfrom the separator to the mud pits. The vacuum breaker stack must be as high as the separator.


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3.3.11 MGS/Gas Buster must be fully inspected and tested every five (5) years. Inspection will includefull visual, Pressure Testing, 100% Magnetic Particle or Dye Penetrant NDE and Ultra Sonic todetermine the integrity of the wall thickness. Additionally, Inspection Documentation with 3 yearvalidity must be submitted at new rig start-up as well as for rig contract renewal.



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FIGURE A-3.2: Mud Gas Separators for Oil Service


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3.4 Full Opening Safety Valves:

3.4.1 A full opening safety valve to fit each size of drill pipe and drill collar in use will be kept in theopen position on the rig floor (including a closing/opening wrench).

3.4.2 A safety valve and appropriate cross-over are also required when running casing and tubing.

3.4.3 Care should be taken to ensure that valves have the proper threads and that they will gothrough the BOP stack and casing. This will allow the valves to be stripped into the hole belowan inside BOP.

NOTE : Full Open Safety and Kelly valves must be designed and manufactured in compliance with APISpec 7-1.

The term 'full opening' does not mean that the ID of the valve is the same as the pipe, but ratherthat the bore through the valve is not restricted.

3.5 Insid e BOP:

3.5.1 An inside BOP to fit each size of drill pipe and drill collar in use will be kept in the open positionon the rig floor.

NOTE : Inside BOP must be designed and manufactured in compliance with API Spec 7-1.



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3.6 Trip Tank:

3.6.1 A circulating trip tank will be used on all rigs while tripping out of or back into the hole.

3.6.2 The trip tanks shall have two (2) 60 barrel compartments.

3.6.3 There shall be two (2) independent measuring devices, a mechanical float operated pit levelindicator graduated in inches and an electro-mechanical device.

FIGURE A-3.3: Typical Trip Tank3.6.4 Calculated versus actual volumes shall be monitored and recorded in a log book recording the

following data:

Volume and weight of slug Number of strokes the slug is pumped. Time for slug to stabilize and flow to stop in the annulus. Amount of mud to fill hole:

o 5 Stands for Drill Pipeo 2 Stands for HWDPo Every Stand for Dill Collars

NOTE: If the volume of mud used to fill the hole is not correct for any interval, stop pulling anddetermine the reason the hole is not taking mud properly.

Total volume of mud per trip to fill hole (calculated and measured) Leave drill pipe wiper rubbers off pipe for the first five (5) stands to observe hole.


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3.7 Bowl Protectors (Wear Bushi ngs):

Bowl protectors, or wear bushings, protect the hanger bowl in the casing or tubing head during drillingoperations.

3.7.1 Bowl protectors shall be used in all operations when drilling through the wellhead.

NOTE: Bowl protectors, just like BOP test plugs have a Manufacturer specific profile. The bowlprotector used must match the Manufacturer and Model of the Wellhead.

3.8 Valve Removal Plugs :

Valve Removal (VR) plugs are one-way check valves that can be installed through an outlet valve on acasing head, casing spool or tubing spool into a female thread in the outlet for its repair or replacement.Once the valve has been repaired or replaced the VR plug can be removed.

3.8.1 VR plugs shall be removed from the wellhead in order to have access to the annulus. Thisshould be confirmed prior to nippling up the wellhead.

3.8.2 VR plugs are to be installed under the blind flanges on all wellheads prior to the rig move/wellcompletion.

3.8.3 Under no circumstances should a VR plug be left in a side outlet that has a valve installed.

3.9 Drillpip e Float Valves:

Drill pipe float valves shall be run in all Saudi Aramco operations except when planned operationspreclude running a float; testing, treating or squeezing. The drillpipe float valve shall be positioneddirectly above the bit.

3.10 Weco Connections:

3.10.1 Weco connections (other than the remote connections at the end of the catwalk) are notacceptable for kill, emergency kill or choke line service.

3.10.2 Factory Manufactured Integral or butt welded Figure 1502 connections are acceptabledownstream of the choke manifold buffer tank for land and offshore operations. Field fabricatedconnections are not acceptable.

3.10.3 Weco type connections are not acceptable on well test lines upstream of the Choke & KillManifold.

3.10.4 2 inch Figure 602 connections are not allowed in any Saudi Aramco Drilling and WorkoverOperation.

3.11 Chiksans / Swivel Joint :

3.11.1 Chiksans are sections of pipe with hammer unions and two swivels in each joint. The primaryuse of chiksans is to run temporary lines for high pressure pumping and cementing operations.

3.11.2 Chiksans shall not be used in kill lines, emergency kill lines or choke lines.


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3.12 Accumu lator Closing Units:

The brand of closing unit used by the Drilling or Workover Contractor is not specified by Saudi Aramco,however, all closing units shall meet the following requirements.

Fluid Requirements:

3.12.1 The accumulator shall store enough fluid under pressure to close all preventers, open the chokeHCR valve and retain 50% of the calculated closing volume with a minimum of 200 psi abovepre-charge pressure without assistance from the accumulator pumps.

Design Requirements:

3.12.2 The accumulators and all fittings will be a minimum of 3,000 or 5,000 psi working pressuredepending on the BOP Ram Bonnet working pressure. The Accumulator and all Hydraulic linesfrom the accumulator to the BOP stack shall be designed and manufactured in accordance with

API Specification 16D. All Accumulators and Lines must be manufactured by an API 16DLicensed Facility. Onshore Hoses must be sleeved and shielded externally steel encased(equivalent to Gates 16 EFBOP Blow-Out Preventer Hose). Offshore hoses are not required tobe externally steel encased. The hose end connection must be of a winged hammer or hexunion style. All piping and connections used from the Accumulator Unit to the BOP must be

ASME/ANSI SCH 160 or equivalent. Quick-Connect type connections are not allowed. Manifoldand BOP hydraulic lines should be tested to the system working pressure at installation.

NOTE: All air and hydraulic BOP operating units shall be equipped with regulator valves similarto the Koomey type TR-5. These will not fail open causing loss of operating pressure.

Bott le Pre-Charge Requir ements:

3.12.3 Accumulator bottles will be pre-charged with nitrogen as per manufacturersspecifications/recommendations. The minimum required pre-charge pressure for a 3,000 psi(20.7 MPa) working pressure accumulator unit is 1,000 psi (6.9 MPa). The minimum requiredpre-charge pressure for a 5,000 psi (34.5 MPa) working pressure accumulator unit is 1,500 psi (10.3 MPa). The nitrogen pre-charge pressure shall be checked and adjusted prior toconnecting the closing unit to the BOP stack and any other time the accumulator must becompletely de-pressured.

3.12.4 The accumulator should be capable of closing each ram within 30 seconds. Closing time shouldnot exceed 30 seconds for annulars smaller than 18-3/4 nominal bore and 45 seconds forannular preventers of 18-3/4 and larger.

Operating Controls:

3.12.5 All operating controls shall be clearly marked with function and ram sizes. Accumulator controlsmust be in open or closed position, but not in neutral position. During normal drilling operationsthe HCR valve next to the wellhead will be closed. Unused functions shall be marked Out ofService, covered or have the handles removed on the main and remote units. Unusedfunctions shall have the open/close lines plugged at the main unit.


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Accumulat or and Contr ol s Locati on s:

3.12.6 Master Controls shall be at the accumulator. There must be at least two (2) sets of remotecontrols for operating the accumulator to activate the BOPs and all HCR valves. HCR valves onthe choke line, kill line and the C&K manifold shall be powered by the main accumulator unit.One remote control shall be on the rig floor, accessible by and visible to the driller and the othershall be located near the Company Representatives office.

Onshore: The accumulator shall be located at a remote location, at least 60 feet distancefrom the wellbore for oil wells and 100 feet for gas wells, shielded from the wellheadand protected from other operations around the rig.

Offshore: The accumulator shall be shielded from the wellhead and the drill floor andprotected from other operations around the rig. It should be located as far aspractically possible from the wellhead.

Pump System:

3.12.7 Two pump systems are required. The preferred configuration is to have one electric/hydraulicand the second pneumatic (air)/hydraulic. The primary electric/hydraulic pump system and thesecondary pneumatic/hydraulic pump system must be independent of each other and fullyoperational when the accumulator is in use. The high-pressure set point for both the electricpump and air pump should be 3,000 or 5,000 psi. The low-pressure set point should be above2,800 psi for both systems. Do not bleed off pressure due to ambient temperature rise.Pressure may vary from 3,000 to 3,400 or 5,000 to 5,400 psi in a 24-hour period.

It is permissible to have two independent electric/hydraulic systems. however, they must haveseparate and totally independent prime movers.Each of the two systems shall have the quantity and sizes of pumps such that, with theaccumulators isolated from service, the following steps are completed within two minutes:

The annular BOP closes on the minimum size drill pipe being used All hydraulically operated valves opened Provide the pressure recommended by the annular BOP manufacturer to effect a seal on

the annulus

Pressure Regulator Settings:

3.12.8 The pressure regulators for the annular preventer and ram preventers will be set as permanufacturers specification/recommendation. All BOPs with Shear Blind Rams installed shallhave a bypass to route full system pressure to the SBR's.

NOTE 1 For non-emergency BOP operation, use of the lowest possible pressure will extendelastomer life. Upon completion of the daily testing the pressure regulators shall bereturned to the normal operation pressure.

NOTE 2 DO NOT close annular preventers on open hole for complete shut-off except in anemergency.


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NOTE 3 DO NOT close pipe rams without pipe in the hole. Pipe rams should only be closedon the proper size pipe in order to avoid damage to the rubber packer or to the ramcarriers (DO NOT CLOSE on TOOL JOINTS).

Shear Ram Safety Covers and Alarms :

3.12.9 The Shear Blind Ram controls are to have the following safety and alarm features:

Safety covers (box style) shall be installed over all SBR controls. These covers will besecured with a pin (that must be removed before opening the cover) and will be of a typethat must be lifted to operate the control. They should be clear plastic or have observationholes in them so the position lights may be seen. Covers shall be installed on all SBRcontrols at all remote stations and the accumulator.

The covers shall be fitted with switches that will activate horns and strobe lights when thecover is lifted, before the control is operated. Horns will be installed on the rig floor and atthe accumulator. The alarms will be tested during each well control drill and BOP test. Thealarms should emit a significantly different sound than the H 2S or any other alarms on therig.

3.13 Strok e Count ers:

Stroke counters provide the Driller a method of measuring fluid volumes when displacing special fluidsor lost circulation pills. It is also used to determine pumped volumes when executing well controlprocedures.

3.13.1 Stroke counters are required on all rigs at both the Driller's station and the choke controlconsole.

NOTE: The kill line should not be used in conjunction with the rig pumps and a stroke counterfor hole filling purposes. The kill line is an emergency piece of equipment and shouldnot be used for routine hole fill-up during trips.

3.14 Gas Detector s:

These devices, usually found in mud logging units, are useful in detecting abnormal pressure sectionsas well as shows of hydrocarbons. Rig Supervisors should monitor the trip gas, connection gas, andbackground gas for any significant change. The presence of gas in the mud can be one of the moreuseful indicators of abnormal pressure. Gas Detector readings can sometimes be misleading, however,and the important things to look for are the relative trends and magnitudes, rather than the individualnumber of gas units reported.

3.15 Drill Rate Recorders :

These devices come in both analogue and digital styles. They are useful as correlation tools,particularly if logs are available from other wells in the area. The records can be used to detect andcorrelate formation tops and types, as well as in selecting bits and estimating their useful lives. Asudden increase in penetration rate can be one of the first signs of a well kick.

3.15.1 All rigs should have a drill rate recorder.


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3.16 Pump Lines for Existing Offshore Well Kill :

Steel chicksan swivel joints, connections and piping may be used for the purpose of killing an existingwell with cased hole prior to or after rig arrival. However, only factory Manufactured Integral or buttwelded Figure 1502 connections are acceptable.


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CHAPTER B - B OPE SYSTEM CONFIGURATION

Current Revision: JUNE, 2014 B - 1Previous Revision: MAY, 2010

CHAPTER B: BOPE SYSTEM CONFIGURATION

TABLE OF CONTENTS

1.0 BOP EQUIPMENT SYSTEM CONFIGURATION1.1 Pressure Rating of BOPE Systems B-3

2.0 CLASS A 15,000 psi BOP STACK2.1 Usage B-3

2.2 Class A 15,000 psi BOP Stack Arrangement (Single Sized Drill Pipe) B-4

2.3 Class A 15,000 psi BOP Stack Arrangement (Tapered Drill Pipe String) B-7








5.2 Class A 3,000 psi BOP Stack Arrangement for Large Hole (Single Sized Drill Pipe) B-16

5.3 Class A 3,000 psi BOP Stack Arrangement for Smaller Hole (Single Sized Drill Pipe) B-18


6.0 CLASS B 3,000 psi BOP STACK6.1 Usage B-19

6.2 Class B 3,000 psi BOP Stack Arrangement B-19

7.0 CLASS C 3,000 psi BOP STACK B-21

8.0 CLASS D DIVERTER STACK B-22

9.0 CLASS I 2,000 psi WORKOVER STACK9.1 Usage B-24

9.2 Class I 2,000 psi Stack Arrangement B-24


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10.0 CLASS II 3,000 psi WORKOVER STACK10.1 Usage B-25

10.2 Class II 3,000 psi Stack Arrangement B-25

11.0 CLASS III 5,000 psi WORKOVER STACK11.1 Usage B-25

11.2 Class III 5,000 psi Stack Arrangement B-26

12.0 CLASS IV 10,000 psi WORKOVER STACK12.1 Usage B-26

12.2 Class IV 10,000 psi Stack Arrangement B-26

13.0 CLASS V 15,000 psi WORKOVER STACK13.1 Usage B-26

13.2 Class IV 10,000 psi Stack Arrangement B-26

14.0 SPECIAL WELL OPERATIONS BOP STACKS14.1 BOP Equipment Requirements for Coil Tubing Operations B-26

14.2 BOP Equipment Requirements for Snubbing B-30

14.3 BOP Equipment Requirements for Electric Line Operations B-33

15.0 CHOKE MANIFOLDS15.1 15,000 PSI Working Pressure Choke Manifold B-35

15.2 10,000 PSI Working Pressure Choke Manifold B-38



15.5 Location B-44

15.6 Choke Manifold Pressure Ratings B-44

15.7 Piping Specifications B-44

15.8 Choke Manifold Discharge and Flare Lines B-44

15.9 Gas Buster Lines B-46


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1.0 BOP EQUIPMENT SYSTEM CONFIGURATION

This Chapter of the Well Control Manual sets forth the configurations for BOP equipment systems for use inDrilling and Workover Operations. All equipment must comply with the other chapters in this manual.Variations or deviations of BOP equipment, specifications, arrangement, pressure rating or requirementsfrom this standard requires endorsement of the Well Control Committee, and approval by the Vice Presidentof Drilling and Workover. The enforcement of these equipment standards shall be the responsibility of theDrilling or Workover Rig Superintendent. The Rig Foreman shall ensure that the proper equipment isavailable and correctly installed. If not specified in these standards all BOP equipment shall comply with APISpecifications and Recommended Practices. The BOP equipment must be arranged to allow:

A means of closing the top of the open hole, as well as around drill pipe or collars, and stripping thedrill string to bottom.

A means of pumping into a hole and circulating out a well kick.

A controlled release of the influx. Redundancy in equipment in the event that any one function fails. All preventers shall be installed so that rams can be changed without moving the stack. The drilling program shall specify the Class BOP stack (not individual components) to be used.

1.1 Pressur e Rating of BOPE Systems :

The pressure rating of the BOP system is based on the MASP (Maximum Anticipated SurfacePressure). The minimum rated working pressure of the BOP system shall be selected based onMASP for each hole section as detailed in the table below:

BOP EquipmentPressure Rating

OIL WELLMASP (in PSI)

GAS WELLMASP (in PSI)

INJECTION WELLMASP (in PSI)

3,000 PSI 2,550 2,700 < 3,0005,000 PSI 4,250 4,500 < 5,000

10,000 PSI 8,500 9,000 < 10,00015,000 PSI 12,750 13,500 < 15,000

NOTE-1: Does not include diverter requirements.NOTE-2: BOPs with higher rated working pressure than shown above may be used at any time.

2.0 CLASS A 15,000 PSI BOP STACK

2.1 Usage:

A Class A 15,000 psi BOP stack shall be installed on all offshore and onshore wells with a MASPup to the limits given in the table above. If MASP exceeds these limits a higher pressure rating will

be required.

The through bore of the BOP stack including drilling spools, risers, DSA's and any other equipmentwill be at least as large as the wellhead section immediately below it. These BOP stacks areavailable in 7-1/16", 11", 13-5/8" and 18-3/4" 15M.


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2.2 Class A 15,000 psi BOP Stack Arrang ement (Single Size Dril l Pipe):

When using a single size of drill pipe the stack arrangement (from bottom to top) shall be asdescribed below and as shown in Figure B-1:

2.2.1 A wellhead spool or tree with a 18-3/4", 13-5/8", 11 or 7" 15M flange with two (2) 3-1/16"15M studded side outlets shall be installed. Each outlet shall have two (2) 3-1/16" (minimum)15M flanged gate valves with a blind flange installed.

2.2.2 If the top flange of the wellhead is below ground level, a spacer spool spacer is required. Ifthe BOP Stack is larger than the wellhead a double studded adapter flange is required.

2.2.3 A flanged or studded double gate ram preventer shall be installed on the wellhead or spool.The BOP shall be above ground level with master drill pipe rams in the bottom position (1)and blind rams in the top position (2).

2.2.4 A flanged drilling cross shall be installed on the double ram preventer. The drilling cross shallhave two (2) 4-1/16" 15M flanged side outlets.

2.2.5 Kill Lines

There shall be two (2) kill lines, an upper and a lower. Both lines shall be 3-1/16" 15M andconfigured as below:

From the drilling cross out on the kill line side, there shall be:

a double studded adapter flange 4-1/16" 15M to 3-1/16" 15M a 3-1/16" 15M flanged manually operated gate valve

a 3-1/16" 15M flanged hydraulic control (HCR) gate valve a 3-1/16" 15M flanged spacer spool a 3-1/16" 15M studded tee

The bottom outlet of the tee will connect to the lower kill line. The other side of the tee willhave a flanged spacer spool followed by a second studded tee. On each side of the secondtee there shall be a 3-1/16" 15M flanged gate valve and a 3-1/16" 15M flanged check valve.On the remote (emergency pump connection) side, the kill line shall be 15M and run at least90 feet from the wellbore to the end of the catwalk, with a flange to Weco 3" welded union.On the primary (mud pump) side, the kill line shall be connected directly to the mud pumpsor to the stand pipe manifold, with a 10M manual isolation valve between the kill line and the7,500 psi stand pipe.

The lower kill line from the 4-1/16" 15M BOP master pipe ram side outlet out there shall be: a 4-1/16" X 3-1/16" 15M DSA two (2) 3-1/16" 15M flanged manually operated gate valves 3-1/16" 15M flanged spacer spools and studded (targeted) tees as required a 3-1/16" 15M flanged manually operated gate valve attached directly to the studded

tee on the upper kill line.


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2.2.5 Choke LinesThere shall be two (2) choke lines, an upper and a lower. Both lines shall be 4-1/16" 15Mand configured as below:

From the drilling cross out on the choke line side there shall be:

a 4-1/16" 15M flanged manually operated gate valve a 4-1/16" 15M flanged hydraulic control (HCR) gate valve a 4-1/16" 15M flanged spacer spool a 4-1/16" 15M studded tee

The bottom outlet of the tee will connect to the lower choke line. The other side of the teewill connect (through flanged line) to the manually operated gate valve at the chokemanifold.

The lower choke line from the 4-1/16" 15M BOP master pipe ram side outlet out there shallbe:

a 4-1/16" 15M flanged manually operated gate valve a 4-1/16" 15M flanged hydraulic control (HCR) gate valve a 4-1/16" 15M flanged spacer spools and studded (targeted) tees as required a 4-1/16" 15M flanged manually operated gate valve attached directly to the studded

tee on the upper choke line.

NOTE : All steel piping shall be made with 15M flanges, targeted tees, block-tee elbows, andfactory-manufactured 15M working pressure line. All tees must be targeted with

renewable 15M blind flanges (welded tees are not acceptable).

Chiksans and Weco connections (other than the remote connections at end of thecatwalk) are not acceptable for kill line, or choke line. Coflex hose (refer to Chapter

A, Section 2.0) may be used in combination with steel line for the choke or kill line.

2.2.6 A 15M flanged or studded double gate ram preventer shall be installed on the 15M drillingcross. There shall be shear blind rams in the bottom (3) and drill pipe rams in the top (4) ofthe double ram preventer.

2.2.7 A 10M or 15M annular preventer will be installed on the top of the double ram preventer.The annular shall be flanged bottom X studded top.

2.2.8 A flanged rotating head, with a flanged bottom connection to match the top connection of theannular preventer and a 9" 3M flanged side outlet, may be installed on top of the annularpreventer. A spacer spool may be required if annular studded top is not compatible with therotating head flange.


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Figure B-1: Class 'A' 15,000 psi BOP Stack with Single Sized Drill Pipe


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2.3 Class A 15,000 psi BOP Stack Arrang ement (Tapered Dril l Pipe Strin g):

When using a tapered string of drill pipe the stack arrangement shall be the same as that for thesingle string EXCEPT the blind rams in the bottom double (2) shall be changed to pipe rams andsized for the smaller sized pipe and the master pipe rams (1) and upper pipe rams (4) shall be sizedfor the larger pipe as shown in Figure B-2:

Figure B-2: Class 'A' 15,000 psi BOP Stack with a Tapered String of Drill Pipe


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3.1 Usage:

A Class A 10,000 psi BOP stack shall be installed on all offshore and onshore wells with a MASP ofup to 8,000 psi.

The through bore of the BOP stack including drilling spools, risers, DSA's and any other equipmentwill be at least as large as the wellhead section immediately below it. These BOP stacks areavailable in 7-1/16", 11", 13-5/8" and 18-3/4" 10M

3.2 Class A 10,000 psi BOP Stack Arrang ement (Single Size Dril l Pipe):

When using a single size of drill pipe the stack arrangement (from bottom to top) shall be as

described below and as shown in Figure B-3:3.2.1 A wellhead spool or tree with a 18-3/4", 13-5/8", 11 or 7" 10M flange with two (2) 3-1/16"

(minimum) 10M studded side outlets shall be installed. Each outlet shall have two (2) 3-1/16"10M flanged gate valves with a 3-1/16 blind flange installed.

3.2.2 If the top flange of the wellhead is below ground level, a spacer spool spacer is required. Ifthe BOP Stack is larger than the wellhead a double studded adapter flange is required.

3.2.3 A flanged or studded double gate ram preventer shall be installed on the wellhead or spool.The BOP shall be above ground level with master drill pipe rams in the bottom position (1)and blind rams in the top position (2).

3.2.4 A flanged drilling cross shall be installed on the double ram preventer. The drilling cross shallhave two (2) 4-1/16" 10M flanged side outlets.

3.2.5 Kill Lines

There shall be two (2) kill lines, an upper and a lower. Both lines shall be 2-1/16" 10M andconfigured as below:


a double studded adapter flange 4-1/16" 10M to 2-1/16" 10M a 2-1/16" 10M flanged manually operated gate valve a 2-1/16" 10M flanged hydraulic control (HCR) gate valve a 2-1/16" 10M flanged spacer spool a 2-1/16" 10M studded tee

The bottom outlet of the tee will connect to the lower kill line. The other side of the tee willhave a flanged spacer spool and followed by another studded tee. On each side of this teethere shall be a 2-1/16" 10M flanged gate valve and a 2-1/16" 10M flanged check valve. Onthe remote (emergency pump connection) side, the kill line shall be 10M and run at least 90feet from the wellbore to the end of the catwalk, with a flange to Weco 2" welded union. Onthe primary (mud pump) side, the kill line shall be connected directly to the mud pumps or tothe stand pipe manifold, with a 5M manual isolation valve between the kill line and the 5,000psi stand pipe.


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The lower kill line from the 4-1/16" 10M BOP master pipe ram side outlet out there shall be:

a 4-1/16" X 2-1/16" 10M DSA two (2) 2-1/16" 10M flanged manually operated gate valves 2-1/16" 10M flanged spacer spools and studded (targeted) tees as required a 2-1/16" 10M flanged manually operated gate valve attached directly to the studded

tee on the upper kill line.

3.2.6 Choke Lines

There shall be two (2) choke lines, an upper and a lower. Both lines shall be 4-1/16", 10Mand configured as below:

From the drilling cross out on the choke line side there shall be:

a 4-1/16" 10M flanged manually operated gate valve a 4-1/16" 10M flanged hydraulic control (HCR) gate valve a 4-1/16" 10M flanged spacer spool a 4-1/16" 10M studded tee

The bottom outlet of the tee will connect to the lower choke line. The other side of the teewill connect (through flanged line) to the manually operated gate valve at the chokemanifold.

The lower choke line from the 4-1/16", 10M BOP master pipe ram side outlet there shall be:

a 4-1/16" 10M flanged manually operated gate valve a 4-1/16" 10M flanged hydraulic control (HCR) gate valve

4-1/16" 10M flanged spacer spools and studded (targeted) tees as required a 4-1/16" 10M flanged manually operated gate valve attached directly to the studded

tee on the upper choke line.

NOTE : All steel piping shall be made with 10M flanges, targeted tees, block-tee elbows, andfactory manufactured 10M working pressure line. All tees must be targeted withrenewable 10M blind flanges (welded tees or field fabricated equipment is notacceptable).

Chiksans and Weco connections (other than the remote connections at end of thecatwalk) are not acceptable for kill line, or choke line. Coflex hose (refer to Chapter

A Section 2.0) may be used in combination with steel line for the choke or kill line.

3.2.7 A 10M flanged or studded double gate ram preventer shall be installed on the 10M drillingcross. There shall be shear blind rams in the bottom (3) and drill pipe rams in the top (4) ofthe double ram preventer.

3.2.8 A 10M annular preventer will be installed on the top of the double ram preventer. Theannular shall be flanged bottom X studded top.

3.2.9 A flanged rotating head, with a flanged bottom connection to match the top connection of theannular preventer and a 9" 3M flanged side outlet, may be installed on top of the annular


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preventer. A spacer spool may be required if annular studded top is not compatible with

rotating head flange.

Figure B-3: Class 'A' 10,000 psi BOP Stack with Single Sized Drill Pipe


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3.3 Class A 10,000 psi BOP Stack Arrang ement (Tapered Dril l Pipe Strin g):

When using a tapered string of drill pipe the stack arrangement shall be the same as that for thesingle string EXCEPT the blind rams in the bottom double (2) shall be sized for the smaller sizedpipe and the master pipe rams (1) and upper pipe rams (4) shall be sized for the larger pipe asshown in Figure B-4.


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Figure B-4 Class A 10,000 psi BOP Stack with a Tapered String of Drill Pipe

4.0 CLASS A 5,000 PSI BOP STACKS 4.1 Usage:

A Class A 5,000 psi BOP stack shall be installed on wells where MASP may become more than2,401 psi but not more than 4,000 psi. All of the elements of the BOP stack shall be 5,000 psi ratedworking pressure. All preventers shall be installed so that rams can be changed without moving thestack.

The through bore of the BOP stack including drilling spools, risers, DSA's and any other equipmentwill be at least as large as the wellhead section immediately below it. These BOP stacks areavailable in 7-1/16", 11", 13-5/8" and 18-3/4" 5M.

4.2 Class A 5,000 psi BOP Stack Arrangement:

The stack arrangement (from bottom to top) shall be as described below and as shown in Figure B-5:

4.2.1 A wellhead spool (or casing head) with a 18-3/4", 13-5/8", 11 or 7" 3M or 5M flange with two(2) 2-1/16" or 3-1/16" 3M or 5M studded side outlets shall be installed. One outlet shall havea flanged gate valve with a blind flange installed. The other outlet shall have a manuallyoperated flanged gate valve installed next to the wellhead and a hydraulically operated(HCR) flanged gate valve connecting to the emergency kill line. The emergency kill line shallbe an individual line with flanged steel piping (no chiksan swings or hammer unions) and aminimum 2 5M rated working pressure. Flexible hose (compliant with Chapter A section2.0) may be used in combination with steel line.

The emergency kill line shall extend from the wellbore to end of the catwalk (approximately90 feet), with a 2" 1502 Weco welded union (threaded connections are not acceptable) forconnection to an emergency pump. Offshore the emergency kill line will extend to theemergency pump / cement unit.

NOTE: If shear blind rams are utilized, then the emergency kill line shall be 3 and 5M ratedworking pressure. The manual gate valve shall remain as 2 with double studdedadapter to 3.

NOTE: If the wellhead spool has a 5M top flange, then the side outlet valves shall be 5M.

NOTE: All BOP equipment with working pressures of 3,000 psi and above shall haveflanged, welded, integral, or hubbed connections only.


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Figure B-5: Class 'A' 5,000 and 3,000 psi BOP Stack with VBRs


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4.2.2 If the top flange of the wellhead is below ground level, a spacer spool is required. If the BOP

Stack is larger than the wellhead a double studded adapter flange is required.4.2.3 A 5M flanged single ram preventer shall be installed on the wellhead spool with master drill

pipe rams.

4.2.4 A 5M flanged drilling cross shall be installed on the single ram preventer. The drilling crossshall have two (2) 3-1/8" (minimum) 5M side outlets.

4.2.5 There shall be a double studded adapter flange to adapt from one of the BOP side outlets tothe 2-1/16" 5M kill line and one from the other BOP side outlet to the 3-1/8 choke line.

4.2.6 Kill Lines:


a 2-1/16" 5M flanged manually operated gate valve a 2-1/16" 5M flanged hydraulic control gate valve a 2-1/16" 5M flanged spacer spool a 2-1/16" 5M flanged tee

On each side of the tee there shall be a 2-1/16" 5M flanged gate valve and a 2-1/16" 5Mflanged check valve.

On the remote side, the kill line shall be 5M and run at least 90 feet from the wellbore to theend of the catwalk, with a flange to Weco 2" welded union.

On the primary side, the kill line shall be 5M and connected directly to the mud pumps or to

the stand pipe manifold.

4.2.7 Choke Lines:

On the choke line, from the drilling cross out, there shall be:

a 3-1/8" 5M flanged manually operated gate valve a 3-1/8" 5M flanged hydraulic control gate valve a 3-1/8" 5M steel flanged line or flexible hose (Chapter A, Section 2.0) to a 3-1/8" 5M

flanged manually operated gate valve at the choke manifold

NOTE : All steel piping shall be made with 5M flanges, targeted tees, block-tee elbows, andfactory-made 5M working pressure line. All tees must be targeted with renewable

5M blind flanges (welded tees are not acceptable).Chiksans and Weco connections (other than the remote connection at the end of thecatwalk on land operations) are not acceptable. Flexible hose (refer to Chapter ASection 2.0) may be used in combination with steel line for kill, emergency kill line,or choke line.

4.2.8 Either two (2) flanged/studded single ram preventers or a double ram preventer shall beinstalled, with blind rams in the position immediately above the drilling spool and VBRsinstalled immediately below the annular.


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Variable bore rams are required to be used on Class A 5M stacks. However, the master

pipe ram must be a fixed ram.NOTE : Currently, Camerons Extended Range High Temperature VBR-II Packer is the only

variable bore ram that is approved for 5M applications (3-1/2" - 5-7/8" pipe sizes). Additional information regarding the use of variable bore rams is provided in Chapter A, Section 1.4.

4.2.9 A 5M flanged bottom and studded top annular preventer will be installed on the top rampreventer.

4.2.10 A rotating head is optional.

4.3 Class A 5,000 psi BOP Stack Arrangement for Tapered Drill Pipe String:

The Class A 5,000 BOP Stack arrangement for tapered drill strings will be the same as it is forsingle sized drillpipe EXCEPT the upper pipe rams (position 3) will be sized for the smaller sized drillpipe as shown in Figure B-5. Alternatively, the upper pipe rams may be Variable Bore Rams as perChapter A Section 1.4. NOTE: Variable Bore Rams are not allowed in the Master Pipe Ramposition (lowermost rams).



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5.1 Usage:

Large Diameter Hole (as with Deep Gas Wells):

A Class A 3,000 psi BOP stack shall be installed on all wells where large diameter hole (as withdeep gas wells) is being drilled, as through 18-5/8" casing, and where hydrocarbon reservoirs with aMASP of up to 2,400 psi may be drilled. All preventers shall be installed so that rams can bechanged without moving the stack.

Smaller Diameter Hole (as wit h Criti cal Oil Wells):

At the discretion of the Drilling Manager, some wells may require a Class A 3,000 psi stack instead

of a Class B 3,000 psi stack.Shear blind rams on onshore stacks are required only on wells with high H 2S, wells in gas cap areasand wells in populated areas (close proximity). Further details on the use of shear blind rams isprovided in Chapter A section 1.5.

5.2 Class A 3,000 psi BOP Stack Arrangement for Large Diameter Hole (Single Size Dril l Pipe):

All elements of Class A 3,000 psi stacks shall be at least 3,000 psi rated working pressure. Thethrough bore of the BOP stack including drilling spools, risers, DSA's and any other equipment willbe at least as large as the wellhead section immediately below it. These BOP stacks are available in7-1/16", 11", 13-5/8" and 20-3/4 and 26-3/4" 3M. Each ram preventer shall have two (2) 4-1/16" 3Mside outlets. A double ram preventer will have four side outlets.

When using a single size of drill pipe the stack arrangement (from bottom to top) shall be asdescribed below and as shown in Figure B5:

5.2.1 A wellhead spool (18-5/8" landing base or casing spool) with 20-3/4" 3,000 psi flange andtwo (2) 3-1/16" 3M side outlets for emergency kill operations shall be installed. One outletshall have a 3-1/16" 3M gate valve with a 3-1/16" 3M blind flange. The other outlet shallhave a manually operated 3-1/16" 3M flanged gate valve next to the wellhead and ahydraulic control 3-1/16" 3M flanged gate valve tied into the emergency kill line. Theemergency kill line shall be an individual line with flanged steel piping (no chiksan swings orhammer unions) and a minimum 3 3M rated working pressure. Coflex hose (coflon lined)may be used in combination with steel line. The emergency kill line shall extend from thewellbore to end of the catwalk (approximately 90 feet), with a 3" 1502 Weco welded union(threaded connections are not acceptable) for connection to an emergency pump.

5.2.2 If the wellhead top flange is below ground level a spacer spool is required. If the BOP Stackis larger than the wellhead a DSA is required.

5.2.3 A 26-3/4 or 20-3/4 3M flanged single ram preventer shall be installed on the wellhead spoolabove ground level with master drill pipe rams (1).

5.2.4 A 26-3/4 or 20-3/4 3M flanged drilling cross shall be installed on the single ram preventer. A drilling cross shall have two (2) 4-1/16" 3M side outlets.


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5.2.5 Either a 26-3/4" or 20-3/4" 3M flanged double ram preventer or two (2) single ram preventers

shall be installed, with blind rams (2) and drill pipe rams (3).5.2.6 A 26-3/4 or 20-3/4" 3M to 30 1M or 21-1/4" 2M double studded adapter flange (DSA) will

be required on top of this preventer. The DSA can be eliminated if a 26-3/4 or 20-3/4" 3Mpsi flange is manufactured on the annular preventer.

5.2.7 A 30 1M or 21-1/4" 2M flanged bottom annular preventer shall complete this stack.

5.2.8 Kill Lines


a 2-1/16" 3M minimum flanged manually operated gate valve a 2-1/16" 3M minimum flanged hydraulic control gate valve a 2-1/16" 3M minimum flanged spacer spool a 2-1/16" 3M minimum flanged tee

On each side of the tee there shall be a 2-1/16" 3M minimum flanged gate valve and a 2-1/16" 3M minimum flanged check valve.

On the remote side, the kill line shall be 3M minimum and run at least 90 feet from thewellbore to the end of the catwalk, with a flange to Weco 2" welded union.

On the primary side, the kill line shall be 3M minimum and connected directly to the mudpumps or to the stand pipe manifold.

5.2.9 Choke Lines


a 3-1/8" 3M minimum flanged manually operated gate valve a 3-1/8" 3M minimum flanged hydraulic control gate valve a 3-1/8" 3M minimum steel flanged line or flexible hose (Chapter A, Section 2.0) to a 3-

1/8" 3M minimum flanged manually operated gate valve at the choke manifold

NOTE : All steel piping shall be made with 3M minimum flanges, targeted tees, block-teeelbows, and factory-made 3M minimum working pressure line. All tees must betargeted with renewable 3M minimum blind flanges (welded tees are notacceptable).

Chiksans and Weco connections (other than the remote connection at the catwalk,land operation) are not acceptable. Flexible hose (refer to Chapter A Section 2.0)may be used in combination with steel line for kill, emergency kill line, or choke line.

5.2.10 A 3M minimum flanged bottom and studded top annular preventer will be installed on the topram preventer.

5.2.11 A rotating head is optional.


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5.3 Class A 3,000 psi BOP Stack Arrangement for Smaller Diameter Hole (Singl e Size Dril l Pipe):

When using a single size of drill pipe the stack arrangement (from bottom to top) shall be asdescribed below and as shown in Figure B-5:

5.3.1 A wellhead spool (13-3/8" landing base) with 13-5/8" 3,000 psi flange and two (2) 2-1/16" 3Mside outlets for emergency kill operations shall be installed. One outlet shall have a 2-1/16"3M gate valve with a 2-1/16" 3M blind flange. The other outlet shall have a manuallyoperated 2-1/16" 3M flanged gate valve next to the wellhead and a hydraulic control 2-1/16"3M flanged gate valve tied into the emergency kill line. The emergency kill line shall be anindividual line with flanged steel piping (no chiksan swings or hammer unions) and aminimum 3 3M rated working pressure (if SBR used) otherwise 2 3M. Coflex hose (coflonlined) may be used in combination with steel line. The emergency kill line shall extend fromthe wellbore to end of the catwalk (approximately 90 feet), with a 1502 WECO welded union(threaded connections are not acceptable) for connection to an emergency pump.

Note : If shear blind rams are utilized, then the emergency kill line shall be 3 and 3M ratedworking pressure. The manual gate valve shall remain as 2 with double studdedadapter to 3.

5.3.2 If the wellhead top flange is below ground level, a 13-5/8 3M spacer spool may be requiredto raise the bottom flange of the BOP to (or above) ground level.

5.3.3 A 13-5/8 3M flanged single ram preventer shall be installed on the wellhead spool aboveground level with master drill pipe rams.

5.3.4 A 13-5/8 3M flanged drilling cross shall be installed on the single ram preventer. A drillingcross shall have two (2) 3-1/16" 3M side outlets. The same arrangement on the kill andchoke lines as for the Class A 5,000 psi BOP stack (land operation) shall be used, asshown in Figure B-6.

5.3.5 Either two (2) 13-5/8" 3M flanged single ram preventers or a double ram preventer shall beinstalled, with blind rams or shear blind rams, see required applications in Section 1.7.4,(bottom) and drill pipe rams (top).

5.3.6 A 13-5/8" 3M flanged bottom with studded top annular preventer shall complete this stack.

5.3.7 Choke and kill lines shall be configured as per section 5.2 above.

5.4 Class A 3,000 psi BOP Stack Arrangement for Tapered Drill Pipe String:

The Class A 3,000 BOP Stack arrangement for tapered drill strings will be the same as it is forsingle sized drillpipe EXCEPT the upper pipe rams (position 3) will be sized for the smaller sized drillpipe as shown in Figure B-5. Alternatively, the upper pipe rams may be Variable Bore Rams as perChapter A Section 1.4. NOTE: Variable Bore Rams are not allowed in the Master Pipe Ramposition (lowermost rams).


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6.0 Class B 3,000 psi BOP Stack6.1 Usage:

A Class B 3,000 psi BOP stack (Figure B-6) shall be installed, as a minimum, on all development oilproducers, water injectors, observation and water disposal wells. All BOP equipment shall be 13-5/83M (or 26-1/4 when used on deep gas wells), with kill and choke line requirements as previouslydescribed in the Class A 3M. The kill line shall be 3M and connected directly to the mud pumps orto the stand pipe manifold.

This stack will also be used for deep gas wells on 24 or 18-5/8 casing.

6.2 Class B 3,000 psi BOP Stack Arrangement :

All BOP equipment for these wells shall be arranged as described below.

6.2.1 A wellhead spool or casing head with a 3,000 psi flanged top and two (2) 2-1/16" 3M sideoutlets for emergency kill operations shall be installed. One outlet shall have a 2-1/16" 3Mgate valve with a 2-1/16" 3M blind flange. The other outlet shall have a manually operated 2-1/16" 3M flanged gate valve next to the wellhead and a hydraulic control 2-1/16" 3M flangedgate valve tied into the emergency kill line. The emergency kill line shall be an individual linewith flanged steel piping (no chiksan swings or hammer unions) and a minimum 3 3M ratedworking pressure (if SBR used) otherwise 2 3M. Coflex hose (coflon lined) may be used incombination with steel line. The emergency kill line shall extend from the wellbore to end ofthe catwalk (approximately 90 feet), with a 1502 WECO welded union (threaded connectionsare not acceptable) for connection to an emergency pump.

Note : If used on deep gas wells with 24 or 18-5/8 casing the side outlets will be 4 andkill lines will be 3 3M.

6.2.2 If the wellhead top flange is below ground level, a 3M spacer spool may be required.

6.2.3 A 3,000 psi single ram preventer shall be installed on the wellhead spool above ground levelwith master drill pipe rams.

6.2.4 A 3,000 psi flanged drilling cross shall be installed on the single ram preventer. The drillingcross shall have two (2) 3-1/16" 3M side outlets.

6.2.5 A 3,000 psi single ram preventer shall be installed on the top of the drilling cross with blindrams.

6.2.6 A 3,000 psi flanged bottom with studded top annular preventer shall complete this stack.

6.2.7 Kill Lines


a 2-1/16" 3M minimum flanged manually operated gate valve a 2-1/16" 3M minimum flanged hydraulic control gate valve a 2-1/16" 3M minimum flanged spacer spool


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a 2-1/16" 3M minimum flanged tee

On each side of the tee there shall be a 2-1/16" 3M minimum flanged gate valve and a 2-1/16" 3M minimum flanged check valve.On the remote side, the kill line shall be 3M minimum and run at least 90 feet from thewellbore to the end of the catwalk, with a flange to Weco 2" welded union.

On the primary side, the kill line shall be 3M minimum and connected directly to the mudpumps or to the stand pipe manifold.

6.2.8 Choke Lines


a 3-1/8" 3M minimum flanged manually operated gate valve a 3-1/8" 3M minimum flanged hydraulic control gate valve a 3-1/8" 3M minimum steel flanged line or flexible hose (Chapter A, Section 2.0) to a 3-

1/8" 3M minimum flanged manually operated gate valve at the choke manifold

NOTE : All steel piping shall be made with 3M minimum flanges, targeted tees, block-teeelbows, and factory-made 3M minimum working

Drilling & Work Over Manual-2014

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