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Guide for the Classification of Drilling Systems

GUIDE FOR THE

CLASSIFICATION OF DRILLING SYSTEMS

MARCH 2011

American Bureau of Shipping Incorporated by Act of Legislature of the State of New York 1862

Copyright 2011 American Bureau of Shipping ABS Plaza 16855 Northchase Drive Houston, TX 77060 USA

Foreword

ForewordThis Guide has been revised to assist the industry with Classification of Drilling Systems. This revision supersedes the 2006 ABS Guide for the Certification of Drilling Systems. This Guide becomes effective as of 1 March 2011. The Guide describes criteria to be used for drilling systems, which are to be approved by the American Bureau of Shipping (ABS), and it is built upon requirements of the recognized codes and standards, as referenced in this Guide. The Guide contains the following nine (9) main sections and five (5) appendices: Section 1 Section 2 Section 3 Section 4 Section 5 Section 6 Section 7 Section 8 Section 9 Appendix 1 Appendix 2 Appendix 3 Appendix 4 Appendix 5 Scope and Condition of Classification Design of Drilling Systems Drilling Systems Scope of Drilling System and Equipment Approval Drilling System Piping Materials for Drilling Systems and Equipment Welding and Nondestructive Examination Surveys at Vendors Plant During Installation and Commissioning Surveys After Construction and Maintenance of Class Typical Codes and Standards Related to ABS Classification of Drilling Systems Sample Manufacturers Affidavit of Compliance Sample of Independent Review Certificate Sample of Certificate of Conformity Sample of Maintenance Release Note

This Guide is to be used in conjunction with other applicable ABS Rules and Guides, codes and standard as referenced therein, and applicable national regulations. ABS Classification continues to provide the offshore industry with a pathway toward agreement by Regulatory Authorities. However, the Owner/Operators specific request for compliance with applicable requirements of Flag or Coastal State Authorities affecting the drilling systems is to be filed as an addendum to the Request for Classification. The following major changes to the Guide were incorporated into the March 2011 CDS Guide:General

The scope has been revised to ABS Guide for the Classification of Drilling Systems from ABS Guide for the Certification of Drilling Systems Scope and Condition of Classification section is modified to be in the same format and layout as ABS Rules Conditions of Classification Offshore Units and Structures (Part 1). The Scope of Section 1 was expanded to cover all applicable drilling systems, subsystems, equipment, and/or components. Definitions and Acronyms and Abbreviations sections relating to drilling system terminology were added. The Design Plans and Data have been significantly expanded in order to clearly identify the engineering submittal requirements for drilling systems, subsystems, equipment and/or components.ABS GUIDE FOR THE CLASSIFICATION OF DRILLING SYSTEMS . 2011

Section 1

Section 2

ii

Section 3

The general structure of the Guide and specifically Section 3, Drilling Systems, has been revised to address the Classification requirements starting from the wellbore migrating towards the top of the derrick. Additional requirements for autoshear, deadman, acoustic control and additional shear rams for DP units, etc. Clarified and identified the steps to ABS approval process of drilling systems, subsystems, equipment and/or components. Vendor Release Note (VRN) deleted from the Guide. ABS no longer issues any document to the Vendor without satisfactory completion of the required design review and surveys. Clarified and expanded Table 1 of Section 4 to list additional drilling system equipment and components, and further clarified ABS approval process (i.e., ABS Design Review, ABS Approval Letter, IRC, etc.) and the limited use of PDA/ABS Type Approval. Clarified the requirements for Flexible Lines/Hydraulic Hoses to consider different servcie categories. Categorized and defined the load-bearing and pressure-retaining equipment and components. Clarified the toughness requirements and values based on the equipment or component loading category. Editorial changes Clarified and expanded the requirements for surveys at manufacture and during assembly, and surveys onboard during installation, particularly by requiring proper record keeping of inspections and testing done on equipment for well control system. Maintenance Release Note (MRN) Further clarified the requirement for issuance of the MRN and its affect on maintenance of the drilling system certification. Revised and clarified Annual Survey and Special Periodical Survey requirements, particularly by requiring the surveys to be carried in accordance with an ABS reviewed and agreed inspection program called In-Service Inspection Program (ISIP), and by requiring proper record keeping of maintenance, inspections and testing done on equipment for well control system. Updated the title and contents of Appendix 1 to Typical Codes and Standards Related to ABS Classification of Drilling Systems Updated the contents to provide additional parameters for Appendix 2 Sample of Manufacturers Affidavit of Compliance The sample copy of a Vendor Release Note is deleted and replaced by the sample copy of an Independent Review Certificate (IRC).

Section 4

Section 5

Section 6

Section 7

Section 8

Section 9

Appendix 1

Appendix 2

Appendix 3

ABS GUIDE FOR THE CLASSIFICATION OF DRILLING SYSTEMS . 2011

iii

Appendix 4

The sample copy of the Maintenance Release Note is replaced by the sample copy of a Certificate of Compliance (CoC). The sample of Maintenance Release Note is moved to Appendix 5. The sample copy of the Maintenance Release Note (MRN) is provided.

Appendix 5

iv


Table of Contents

GUIDE FOR THE

CLASSIFICATION OF DRILLING SYSTEMSCONTENTSSECTION 1 Scope and Conditions of Classification............................................... 1 1 Classification.......................................................................................11.1 1.3 1.5 1.7 Process ........................................................................................... 1 Certificates and Reports .................................................................. 1 Representations as to Classification ............................................... 2 Scope of Classification .................................................................... 2 Termination of Classification and Notice of Surveys ....................... 3 Suspension of Class........................................................................ 3 Lifting of Suspension ....................................................................... 3 Cancellation of Class....................................................................... 4 ABS Class Notation ......................................................................... 4 Systems Not Built Under Survey ..................................................... 4 Applications ..................................................................................... 4 Effective Date of Change of Requirement ....................................... 5 Scope .............................................................................................. 5 Alternatives...................................................................................... 6 International and Other Regulations................................................ 8 Governmental Regulations .............................................................. 8

3

Suspension and Cancellation of Class ...............................................33.1 3.3 3.5 3.7

5

Class Notation.....................................................................................45.1 5.3

7

Rules for Classification .......................................................................47.1 7.3 7.5 7.7

9

Other Regulations ...............................................................................89.1 9.3

11 13 15

IACS Audit ..........................................................................................8 Submission of Plans ...........................................................................8 Conditions for Survey After Construction............................................915.1 15.3 Damage, Failure and Repair ........................................................... 9 Notification and Availability for Survey........................................... 10

17 19 21

Units ..................................................................................................10 Fees ..................................................................................................10 Disagreement....................................................................................1021.1 21.3 Rules and Guides.......................................................................... 10 Surveyor ........................................................................................ 10

23 25 27 29

Limitation of Liability..........................................................................11 References........................................................................................11 Definitions .........................................................................................12 Acronyms and Abbreviations ............................................................20 v


SECTION 2

Design of Drilling Systems .................................................................. 22 1 Design of Drilling System..................................................................221.1 1.3 1.5 1.7 1.9 General..........................................................................................22 Equipment Layout..........................................................................22 Overpressurization Protection .......................................................23 Materials ........................................................................................23 Welding and Nondestructive Examination .....................................23

3 5

Design Specifications........................................................................23 Design Considerations......................................................................235.1 5.3 5.5 5.7 Recognized Standards ..................................................................23 Alternative Basis of Design............................................................24 Corrosion/Erosion Allowance.........................................................24 Design Conditions..........................................................................24 General Arrangement for Drilling System ......................................26 Well Control Systems and Equipment ...........................................26 Marine Drilling Riser Systems........................................................30 Drill String Compensation Systems ...............................................31 Bulk Storage, Transfer, and Circulation Systems ..........................32 Hoisting, Lifting, Pipe Handling System .........................................33 Mechanical Load-Bearing Equipment ............................................36 Well Testing System ......................................................................37 Electrical Systems and Equipment ................................................39 Control Systems ............................................................................39 Pressure-Retaining Equipment ......................................................40 Piping Systems and Piping Components.......................................40 Flexible Lines/Hydraulic Hoses......................................................41 Manufacturing Specifications .........................................................41

7

Design Plans and Data .....................................................................257.1 7.3 7.5 7.7 7.9 7.11 7.13 7.15 7.17 7.19 7.21 7.23 7.25 7.27

SECTION 3

Drilling Systems ................................................................................... 42 1 General .............................................................................................42 3 Well Control System .........................................................................433.1 3.3 3.5 3.7 3.9 3.11 Blowout Preventer System and Equipment ...................................43 Lower Marine Riser Package (LMRP) ...........................................47 Choke and Kill Systems and Equipment........................................48 Diverter System and Equipment ....................................................52 Marine Drilling Riser Systems........................................................53 Auxiliary Well Control Equipment...................................................53 Riser Tensioning System and Equipment......................................55 Marine Drilling Riser Operating Envelope......................................55 Technical Requirements ................................................................56 Design Documentation ..................................................................57 Drill String Compensation Equipment ............................................58

5

Marine Drilling Riser System.............................................................545.1 5.3 5.5 5.7

7

Drill String Compensation System ....................................................587.1

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9

Bulk Storage, Circulation and Transfer Systems..............................589.1 9.3 9.5 9.7 Bulk Storage and Transfer Equipment .......................................... 59 Cementing System and Equipment ............................................... 59 Mud Return System and Equipment.............................................. 60 Well Circulation System and Equipment........................................ 60 Derricks/Masts............................................................................... 61 Hoisting Equipment ....................................................................... 64 Lifting Equipment........................................................................... 67 Pipe Handling Equipment .............................................................. 71 Rotary Equipment.......................................................................... 72 Miscellaneous Equipment.............................................................. 73 Well Test System and Equipment ................................................. 74 Burner/Flare Booms ...................................................................... 74 Hydrocarbon Disposal Facilities .................................................... 75 Surface Safety Systems ................................................................ 75 Classified Areas ............................................................................ 75 Operational Procedures................................................................. 76 Control Systems ............................................................................ 76 Control Systems for Well Control Equipment ................................ 77 Electrical Control Systems and Computer-Based Systems ........... 77 Safety Systems ............................................................................. 78 Pressure Vessels .......................................................................... 78 Hydraulic Cylinders ....................................................................... 79

11

Hoisting, Lifting, Rotating and Pipe Handling Systems ....................6111.1 11.3 11.5 11.7 11.9 11.11

13

Well Test System ..............................................................................7313.1 13.3 13.5 13.7 13.9 13.11

15

Control Systems................................................................................7615.1 15.3 15.5 15.7

17

Pressure-Retaining Equipment.........................................................7817.1 17.3

19 21

Electrical Systems and Equipment ...................................................79 Rotating Machinery ...........................................................................8021.1 21.3 Internal Combustion Engines ........................................................ 80 Electrical Rotating Machinery ........................................................ 80 Skid Structures .............................................................................. 80 Drip Pans....................................................................................... 81

23

Skid Mounted Equipment..................................................................8023.1 23.3

SECTION 4

Scope of Drilling System and Equipment Approval.......................... 82 1 General .............................................................................................82 3 Approval Process..............................................................................823.1 3.3 3.5 3.7 3.9 Design Review .............................................................................. 83 ABS Survey ................................................................................... 84 Issuance of Certificates and Reports............................................. 84 Individual Equipment Approval: Non-Class Installation ................. 85 Vendor Coordination Program....................................................... 85

TABLE 1

Approval Codes for Drilling Systems and Equipment .............86


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SECTION 5

Drilling System Piping ....................................................................... 102 1 General ...........................................................................................102 3 Design Criteria ................................................................................1023.1 3.3 3.5 3.7 Piping Systems and Components................................................102 Fittings and Valves ......................................................................103 Piping Connections......................................................................103 Flexible Lines/Hydraulic Hoses....................................................104 Toughness ...................................................................................106 Composite Materials ....................................................................106

5

Materials..........................................................................................1065.1 5.3

7

Welding and NDE ...........................................................................106

SECTION 6

Materials for Drilling Systems and Equipment ................................ 107 1 General ...........................................................................................107 3 Selection of Structural Steels..........................................................107 5 Selection of Drilling Equipment Materials .......................................1075.1 5.3 5.5 Material Properties.......................................................................108 Toughness ...................................................................................108 Corrosion Hydrogen Sulfide......................................................109 Welding........................................................................................109 Forming .......................................................................................109 General........................................................................................110 Rolled Products ...........................................................................110 Forgings.......................................................................................110 Castings.......................................................................................110 Elastomeric Sealants ...................................................................110 Ring Joint Gaskets.......................................................................110 Materials ......................................................................................111 Traceability ..................................................................................111

7

Fabrication Considerations .............................................................1097.1 7.3

9

Primary Product Form.....................................................................1109.1 9.3 9.5 9.7

11

Sealing Materials ............................................................................11011.1 11.3

13

Materials and Traceability ...............................................................11113.1 13.3

SECTION 7

Welding and Nondestructive Examination....................................... 112 1 General ...........................................................................................112 3 Specifications ..................................................................................1123.1 3.3 Welding Procedure Specification .................................................112 NDE Procedures..........................................................................113

5 7 9 11

Welder/Welding Operator Qualification ..........................................113 Qualification of Nondestructive Technicians...................................113 Post Weld Heat Treatment..............................................................113 Nondestructive Examination ...........................................................11311.1 11.3 Extent of Examination for Materials and Welds ...........................113 Methods and Acceptance Criteria................................................114

13 viii

Record Retention ............................................................................115ABS GUIDE FOR THE CLASSIFICATION OF DRILLING SYSTEMS . 2011

SECTION 8

Surveys at Vendors Plant During Installation and Commissioning .................................................................................. 116 1 General ...........................................................................................116 3 Surveys at Manufacture and During Assembly...............................1163.1 3.3 3.5 3.7 3.9 3.11 3.13 Testing of Well Control Equipment and BOPs ............................ 117 Testing of Marine Drilling Riser System and Associated Components ................................................................................ 117 Testing of Drill String Compensation System .............................. 118 Testing of Bulk Storage, Circulating and Transfer Systems ........ 118 Testing of Hoisting, Lifting, Rotating, and Pipe Handling Systems....................................................................................... 118 Testing of Well Test Equipment................................................... 118 Testing of Skid Structures ........................................................... 118 Testing of Base-mounted Winches and Other Lifting Appliances 121 Testing of Burner/Flare Boom ..................................................... 121

5

Onboard Surveys During Installation ..............................................1195.1 5.3

7

Commissioning Surveys of the Drilling Systems ............................121

SECTION 9

Surveys After Construction and Maintenance of Class.................. 123 1 General ...........................................................................................123 3 Surveys Onshore and Issuance of Maintenance Release Notes...............................................................................................123 5 Survey of Drilling Systems ..............................................................1245.1 5.3 5.5 5.7 5.9 5.11 Survey Intervals and Maintenance Manuals/Records ................. 124 Annual Surveys ........................................................................... 124 Special Periodical Surveys .......................................................... 125 Continuous Survey Program ....................................................... 126 Survey Based on Preventative Maintenance Techniques ........... 126 Surveys Using Risk-based Techniques ....................................... 126

7

Modifications, Damage and Repairs...............................................126

APPENDIX 1 Typical Codes and Standards Related to ABS Classification of Drilling Systems ................................................................................. 127 APPENDIX 2 Sample Manufacturers Affidavit of Compliance ............................. 131 APPENDIX 3 Sample of Independent Review Certificate (IRC) ............................ 132 APPENDIX 4 Sample of Certificate of Conformity (CoC) ...................................... 135 APPENDIX 5 Sample Maintenance Release Note (MRN)....................................... 136


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Section 1: Scope and Conditions of Classification

SECTION

1

Scope and Conditions of Classification

1

ClassificationThe requirements for conditions of Classification for entire drilling units and offshore structures are contained in the ABS Rules for Conditions of Classification Offshore Units and Structures (Part 1). Additional requirements specific to a drilling system, its subsystems, equipment or components are contained in this Guide.

1.1

Process The term Classification, as used herein, indicates that drilling systems, subsystems, equipment, and/or components have been designed, constructed, installed, and surveyed in compliance with this Guide, in conjunction with other applicable ABS Rules and Guides, codes and standards as referenced therein, and applicable national regulations. The continuance of Classification is dependent on the fulfillment of requirements for surveys after construction.The Classification process consists of: a) b) c) d) The development of Rules, Guides, standards and other criteria for the design, construction, installation and maintenance of drilling systems, subsystems, equipment, and/or components; The review of the design and survey during and after construction to verify compliance with such Rules, Guides, standards or other criteria; The assignment and registration of Class when such compliance has been verified, and; The issuance of a renewable Classification certificate, with annual endorsements, valid for five (5) years.

The Rules, Guides and standards are, in general, developed by the International Association of Classification Societies and ABS staff and passed upon by committees made up of naval architects, ocean and marine engineers, shipbuilders, engine builders, steel makers, process engineers and by other technical, operating and scientific personnel associated with the worldwide maritime industry. Theoretical research and development, established engineering disciplines, as well as satisfactory service experience are utilized in their development and promulgation. ABS and its committees can act only upon such theoretical and practical considerations in developing Rules and standards. ABS Surveyors apply normally accepted examination and testing standards to those items specified for each survey by the Rules; construction/manufacturing procedures, safety procedures and construction supervision remain the responsibility of the shipyard, the offshore unit or structures repairer, manufacturer, Owner/Operator or other client. For Classification, the drilling system, subsystems, equipment, and/or components are to comply with the requirements of this Guide, in conjunction with all other applicable ABS Rules and Guides, codes and standards as referenced therein.

1.3

Certificates and Reports Plan review and surveys during and after construction are conducted by ABS to verify to itself and its committees that a drilling system, subsystem, equipment or component is in compliance with this Guide and to the satisfaction of the attending ABS Surveyor. All reports and certificates are issued solely for the use of ABS, its committees, its clients and other authorized entities.ABS will release information from reports and certificates to the cognizant authorities (e.g., Coastal State or Flag State) to assist in rectification of deficiencies during any intervention by the authorities. Such information includes text of conditions of Classification, survey due dates and certificate expiration dates. The Owner/Operator will be advised of any request and/or release of information.


1

Section

1


ABS will release certain information to the offshore unit or structures underwriters for underwriting purposes. Such information includes text of overdue conditions of Classification, survey due dates and certificate expiration dates. The Owner/Operator will be advised of any request and/or release of information. In the case of overdue conditions of Classification, the Owner/Operator will be given the opportunity to verify the accuracy of the information prior to release. ABS may release offshore unit or structure-specific information related to the Classification and statutory certification status. This information may be published on the ABS website or by other media and may include the offshore unit or structure classification, any operating restrictions noted in the ABS Record, the names, dates and locations of all surveys performed by ABS, the expiration date of all Class and statutory certificates issued by ABS, survey due dates, the text of conditions of Classification (also known as outstanding recommendations), transfers, suspensions, withdrawals, cancellations and reinstatements of Class, and other related information as may be required.

1.5

Representations as to Classification Classification is a representation by ABS as to the structural and mechanical fitness for a particular use or service, in accordance with its Rules, Guides and standards. The Rules and Guides of the American Bureau of Shipping are not meant as a substitute for the independent engineering judgment of professional designers, naval architects, marine engineers, owners, operators, masters and crew, nor as a substitute for the quality control procedures of ship and platform builders, engine builders, steel makers, suppliers, manufacturers and sellers of marine vessels, materials, system components, machinery or equipment. ABS, being a technical society, can only act through Surveyors or others who are believed by it to be skilled and competent.ABS represents solely to the drilling system Owner/Operator or other client of ABS that when assigning Class, it will use due diligence in the development of Rules, Guides and standards, and in using normally applied testing standards, procedures and techniques as called for by the Rules, Guides, standards or other criteria of ABS for the purpose of assigning and maintaining Class. ABS further represents to the Owner/Operator or other client of ABS that its certificates and reports evidence compliance only with one or more of the Rules, Guides, standards or other criteria of ABS, in accordance with the terms of such certificate or report. Under no circumstances whatsoever are these representations to be deemed to relate to any third party. The user of this document is responsible for ensuring compliance with all applicable laws, regulations and other governmental directives and orders related to a vessel, its machinery and equipment, or their operation. Nothing contained in any Rule, Guide, standard, certificate or report issued by ABS shall be deemed to relieve any other entity of its duty or responsibility to comply with all applicable laws, including those related to the environment.

1.7

Scope of Classification Nothing contained in any certificate or report is to be deemed to relieve any designer, builder, owner, manufacturer, seller, supplier, repairer, operator, other entity or person of any warranty, express or implied. Any certificate or report evidences compliance only with one or more of the Rules, Guides, standards or other criteria of the American Bureau of Shipping, and is issued solely for the use of ABS, its committees, its clients or other authorized entities.Nothing contained in any certificate, report, plan or document review or approval is to be deemed to be in any way a representation or statement beyond those contained in 1/1.5. ABS is not an insurer or guarantor of the integrity or safety of a drilling system, subsystem, equipment or component. The validity, applicability and interpretation of any certificate, report, plan or document review or approval are governed by the Rules, Guides and standards of the American Bureau of Shipping, who shall remain the sole judge thereof. ABS is not responsible for the consequences arising from the use by other parties of the Rules, Guides, standards or other criteria of the American Bureau of Shipping, without review, plan approval and survey by ABS. The term approved is to be interpreted to mean that the plans, reports or documents have been reviewed for compliance with one or more of the Rules, Guides, standards or other criteria of ABS. This Guide is published with the understanding that responsibility for shutting down drilling operations, beyond the limit specified in the drilling system design basis, does not rest upon the Committee.

2


Section

1


33.1

Suspension and Cancellation of ClassTermination of Classification and Notice of Surveys The continuance of the Classification of the drilling system, subsystem, equipment, and/or component is conditional upon the Guide requirements for periodical, damage and other surveys being duly carried out. The Committee reserves the right to reconsider, withhold, suspend or cancel the Class of any drilling system, subsystems, equipment, and/or components for noncompliance with the Rules, for defects reported by the Surveyors which have not been rectified in accordance with their recommendations or for nonpayment of fees which are due on account of Classification. Suspension or cancellation of Class may take effect immediately or after a specified period of time.It is the responsibility of the Owner/Operator to ensure that all surveys necessary for the maintenance of Class are carried out at the proper time. ABS will give proper notice to an Owner/Operator of upcoming surveys. This may be done by means of a letter, a quarterly status report or other communication. The nonreceipt of such notice, however, does not absolve the Owner/Operator from his responsibility to comply with survey requirements for maintenance of Class.

3.3

Suspension of Class Class will be suspended and the Certificate of Classification will become invalid from the date of any use, operation or other application of any drilling system, subsystems, equipment, and/or components for which it has not been approved and which affects or may affect Classification or the structural integrity, quality or fitness for a particular use or service.Class will be suspended and the Certificate of Classification will become invalid in any of the following circumstances affecting the drilling system: i) ii) iii) If Continuous Survey items which are due or overdue at the time of Annual Survey are not completed and no extension has been granted, If the Periodical Surveys required for maintenance of Class, other than Annual or Special Periodical Surveys, are not carried out by the due date and no Rule-allowed extension has been granted, or If any damage, failure or deterioration repair has not been completed as recommended.

Class will be subject to a suspension procedure if recommendations issued by the Surveyor are not carried out and/or completed by their due dates and no extension has been granted. Class may be suspended, in which case the Certificate of Classification will become invalid, if proposed repairs, as referred to in 1/15.1, have not been submitted to ABS and agreed upon prior to commencement. Class is automatically suspended and the Certificate of Classification is invalid in any of the following circumstances: i) ii) If the Annual Survey is not completed by the date which is three (3) months after the due date, If the Special Periodical Survey is not completed by the due date, unless the drilling system is under attendance for completion prior to resuming operation. Under exceptional circumstances, consideration may be given for an extension of the Special Survey, provided the drilling system is attended and the attending Surveyor so recommends. Such an extension shall not exceed three (3) months.

3.5

Lifting of Suspension Class will be reinstated after suspension for overdue surveys upon satisfactory completion of the overdue surveys. Such surveys will be credited as of the original due date. Class will be reinstated after suspension for overdue recommendations upon satisfactory completion of the overdue recommendation. Class will be reinstated after suspension for overdue continuous survey items upon satisfactory completion of the overdue items.


3

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3.7

Cancellation of Class If the circumstances leading to suspension of Class are not corrected within the time specified, Class will be cancelled.Class is cancelled immediately when drilling systems, subsystems, equipment, and/or components are operated without having completed recommendations which were required to be dealt with before the drilling system was brought back into service. When Class has been suspended for a period of three (3) months due to overdue Annual, Special or other periodical surveys required for maintenance of Class; overdue Continuous Survey items; or overdue outstanding recommendations, the CDS Notation will be canceled. A longer suspension period may be granted for drilling systems, subsystems, equipment, and/or components which are either laid up, awaiting disposition of a casualty or under attendance for reinstatement.

55.1

Class NotationABS Class Notation Drilling systems, subsystems, equipment, and/or components that have been built, installed and commissioned to the satisfaction of the Surveyors to the full requirements of this Guide, where approved by the Committee for service for the specified design environmental conditions, will be classed and distinguished in the ABS Record by the notation CDS. Systems Not Built Under Survey The symbol (Maltese-Cross) signifies that the drilling system, subsystems, equipment, and/or components were built, installed and commissioned to the satisfaction of the Surveyors. Drilling systems, subsystems, equipment, and/or components that have not been built under ABS survey, but which are submitted for Classification, will be subjected to special consideration. Where found satisfactory and thereafter approved by the Committee, they will be classed and distinguished in the Record by the notation described above, but the symbol signifying survey during construction will be omitted.

5.3

77.1

Rules for ClassificationApplications This Guide contains provisions for the Classification of offshore drilling systems, subsystems, equipment, and/or components that are used for hydrocarbon well drilling, completion, workover, and/or well testing or supporting such activities on mobile offshore drilling units (MODUs), offshore installations, tendering vessels, and other structures that are classed by ABS. This Guide is intended for use in conjunction with the latest edition of the following or other applicable ABS Rules and Guides: ABS Rules for Building and Classing Mobile Offshore Drilling Units (MODU Rules) ABS Guide for Building and Classing Mobile Offshore Units (MOU Guide) ABS Rules for Building and Classing Offshore Installations (Offshore Installations Rules) ABS Guide for Building and Classing Floating Production Installations (FPI Guide) ABS Rules for Building and Classing Steel Vessels (Steel Vessel Rules) ABS Guide for Building and Classing Facilities on Offshore Installations (Facilities Guide)

If specifically requested by the Owner/Operator, this Guide can also be used as a basis for acceptance or certification under the requirements of other Administrations. An Owner/Operator who requires a drilling system to be evaluated for compliance with other national regulations should contact ABS. If specifically requested by the manufacturers, Owner/Operator, or designers, ABS can provide approval of individual equipment or component associated with drilling systems or subsystems in accordance with the requirements of this Guide (see 4/3.7), and where the installation unit may not be classed with ABS.ABS GUIDE FOR THE CLASSIFICATION OF DRILLING SYSTEMS . 2011

4

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7.3

Effective Date of Change of Requirement7.3.1 Effective Date This Guide and subsequent changes to this Guide are to become effective on the date specified by ABS. In general, the effective date is not less than six months from the date on which the Guide is published and released for its use. However, ABS may bring into force the Guide or individual changes before that date, if necessary or as appropriate. Implementation of Rule Changes In general, until the effective date, plan approval for designs will follow prior practice, unless review under the latest Guide is specifically requested by the party signatory to the application for Classification.

7.3.2

Where design of drillings systems, subsystems, equipment or components comply with the requirements of this Guide at the time of approval and/or construction, no retroactive application of later requirement changes to such drilling systems, subsystems, equipment or components will be required unless necessary or appropriate.

7.5

Scope This Guide covers the aspects of drilling systems, subsystems, equipment, and/or components used in connection with hydrocarbon well drilling, completion, workover, and well testing operations.Compliance with this Guide is required for the drilling systems, subsystems, equipment, and/or components mentioned in Section 3, Drilling Systems, and typical listing in Section 4, Table 1. The drilling system includes, but is not limited to, the following: Well Control System Blowout Preventer (BOP) Equipment Lower Marine Riser Package (LMRP) Choke and Kill System Diverter System Auxiliary Well Control Equipment Riser Tensioning System Riser Joints Connectors Riser Handling Tools

Marine Drilling Riser System and Associated Components

Drill String Compensation System Bulk Storage, Circulating and Transfer System Hoisting, Lifting, Rotating and Pipe Handling System Derrick, Derrick Support Structures Drawwork, Rotary Table Well Test System Burner Booms Internal Combustion Engines Driving Drilling Machine Pressure Vessels Associated with Drilling and Well Control, Tensioning, and Fluid Storage Compressors for Drilling-Related Functions


5

Section

1


High Pressure Piping, Flexible Lines, and Hydraulic Hoses Choke and Kill Mud and Cement Rotary and Vibratory Hoses

Fire Detection, Gas Detection, and Fire Protection Systems Well Control and Drilling Control Systems Emergency Shutdown Systems Electrical Systems and Equipment All Lifting Devices for Drilling and Drilling Support Operations Miscellaneous Drilling Support Systems

7.7

Alternatives7.7.1 General The Committee is ready to consider alternative arrangements and designs which can be shown, through either satisfactory service experience or a systematic analysis based on sound engineering principles, to meet the overall safety, serviceability and design standards of the Rules and Guides. National Standards i) The Committee will consider special arrangements or design of drilling systems and their equipment which can be shown to comply with standards recognized in the country provided that the proposed standards are not less effective.

7.7.2

ii)

When alternate standards are proposed, comparative analyses are to be provided to demonstrate equivalent level of safety to the recognized standards as listed in this Guide and to be performed in accordance with 1/7.7 of this Guide.

7.7.3

Novel Features Drilling systems which contain novel features of design to which the provisions of this Guide are not directly applicable may be classed, when approved by the Committee, on the basis that this Guide, insofar as applicable, has been complied with and that special consideration has been given to the novel features, based on the best information available at that time. Justifications of the novel features can be accomplished by applying 1/7.7 of this Guide. Risk Evaluations for Alternative Arrangements and Novel Features i) Risk evaluations for the justification of alternative arrangements or novel features may be applicable either to the drilling system as a whole, or to individual systems, subsystems, equipment or components.

7.7.4

ii)

ABS will consider the application of risk evaluations for alternative arrangements and novel features in the design of the drilling system, subsystems, equipment or components, verification surveys during construction, and surveys for maintenance of Class. When applied, risk assessment techniques are to demonstrate that alternatives arrangements and/or novel features provide acceptable levels of safety in line with current offshore and marine industry practice. The ABS Guidance Notes on Review and Approval of Novel Concepts, ABS Guidance Notes on Risk Assessment Applications for the Marine and Offshore Oil and Gas Industries, and ABS Guide for Risk Evaluations for the Classification of Marine-Related Facilities provides guidance to ABS clients on how to prepare a risk evaluation to demonstrate equivalency or acceptability for a proposed drilling system design.

iii)

iv)

6


Section

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v)

Portions of the drilling system or any of its subsystems, equipment or components not explicitly included in the risk evaluation submitted to ABS are to comply with any applicable part of the ABS Rules and Guides. If any proposed alternative arrangement or novel feature affects any applicable requirements of Flag and Coastal State, it is the responsibility of the Owner/Operator to discuss with the applicable authorities the acceptance of alternatives based on risk evaluations. Risk assessment techniques may be used to demonstrate that alternatives and novel features provide acceptable levels of safety in line with current offshore and marine industry practice. When this optional risk assessment is applied at the specific request of the designer or manufacturer, all hazards that may affect the drilling system or any of its subsystems, equipment or components are to be identified. A systematic process is to be applied to identify situations where a combination or sequence of events could lead to undesirable consequences (property damage, personnel safety and environmental damage), with consideration given to all foreseeable causes. The objective of the hazard identification is to identify areas of the design that may require the implementation of further risk control options in order to reduce the risk to an acceptable level. The hazard identifications are to consider, as a minimum, the following events: Release of H2S, CO2, etc. Hydrocarbon Release (Liquid or Gas) Blowout Fire and Explosion Loss of Purge Air Structural Failure Mechanical Failure Electrical Failure Loss/Failure of Mooring Loss/Failure of Station Keeping Loss of Stability Impact to Equipment Dropped Objects Collision Helicopter Crash Extreme Environment

vi)

7.7.4(a) Risk Assessment. i) ii)

iii)

iv)

v)

vi) vii)

The identified risk control options (prevention and mitigation measures) deemed necessary to be implemented are to be considered part of the design basis of the drilling system. Appendix 4 in the ABS Guide for Risk Evaluations for the Classification of Marine-Related Facilities contains a description of the most common hazard identification techniques. Also, Appendix 2 in the same Guide provides an overview of how to assemble an appropriate risk assessment team. When the risk assessment technique is considered, ABS participation in the hazard identification meeting(s) is recommended. Tangible benefits can be derived by the participation of an ABS representative who will later be directly involved in reviewing the designs for ABS Classification.

viii)


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99.1

Other RegulationsInternational and Other Regulations i) While this Guide covers the requirements for the Classification of drilling systems, subsystems, equipment, and/or components, the attention of Owner/Operator, designers and builders is directed to the regulations of international, governmental and other authorities dealing with those requirements in addition to or over and above the Classification requirements.ii) Where authorized by the Administration of a country signatory thereto and upon request of the Owner/Operator of a classed drilling system or one intended to be classed, ABS will survey for compliance with the provision of International and Governmental Conventions and Codes, as applicable.

9.3

Governmental Regulations Where authorized by a government agency and upon request of the Owner/Operator of a new or existing drilling system, ABS will survey and certify a classed drilling system or one intended to be classed for compliance with particular regulations of that government on their behalf.

11

IACS AuditThe International Association of Classification Societies (IACS) conducts audits of processes followed by all of its member societies to assess the degree of compliance with the IACS Quality System Certification Scheme requirements. For this purpose, auditors for IACS may accompany ABS personnel at any stage of the Classification or statutory work, which may necessitate the auditors having access to the drilling system, subsystems, equipment, and/or components or access to the premises of the builder or manufacturer. In such instances, prior authorization for the auditors access will be sought by the local ABS office.

13

Submission of PlansTypical documentation that is required to be submitted for drilling system, subsystems, equipment, and/or components for the ABS Classification process is provided in Subsection 2/7 of this Guide. i) Section 4 provides the ABS approval process for drilling systems, subsystem, equipment, and/or components. Subsequently, Section 4, Table 1 identifies the typical drilling system, subsystems, equipment, and/or components that are part of the ABS Classification process. Drilling system, subsystem, equipment and/or component-related drawings, calculations and documentation are required to be submitted to ABS by entities as listed in Subsection 2/7 of this Guide to substantiate that the design of the systems, subsystems, equipment and/or components are in compliance with this Guide, and applicable codes or standards, as listed in this Guide. Upon satisfactory completion of ABS review of design plans and data, ABS Engineers will issue an ABS approval letter and an Independent Review Certificate (IRC), as specified in Section 4, Table 1 of this Guide. This letter or certificate, in conjunction with ABS approved documentation, will be used and referenced during surveys. Subsequently, the ABS Surveyor will issue appropriate survey reports. Upon satisfactory completion of all of the required engineering design review and survey processes (inspection, testing, installation and commissioning), ABS will issue the Classification Certificate to the operating unit, including the Class notation CDS (abbreviation for Classed Drilling System).

ii)

iii)

iv)

8


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1515.1

Conditions for Survey After ConstructionDamage, Failure and Repair15.1.1 Examination and Repair i) Damage, failure, deterioration or repair to the drilling system, subsystems, equipment, and/or components which affects Classification is to be submitted by the Owner/Operator or their representatives for examination by the Surveyor at the first opportunity.

ii)

All repairs found necessary by the Surveyor are to be carried out to the Surveyors satisfaction.

15.1.2 Repairs i) Where repairs to the drilling system, subsystems, equipment, and/or components which may affect Classification are planned in advance to be carried out, a complete repair procedure including the extent of the proposed repair and the need for Surveyors attendance is to be submitted to and agreed upon by the Surveyor reasonably in advance.

ii)

Failure to notify ABS in advance of the repairs may result in suspension of the drilling systems Classification until such time as the repair is redone or evidence is submitted to satisfy the Surveyor that the repair was properly carried out.

15.1.3 Representation Nothing contained in this section or in a Rule or regulation of any government or other administration, or the issuance of any report or certificate pursuant to this section or such a Rule or regulation, is to be deemed to enlarge upon the representations expressed in 1/1.1 through 1/1.7 hereof, and the issuance and use of any such reports or certificates are to be governed in all respects by 1/1.1 through 1/1.7 hereof. 15.1.4 Temporary Installation, Maintenance, Modification, Repair or Replacements 15.1.4(a) Temporary Installation

i) ii) iii)

ABS is to be notified of the Owner/Operators intention to install temporary equipment that can affect the safety or intended functioning of the classed drilling system. The installation of temporary equipment is to be no less effective than permanent drilling system equipment. ABS reserves the right to approve such equipment and is to be advised of temporary installations. When the subsystems, equipment, and/or components of the drilling system are subject to annual maintenance or inspections due to repairs by qualified personnel on the drilling unit or by an authorized company/manufacturer offshore or onshore, ABS is to be notified for survey of the subsystems, equipment, and/or components preferably before it is placed into service (see Subsection 9/3). These surveys will be carried out in accordance with API requirements or other recognized codes/standards referenced in this Guide and is to be considered part of ABSs Annual Survey for Drilling Systems.

15.1.4(b) Maintenance i)

ii)

15.1.4(c) Modification. Where a major modification or replacement is made to subsystems, equipment, and/or components that are part of a classed drilling system, ABS is to be notified and the applicable requirements of this Guide are to be met. 15.1.4(d) Repair or Replacement. When any subsystems, equipment, and/or component of the drilling system is replaced, modified, repaired or undergone maintenance which may affect Classification, relevant documents are to be included in a drilling system log for Surveyors verification during periodical surveys.ABS GUIDE FOR THE CLASSIFICATION OF DRILLING SYSTEMS . 2011

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15.3

Notification and Availability for Survey The Surveyors are to have access to classed drilling systems, subsystems, equipment, and/or components at all reasonable times.i) For the purpose of Surveyor monitoring, the attending Surveyors are also to have access to classed drilling systems, subsystems, equipment, and/or components at all reasonable times. Such access may include attendance at the same time as the assigned Surveyor or during a subsequent visit without the assigned Surveyor. The Owner/Operator or their representatives are to notify the Surveyors for inspection on occasions when the units on which the drilling systems are installed are in dry dock or on a slipway. The Surveyors are to undertake all surveys on classed drilling systems, subsystems, equipment, and/or components upon request, with adequate notification, of the Owner/Operator or their representatives, and are to report thereon to the Committee. Should the Surveyors find occasion during any survey to recommend repairs or further examination, notification is to be given immediately to the Owner/Operator or their representatives so that appropriate action may be taken. The Surveyors are to avail themselves of every convenient opportunity for carrying out periodical surveys in conjunction with surveys of damages and repairs in order to avoid duplication of work.

ii) iii)

iv)

v)

17

UnitsThis Guide is written in three systems of units, viz., SI units, MKS units and US customary units. Each system is to be used independently of any other system. Unless indicated otherwise, the format of presentation of the three systems of units in this Guide is as follows: SI units (MKS units, US customary units)

19

FeesFees in accordance with normal ABS practice will be charged for all services rendered by ABS. Expenses incurred by ABS in connection with these services will be charged in addition to the fees. Fees and expenses will be billed to the party requesting that particular service.

2121.1

DisagreementRules and Guides Any disagreement regarding either the proper interpretation of Rules and Guides or the translation of Rules and Guides from the English language edition is to be referred to ABS for resolution. Surveyor In case of disagreement between the Owner/Operator or builders and the Surveyors regarding the material, workmanship, extent of repairs or application of the Rules and Guides relating to any system classed or proposed to be classed by ABS, an appeal may be made in writing to the Committee, who will order a special survey to be held. Should the opinion of the Surveyor be confirmed, expense of this special survey is to be paid by the party appealing.

21.3

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23

Limitation of LiabilityThe combined liability of the American Bureau of Shipping, its committees, officers, employees, agents or subcontractors for any loss, claim or damage arising from its negligent performance or nonperformance of any of its services or from breach of any implied or express warranty of workmanlike performance in connection with those services, or from any other reason, to any person, corporation, partnership, business entity, sovereign, country or nation, will be limited to the greater of a) $100,000 or b) an amount equal to ten times the sum actually paid for the services alleged to be deficient. The limitation of liability may be increased, up to an amount twenty-five times the sum paid for services, upon receipt of Clients written request at or before the time of performance of services, and upon payment by Client of an additional fee of $10.00 for every $1,000.00 increase in the limitation.

25

ReferencesIn addition to the ABS Rules, and Guides as listed in 1/7.1, the additional requirements of the following Guides, codes or standards are referenced in this Guide: ABS Guidance Notes on Review and Approval of Novel Concepts (Novel Concepts Guide) ABS Guide for Risk Evaluations for the Classification of Marine-Related Facilities ABS Guidance Notes on Risk Assessment Applications for the Marine and Offshore Oil and Gas Industries ABS Guide for Well Test Systems ABS Guide for Certification of Lifting Appliances ABS Guide for Surveys Using Risk-Based Inspections for the Offshore Industry(RBI Guide) ABS Guide for Surveys Based on Reliability-Centered Maintenance (RCM Guide) AGMA American Gear Manufacturers Association AISC American Institute of Steel Construction ANSI American National Standards Institute API American Petroleum Institute ASME American Society of Mechanical Engineers ASNT American Society for Nondestructive Testing ASTM American Society for Testing and Materials AWS American Welding Society IEC International Electrotechnical Commission IEEE Institute of Electrical and Electronic Engineers IACS International Association of Classification Societies ISO International Organization for Standardization NACE National Association of Corrosion Engineers NEMA National Electrical Manufacturers Association NFPA National Fire Protection Association NFPA National Fluids Power Association SAE Society of Automotive Engineers SPE Society of Petroleum Engineers UL Underwriters Laboratory

ABS is prepared to consider other recognized codes, standards, alternative design methodology and industry practice, on a case-by-case basis, with justifications as indicated in 1/7.7 of this Guide.ABS GUIDE FOR THE CLASSIFICATION OF DRILLING SYSTEMS . 2011

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27

DefinitionsThe following definitions are provided to clarify the use of certain terms in the context of this Guide: Accumulator: A pressure vessel charged with high pressure air or nitrogen gas and used to store hydraulic fluid under pressure for operation of blowout preventers. Acoustic Control Systems: Acoustic signal transmission may be used as an emergency backup means for controlling critical BOP stack functions, such as pipe ram preventers, shear ram preventer and marine drilling riser connector including LMRP. The acoustic control system includes a surface electronics package, acoustic pod transponder, subsea electronic package and a subsea electro-hydraulic package. Acoustic Pod Transponder: Device which receives acoustic signals from the surface and provides command signals to the subsea BOP control system. Actuator: A mechanism for the remote or automatic operation of a valve or choke. Annular Blowout Preventer: A device typically installed above the ram preventers used to control wellhead pressure. A reinforced rubber packing element is compressed by hydraulic pressure to actuate the device to seal. A standard annular BOP will shut off annular pressure, open-hole pressure and afford stripping of tubing/drill pipe while containing well pressure. Autoshear System: A safety system that is designed to automatically shut-in the wellbore in the event of a disconnect of the LMRP. When the autoshear is armed, disconnect of the LMRP closes the shear rams on BOP stack. Auxiliary Line: A conduit (excluding choke and kill lines) attached to the outside of the drilling riser main tube (e.g., hydraulic supply line, buoyancy control line, mud boost line). Backpressure (Casing Pressure, Choke Pressure): The pressure existing at the surface on the casing side of the drill string/annulus flow system. Backup: An element or system that is intended to be used only in the event that the primary element or system is nonfunctional. Blind Rams: See Rams Blind-shear Rams: See Rams Blowout: An uncontrolled flow of well fluids/gas and/or formation fluids/gas from the wellbore to the surface or into lower pressured subsurface zones (underground blowout). Blowout Preventer (BOP): The equipment installed at the wellhead to prevent the escape of fluids under pressure either in the annular space between the casing and drill pipe or in an open hole during drilling and completion operations. Blowout Preventer (BOP) Handling Crane: Gantry-type crane used to move BOP from storage location to BOP transporter/skidder location. Blowout Preventer (BOP) Operating and Control System: System of pumps, valves, accumulators, fluid storage and mixing equipment, manifold, piping, hoses, control panels and other items necessary to hydraulically operate the BOP equipment. Blowout Preventer (BOP) Assembly: The complete assembly of BOP stack, frame, accumulators, pods, valves, piping, connectors, jumpers, control systems, ROV interface panels, control piping, etc. Blowout Preventer (BOP) Stack: The complete assembly of well control equipment including preventers, spools, valves, and nipples connected to the top of the casinghead. Blowout Preventer (BOP) Stack Frame: Steel frame to which the lower stack is mounted for handling and mating with LMRP. Also serves as a support structure to mount various subsea equipment, such as subsea accumulators and control pods. Blowout Preventer (BOP) Transporter/Skidder: C-frame or fork-lift type trolley used to position the BOP for deployment on the riser. May include integrated test stump.

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Buffer Tank: A targeted, horizontal or vertical, cylindrical tank that changes the direction of fluid flow downstream of the choke and serves as a flow director to the flare line, gas buster or mud-gas separator. Bulk Storage: Tanks that are designed for storage of bulk materials for drilling fluid and cement mixing (barite, bentonite, cement, etc.). Buoyancy Equipment: Devices added to riser joints to reduce their apparent weight, thereby reducing riser top tension requirements. Burner Boom: Boom which extends over the deck edge to flare hydrocarbon from kick circulation or well test operations. Casinghead/Spool: The part of the wellhead to which the BOP stack is connected. Casing Stabbing Board: Folding platform located in the derrick which positions the stabbing hand (pipe stabber) while running casing. Similar to monkey board, but at a lower height. Catastrophic Release: Major hydrocarbon release that results from uncontrolled developments and that may lead to serious danger to personnel, asset, and environment. Catwalk Ramp (Riser Skate): Combination conveyer and lifting riser transport system used to move riser sections, drill pipes, casing or tool joints from deck storage to the drill floor. Cementing Manifold: Used to direct high pressure cement through the cement standpipe. Cement Pump: High pressure positive-displacement-type pump used for cementing operations, often connected to the kill line for emergency kill operations, usually smaller capacity than mud pump. Choke: A device with either a fixed or variable orifice used to control the rate of flow of liquids and/or gas. Chokes are also used to control the rate of the flow of drilling mud out of the hole when the well is closed in with the blowout preventer and a kick is being circulated out of the hole. Choke Line: The high-pressure piping (flexible lines, rigid piping, valves, connectors, fittings, etc.) between the mud pumps and BOP outlets or wellhead outlets. Choke Line Valve: The valve(s) connected to and a part of the BOP stack that allows fluids flow to the choke manifold. Choke Manifold: An assembly of valves, chokes, gauges, and piping components through which drilling fluid is circulated when the blowout preventer is closed to control the pressure encountered during a kick. Clamp Connection: A pressure sealing device used to join two items without using conventional bolted flange joints. The two items to be sealed are prepared with clamp hubs. These hubs are held together by a clamp containing minimum of four bolts. Classified Area: A location in which flammable gases or vapors are or may be present in the air in quantities sufficient to produce explosive or ignitable mixtures (see the MODU Rules, API RP 500 or API RP 505 for additional details). Closing Unit: The assembly of pumps, valves, lines, accumulators, and other items necessary to open and close the BOP equipment. Computer-Based Systems: Programmable Logic Solvers (PLC), Distributed Control Systems (DCS), PC or server-based computation systems and any E/E/PES. In most situations, hydraulic and/or pneumatic medium is controlled by the computer-based control system. Control Panel/Console: Main operator interface for various installation systems (may be hydraulic, electric, electronic, mechanical, pneumatic, or any combination thereof). Control Manifold: An assembly of valves and piping to control the flow of hydraulic fluid to operate the various components of systems, equipment or components. Control Panel, Remote: A panel containing a series of controls that will operate the valves on the control manifold from a remote point. Control Pod: An assembly of subsea valves and regulators that when activated from the surface will direct hydraulic fluid through special apertures to operate the BOP equipment.ABS GUIDE FOR THE CLASSIFICATION OF DRILLING SYSTEMS . 2011

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Control Stations: Spaces containing the following, as applicable: Radio or main navigation equipment Central process control rooms Dynamically positioning control system Centralized ballast control station Battery room Fire control equipment and fire recording Fire extinguishing system serving various locations Emergency source of power CO2 bottle room Fire pumps

Crown: Upper sections of the derrick Crown Block: Assembly of sheaves mounted at the derrick top (crown) through which the drilling line is reaved. Deadman System: A safety system that is designed to automatically close the wellbore in the event of a simultaneous absence of hydraulic supply and signal (control and communication) transmission capacity in both subsea control pods. Degasser: Device used to remove entrained gas from a drilling fluid in normal well circulation. Desander: Centrifugal device for removing sand from drilling fluid. Desilter: Centrifugal device used for removing silt from drilling fluid. Deadline Anchor: Device to securely fasten one end of drill line to the drill floor or derrick structure. Derrick (Mast): Main load-bearing structure in drilling unit used as support structure for the drill string, and top drive assembly. Design Approved Products (PDA): See 1-1-A2/5.1.3 of the ABS Rules for Conditions of Classification Offshore Units and Structures (Part 1). Design Pressure: The pressure used in the design of pressure-retaining equipment or piping systems for the purpose of determining the minimum permissible thickness or physical characteristics of the different parts of the pressure-retaining equipment or piping systems. When applicable, static head and other external loads (e.g., bending, torsional, tension, compression, temperature gradient, etc.) are to be added to the design pressure to determine the thickness of any specific part of the pressure-retaining equipment or piping systems. Diverter: A device attached to the wellhead or marine drilling riser to close the vertical access in order to prevent upward flow of well fluids and direct flow into a line away from the rig floor. Diverter Control System: The assemblage of pumps, accumulator bottles, manifolds, control panel, valves, lines, etc., used to operate the diverter system. Diverter System: The assemblage of an annular sealing device, flow control means, vent system components, and control system that facilitates closure of the upward flow path of well fluids and opening of the vent to atmosphere. Diverter Vent Line/Diverter Piping: The conduit which directs the flow of gas and wellbore fluids away from the drill floor to the atmosphere. Drape Hoses (Moonpool Line): A flexible line connecting a choke, kill, and auxiliary line terminal fitting on the telescopic joint to the appropriate piping on the rig structure. A U-shaped bend in this line allows for relative movement between the vessel and the outer barrel of the telescopic joint as the vessel moves. Drawworks: Large winch located on the drill floor used to raise and lower the drill string, top drive assembly by taking in or paying out the drilling line through the crown block and traveling block. Drill Floor Substructure: The foundation structure(s) on which the derrick, rotary table, drawworks, and other drilling equipment are supported. Drill Pipe Safety Valve: A full-opening valve located on the rig floor with threads to match the drill pipe connections in use. This valve is used to close off the drill pipe to prevent flow from the well.14ABS GUIDE FOR THE CLASSIFICATION OF DRILLING SYSTEMS . 2011

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Drilling Spool: A fitting placed in the blowout preventer stack with internal diameters at least equal to the bore of the BOP to provide space between preventers with smaller side outlets for facilitating stripping and other operations, to permit attachment of choke and kill lines, and for localizing possible erosion by fluid flow to the spool. Dump Tank: Calibrated tank used to measure the volume of a liquid, may be drilling mud or reservoir fluids. Electrical Control System: Control systems that are based on relays and analog discrete components without a central processor unit. Manual switches, relays and potentiometers are used for control of the equipment. In most situations, hydraulic and/or pneumatic medium is controlled by the electrical control system. Elevator, Drilling: Hinged clamp-type device used to grasp drill pipe or casing for lifting by the drilling hook, may be either manually or hydraulically/pneumatically operated. Elevator, Personnel: Lifting device used for rig personnel, may be on or off the drill floor. Equipment: Mechanical and structural components of the drilling systems. Escape Routes: Designated path used by personnel to evade an immediate danger and ultimately leads to a temporary refuge or muster station. Finger Board: A rack located in the derrick that supports the top of the stands of pipe stacked in the derrick. Fill-up Valve: A special riser joint having a valve means to allow the riser annulus to be opened to the sea. To prevent riser pipe collapse, an automatic actuator controlled by a differential-pressure sensor may open the valve. Flammable Fluid: Any fluid, regardless of its flash point, capable of feeding a fire. Examples are diesel fuel, hydraulic oil (oil-based), lubricating oil, crude oil, or hydrocarbons. Flash Point: The minimum temperature at which a combustible liquid gives off vapor in sufficient concentration to form an ignitable mixture with air near the surface of the liquid or within the vessel used, as determined by the test procedure and apparatus specified in NFPA 30. Flex Joint: A steel and elastomer assembly having central through-passage equal to or greater in diameter than the riser bore that may be positioned in the riser string to reduce local bending stresses. Flexible Lines/Hydraulic Hoses: Conduits that can accommodate the relative motion, and/or vibration encountered on drilling facility and use to transfer fluids (mud, cement, hydraulic fluids, etc.). Typical uses for flexible lines and/or hydraulic hoses within the drilling facility are: Rotary and vibratory hoses Cementing hoses Choke and kill flexible lines, and auxiliary lines (drapes and jumpers) Hydraulic hoses for control functions and operations

Floating Installation: An offshore facility designed to provide hydrocarbon processing and/or hydrocarbon storage, and offload hydrocarbons. The term is used to generically identify a buoyant facility that is sitespecific. The installation is securely and substantially moored so that it cannot be moved without a special effort. Gimbal: Shock absorbing support for the riser spider which allows some angular movement of the spider and riser relative to the rig support structure. Gooseneck: Curved connection between the rotary hose and the swivel or top drive. Hazardous Area: See Classified Areas. Heave: Vessel motion in the vertical direction due to marine environment. Hook, Drilling: Hook-shaped lifting device attached to the traveling block from which the swivel (or top drive) is suspended. Hydraulic Cylinder: Mechanical device used to convert hydraulic fluid pressure to linear action.ABS GUIDE FOR THE CLASSIFICATION OF DRILLING SYSTEMS . 2011

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Hydraulic Hoses: Conduits that can accommodate the relative motion, and/or vibration encountered on a drilling facility and used to transfer fluid for hydraulic system functions. Hydraulic Power Unit (HPU): Skid-mounted systems used to provide hydraulic power, usually comprised of a hydraulic fluid reservoir, filters, hydraulic pump, motor and control. Hydrogen Sulfide (H2S): A highly toxic, flammable, corrosive gas sometimes encountered in hydrocarbonbearing formations. Hydrogen Sulfide Service: Refers to equipment designed to resist corrosion and hydrogen embrittlement caused by exposure to hydrogen sulfide. Ignitable Mixture: A mixture that is within the flammable range (between the upper and lower limits) and is therefore capable of propagation of flame away from the source of ignition. Inside Blowout Preventer (IBOP): Backpressure or check valve installed in drill string to prevent a blowout inside the drill string. Flow is possible only downward, allowing mud to be pumped in but preventing any flow back up the drill string. Iron Roughneck: Tool with automated combination of spinning and torqueing for make-up or break-down of drill string pipes during drilling operation. Jumper Line: A flexible section of choke, kill, or auxiliary line that provides a continuous flow around a flex/ball joint while accommodating the angular motion at the flex/ball joint. Kelly: The uppermost component of the drill string; the kelly is an extra-heavy joint of pipe with flat or fluted sides that is free to move vertically through a kelly bushing in the rotary table; the kelly bushing imparts torque to the kelly and thereby the drill string is rotated. Kelly Bushing: Device which imparts torque to the kelly from the master bushing and permits vertical movement of the kelly. Kelly Cock: A valve immediately above the kelly that can be closed to confine pressures inside the drill string. Kelly Spinner: Pneumatically-operated device mounted to the top of the kelly used to spin up the kelly for making connections on a rotary table-type rig. Kelly Valve, Lower: An essentially full-opening valve installed immediately below the kelly, with outside diameter equal to the tool joint outside diameter. Kick: Unscheduled, unwanted entry of water, gas, oil or other formation fluid into wellbore. It occurs because pressure exerted by column of drilling fluid is not great enough to overcome the pressure exerted by the fluids in the formation drilled. If prompt action is not taken to control the kick or kill the well, a blowout will occur. Kill: In drilling/well servicing, to prevent a threatened blowout by taking suitable preventative measures (e.g., to shut in well with blowout preventer, circulate kick out, and increase weight of drilling/completion/ workover fluid). Kill Line: The high-pressure piping (flexible lines, rigid piping, valves, connectors, fittings, etc.) between the pumps (cement or mud pumps) and BOP outlets or wellhead outlets. Kill Unit: Control panel for choke manifold. Links, Drilling (Bell Nipple): Strong rods which connect the drilling elevators to the hook and allow movement for the elevator to be pushed out of the way when not in use. Lower Explosive Limit (L.E.L.): The lowest concentration of combustible vapors or gases, by volume in mixture with air, which can be ignited at ambient conditions. Lower Marine Riser Package (LMRP): Part of the blowout preventer stack assembly; usually contains LMRP connector, one or more annular-type preventers, lower flex joint, riser adapter, and MUX control pods. Lower Marine Riser Package (LMRP) Connector: Hydraulic connector used to securely latch the LMRP to the BOP stack.

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Lower Marine Riser Package (LMRP) Frame: Structural frame which is used for handling of the LMRP and integration with the BOP stack. It also serves as a support structure to mount various subsea equipment such as subsea accumulators and control pods. Machinery Spaces (other than Category A): All spaces containing machinery, boilers, and other fired processes, oil fuel units, steam and internal combustion engines, generators, and major electrical machinery, oil filling stations, refrigerating, stabilizing, ventilation, and air-conditioning machinery and similar spaces. Machinery Spaces of Category A: All spaces which contain internal combustion-type machinery used either: For main propulsion; or For other purposes where such machinery has in the aggregate a total power of not less than 375 kW; or Which contain any oil-fired boiler or oil fuel unit; and trunks to such spaces.

Manifold: An accessory system of piping to a main piping system (or another conductor) that serves to divide a flow into several parts, to combine several flows into one, or to reroute a flow to any one of several possible destinations. Manriding Winch: Winch used solely for personnel lifting operations. Marine Drilling Riser System: The extension of the well bore from the subsea BOP stack to the floating drilling vessel which provides for fluid returns to the drilling vessel, supports the choke, kill, and control lines, booster lines, auxiliary lines, guides tools into the well, and serves as a running string for the BOP stack. Master Bushing: Device which imparts torque from the rotary table to the kelly bushing and accepts the slips. Maximum Allowable Working (Operating) Pressure (MAWP) or Rated Working Pressure (RWP): The maximum internal pressure equipment or system is designed to operate or work and to contain and/or control the pressure. Minimum Design Temperature (MDT): The lowest predictable metal temperature occurring during normal operation including start-up, shut-down and ambient situation is to be used. Mud Agitator: Motor-driven paddle or blade to mix, or maintain mixture of, drilling mud in the mud pits. Mud Boost Line: An auxiliary line which provides supplementary fluid supply from the surface and injects it into the riser at the LMRP to assist in the circulation of drill cuttings up the marine drilling riser, when required. Mud-Gas Separator: A vessel for removing free gas from the drilling fluid returns, generally used when circulating a gas kick out of the well. Mud Pump: Large high-pressure pump used to circulate drilling fluid, usually positive-displacement type. Multiplex (MUX) Control System: A system utilizing electrical or optical conductors in an armored subsea umbilical cable such that, on each conductor, multiple distinct functions are independently operated by dedicated serialized coded commands. Nonhazardous Areas (Unclassified Locations): Locations determined to be neither hazardous areas nor classified areas (see Classified Area for definition). Operating Conditions: A set of conditions (e.g., pressure, temperature, flow rates, composition, loads, etc.) chosen for normal operation of a facility, system, or equipment. Personnel Basket: Device in which personnel ride in during lifting operations in personnel cranes, elevators, and man-riding winches. Pipe Rams: See Rams. Power Slips: Automated slips controlled by the driller, usually hydraulically or pneumatically operated. Power Tongs: Automated tongs used to torque drill pipe to final torque or to breakout pipe connections. Process Area: Area where processing equipment is located to handle hydrocarbon. This includes wellhead/manifold areas, well testing equipment. Pulsation Dampeners: Chambered device used to dampen pressure pulsations in a fluid flow.ABS GUIDE FOR THE CLASSIFICATION OF DRILLING SYSTEMS . 2011

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Pup Joint: A shorter-than-standard-length riser joint, tool joint, or drill pipe. Rams: Mechanical device use for closing, shearing and sealing component of a blowout preventer. One of three types blind, shear, or pipe may be installed in several preventers mounted in a stack on top of wellbore. Blind rams: Blind ram ends are not intended to seal against any drill pipe or casing. The rams seal against each other to effectively close the hole. Shear rams: Shear rams (non-sealing): Shear rams have a built-in cutting edge that will shear tubular that may be in the hole. Blind-shear rams: Blind rams with a built-in cutting edge that will shear against any drill pipe or casing. They seal against each other to effectively close the hole. Super shear ram: Shear rams that are capable to shear drill collars and large diameter casing. These rams are also capable of shearing heavy wall drill pipe and tool joints. The super shear rams are non-sealing rams.

Pipe ram is a sealing component with an indentation and packing for drill pipe, drill collars or casing that closes the annular space between the pipe and the blowout preventer or wellhead. Separate rams are necessary for each size (outside diameter) pipe in use. Pipe rams can include: Fixed bore pipe ram: Closing and sealing component in a ram blowout preventer that is capable of sealing only specified tubular size Variable bore pipe ram: Closing and sealing component in a ram blowout preventer that is capable of sealing on a range of tubular sizes

Rated Setback Load: The maximum weight of tubular goods which can be supported by the substructure in the setback area. Rated Working Pressure (RWP) or Maximum Allowable Working (Operating) Pressure (MAWP): The maximum internal pressure equipment or system is designed to operate or work and to contain and/or control the pressure. Remotely Operated Vehicle (ROV): An unmanned vehicle for offshore subsea use. Reels (MUX, Hotline): Large spool and winch system used to store, deploy and retrieve flexible lines. Riser Adapter: Crossover between riser and flex/ball joint. Riser Joint: A section of riser main tube having flanged connector (or equivalent ) ends fitted with a box and pin and including choke, kill and (optional) auxiliary lines, booster lines, and their support brackets. Riser Running/Handling Tool: A device that joins to the upper end of a riser joint to permit the lifting and lowering of the joint and the assembled riser string in the derrick by the elevators. Riser Spider Fixed: A device having retractable jaws or dogs used to support the riser string on the uppermost coupling support shoulder during deployment and retrieval of the riser. Riser Spider Elevator: Riser spider that is capable of being used as elevators. Riser Tensioners: Systems for providing and maintaining top tension on the deployed riser string to prevent buckling. Riser Tensioner Ring: The structural interface of the telescopic joint outer barrel and the riser tensioners. The tensioner ring may be an integral part of the telescopic joint. Rotary Hose (also known as Kelly Hose): Flexible hose which conducts high-pressure drilling fluids from the standpipe to the gooseneck/swivel and kelly or top drive. Rotary Swivel: A device hanging on the traveling hook that allows the drill string to rotate while hanging and provide path for fluids flow.

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Rotary Table: A device through which passes the bit and drill string and that transmits rotational action to the kelly. Rupture (or Bursting) Disc: A device designed to rupture or burst and relieve pressure at a defined pressure and rate. The device will not close after being activated. Safe Working Load (SWL): The maximum rated load within the lifting appliance rated capacity for the given operating conditions. Safety Factor: The relationship between maximum allowable stress level and a defined material property, normally specified minimum yield strength. Safety Shutdown: A safety system action that will be initiated upon signal or failure a

Dicionário de O&G

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