Specification for Control Systems for Drilling Well Control Equipment and Control Systems for Diverter Equipment

API SPECIFICATION 16D (SPEC 16D) SECOND EDITION, JULY 2004 EFFECTIVE DATE, JANUARY 2005

Specification for Control Systems for Drilling Well Control Equipment and Control Systems for Diverter Equipment

Upstream Segment

API SPECIFICATION 16D (SPEC 16D) SECOND EDITION, JULY 2004 EFFECTIVE DATE, JANUARY 2005

SPECIAL NOTES

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This document was produced under API standardization procedures that ensure appropriate notification and participation in the developmental process and is designated as an API stan- dard. Questions concerning the interpretation of the content of this standard or comments and questions concerning the procedures under which this standard was developed should be directed in writing to the Director of the Standards department, American Petroleum Institute, 1220 L Street, N.W., Washington, D.C. 20005. Requests for permission to reproduce or trans- late all or any part of the material published herein should be addressed to the Director, Busi- ness Services.

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Copyright © 2004 American Petroleum Institute

FOREWORD

This specification is under the jurisdiction of the API Subcommittee on Standardization of Drilling Well Control Systems. It represents a composite of industry-accepted practices and standard specifications employed by various equipment-manufacturing companies. The goal of this specification is to assist the oil and gas industry in promoting personnel safety, public safety, integrity of the drilling rig and associated equipment, and preservation of the environ- ment for land and marine drilling operations. In some instances, reconciled composites of these practices are included in this publication. Suggested revisions are invited and should be submitted to the API, Standards Department, 1220 L Street, NW, Washington, DC 20005, or by e-mail to standards@api.org.

API publications may be used by anyone desiring to do so. Every effort has been made by the Institute to assure the accuracy and reliability of the data contained in them; however, the Institute makes no representation, warranty, or guarantee in connection with this publication and hereby expressly disclaims any liability or responsibility for loss or damage resulting from its use or for the violation of any federal, state, or municipal regulation with which this publication may conflict.

This standard shall become effective on the date printed on the cover but may be used vol- untarily from the date of distribution.

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Page

1. TESTING 51

   1. Qualification Testing 51

   2. Factory Acceptance Testing 53

2. MARKING 53

   1. Temporary Marking 53

   2. Permanent Marking 53

   3. Traceability Marking Methods 53

   4. Manufacturer’s Identification Markings 54

   5. Equipment Name Plate Data 54

   6. Other Markings 54

3. STORING AND SHIPPING 54

   1. Protection and Preservation 54

   2. Packing 54

   3. Identification 54

   4. Installation, Operation and Maintenance Documentation 55

ANNEX A (INFORMATIVE) 57

ANNEX B 59

ANNEX C 65

ANNEX D API MONOGRAM SYSTEMS AND MARKING

REQUIREMENTS 97

Tables

1. Ambient Temperature Classification Chart 8

2. Calculation Method Overview 10

1. Control Operating and Interface Requirements Subsea BOP Stack 59

2. Subsea Stack Hydraulic Control System Control Function List 60

3. Subsea Stack Hydraulic Control System Control Readback Function List 62

4. Subsea Diverter Hydraulic Control System Control Function List 63

Specification for Control Systems for Drilling Well Control Equipment and Control Systems for Diverter Equipment

1 Scope

1.1 GENERAL

These specifications establish design standards for systems, that are used to control blowout preventers (BOPs) and associated valves that control well pressure during drilling operations. The design standards applicable to subsystems and components do not include material selection and manufacturing process details but may serve as an aid to purchasing. Although diverters are not considered well control devices, their controls are often incorporated as part of the BOP control system. Thus, control systems for diverter equipment are included herein. Control systems for drilling well control equipment typically employ stored energy in the form of pressurized hydraulic fluid (power fluid) to operate (open and close) the BOP stack components. Each operation of a BOP or other well component is referred to as a control function. The control system equipment and circuitry vary generally in accor- dance with the application and environment. The specifications provided herein describe the following control system categories:

1. Control systems for surface mounted BOP stacks. These systems are typically simple return-to-reservoir hydraulic control systems consisting of a reservoir for storing hydraulic fluid, pump equipment for pressurizing the hydraulic fluid, accumulator banks for storing power fluid and manifolding, piping and control valves for transmission of control fluid to the BOP stack functions.

2. Control systems for subsea BOP stacks (common elements). Remote control of a seafloor BOP stack requires specialized equipment. Some of the control system elements are common to virtually all subsea control systems, regardless of the means used for function signal transmission.

3. Discrete hydraulic control systems for subsea BOP stacks. In addition to the equipment required for surface-mounted BOP stacks, discrete hydraulic subsea control systems use umbilical hose bundles for transmission of hydraulic pilot signals subsea. Also used are dual subsea control pods mounted on the LMRP (lower marine riser package), and housing pilot operated control valves for directing power fluid to the BOP stack functions. Spent water-based hydraulic fluid is usually vented subsea. Hose reels are used for storage and deployment of the umbilical hose bundles. The use of dual subsea pods and umbilicals affords backup security.

4. Electro-hydraulic/multiplex control systems for subsea BOP stacks. For deepwater operations, transmission subsea of electric/ optical (rather than hydraulic) signals affords short response times. Electro-hydraulic systems employ multi-conductor cables, having a pair of wires dedicated to each function to operate subsea solenoid valves which send hydraulic pilot signals to the control valves that operate the BOP stack functions. Multiplex control systems employ serialized communications with multi- ple commands being transmitted over individual conductor wires or fibers. Electronic/optical data processing and transmission are used to provide the security of codifying and confirming functional command signals so that a stray signal, cross talk or a short circuit should not execute a function.

5. Control systems for diverter equipment. Direct hydraulic controls are commonly used for operation of the surface mounted diverter unit. Associated valves may be hydraulically or pneumatically operated.

6. Auxiliary equipment control systems and interfaces. For floating drilling operations, various auxiliary functions such as the telescopic joint packer, 30 in. latch/pin connection, riser annulus gas control equipment, etc., require operation by the control system. These auxiliary equipment controls, though not specifically described herein, shall be subject to the relevant specifica- tions provided herein and requirements for similar equipment.

7. Emergency disconnect sequenced systems (EDS). (Optional) An EDS provides automatic LMRP disconnect when specific emergency conditions occur on a floating drilling vessel. These controls, though not specifically described herein, shall be sub- ject to the relevant specifications provided herein and requirements for similar equipment.

8. Backup Systems (Optional). When the subsea control system is inaccessible or non-functional, an independent control system may be used to operate selected well control, disconnect, and/or recovery functions. They include acoustic control systems, ROV (Remotely Operated Vehicle) operated control systems and LMRP recovery systems. For surface control systems, a reserve supply of pressurized nitrogen gas can serve as a backup means to operate functions in the event that the pump system power supply is lost. These controls, though not specifically described herein, shall be subject to the relevant specifications provided herein and requirements for similar equipment.

9. Special deepwater/harsh environment features (Optional). For deepwater/harsh environment operations, particularly where multi- plex BOP controls and dynamic positioning of the vessel are used, special control system features may be employed. These controls, though not specifically described herein, shall be subject to the relevant specifications provided herein and requirements for similar equipment.

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