Transcription
Specification for Control Systemsfor Drilling Well Control Equipmentand Control Systems for DiverterEquipmentAPI SPECIFICATION 16D (SPEC 16D)SECOND EDITION, JULY 2004EFFECTIVE DATE, JANUARY 2005
Specification for Control Systemsfor Drilling Well Control Equipmentand Control Systems for DiverterEquipmentUpstream SegmentAPI SPECIFICATION 16D (SPEC 16D)SECOND EDITION, JULY 2004EFFECTIVE DATE, JANUARY 2005
SPECIAL NOTESAPI publications necessarily address problems of a general nature. With respect to particular circumstances, local, state, and federal laws and regulations should be reviewed.API is not undertaking to meet the duties of employers, manufacturers, or suppliers to warnand properly train and equip their employees, and others exposed, concerning health andsafety risks and precautions, nor undertaking their obligations under local, state, or federallaws.Information concerning safety and health risks and proper precautions with respect to particular materials and conditions should be obtained from the employer, the manufacturer orsupplier of that material, or the material safety data sheet.Nothing contained in any API publication is to be construed as granting any right, by implication or otherwise, for the manufacture, sale, or use of any method, apparatus, or productcovered by letters patent. Neither should anything contained in the publication be construed asinsuring anyone against liability for infringement of letters patent.Generally, API standards are reviewed and revised, reaffirmed, or withdrawn at least everyfive years. Sometimes a one-time extension of up to two years will be added to this reviewcycle. This publication will no longer be in effect five years after its publication date as anoperative API standard or, where an extension has been granted, upon republication. Status ofthe publication can be ascertained from the API Standards department telephone (202) 6828000. A catalog of API publications, programs and services is published annually and updatedbiannually by API, and available through Global Engineering Documents, 15 Inverness WayEast, M/S C303B, Englewood, CO 80112-5776.This document was produced under API standardization procedures that ensure appropriatenotification and participation in the developmental process and is designated as an API standard. Questions concerning the interpretation of the content of this standard or comments andquestions concerning the procedures under which this standard was developed should bedirected 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 translate all or any part of the material published herein should be addressed to the Director, Business Services.API standards are published to facilitate the broad availability of proven, sound engineeringand operating practices. These standards are not intended to obviate the need for applyingsound engineering judgment regarding when and where these standards should be utilized.The formulation and publication of API standards is not intended in any way to inhibit anyonefrom using any other practices.Any manufacturer marking equipment or materials in conformance with the markingrequirements of an API standard is solely responsible for complying with all the applicablerequirements of that standard. API does not represent, warrant, or guarantee that such products do in fact conform to the applicable API standard.All rights reserved. No part of this work may be reproduced, stored in a retrieval system, ortransmitted by any means, electronic, mechanical, photocopying, recording, or otherwise,without prior written permission from the publisher. Contact the Publisher,API Publishing Services, 1220 L Street, N.W., Washington, D.C. 20005.Copyright 2004 American Petroleum Institute
FOREWORDThis specification is under the jurisdiction of the API Subcommittee on Standardization ofDrilling Well Control Systems. It represents a composite of industry-accepted practices andstandard specifications employed by various equipment-manufacturing companies. The goalof this specification is to assist the oil and gas industry in promoting personnel safety, publicsafety, integrity of the drilling rig and associated equipment, and preservation of the environment for land and marine drilling operations. In some instances, reconciled composites ofthese practices are included in this publication. Suggested revisions are invited and should besubmitted to the API, Standards Department, 1220 L Street, NW, Washington, DC 20005, orby e-mail to [email protected] publications may be used by anyone desiring to do so. Every effort has been made bythe Institute to assure the accuracy and reliability of the data contained in them; however, theInstitute makes no representation, warranty, or guarantee in connection with this publicationand hereby expressly disclaims any liability or responsibility for loss or damage resultingfrom its use or for the violation of any federal, state, or municipal regulation with which thispublication may conflict.This standard shall become effective on the date printed on the cover but may be used voluntarily from the date of distribution.iii
CONTENTSPage1SCOPE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11.1 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12NORMATIVE REFERENCES. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23TERMS, DEFINITIONS, AND ABBREVIATED TERMS . . . . . . . . . . . . . . . . . . . . . 24GENERAL CONTROL SYSTEM DESIGN REQUIREMENTS. . . . . . . . . . . . . . . . . 74.1 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 74.2 Design Review . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 74.3 Equipment Design Specifications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 155CATEGORIES OF CONTROL SYSTEM APPLICATION. . . . . . . . . . . . . . . . . . . .5.1 Control Systems for Surface Mounted BOP Stacks . . . . . . . . . . . . . . . . . . . . . .5.2 Control Systems for Subsea BOP Stacks (Common Elements). . . . . . . . . . . . .5.3 Discrete Hydraulic Control Systems for Subsea BOP Stacks . . . . . . . . . . . . . .5.4 Electro-hydraulic and Multiplex (MUX) Control Systemsfor Subsea BOP Stacks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5.5 Diverter Control Systems. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5.6 Auxiliary Equipment, Control System Features and Interfaces . . . . . . . . . . . . .5.7 Emergency Disconnect Sequenced Systems (EDS) (Optional) . . . . . . . . . . . . .5.8 Backup Control Systems (Optional) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5.9 Special Deepwater/Harsh Environment Features (Optional) . . . . . . . . . . . . . . .191922303134363737416PERIODIC INSPECTION AND MAINTENANCE PROCEDURE . . . . . . . . . . . . . 417DOCUMENTATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7.1 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7.2 Quality Control Records . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7.3 Manufacturing Documentation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7.4 Test Procedures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7.5 Certifications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4242424242438MANUFACTURING PROCESSES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8.1 Structural Steel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8.2 Steel Groups. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8.3 Structural Shape and Plate Specifications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8.4 Welding . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8.5 Cathodic Protection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8.6 Painting. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .444444444547479COMMODITY ITEMS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .9.1 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .9.2 Pressure Containing Components . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .9.3 Electrical and Electronic Equipment and Installation. . . . . . . . . . . . . . . . . . . . .9.4 Mechanical Equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .9.5 Fluids and Lubricants. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .484848505151v
Page10 TESTING. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5110.1 Qualification Testing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5110.2 Factory Acceptance Testing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5311 MARKING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .11.1 Temporary Marking . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .11.2 Permanent Marking . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .11.3 Traceability Marking Methods . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .11.4 Manufacturer’s Identification Markings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .11.5 Equipment Name Plate Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .11.6 Other Markings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5353535354545412 STORING AND SHIPPING. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .12.1 Protection and Preservation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .12.2 Packing. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .12.3 Identification . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .12.4 Installation, Operation and Maintenance Documentation . . . . . . . . . . . . . . . . .5454545455ANNEX AANNEX BANNEX CANNEX D575965Tables12B-1B-2B-3B-4(INFORMATIVE) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .API MONOGRAM SYSTEMS AND MARKINGREQUIREMENTS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .97Ambient Temperature Classification Chart . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8Calculation Method Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10Control Operating and Interface Requirements Subsea BOP Stack . . . . . . . . . . . 59Subsea Stack Hydraulic Control System Control Function List . . . . . . . . . . . . . . 60Subsea Stack Hydraulic Control System Control Readback Function List. . . . . . 62Subsea Diverter Hydraulic Control System Control Function List . . . . . . . . . . . . 63
Specification for Control Systems for Drilling Well Control Equipmentand Control Systems for Diverter Equipment1 Scope1.1 GENERALThese specifications establish design standards for systems, that are used to control blowout preventers (BOPs) and associatedvalves that control well pressure during drilling operations. The design standards applicable to subsystems and components do notinclude material selection and manufacturing process details but may serve as an aid to purchasing. Although diverters are notconsidered well control devices, their controls are often incorporated as part of the BOP control system. Thus, control systems fordiverter equipment are included herein. Control systems for drilling well control equipment typically employ stored energy in theform of pressurized hydraulic fluid (power fluid) to operate (open and close) the BOP stack components. Each operation of a BOPor other well component is referred to as a control function. The control system equipment and circuitry vary generally in accordance with the application and environment. The specifications provided herein describe the following control system categories:a. Control systems for surface mounted BOP stacks. These systems are typically simple return-to-reservoir hydraulic control systemsconsisting of a reservoir for storing hydraulic fluid, pump equipment for pressurizing the hydraulic fluid, accumulator banks forstoring power fluid and manifolding, piping and control valves for transmission of control fluid to the BOP stack functions.b. Control systems for subsea BOP stacks (common elements). Remote control of a seafloor BOP stack requires specializedequipment. Some of the control system elements are common to virtually all subsea control systems, regardless of the meansused for function signal transmission.c. 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 usedare dual subsea control pods mounted on the LMRP (lower marine riser package), and housing pilot operated control valves fordirecting power fluid to the BOP stack functions. Spent water-based hydraulic fluid is usually vented subsea. Hose reels are usedfor storage and deployment of the umbilical hose bundles. The use of dual subsea pods and umbilicals affords backup security.d. 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 thecontrol valves that operate the BOP stack functions. Multiplex control systems employ serialized communications with multiple commands being transmitted over individual conductor wires or fibers. Electronic/optical data processing and transmissionare used to provide the security of codifying and confirming functional command signals so that a stray signal, cross talk or ashort circuit should not execute a function.e. Control systems for diverter equipment. Direct hydraulic controls are commonly used for operation of the surface mounteddiverter unit. Associated valves may be hydraulically or pneumatically operated.f. Auxiliary equipment control systems and interfaces. For floating drilling operations, various auxiliary functions such as thetelescopic joint packer, 30 in. latch/pin connection, riser annulus gas control equipment, etc., require operation by the controlsystem. These auxiliary equipment controls, though not specifically described herein, shall be subject to the relevant specifications provided herein and requirements for similar equipment.g. Emergency disconnect sequenced systems (EDS). (Optional) An EDS provides automatic LMRP disconnect when specificemergency conditions occur on a floating drilling vessel. These controls, though not specifically described herein, shall be subject to the relevant specifications provided herein and requirements for similar equipment.h. Backup Systems (Optional). When the subsea control system is inaccessible or non-functional, an independent control systemmay 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, areserve supply of pressurized nitrogen gas can serve as a backup means to operate functions in the event that the pump systempower supply is lost. These controls, though not specifically described herein, shall be subject to the relevant specificationsprovided herein and requirements for similar equipment.i. Special deepwater/harsh environment features (Optional). For deepwater/harsh environment operations, particularly where multiplex BOP controls and dynamic positioning of the vessel are used, special control system features may be employed. Thesecontrols, though not specifically described herein, shall be subject to the relevant specifications provided herein and requirementsfor similar equipment.1
2API SPECIFICATION 16D (SPEC 16D)2 Normative ReferencesABS Class Society Rules: CDS (Certification of Drilling Systems)APIRP 14FRP 500Design and Installation of Electrical Systems for Fixed and Floating Offshore Petroleum FacilitiesRecommended Practice for Classification of Locations for Electrical InstallationsANSI1Y32.10Graphic Symbols for Fluid Power DiagramsASME2B31.1Power PipingB31.3Process PipingASME Boiler and Pressure Vessel CodeAWS3A2.4-86D1.1ISO/IEC4IEC 529ISO 1219ISO 13628-8/API RP 17HISO 14224Welding Symbols ChartStructural Welding Code—SteelDegrees of Protection by EnclosuresFluid Power—systems and components—graphic symbols and circuit diagramsROV interfaces on subsea production systemsCollection and exchange of reliability and maintenance data for equipmentNACE International5RP0176Corrosion Control of Steel Fixed Offshore Structures Associated with Petroleum ProductionOther StandardsBritish Design Code BS-5500 Specification for Unfired Fusion Welded Pressure VesselsDOT Spec 3AA2015Welding, Cutting and BrazingGerman Design Code AD-MerkblaetterNEMA 4X3 Terms, Definitions, and Abbreviated TermsGraphic symbols for fluid power diagrams shall be in accordance with ANSI Y32.10 and/or ISO Standard 1219, latest editions.For the purposes of this specification, the following definitions apply:3.1 accumulator: A pressure vessel charged with non-reactive or inert gas used to store hydraulic fluid under pressure foroperation of blowout preventers.3.2 accumulator bank: An assemblage of multiple accumulators sharing a common manifold.3.3 accumulator precharge: An initial inert gas charge in an accumulator, which is further compressed when the hydraulicfluid is pumped into the accumulator, thereby storing potential energy.3.4 acoustic control system: A subsea control system that uses coded acoustic signals for communications and is normallyused as an emergency backup having control of a few selected critical functions.3.5 air pump/air-powered pump: Air driven hydraulic piston pump.3.6 annular BOP: A device with a generally toroidal shaped steel-reinforced elastomer packing element that is hydraulicallyoperated to close and seal around any drill pipe size or to provide full closure of the wellbore.1American National Standards Institute, 25 West 43rd Street, 4th Floor, New York, New York 10036. www.ansi.org2ASME International, 3 Park Avenue, New York, New York 100160-5990. www.asme.org3American Welding Society, 550 N.W. LeJeune Road, Miami, Florida 33135. www.aws.org4International Organization for Standardization, 1, rue de Varemb e, Case postale 56, CH-211, Geneva 20, Switzerland.5NACE International, 1440 South Creek Drive, P.O. Box 218340, Houston, Texas 77218-8340. www.nace.orgwww.iso.org
SPECIFICATION FOR CONTROL SYSTEMS FOR DRILLING WELL CONTROL EQUIPMENT AND CONTROL SYSTEMS FOR DIVERTER EQUIPMENT33.7 arm: To enable the operation of a critical function or functions.3.8 backup: An element or system that is intended to be used only in the event that the primary element or system is non-functional.3.9 blind ram BOP: A BOP having rams which seal against each other to close the wellbore in the absence of any pipe.3.10 block position: The center position of a three-position control valve.3.11 blowout: An uncontrolled flow of pressurized wellbore fluids.3.12 BOP (blowout preventer): A device that allows the well to be sealed to confine the well fluids in the wellbore.3.13 BOP closing ratio (ram BOP): A dimensionless factor equal to the area of the piston operator divided by area of theram shaft.3.14 BOP control system: The 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.3.15 BOP stack: The assembly of well control equipment including BOPs, spools, valves, and nipples connected to the top ofthe casing head.3.16 BOP stack maximum rated wellbore pressure: The pressure containment rating of the ram BOPs in a stack.Note: In the event that the rams are rated at different pressures, the BOP stack maximum rated wellbore pressure is considered equal to the lowest rated ram BOP pressure. In stacks that do not contain any ram BOP, the BOP stack maximum rated wellbore pressure is considered equal tothe lowest rated BOP pressure.3.17 central control unit (CCU): The central control point for control and monitoring system functions and communications.3.18 check valve: A valve that allows flow through it in one direction only.3.19 choke line: A high-pressure line connected below a BOP to transmit well fluid flow to the choke manifold during wellcontrol operations.3.20 choke and kill valves: BOP stack-mounted valves that are connected below selected BOPs to allow access to the wellbore to either choke or kill the well.3.21 closing unit (closing system): See BOP control system.3.22 commodity item: A manufactured product purchased by the control system manufacturer for use in the construction ofcontrol systems for drilling well control equipment.3.23 control fluid: Hydraulic oil, water based fluid, or gas which, under pressure, pilots the operation of control valves ordirectly operates functions.3.24 control hose bundle: A group of pilot and/or supply and/or control hoses assembled into a bundle covered with anouter protective sheath.3.25 control line: A flexible hose or rigid line that transmits control fluid.3.26 control manifold: The assemblage of valves, regulators, gauges and piping used to regulate pressures and control theflow of hydraulic power fluid to operate system functions.3.27 control panel: An enclosure displaying an array of switches, push buttons, lights and/or valves and various pressuregauges or meters to control or monitor functions. Control panel types include: diverter panel; rig floor panel; master panel; andmini or auxiliary remote panel. All of these panels are remote from the main hydraulic manifold and can be pneumatic, electric orhydraulic powered.1. Diverter Panel—A panel that is dedicated to the diverter and flowline system functions.2. Rig Floor Panel (Driller’s Panel)—The BOP control panel mounted near the driller’s position on the rig floor.3. Master Panel (Hydraulic or Electric)—The panel mounted in close proximity to the primary power fluid supply. All controlfunctions are operable from this panel including all required regulators, gauges, meters, audible alarms, and visible alarms.
4API SPECIFICATION 16D (SPEC 16D)4. Mini or Auxiliary Remote Panel (Toolpusher’s Panel)—A full or limited function panel mounted in a remote location foruse as an emergency backup.3.28 control pod: The assemblage of valves and pressure regulators which respond to control signals to direct hydraulicpower fluid through assigned porting to operate functions.3.29 control valve (surface control system): A valve mounted on the hydraulic manifold which directs hydraulic powerfluid to the selected function (such as annular BOP close) while simultaneously venting the opposite function (annular BOP open).3.30 control valve (subsea control system): A pilot operated valve in the subsea control pod that directs power fluid tooperate a function.3.31 dedicated: An element or system that is exclusively used for a specific purpose.3.32 disarm: To disable the operation of a critical function or functions.3.33 disconnect:1. Unlatch and separation of the LMRP connector from its mandrel.2. Unlatch and separation of the BOP stack connector from the wellhead.3.34 discrete hydraulic control system: A system utilizing pilot hoses to transmit hydraulic pressure signals to activatepilot-operated valves assigned to functions.3.35 diverter: A device attached to the wellhead or marine riser to close the vertical flow path and direct well flow (typicallyshallow gas) into a vent line away from the rig.3.36 drift-off: An unintended lateral move of a dynamically positioned vessel off of its intended location relative to the wellhead, generally caused by loss of station keeping control or propulsion.3.37 drive-off: An unintended lateral move of a dynamically positioned vessel off its location driven by the vessel’s main propulsion or station keeping thrusters.3.38 “dunking” transducer: A portable hydrophone.3.39 dynamic positioning (automatic station keeping): A computerized means of maintaining a vessel on location byselectively driving thrusters.3.40 electric pump: An electrically driven hydraulic pump, usually a three-plunger (triplex) pump.3.41 electro-hydraulic (EH) control system: A system utilizing electrical conductor wires in an armored subsea umbilical cable to transmit command signals to solenoid-operated valves which in turn activate pilot-operated control valvesassigned to functions.Note: One pair of wires is dedicated to each function.3.42 factory acceptance testing: Testing by a manufacturer of a particular product to validate its conformance to performance specifications and ratings.3.43 function: Operation of a BOP, choke or kill valve or other component, in one direction (example, closing the blind ramsis a function, opening the blind rams is a separate function).3.44 hose bundle: See control hose bundle.3.45 hydraulic conduit: An auxiliary line on a marine drilling riser used for transmission of control fluid between the surfaceand the subsea BOP stack.3.46 hydraulic connector: A mechanical connector that is activated hydraulically and connects the BOP stack to the wellhead or the LMRP to the BOP stack.3.47 hydrophone: An underwater listening device that converts acoustic energy to electric signals or converts electric signalsto acoustic energy for acoustic transmission.3.48 interflow: The control fluid lost (vented) during the travel of the piston in a control valve during the interval when thecontrol valve’s inlet and vent points are temporarily interconnected.
SPECIFICATION FOR CONTROL SYSTEMS FOR DRILLING WELL CONTROL EQUIPMENT AND CONTROL SYSTEMS FOR DIVERTER EQUIPMENT53.49 jumper: A segment of hose or cable used to make a connection such as a hose reel junction box to the control manifold.3.50 junction box (J-box) (electrical): An enclosure used to house the termination points of electrical cables and components that may also contain electrical components required for system operation.3.51 junction box (J-box) (hydraulic or pneumatic): A bolt-on plate having multiple stab-type terminal fittings used forquick connection of the multi-hose bundle to a pod, hose reel or manifold.3.52 kill line: A high-pressure line from the mud pumps to a connection below a BOP that allows fluid to be pumped into thewell or annulus with the BOP closed during well control operations.3.53 LMRP (lower marine riser package): The upper section of a two-section subsea BOP stack consisting of the hydraulic connector, annular BOP(s), flex/ball joint, riser adapter, flexible choke and kill lines, and subsea control pods.Note: This interfaces with the lower subsea BOP stack.3.54 limit switch: A hydraulic, pneumatic or electrical switch that indicates the motion or position of a device.3.55 manifold: An assemblage of pipe, valves, and fittings by which fluid from one or more sources is selectively directed tovarious systems or components.3.56 mixing system: A system that mixes a measured amount of water soluble lubricant and, optionally, glycol to feed waterand delivers it to a storage tank or reservoir.3.57 multiplex (MUX) control system: A system utilizing electrical or optical conductors in an armored subsea umbilicalcable such that, on each conductor, multiple distinct functions are independently operated by dedicated serialized coded commands.Note: Solenoid-operated valves in turn activate pilot-operated valves assigned to functions.3.58 non-retrievable control pod: A pod that is fixed in place on the LMRP and not retrievable independently.3.59 paging: A computer display method of conveying or mapping between displays or screens to allow increased information or control utilizing multiple screens, but not displayed simultaneously.3.60 pilot fluid: Control fluid that is dedicated to the pilot supply system.3.61 pilot line: A line that transmits pilot fluid to operate a control valve.3.62 pipe ram BOP: A hydraulically operated assembly typically having two opposed ram assemblies that move inward toclose on pipe in the wellbore and seal the annulus.3.63 pipe rams: Rams whose ends are contoured to seal around pipe to close t
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 .
