EN ISO 13624-1:2009

2003-01.Slovenski inštitut za standardizacijo. Razmnoževanje celote ali delov tega standarda ni dovoljeno.Erdöl- und Erdgasindustrien - Bohr- und Förderanlagen - Auslegung und Betrieb von Bohrförderanlagen auf See (ISO 13624-1:2009)Industries du pétrole et du gaz naturel - Équipement de forage et de production - Partie 1: Conception et exploitation des tubes prolongateurs pour les forages en mer (ISO 13624-1:2009)Petroleum and natural gas industries - Drilling and production equipment - Part 1: Design and operation of marine drilling riser equipment (ISO 13624-1:2009)75.180.10Oprema za raziskovanje in odkopavanjeExploratory and extraction equipmentICS:Ta slovenski standard je istoveten z:EN ISO 13624-1:2009SIST EN ISO 13624-1:2010en,fr01-januar-2010SIST EN ISO 13624-1:2010SLOVENSKI
STANDARD
EUROPEAN STANDARD NORME EUROPÉENNE EUROPÄISCHE NORM
EN ISO 13624-1
November 2009 ICS 75.180.10 English Version
Petroleum and natural gas industries - Drilling and production equipment - Part 1: Design and operation of marine drilling riser equipment (ISO 13624-1:2009)
Industries du pétrole et du gaz naturel - Équipement de forage et de production - Partie 1: Conception et exploitation des tubes prolongateurs pour les forages en mer (ISO 13624-1:2009)
Erdöl- und Erdgasindustrien - Bohr- und Förderanlagen - Auslegung und Betrieb von Bohrförderanlagen auf See (ISO 13624-1:2009) This European Standard was approved by CEN on 29 September 2009.
CEN members are bound to comply with the CEN/CENELEC Internal Regulations which stipulate the conditions for giving this European Standard the status of a national standard without any alteration. Up-to-date lists and bibliographical references concerning such national standards may be obtained on application to the CEN Management Centre or to any CEN member.
This European Standard exists in three official versions (English, French, German). A version in any other language made by translation under the responsibility of a CEN member into its own language and notified to the CEN Management Centre has the same status as the official versions.
CEN members are the national standards bodies of Austria, Belgium, Bulgaria, Cyprus, Czech Republic, Denmark, Estonia, Finland, France, Germany, Greece, Hungary, Iceland, Ireland, Italy, Latvia, Lithuania, Luxembourg, Malta, Netherlands, Norway, Poland, Portugal, Romania, Slovakia, Slovenia, Spain, Sweden, Switzerland and United Kingdom.
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Reference numberISO 13624-1:2009(E)© ISO 2009
INTERNATIONAL STANDARD ISO13624-1First edition2009-11-15Petroleum and natural gas industries — Drilling and production equipment — Part 1: Design and operation of marine drilling riser equipment Industries du pétrole et du gaz naturel — Équipement de forage et de production — Partie 1: Conception et exploitation des tubes prolongateurs pour les forages en mer
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ISO 13624-1:2009(E) © ISO 2009 – All rights reserved iii Contents Page Foreword.v Introduction.vi 1 Scope.1 2 Normative references.1 3 Terms, definitions, and abbreviations.2 3.1 Terms and definitions.2 3.2 Abbreviations.10 4 Component function and selection.11 4.1 Introduction.11 4.2 Component selection criteria.11 4.3 Marine drilling riser system.11 4.4 Tensioner system.13 4.5 Diverter system (surface).14 4.6 Telescopic joint (slip joint).14 4.7 Riser joints.16 4.8 Lower marine riser package (LMRP).17 4.9 Flex and ball joints.18 4.10 Flexible choke and kill lines.19 4.11 Riser running equipment.20 4.12 Riser-mounted choke/kill and auxiliary lines.21 4.13 Buoyancy equipment.22 4.14 Specialty equipment.23 5 Riser response analysis.24 5.1 General considerations.24 5.2 Riser analysis procedure.24 5.3 Design.25 5.4 General riser modelling and analysis approach.29 5.5 Coupled/decoupled analysis methodology.35 5.6 Drift-off/drive-off analysis methodology.36 5.7 Weak-point analysis methodology.37 5.8 Recoil analysis methodology.38 5.9 High-current environment.38 5.10 Hang-off analysis methodology.41 6 Riser operations.44 6.1 Introduction.44 6.2 Rise operations manual.44 6.3 Drilling-riser-operations information systems.44 6.4 Preparing to run riser.45 6.5 Riser running and retrieval.48 6.6 Installed riser operations.51 6.7 Emergency disconnect — Sudden storm, drive-/drift-off.57 7 Riser integrity.58 7.1 Basis of inspection requirements.58 7.2 Maintenance after riser retrieval.62 7.3 Other riser system maintenance.62 7.4 Transportation, handling, and storage.62 7.5 Scheduled field inspection and maintenance.64 7.6 In-service inspection.64 SIST EN ISO 13624-1:2010

ISO 13624-1:2009(E) iv © ISO 2009 – All rights reserved 7.7 Guidance on components for inspection.68 7.8 Inspection objectives and acceptance criteria.69 7.9 Operational records for riser components.71 8 Special situations.73 8.1 Deep-water drilling.73 8.2 Guidelineless systems.76 8.3 Cold weather considerations.76 8.4 Riser collapse considerations.77 8.5 H2S considerations.78 Annex A (informative)
Riser analysis data worksheet.79 Annex B (informative)
Fatigue.83 Annex C (informative)
Sample riser calculations.85 Annex D (informative)
Example riser running procedure.96 Annex E (informative)
Sample calculation of maximum and minimum TJ stroke arising from space-out tolerance, riser stretch, draft, tide, heave and offset.98 Bibliography.102
ISO 13624-1:2009(E) © ISO 2009 – All rights reserved v Foreword ISO (the International Organization for Standardization) is a worldwide federation of national standards bodies (ISO member bodies). The work of preparing International Standards is normally carried out through ISO technical committees. Each member body interested in a subject for which a technical committee has been established has the right to be represented on that committee. International organizations, governmental and non-governmental, in liaison with ISO, also take part in the work. ISO collaborates closely with the International Electrotechnical Commission (IEC) on all matters of electrotechnical standardization. International Standards are drafted in accordance with the rules given in the ISO/IEC Directives, Part 2. The main task of technical committees is to prepare International Standards. Draft International Standards adopted by the technical committees are circulated to the member bodies for voting. Publication as an International Standard requires approval by at least 75 % of the member bodies casting a vote. Attention is drawn to the possibility that some of the elements of this document may be the subject of patent rights. ISO shall not be held responsible for identifying any or all such patent rights. ISO 13624-1 was prepared by Technical Committee ISO/TC 67, Materials, equipment and offshore structures for petroleum, petrochemical and natural gas industries, Subcommittee SC 4, Drilling and production equipment. ISO 13624 consists of the following parts, under the general title Petroleum and natural gas industries — Drilling and production equipment: ⎯ Part 1: Design and operation of marine drilling riser equipment ⎯ Part 2: Deepwater drilling riser methodologies, operations, and integrity technical report (Technical Report)
ISO 13624-1:2009(E) vi © ISO 2009 – All rights reserved Introduction Since the first edition of API RP 16Q was first issued in November, 1993, hydrocarbon exploration in deep-water environments has increased significantly. As a consequence of this, the need has been identified to update that code of practice to address the issues of deep-water drilling risers in sufficient detail to supplement API RP 16Q for drilling in water depths up to 3 048 m (10 000 ft). Under the auspices of the DeepStar programme, substantial work was commissioned during 1999 and 2000 by the DeepStar Drilling Committee 4502 and lead to the development by several contractors of Deep-water Drilling Riser Methodologies, Operations, and Integrity Guidelines in February 2001. These guidelines were intended to supplement the existing text of API RP 16Q (1993). In a subsequent Joint Industry Project funded by DeepStar 5500 and in collaboration with API, these guidelines were supplemented with other identified revisions to produce a draft update second edition of API RP 16Q and an associated API Technical Report 16TR1, designed to be read in conjunction with the revised API RP 16Q and to supplement its contents, by providing additional guidance on recommended riser analysis methodologies through detailed explanations, step-by-step procedures and worked examples. API publications can be used by anyone desiring to do so. Every effort has been made to assure the accuracy and reliability of the data contained in them. It is the responsibility of the users of this part of ISO 13624 to ensure that its use does not result in any loss or damage or in the violation of any federal, state, or municipal regulation. Annex A through Annex E are informative.
INTERNATIONAL STANDARD ISO 13624-1:2009(E) © ISO 2009 – All rights reserved 1 Petroleum and natural gas industries — Drilling and production equipment — Part 1: Design and operation of marine drilling riser equipment 1 Scope This part of ISO 13624 pertains to the design, selection, operation and maintenance of marine riser systems for floating drilling operations. Its purpose is to serve as a reference for designers, for those who select system components, and for those who use and maintain this equipment. It relies on basic engineering principles and the accumulated experience of offshore operators, contractors, and manufacturers. NOTE Technology is advancing in this field and improved methods and equipment are continually evolving. Each owner and operator is encouraged to observe the recommendations outlined herein and to supplement them with other proven technology that can result in more cost effective, safer, and/or more reliable performance. The marine drilling riser is best viewed as a system. It is necessary that designers, contractors, and operators realize that the individual components are recommended and selected in a manner suited to the overall performance of that system. For the purposes of this part of ISO 13624, a marine drilling riser system includes the tensioner system and all equipment between the top connection of the upper flex/ball joint and the bottom of wellhead conductor outer casing. It specifically excludes the diverter. Also, the applicability of this part of ISO 13624 is limited to operations with a subsea BOP stack deployed at the seafloor. Clauses 1 through 7 of this part of ISO 13624 are directly applicable to most floating drilling operations. Special situations are addressed in 8.1 and 8.4 dealing with deep-water drilling and collapse. The special considerations required for guidelineless drilling are addressed in 8.2. In addition, 8.3 and 8.5 address operations in cold-weather conditions and H2S considerations. It is important that all riser primary-load-path components addressed in this part of ISO 13624 be consistent with the load classifications specified in ISO 13625. 2 Normative references The following referenced documents are indispensable for the application of this document. For dated references, only the edition cited applies. For undated references, the latest edition of the referenced document (including any amendments) applies. ISO 13625, Petroleum and natural gas industries — Drilling and production equipment — Marine drilling riser couplings BS 7910, Guide to methods for assessing the acceptability of flaws in metallic structures SIST EN ISO 13624-1:2010

ISO 13624-1:2009(E) 2 © ISO 2009 – All rights reserved 3 Terms, definitions, and abbreviations 3.1 Terms and definitions For the purposes of this document, the following terms and definitions apply. 3.1.1 accumulator 〈BOP〉 pressure vessel charged with gas (nitrogen) over liquid and used to store hydraulic fluid under pressure for operation of blowout preventers 3.1.2 accumulator 〈riser tensioner〉 pressure vessel charged with gas (generally nitrogen) over liquid that is pressurized on the gas side from the tensioner high-pressure gas supply bottles and supplies high-pressure hydraulic fluid to energize the riser tensioner cylinder 3.1.3 actuator mechanism for the remote or automatic operation of a valve or choke 3.1.4 air-can buoyancy tension applied to the riser string by the net buoyancy of an air chamber created by a closed top, open-bottom cylinder forming an air-filled annulus around the outside of the riser pipe 3.1.5 annulus space between two pipes when one pipe is inside the other 3.1.6 apparent weight effective weight submerged weight weight minus buoyancy NOTE Apparent weight is commonly referred to as weight in water, wet weight, submerged weight, or effective weight. 3.1.7 auxiliary line conduit (excluding choke-and-kill lines) attached to the outside of the riser main tube EXAMPLE Hydraulic supply line, buoyancy-control line, mud-boost line. 3.1.8 back pressure pressure resulting from restriction of fluid flow downstream 3.1.9 ball joint ball-and-socket assembly that has a central through-passage equal to or greater than the riser internal diameter and that may be positioned in the riser string to reduce local bending stresses 3.1.10 blowout uncontrolled flow of well fluids from the wellbore SIST EN ISO 13624-1:2010

ISO 13624-1:2009(E) © ISO 2009 – All rights reserved 3 3.1.11 blowout preventer BOP device attached immediately above the casing, which can be closed to shut in the well 3.1.12 blowout preventer 〈annular type〉 remotely controlled device which can form a seal in the annular space around any object in the wellbore or upon itself NOTE
Compression of a reinforced elastomer packing element by hydraulic pressure effects the seal. 3.1.13 BOP stack assembly of well-control equipment, including BOPs, spools, valves, hydraulic connectors and nipples, that connects to the subsea wellhead NOTE Common usage of this term sometimes includes the lower marine riser package (LMRP). 3.1.14 bottom-hole assembly BHA assembly composed of the bit, stabilizers, reamers, drill collars, various types of subs, etc., that is connected to the bottom of a string of drillpipe 3.1.15 box female member of a riser coupling, C&K line stab assembly or auxiliary line stab assembly 3.1.16 breech-block coupling coupling that is engaged by rotation of one member into an interlock with another member by an angle of rotation of 90 ° or less 3.1.17 buoyancy-control line auxiliary line dedicated to controlling, charging or discharging air-can buoyancy chambers 3.1.18 buoyancy equipment devices added to riser joints to reduce their apparent weight, thereby reducing riser top tension requirements NOTE The devices normally used for risers take the form of syntactic foam modules or open-bottom air chambers. 3.1.19 choke-and-kill line C&K line kill line external conduit arranged laterally along the riser pipe and used for circulation of fluids into and out of the wellbore to control well pressure 3.1.20 control pod assembly of subsea valves and regulators that, when activated from the surface, directs hydraulic fluid through special porting to operate BOP equipment 3.1.21 coupling mechanical means for joining two sections of riser pipe in an end-to-end engagement SIST EN ISO 13624-1:2010

ISO 13624-1:2009(E) 4 © ISO 2009 – All rights reserved 3.1.22 diverter device attached to the wellhead or marine riser to close the vertical flow path and direct well flow away from the drill-floor and rig 3.1.23 dog-type coupling coupling having wedges (dogs) that are mechanically driven between the box and pin for engagement 3.1.24 drape hose flexible line connecting a choke, kill or auxiliary line terminal fitting on the telescopic joint to the appropriate piping on the rig structure NOTE A U-shaped bend or “drape” in this line allows for relative movement between the inner barrel of the telescopic joint and the outer barrel of the telescopic joint as the vessel moves. 3.1.25 drift-off unintended lateral move of a dynamically positioned vessel off of its intended location relative to the wellhead, generally caused by loss of stationkeeping control or propulsion 3.1.26 drilling fluid mud water- or oil-based fluid circulated down the drillpipe into the well and back up to the rig for purposes including containment of formation pressure, the removal of cuttings, bit lubrication and cooling, treating the wall of the well and providing a source for well data 3.1.27 drive-off unintended move of a dynamically positioned vessel off location driven by the vessel's main propulsion or stationkeeping thrusters 3.1.28 dynamic positioning automatic stationkeeping computerized means of maintaining a vessel on location by selectively driving thrusters 3.1.29 dynamic tension limit maximum allowable pressure multiplied by the effective hydraulic area, divided by the number of line parts 3.1.30 effective hydraulic cylinder area net area of moving parts exposed to tensioner hydraulic pressure 3.1.31 effective tension tension that controls the stability of risers See 5.4.4. 3.1.32 factory acceptance testing testing by a manufacturer of a particular product to validate its conformance to performance specifications and ratings SIST EN ISO 13624-1:2010

ISO 13624-1:2009(E) © ISO 2009 – All rights reserved 5 3.1.33 fail safe term applied to equipment or a system so designed that, in the event of failure or malfunction of any part of the system, devices are automatically activated to stabilize or secure the safety of the operation 3.1.34 fillup line line through which fluid is added to the riser annulus 3.1.35 flange-type coupling coupling having two flanges joined by bolts 3.1.36 fleet angle angle between the vertical axis and a riser tensioner line at the point where the line connects to the telescopic joint See Figure 1. 3.1.37 flex joint steel and elastomer assembly that has a central through-passage equal to or greater in diameter than the riser bore and that may be positioned in the riser string to reduce local bending stresses 3.1.38 gooseneck type of terminal fitting using a pipe section with a semicircular bend to achieve a nominal 180° change in flow direction 3.1.39 guidelineless re-entry establishment of pressure-containing connection between the BOP stack and the subsea wellhead or between the LMRP and the BOP stack using a TV image and/or acoustic signals instead of guidelines to guide the orientation and alignment 3.1.40 handling tool running tool device that joins to the upper end of a riser joint to permit lifting and lowering of the joint and the assembled riser string in the derrick by the elevators 3.1.41 heave vessel motion in the vertical direction 3.1.42 hot spot stress local peak stress highest stress in the region or component under consideration NOTE The basic characteristic of a peak stress is that it causes no significant distortion and is principally objectionable as a possible initiation site for a fatigue crack. These stresses are highly localized and occur at geometric discontinuities. 3.1.43 hydraulic connector mechanical connector that is activated hydraulically and connects the BOP stack to the wellhead or the LMRP to the BOP stack SIST EN ISO 13624-1:2010

ISO 13624-1:2009(E) 6 © ISO 2009 – All rights reserved 3.1.44 hydraulic supply line auxiliary line from the vessel to the subsea BOP stack that supplies control system operating fluid to the LMRP and BOP stack 3.1.45 instrumented riser joint IRJ riser joint equipped with sensors for monitoring parameters, such as tension in the riser pipe wall, riser angular offset, annulus fluid temperature and pressure, etc. 3.1.46 jumper hose 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 3.1.47 key-seating formation of a longitudinal slot in the bore of a riser system component caused by frictional wear of the rotating drillstring on the riser component 3.1.48 landing joint riser joint temporarily attached above the telescopic joint used to land the BOP stack on the wellhead when the telescopic joint is collapsed and pinned 3.1.49 landing shoulder riser support shoulder shoulder or projection on the external surface of a riser coupling or other riser component for supporting the riser and BOP stack during deployment and retrieval 3.1.50 lower marine riser package LMRP upper section of a two-section subsea BOP stack consisting of a hydraulic connector, annular BOP, flex joint, riser adapter, jumper hoses for the choke, kill and auxiliary lines, and subsea control pods NOTE This interfaces with the lower subsea BOP stack. 3.1.51 made-up length actual length contributed to a riser string by a made-up riser component (overall component length minus box/pin engagement) 3.1.52 make-up time riser coupling time period beginning when the box and pin are stabbed and ending when the coupling is fully preloaded 3.1.53 make-up tool preload tool device used to engage and/or preload coupling members 3.1.54 marine drilling riser tubular conduit serving as an extension of the wellbore from the equipment on the wellhead at the seafloor to a floating drilling rig SIST EN ISO 13624-1:2010

ISO 13624-1:2009(E) © ISO 2009 – All rights reserved 7 3.1.55 maximum tensioner setting maximum setting that, when added with dynamic variations, is less than the dynamic tension limit (3.1.29) 3.1.56 mud-boost line auxiliary line that provides supplementary drilling fluid from the surface and injects it into the riser at the top of the LMRP to assist in the circulation of drill cuttings up the marine riser, when required 3.1.57 nipple up assemble a system of fluid handling components 3.1.58 nominal stress stress calculated using the nominal pipe wall dimensions of the riser at the location of concern 3.1.59 pin male member of a riser coupling or a choke, kill or auxiliary line stab assembly 3.1.60 preload compressive bearing load developed between box and pin members at their interface NOTE This is accomplished by elastic deformation during make-up of the coupling. 3.1.61 protector, box protector, pin cap or cover used to protect the box or pin from damage during storage and handling 3.1.62 pup joint shorter than standard length riser joint 3.1.63 rated load nominal applied loading condition used during riser design, analysis and testing based on maximum anticipated service loading See API Spec 16F. 3.1.64 response amplitude operator RAO 〈regular waves〉 ratio of a vessel's motion to the wave amplitude causing that motion and presented over a range of wave periods 3.1.65 riser adapter crossover between riser and flex/ball joint 3.1.66 riser annulus space around a pipe (drillpipe, casing or tubing) suspended in a riser NOTE Its outer boundary is the internal surface of the riser pipe. SIST EN ISO 13624-1:2010

ISO 13624-1:2009(E) 8 © ISO 2009 – All rights reserved 3.1.67 riser connector LMRP connector hydraulically operated connector that joins the LMRP to the top of the BOP stack 3.1.68 riser disconnect operation of unlatching of the riser connector to separate the riser and LMRP from the BOP stack 3.1.69 riser hang-off system means for supporting a disconnected deep-water riser from the drilling vessel during a storm without inducing excessive stresses in the riser 3.1.70 riser hang-off tool tool used to latch onto an interior profile in the riser and connect it to the motion compensator 3.1.71 riser joint section of riser main tube having the ends fitted with a box and pin and including choke, kill and (optional) auxiliary lines and their support brackets 3.1.72 riser main tube riser pipe seamless or electric-welded pipe that forms the principal conduit of the riser joint NOTE The riser main tube is the conduit for guiding the drillstring and containing the return fluid flow from the well. 3.1.73 riser recoil system means of limiting the upward acceleration of the riser when a disconnect is made at the riser connector 3.1.74 riser spider 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 3.1.75 riser string deployed assembly of riser joints 3.1.76 riser tensioner means for providing and maintaining top tension on the deployed riser string to prevent buckling 3.1.77 riser tensioner ring structural interface of the telescopic joint outer barrel and the riser tensioners 3.1.78 rotary kelly bushing RKB bushing that sits on top of the rotary table NOTE It transmits torque from the rotary table to the kelly and is commonly used as a reference for vertical measurements from the drill-floor. SIST EN ISO 13624-1:2010

ISO 13624-1:2009(E) © ISO 2009 – All rights reserved 9 3.1.79 stab mating box and pin assembly that provides a pressure-tight engagement of two pipe joints NOTE An external mechanism is usually used to keep the box and pin engaged. EXAMPLE
Riser joint choke and kill stabs are retained in the stab mode by the make-up of the riser coupling. 3.1.80 standard riser joint joint of typical length for a particular drilling vessel's riser storage racks, the derrick V-door size, riser-handling equipment capacity or a particular riser purchase 3.1.81 storm disconnect riser disconnect to avoid excessive loading from vessel motions amplified by inclement weather conditions 3.1.82 strakes helically wound appendages attached to the outside of the riser to suppress vortex induced vibrations 3.1.83 stress amplification factor SAF FSA value equal to the local peak alternating stress in a component (including welds) divided by the nominal alternating stress in the pipe wall at the location of the component NOTE This factor is used to account for the increase in the stresses caused by geometric stress amplifiers that occur in riser components. 3.1.84 thrust collar device for transmitting the buoyant force of a buoyancy module to the riser joint 3.1.85 subsea fill-up valve special riser joint having a valve means to allow the riser annulus to be opened to the sea NOTE To prevent riser pipe collapse, the valve can be opened by an automatic actuator controlled by a differential-pressure sensor. 3.1.86 support bracket bracket positioned at intervals along a riser joint that provides intermediate radial and lateral support from the riser main tube to the choke, kill and auxiliary lines 3.1.87 surge vessel motion along the fore/aft axis 3.1.88 sway vessel motion along the port/starboard axis 3.1.89 syntactic foam typically, a composite material of spherical fillers in a matrix or binder SIST EN ISO 13624-1:2010

ISO 13624-1:2009(E) 10 © ISO 2009 – All rights reserved 3.1.90 telescopic joint slip joint riser joint having an inner barrel and an outer barrel with a means of sealing between them NOTE The inner and outer barrels of the telescopic joint move relative to each other to compensate for the required change in the length of the riser string as the vessel experiences surge, sway, and heave. 3.1.91 telescopic joint packer means of sealing the annular space between the inner and outer barrels of the telescopic joint 3.1.92 terminal fitting connection between a rigid choke, kill or auxiliary line on a telescopic joint and its drape hose, effecting a nominal 180° turn in flow direction 3.1.93 threaded-union coupling coupling having mating threaded members on the pin and box to form the engagement NOTE The threads on one side of the coupling are free to rotate relative to the riser pipe, so it is not necessary that that the joint rotate to make up the coupling. The threads do not form the seal. 3.1.94 tension ring support ring around the top of the joint where tensioner lines are attached 3.1.95 type certification testing testing by a manufacturer of a representative specimen (or prototype) of a product that qualifies the design and, therefore, validates the integrity of other products of the same design, materials and manufacture 3.1.96 vortex induced vibration in-line and transverse oscillation of a riser in a current induced by the periodic shedding of vortices 3.1.97 wellhead connector stack connector hydraulically operated connector that joins the BOP stack to the subsea wellhead 3.2 Abbreviations BOP blowout preventer DP dynamic positioning DTL dynamic tension limit ID internal diameter LFJ lower flex joint LMRP lower marine riser package OD outside diameter RAO response amplitude operator SIST EN ISO 13624-1:2010

ISO 13624-1:2009(E) © ISO 2009 – All rights reserved 11 RKB rotary kelly bushing ROV remotely operated vehicle SAF stress amplification factor UFJ upper flex joint 4 Component function and selection 4.1 Introduction General requirements common to all components are outlined in 4.2 and, where appropriate, individual components are addressed in the rest of Clause 4. The following general format is used: a) function: the basic function of the component is described; b) typical designs: examples of typical designs are presented; c) selection criteria: general performance requirements are outlined. 4.2 Component selection criteria Design of a riser system begins with an assessment of expected operating conditions and an engineering analysis to establish parameters, such as tensile, bending and combined stresses (maximum and mean), buoyancy requirements, top tension requirements, vessel response amplitude operators (RAOs), etc. Other factors influencing riser system design include riser length (water depth), dimensional requirements (bore, wall thickness, etc.), internal pressure rating, choke/kill, and auxiliary-line specifications, make-up method, storage and handling conditions, operating economy, etc. Once established, these riser-system design criteria should permit the selection of riser components that suit the application. All riser primary-load-path components addressed in this part of ISO 13624 shall be consistent with the load classifications specified in ISO 13625. 4.3 Marine drilling riser system The marine riser system forms an extension of the wellbore from the blowout preventer (BOP) stack to the drilling vessel; see Figure 1. The primary functions of the marine riser system are to a) provide for fluid communication between the well and the drilling vessel 1) in the riser annulus under normal drilling conditions, 2) through the choke-and-kill lines when the BOP stack is being used to control the well; b) support the choke, kill and auxiliary lines; c) guide tools into the well; d) serve as a running and retrieving string for the BOP stack. SIST EN ISO 13624-1:2010

ISO 13624-1:2009(E) 12 © ISO 2009 – All rights reserved 123124569710111281314151618171920 Key 1 rotary kelly bushing (RKB) 8 choke line 15 flex/ball joint 2 rotary 9 fleet angle 16 riser/BOP jumper hose 3 diverter 10 kill drape hose 17 LMRP connector 4 telescopic joint inner barrel 11 telescopic joint outer barrel 18 lower marine riser package (LMRP) 5 diverter flex/ball joint 12 kill line 19 blowout preventer (BOP) stack 6 tensioner line 13 riser coupling 20 wellhead connector 7 choke drape hose 14 marine riser joints
Figure 1 — Marine riser system and associated equipment SIST EN ISO 13624-1:2010

ISO 13624-1:2009(E) © ISO 2009 – All rights reserved 13 4.4 Tensioner system 4.4.1 Function Tensioner units are used to apply vertical force to the top of the marine drilling riser to control its stresses and displacements. The units are normally located on the drilling vessel near the periphery of the drill-floor. They provide a nearly constant axial tension to the riser while the floating drilling vessel moves vertically and laterally in response to the wind, waves and current. 4.4.2 Typical design A typical tensioner unit uses a hydraulic ram with large-volume, air-filled auxiliary pressure vessels (APV) to maintain a nearly constant pressure/tension on a line (wire rope). One end of the line is attached at the vessel and the other is attached to the outer barrel of the telescopic joint. Typically, a four-part line-reeving system is used so that the piston stroke is equal to one-quarter of the vessel heave. The number and rating of tensioner units used determines the total capacity of the tensioner system. The tension applied by each unit can be varied up to its design capacity by increasing or decreasing the applied air pressure. The tensioner system should be capable of providing sufficient tension based upon the maximum rated water depth, maximum expected mud weight, and other loadings determined from riser analyses. Direct-acting hydraulic rod-cylinder tensioners are also used on deep-water drilling vessels. Designs for tensioner systems are described in ISO/TR 13624-2:—, Clause 4. 4.4.3 Selection criteria Some important considerations for designing an effective tensioner system are as follows. a) Fleet angle: The idler sheaves should be placed so as to minimize the fleet angle. This maximizes the vertical component of tension, minimizes the horizontal component and increases wireline life. Because of the fleet angle, the vertical tension applied to the outer barrel of the telescopic joint is less than the tension supplied by the tensioner system. A reduction factor (see 5.3.2) should be used to reconcile these parameters. b) Wireline life: Wireline life is a function of many parameters, including wire-rope construction, sheave diameter, applied tension, operating circumstances relating to travel, etc. See APl RP 9B. c) Accumulators and air-pressure vessels: Each tensioner unit should have an accumulator that is large enough to store a volume of hydraulic fluid greater than the cylinder volume. Large air-pressure vessels reduce pressure changes caused by the compression and expansion of the stored air as the tensioner strokes in and out. d) Fluid and air flow requirements: Properly sized lines reduce tension variations caused by piping-system pressure losses. A list of hydraulic fluids compatible with the tensioner units should be specified by the tensioner manufacturer. e) Friction and inertia losses: Seal friction, sheave friction and inertia of sheaves, wire rope, tensioner rods, and pistons all contribute to variations in the wireline tension. f) Dynamic tension limit (DTL): Tensioner ratings are defined differently by various manufacturers
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