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C:\data\User\ISO\New Work Items 2nd Rev\Ist Draft\WD-1\scratch file.docxWORKING DRAFT© ISO 2011 – All rights reservedISO/WD 13628-7 63Part 7: Riser well intervention systemsPetroleum and natural gas industries — Design and operation of subsea production systemsIndustries du pétrolé et du gaz naturel — Conception et exploitation des systémes de production immergés — Partie 7: Systémes de liaison surface/fond de mer pour complétion/reconditionnementPetroleum and natural gas industries — Design and operation of subsea production systems — Part 7: Riser well intervention systemsE2011-06-30(20) PreparatoryISOISO  International Standard2011 ISO 13628ISO 136287ISO/WD 13628-7 SNDrilling and production equipmentMaterials, equipment and offshore structures for petroleum, petrochemical and natural gas indiustries6467 2Heading 2,h2,Heading A,A100,DNV-H2,Heading A1,A1001,DNV-H21Heading 1,h1,Heading section,A,DNV-H1,Heading section1,A1,DNV-H11 02 STD Version 2.1c210 4 ISO TC 67/SC 4 N 

Date:   2011-06-30

ISO/WD 13628-7

ISO TC 67/SC 4/WG 6

Secretariat:   SN

Petroleum and natural gas industries — Design and operation of subsea production systems — Part 7: Riser well intervention systems

Industries du pétrolé et du gaz naturel — Conception et exploitation des systémes de production immergés — Partie 7: Systémes de liaison surface/fond de mer pour complétion/reconditionnement


Warning

This document is not an ISO International Standard. It is distributed for review and comment. It is subject to change without notice and may not be referred to as an International Standard.

Recipients of this draft are invited to submit, with their comments, notification of any relevant patent rights of which they are aware and to provide supporting documentation.


Copyright notice

This ISO document is a working draft or committee draft and is copyright-protected by ISO. While the reproduction of working drafts or committee drafts in any form for use by participants in the ISO standards development process is permitted without prior permission from ISO, neither this document nor any extract from it may be reproduced, stored or transmitted in any form for any other purpose without prior written permission from ISO.

Requests for permission to reproduce this document for the purpose of selling it should be addressed as shown below or to ISO's member body in the country of the requester:

[Indicate the full address, telephone number, fax number, telex number, and electronic mail address, as appropriate, of the Copyright Manger of the ISO member body responsible for the secretariat of the TC or SC within the framework of which the working document has been prepared.]

Reproduction for sales purposes may be subject to royalty payments or a licensing agreement.

Violators may be prosecuted.


Contents Page

Foreword 4

a)Scope 6

b)Normative references 7

c)Terms, definitions, abbreviated terms and symbols 13

d)System requirements 51

e)regulatory requirements; including well containment 55

f)requirements set out in 13628 documents 55

g)barrier requirements; see 1.14 and Annex J 55

h)purchaser specification requirements; see Annex F; 55

i)design basis; see 1.57 , Annex K & L and Annex F; 55

j)design principles, see 1.11 , Annex K & L; 55

k)operational principles; see 1.12 , Annex K & L; 55

l)safety principles; see 1.13; 55

m)operational requirements; see 1.16, Annex K, Annex L and Annex B; 55

n)system and component functional requirements; see 1.24 and 1.26. 55

o) vessel interface requirements 55

p)3rd party interface requirements 55

q)System handling and maintenance requirements 55

s)regulatory requirements; 55

t)barrier requirements; see 1.14; 55

u)end user specification requirements; see Annex F; 55

v)interface requirements, see Annex F; 56

w)design basis; see 1.57 and Annex F; 56

x)design principles; see 1.11; 56

y)operational principles; see 1.12; 56

z)safety principles; see 1.13; 56

aa)operational requirements; see 1.16 and Annex B; 56

ab)system and component functional requirements; see 1.24 and 1.26. 56

ac)measures directed towards reducing the probability of experiencing a drift-off/drive-off situation; 75

ad)measures directed towards reducing the consequences following a drift-off/drive-off. 75

a)mode of operation (tree mode or tubing hanger mode); 77

ae)resulting vessel offset due to loss of vessel station-keeping (i.e. drift-off, drive-off); 77

af)environmental conditions (i.e. water depth, sea-state and current); 77

ag)C/WO riser system emergency shutdown and emergency disconnect sequences and response times; 77

ah)emergency disconnect package disconnect angle; 77

ai)structural capacity of subsea barriers (i.e. wellhead, subsea tree, lower workover riser package, subsea test tree, etc.); 77

aj)pull-out of upper landing string assembly from drilling riser BOP; 77

ak)clearance of surface tree to drill floor; 77

al)stroke of the vessel’s draw works constant tension motion compensator; 77

am)drilling riser’s BOP emergency shutdown and emergency disconnect sequences and response times. 77

an)active or passive heave compensation 77

ao)telescopic joint scope stroke 77

ap)effects of potential pressure entrapment during rig EDS sequence activation. 77

aq)Ability to re-establish on the well and kill the well by pumping at a rate which will displace the tubing fluid into the reservoir and overbalance the well. 77

ar)mode of operation (open water intervention mode or Thru-BOP/drilling riser intervention mode); 77

as)resulting vessel offset due to loss of vessel station-keeping (i.e. drift-off, drive-off); 77

at)environmental conditions (i.e. water depth, sea-state and current); 77

au)riser well intervention system emergency shutdown and emergency disconnect sequences and response times; 77

av)emergency disconnect package disconnect angle; 77

aw)structural capacity of subsea barriers (i.e. wellhead, subsea tree, lower workover riser package, subsea test tree, etc.); 77

ax)pull-out of upper part of the subsea test tree assembly from subsea drilling BOP; 77

ay)clearance of surface tree to drill floor; 78

az)stroke of the vessel’s draw works constant tension motion compensator; 78

ba)stroke of drilling riser slip joint and riser tensioners; 78

bb)subsea drilling BOP's emergency shutdown and emergency disconnect sequences and response times: 78

bc)ability to re-enter on to the subsea well and kill the well. 78

bd)Functional requirements 81

be)allow for well testing, well isolation, well servicing with wireline and coiled tubing access; 81

bf)provide a conduit from the individual bores of a subsea tree or tubing hanger to the surface vessel; 81

bg)allow passage of fluid and tools through the single or multiple bores of the subsea tree/tubing hanger from the workover vessel; 81

bh)provide a conduit to contain all fluids for the application and permit their circulation to and from the wellbore; 81

bi)act as a guide for all tools and equipment being run into or pulled out of the wellbore; 81

bj)provide for the means for connecting workover riser equipments together in a safe and efficient manner on the drill floor or designated work area; 81

bk)serve as a running string for installation and retrieval the subsea tree; 81

bl)serve as a running string for installation and retrieval of the tubing hanger; 81

bm)allow for running the landing string or C/WO riser through the drilling riser and subsea drilling BOP system; 81

bn)allow for running the C/WO riser through open sea; 81

bo)provide a means for connecting control lines to the subsea tree or tubing hanger running tools. 81

a)The design of the subsea well intervention system shall also consider the maintainability of the equipments. Inspection and cleaning shall be easily carried out both externally and internally. Subsea drilling BOP spacer joints and other parts of the system where seawater or well fluids can become trapped in enclosed volumes shall be easily dismantled. 83

bp)Seals and gaskets which are intended to be made up on the vessel shall be available for inspection and easily replaceable on the workover vessel. 83

bq)All primary structural load bearing equipments in the subsea well intervention system shall be qualified for all relevant make/break loads, pressures, temperatures and external loads. 83

br)Resilient, elastomeric or metal-to-metal seals may be used as primary seals to contain hydrocarbons, well control, completion and kill fluids on riser system assembly interfaces and riser connectors. Where metal-to-metal seals are not utilised as a barrier to the environment, redundant seals (primary plus backup) shall be provided. 83

bs)Connection pressure separation loads shall be based on worst-case sealing conditions (i.e. leakage to the largest diameter redundant seal shall be assumed, unless relief is provided). 83

bt)Consideration should be given to pressurising control lines by possible communication and internal leakage from the production or annulus bore. Effects of pressure end loads acting over the area enclosed by the environmental seal should also be considered in the design since one or more of the interior seals could leak. This shall be considered as a temporary failure condition. 83

bu)Equipment subjected to net external pressure shall be provided with a seal system(s) design with external and internal integrity. 83

bv)All seals (including redundant back up seals as referenced in item d) shall be independently qualified for all relevant pressures, temperatures, fluids and services. 84

bw)Primary load bearing equipment leak-tightness shall comply with clause 6.4.11.5 84

bx)Well barrier elements shall be leak-tight after an accidental condition has ocured, see clause 6.4.11.5. 84

by)The inside surfaces of all vertical bores shall be smooth and free of sharp shoulders, and shall be able to pass appropriate drift tools. 84

bz)All valves shall be capable of closing in the flowing direction under maximum flow and pressure conditions. 84

ca)A corrosion allowance shall be assumed whenever relevant, unless corrosion-resistant materials are used. A corrosion allowance and/or the use of corrosion-resistant materials shall be considered given the types of hydrocarbons, well completion, stimulation and kill fluids that will be introduced into the system and the maintenance and storage conditions; see 1.30.4. 84

cb)All equipment which can be subject to net external pressure (e.g. from hydrostatic head) shall be designed to withstand hydrostatic collapse; see 1.31.3.2 and 1.31.3.3. 84

cc)component structural capacities shall be established and documented in accordance with this part of ISO 13628 to allow for the performance of an overall system design analysis; 84

cd)For all equipment that can be subject to subsea drilling BOP pressure (e.g. BOP test pressure, BOP choke and kill pressures), account shall be taken of any axial load effects due to external pressure acting on differential seal areas (i.e. piston effect) in combination with other loading conditions. 84

ce)The subsea well intervention system shall be designed for either guideline or guideline-less installation and retrieval where applicable. 84

cf)Design of guidance systems shall address seal make-up tolerance, angle of re-entry and release, damage to control interfaces and seal surfaces, ability to access existing guidelines, posts or re-entry funnels, wherever appropriate. 84

cg)Bolted flange connections shall be assembled and made up in accordance with a written procedure which has been qualified by test to achieve the specified bolt pretension. A general guideline on bolted flange joint assembly is given in ASME PCC 1-2000 [37]. 84

a)torque transmission through the riser string; 85

ch)accumulated rotational misalignment due to tolerance stack-up; 85

ci)positive indication of tubing hanger alignments; 85

cj)variations in subsea drilling BOP stack configurations (if specified by end user). 85

a)permit orientation alignment of the tubing hanger if required; 86

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