ISO TR 13624-2-2009 Petroleum and natural gas industries - Drilling and production equipment - Part 2 Deepwater drilling riser methodologies operations and inte.pdf

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1、 Reference number ISO/TR 13624-2:2009(E) ISO 2009TECHNICAL REPORT ISO/TR 13624-2 First edition 2009-12-01 Petroleum and natural gas industries Drilling and production equipment Part 2: Deepwater drilling riser methodologies, operations, and integrity technical report Industries du ptrole et du gaz n

2、aturel quipement de forage et de production Partie 2: Mthodologies, oprations et rapport technique dintgrit relatifs aux tubes prolongateurs pour forages en eaux profondes ISO/TR 13624-2:2009(E) PDF disclaimer This PDF file may contain embedded typefaces. In accordance with Adobes licensing policy,

3、this file may be printed or viewed but shall not be edited unless the typefaces which are embedded are licensed to and installed on the computer performing the editing. In downloading this file, parties accept therein the responsibility of not infringing Adobes licensing policy. The ISO Central Secr

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5、sure that the file is suitable for use by ISO member bodies. In the unlikely event that a problem relating to it is found, please inform the Central Secretariat at the address given below. COPYRIGHT PROTECTED DOCUMENT ISO 2009 All rights reserved. Unless otherwise specified, no part of this publicat

6、ion may be reproduced or utilized in any form or by any means, electronic or mechanical, including photocopying and microfilm, without permission in writing from either ISO at the address below or ISOs member body in the country of the requester. ISO copyright office Case postale 56 CH-1211 Geneva 2

7、0 Tel. + 41 22 749 01 11 Fax + 41 22 749 09 47 E-mail copyrightiso.org Web www.iso.org Published in Switzerland ii ISO 2009 All rights reservedISO/TR 13624-2:2009(E) ISO 2009 All rights reserved iiiContents Page Foreword iv Introduction.v 1 Scope1 2 Normative references1 3 Terms and definitions .1 4

8、 Abbreviated terms .7 5 Coupled drilling riser/conductor analysis methodology and worked example7 5.1 Coupled methodology.7 5.2 Decoupled methodology.7 5.3 Analysis considerations .10 5.4 Model development.10 5.5 Coupled riser analysis 19 5.6 Decoupled riser analysis 21 5.7 Worked example 22 5.8 Bas

9、is of analysis .22 5.9 Model description and analysis procedure 29 5.10 Results30 6 Drift-off/drive-off analysis methodology and worked example 33 6.1 Drift-off analysis methodology 33 6.2 Example36 7 Recoil analysis methodology and worked example 50 7.1 Introduction50 7.2 Background50 7.3 Required

10、information 57 7.4 Performance criteria64 7.5 Worked example applicability 68 Bibliography88 ISO/TR 13624-2:2009(E) iv ISO 2009 All rights reservedForeword ISO (the International Organization for Standardization) is a worldwide federation of national standards bodies (ISO member bodies). The work of

11、 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

12、, 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

13、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. In ex

14、ceptional circumstances, when a technical committee has collected data of a different kind from that which is normally published as an International Standard (“state of the art”, for example), it may decide by a simple majority vote of its participating members to publish a Technical Report. A Techn

15、ical Report is entirely informative in nature and does not have to be reviewed until the data it provides are considered to be no longer valid or useful. 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 respon

16、sible for identifying any or all such patent rights. ISO/TR 13624-2 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/TR 13624 consists of the

17、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 ISO/TR 13624-2:2009(E) ISO 2009

18、All rights reserved vIntroduction Since API RP 16Q was issued in 1993, hydrocarbon exploration in 1 200+ m (4 000+ ft) water depths has increased significantly. As a consequence, the need was identified to update that code of practice to address the issues particular to deepwater operations. Under t

19、he auspices of the DeepStar programme, substantial work was commissioned during 1999 and 2000 by the DeepStar Drilling Committee 4502 and led to the development of Deepwater Drilling Riser Methodologies, Operations, and Integrity Guidelines in February 2001. Several contractors participated in these

20、 efforts. These guidelines were intended to supplement and update the existing API RP 16Q:1993 for deepwater application. In a subsequent joint industry project and in collaboration with DeepStar and the API, these guidelines were later supplemented with other identified revisions and technically ed

21、ited by an API task group to produce the revision of API RP 16Q:1993 as ISO 13624-1 and the API Technical Report TR1. This Technical Report is a supplement to the revised API RP 16Q and provides guidance on various analysis methodologies and operating practices. NOTE The figures have been reproduced

22、 as provided by the Technical Committee and, in some cases, contain only USC units. TECHNICAL REPORT ISO/TR 13624-2:2009(E) ISO 2009 All rights reserved 1Petroleum and natural gas industries Drilling and production equipment Part 2: Deepwater drilling riser methodologies, operations, and integrity t

23、echnical report 1 Scope This part of ISO 13624 pertains to mobile offshore drilling units that employ a subsea BOP stack deployed at the seafloor. It is intended that the drilling riser analysis methodologies discussed in this part of ISO 13624 be used and interpreted in the context of ISO 13624-1.

24、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 13624-1:2009, Petroleu

25、m and natural gas industries Drilling and production equipment Part 1: Design and operation of marine drilling riser equipment API RP 16Q:1993, Design, Selection, Operation and Maintenance of Marine Drilling Riser Systems 3 Terms and definitions For the purposes of this document, the following terms

26、 and definitions apply. 3.1 accumulator BOP pressure vessel charged with gas (e.g. nitrogen) over liquid and used to store hydraulic fluid under pressure for operation of blowout preventers 3.2 accumulator riser tensioner pressure vessel charged with gas (e.g. nitrogen) over liquid that is pressuriz

27、ed on the gas side from the tensioner high-pressure gas supply bottles and supplies high-pressure hydraulic fluid to energize the riser tensioner cylinder 3.3 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 form

28、ing an air-filled annulus around the outside of the riser pipe ISO/TR 13624-2:2009(E) 2 ISO 2009 All rights reserved3.4 annulus space between two pipes, when one pipe is positioned inside the other 3.5 apparent weight effective weight submerged weight riser weight in air minus buoyancy NOTE Apparent

29、 weight is commonly referred to as weight in water, wet weight, submerged weight or effective weight. 3.6 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. 3.7 ball joint ball-a

30、nd-socket assembly having a central through passage that has an internal diameter equal to or greater than that of the riser and that may be positioned in the riser string to reduce local bending stresses 3.8 blowout uncontrolled flow of well fluids from the well bore 3.9 blowout preventer BOP devic

31、e attached immediately above the casing, which can be closed to shut in the well 3.10 blowout preventer annular type remotely controlled device that can form a seal in the annular space around any object in the well bore or upon itself NOTE Compression of a reinforced elastomer packing element by hy

32、draulic pressure affects the seal. 3.11 BOP stack assemblage 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). 3.12 box female memb

33、er of a riser coupling, C&K line stab assembly or auxiliary line stab assembly 3.13 buoyancy-control line auxiliary line dedicated to controlling, charging or discharging air-can buoyancy chambers 3.14 buoyancy modules devices added to riser joints to reduce their apparent weight, thereby reducing r

34、iser top tension requirements ISO/TR 13624-2:2009(E) ISO 2009 All rights reserved 33.15 choke-and-kill lines C&K lines kill line external conduits arranged laterally along the riser pipe and used for circulation of fluids into and out of the well bore to control well pressure 3.16 control pod assemb

35、ly of subsea valves and regulators that, when activated from the surface, directs hydraulic fluid through special porting to operate BOP equipment 3.17 coupling mechanical means of joining two sections of riser pipe in an end-to-end engagement 3.18 diverter device attached to the wellhead or marine

36、riser to close the vertical flow path and direct well flow away from the drill floor and rig 3.19 drift-off unplanned lateral move of a dynamically positioned vessel off its intended location relative to the wellhead, generally caused by loss of either stationkeeping control or propulsion 3.20 drill

37、ing 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 transmission medium for well data 3

38、.21 drive-off unplanned move of a dynamically positioned vessel off location driven by the vessels main propulsion or stationkeeping thrusters 3.22 dynamic positioning automatic stationkeeping computerized means of maintaining a vessel on location by selectively driving and/or directing thrusters 3.

39、23 effective tension axial tension that is calculated at any point along a riser in water considering only the top tension and the apparent weight of the riser and its contents NOTE See ISO 13624-1:2009, 5.4.3, and Sparks, 1984. 3.24 factory acceptance testing FAT testing by a manufacturer of a part

40、icular product to validate its conformance to performance specifications and ratings ISO/TR 13624-2:2009(E) 4 ISO 2009 All rights reserved3.25 fill valve valve used to fill the riser with seawater to prevent riser collapse 3.26 fleet angle marine riser angle between the vertical axis and a riser ten

41、sioner line at the point where the line connects to the telescopic joint NOTE This angle changes with change in elevation of the vessel. 3.27 flex joint steel and elastomer assembly having a central through-passage area equal to or greater than the riser bore NOTE Flex joints are commonly placed at

42、the bottom of the riser to reduce local bending stresses at the transition from riser to lower marine riser package. 3.28 heave vessel motion in the vertical direction 3.29 hot-spot stress local peak stress highest stress in the region or component under consideration, which causes no significant di

43、stortion and is principally objectionable as a possible initiation site for a fatigue crack NOTE These stresses are highly localized and occur at geometric discontinuities. 3.30 hydraulic connector a mechanical device that is activated hydraulically and connects the BOP stack to the wellhead or the

44、LMRP to the BOP stack 3.31 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 3.32 jumper hose flexible section of choke, kill or auxiliary line that provides a continuous flow around a flex/ball joint w

45、hile accommodating the angular motion at the flex/ball joint 3.33 lower marine riser package LMRP upper section of a two-section subsea BOP stack consisting of a hydraulic connector, annular BOP, ball/flex joint, riser adapter, jumper hoses for the choke, kill and auxiliary lines, and subsea control

46、 pods NOTE The LMRP lands in the top of the lower subsea BOP stack. 3.34 mud-boost line auxiliary line that provides a 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 riser, when required ISO/TR 13624-

47、2:2009(E) ISO 2009 All rights reserved 53.35 pin male member of a riser coupling or a choke, kill or auxiliary line stab assembly 3.36 pup joint shorter-than-standard length riser joint 3.37 response amplitude operator RAO regular waves ratio of a vessels motion to the wave amplitude causing that mo

48、tion and presented over a range of wave periods 3.38 riser adapter crossover between riser and flex/ball joint 3.39 riser disconnect operation of unlatching of the riser connector to separate the riser and LMRP from the BOP stack 3.40 riser joint section of the riser main tube having ends fitted wit

49、h a box and pin and including choke, kill and (optional) auxiliary lines and their support brackets 3.41 riser main tube riser pipe seamless or electric welded pipe that forms the principal conduit of the riser joint that guides the drill string and contains the return fluid flow from the well 3.42 riser string deployed assembly of riser joints 3.43 riser tensioner means for providing and maintaining top tension on the deployed riser string to prevent buckling 3.44 riser tensioner ring structural interfa