Download

DNV OFFSHORE CODES

DET NORSKE VERITAS

AMENDMENTS AND CORRECTIONS

NOVEMBER 2009Rev.1 2009-11-25

FOREWORDDET NORSKE VERITAS (DNV) is an autonomous and independent foundation with the objectives of safeguarding life, prop-erty and the environment, at sea and onshore. DNV undertakes classification, certification, and other verification and consultancyservices relating to quality of ships, offshore units and installations, and onshore industries worldwide, and carries out researchin relation to these functions.DNV Offshore Codes consist of a three level hierarchy of documents:— Offshore Service Specifications. Provide principles and procedures of DNV classification, certification, verification and con-

sultancy services.— Offshore Standards. Provide technical provisions and acceptance criteria for general use by the offshore industry as well as

the technical basis for DNV offshore services.— Recommended Practices. Provide proven technology and sound engineering practice as well as guidance for the higher level

Offshore Service Specifications and Offshore Standards.DNV Offshore Codes are offered within the following areas:A) Qualification, Quality and Safety MethodologyB) Materials TechnologyC) StructuresD) SystemsE) Special FacilitiesF) Pipelines and RisersG) Asset OperationH) Marine OperationsJ) Wind TurbinesO) Subsea Systems

Comments may be sent by e-mail to [email protected] subscription orders or information about subscription terms, please use [email protected] information about DNV services, research and publications can be found at http://www.dnv.com, or can be obtained from DNV, Veritasveien 1, N-1322 Høvik, Norway; Tel +47 67 57 99 00, Fax +47 67 57 99 11.

© Det Norske Veritas. All rights reserved. No part of this publication may be reproduced or transmitted in any form or by any means, including photocopying and recording, without the prior written consent of Det Norske Veritas.

Computer Typesetting (Adobe FrameMaker) by Det Norske Veritas.Printed in Norway

If any person suffers loss or damage which is proved to have been caused by any negligent act or omission of Det Norske Veritas, then Det Norske Veritas shall pay compensation to such personfor his proved direct loss or damage. However, the compensation shall not exceed an amount equal to ten times the fee charged for the service in question, provided that the maximum compen-sation shall never exceed USD 2 million.In this provision "Det Norske Veritas" shall mean the Foundation Det Norske Veritas as well as all its subsidiaries, directors, officers, employees, agents and any other acting on behalf of DetNorske Veritas.

DNV Offshore Codes, Amendments and Corrections, November 2009 Contents – Page 3

CONTENTS

Sec. 1 Current DNV Offshore Codes ............................. 5

Sec. 2 Offshore Class Related Documents Published Electronically....................................... 8

Sec. 3 Amended Offshore Service Specifications.......... 9DNV-OSS-302: Offshore Riser Systems, October 2003................... 9DNV-OSS-305: Rules for Certification and Verification of Diving Systems, January 2004........................................................... 9DNV-OSS-308: Verification of Lifting Appliances for the Oil and Gas Industry, June 2005..................................................................... 9DNV-OSS-309: Verification, Certification and classification of gas Export and receiving terminals, January 2005 ............................ 9DNV-OSS-401: Technology Qualification Management, July 2006 .......................................................................................... 9

Sec. 4 Amended Offshore Standards ........................... 10DNV-OS-C501: Composite Components, January 2003 ................ 10DNV-OS-C502: Offshore Concrete Structures, April 2007............ 10DNV-OS-C503: Concrete LNG Terminal Structures and Containment Systems, October 2004............................................... 10DNV-OS-E303: Offshore Mooring Fibre Ropes, October 2008..... 10DNV-OS-E402: Offshore Standard for Diving System, January 2004 .................................................................................... 12DNV-OS-F101: Submarine Pipeline Systems, October 2007 ......... 13DNV-OS-F201: Dynamic Risers, 2001 ........................................... 15DNV-OS-J101: Design of Offshore Wind Turbine Structures, October 2007 ................................................................. 17DNV-OS-J102: Design and Manufacture of Wind Turbine Blades, Offshore and Onshore Wind Turbines, October 2006..................... 17

Sec. 5 Amended Recommended Practices ................... 18DNV-RP-B401: Cathodic Protection Design, January 2005.......... 18DNV-RP-C103: Column-Stabilised Units, February 2005 ............. 19

DNV-RP-C201: Buckling Strength of Plated Structures, October 2002 ................................................................................... 19DNV-RP-C202: Buckling Strength of Shells, October 2002 .......... 21DNV-RP-C203: Fatigue Design of Offshore Steel Structures ........ 21DNV-RP-C204: Design against Accidental Loads, November 2004 ............................................................................... 22DNV-RP-C205: Environmental Conditions and Environmental Loads, April 2007 ................................................... 22DNV-RP-C206: Fatigue Methodology of Offshore Ships, October 2006 ................................................................................... 24DNV-RP-C207: Statistical Representation of Soil Data, April 2007........................................................................................ 24DNV-RP-E402: Naval Rescue Submersibles, April 2004 .............. 24DNV-RP-E403: Hyperbaric Evacuation Systems, December 2006................................................................................ 24DNV-RP-F101: Corroded Pipelines, October 2004 ........................ 24DNV-RP-F102: Pipeline Field Joint Coating and Field Repair of Linepipe Coating, October 2003...................................................... 25DNV-RP-F103: Cathodic Protection of Submarine Pipelines by Galvanic Anodes, October 2003...................................................... 25DNV-RP-F106: Factory Applied External Pipeline Coatings for Corrosion Control, October 2003 .................................................... 27DNV-RP-F107: Risk Assessment of Pipeline Protection, March 2001...................................................................................... 28DNV-RP-F109: On-Bottom Stability Design of Submarine Pipelines, October 2007 ................................................ 28DNV-RP-F111: Interference Between Trawl Gear and Pipelines, October 2006 ................................................................................... 29DNV-RP-F202: Composite Risers, May 2003 ................................ 30DNV-RP-F204: Riser Fatigue, July 2005........................................ 30DNV-RP-F205: Global Performance Analysis of Deepwater Floating Structures, October 2004................................. 30DNV-RP-G101: Risk Based Inspection of Offshore Topsides Static Mechanical Equipment, April 2009................................................. 30

DET NORSKE VERITAS

DNV Offshore Codes, Amendments and Corrections, November 2009Page 4 – Contents

DET NORSKE VERITAS

DNV Offshore Codes, Amendments and Corrections, November 2009 Sec.1 – Page 5

SECTION 1CURRENT DNV OFFSHORE CODES

Table 1 Current DNV Offshore Codes

DNV Offshore Codes Printed version Date of amendment

Latest update of Adobe PDF

fileOffshore Service SpecificationsDNV-OSS-101 Rules for Classification of Offshore Drilling and Support Units

Printed version not available. Published electronically only, see Sec.2 Table 1

DNV-OSS-102 Rules for Classification of Floating Production, Storage and Loading Units

DNV-OSS-103 Rules for Classification of LNG/LPG Floating Production and Stor-age Units or Installations

DNV-OSS-121 Classification based on Performance Criteria Determined from Risk Assessment Methodology

DNV-OSS-201 Verification for Compliance with Norwegian Shelf LegislationDNV-OSS-202 Verification for Compliance with UK Shelf RegulationsDNV-OSS-300 Risk Based Verification April 2004 – April 2004DNV-OSS-301 Certification and Verification of Pipelines October 2000 – October 2000DNV-OSS-302 Offshore Riser Systems October 2003 April 2009 April 2009DNV-OSS-304 Risk Based Verification of Offshore Structures October 2006 – October 2006DNV-OSS-305 Rules for Certification and Verification of Diving Systems January 2004 October 2007

April 2008October 2008October 2009

October 2009

DNV-OSS-306 Verification of Subsea Facilities June 2004 – June 2004DNV-OSS-307 Verification of Process Facilities June 2004 – June 2004DNV-OSS-308 Verification of Lifting Appliances for the Oil and Gas Industry June 2005 October 2008 October 2008DNV-OSS-309 Verification, Certification and Classification of Gas Export and Re-

ceiving Terminals January 2005 April 2005

October 2007October 2009

October 2009

DNV-OSS-312 Certification of Tidal and Wave Energy Converters October 2008 – October 2008DNV-OSS-313 Pipe Mill and Coating Yard - Qualification April 2009 – April 2009DNV-OSS-401 Technology Qualification Management July 2006 April 2007 April 2007Offshore StandardsDNV-OS-A101 Safety Principles and Arrangement


DNV-OS-B101 Metallic MaterialsDNV-OS-C101 Design of Offshore Steel Structures, General (LRFD method)DNV-OS-C102 Structural Design of Offshore ShipsDNV-OS-C103 Structural Design of Column Stabilised Units (LRFD method)DNV-OS-C104 Structural Design of Self-elevating Units (LRFD method)DNV-OS-C105 Structural Design of TLPs (LRFD method)DNV-OS-C106 Structural Design of Deep Draught Floating Units/Spars (LRFD and

WSD Method)DNV-OS-C107 Structural Design of Ship-shaped Drilling and Well Service UnitsDNV-OS-C201 Structural Design of Offshore Units (WSD method)DNV-OS-C301 Stability and Watertight IntegrityDNV-OS-C401 Fabrication and Testing of Offshore StructuresDNV-OS-C501 Composite Components January 2003 April 2009 April 2009DNV-OS-C502 Offshore Concrete Structures April 2007 April 2009 April 2009DNV-OS-C503 Concrete LNG Terminal Structures and Containment Systems October 2004 April 2009 April 2009DNV-OS-D101 Marine and Machinery Systems and Equipment


DNV-OS-D201 Electrical InstallationsDNV-OS-D202 Automation, Safety, and Telecommunication SystemsDNV-OS-D301 Fire ProtectionDNV-OS-E101 Drilling PlantDNV-OS-E201 Oil and Gas Processing SystemsDNV-OS-E301 Position MooringDNV-OS-E302 Offshore Mooring ChainDNV-OS-E303 Offshore Mooring Fibre Ropes October 2008 April 2009 April 2009

DET NORSKE VERITAS

DNV Offshore Codes, Amendments and Corrections, November 2009Page 6 – Sec.1

DNV-OS-E304 Offshore Mooring Steel Wire Ropes Printed version not available. Published electronically only, see Sec.2 Table 1

DNV-OS-E401 Helicopter Decks Printed version not available. Published electronically only, see Sec.2 Table 1

DNV-OS-E402 Offshore Standard for Diving Systems January 2004 April 2004October 2004

April 2007October 2007October 2008

April 2009October 2009

October 2009

DNV-OS-E403 Offshore Loading Buoys Printed version not available. Published electronically only, see Sec.2 Table 1

DNV-OS-E406 Design of Free Fall Lifeboats April 2009 – April 2009DNV-OS-F101 Submarine Pipeline Systems October 2007 April 2008


DNV-OS-F201 Dynamic Risers January 2001 October 2001October 2003October 2009

October 2009

DNV-OS-J101 Design of Offshore Wind Turbine Structures October 2007 October 2007October 2008

December 2008November 2009

November 2009

DNV-OS-J102 Design and Manufacture of Wind Turbine Blades, Offshore and Onshore Wind Turbines

October 2006 April 2007 April 2007

DNV-OS-J201 Offshore Substations for Wind Farms October 2009 – October 2009Recommended PracticesDNV-RP-A201 Plan Approval Documentation Types – Definitions – – October 2009DNV-RP-A203 Qualification Procedures for New Technology September 2001 – September 2001DNV-RP-B101 Corrosion Protection of Floating Production and Storage Units April 2007 – April 2007DNV-RP-B401 Cathodic Protection Design January 2005 April 2005

October 2005April 2006


April 2008

April 2008

DNV-RP-C101 Allowable Thickness Diminution for Hull Structure of Offshore Ships

April 2007 – April 2007

DNV-RP-C102 Structural Design of Offshore Ships February 2002 – February 2002DNV-RP-C103 Column Stabilised Units February 2005 April 2008

April 2009April 2009

DNV-RP-C201 Buckling Strength of Plated Structures October 2002 April 2003April 2004


October 2008

DNV-RP-C202 Buckling Strength of Shells October 2002 April 2005 April 2005DNV-RP-C203 Fatigue Design of Offshore Steel Structures April 2008 October 2008 October 2008DNV-RP-C204 Design against Accidental Loads November 2004 April 2005 April 2005DNV-RP-C205 Environmental Conditions and Environmental Loads April 2007 October 2007


April 2009June 2009

June 2009

DNV-RP-C206 Fatigue Methodology of Offshore Ships October 2006 April 2007 April 2007DNV-RP-C207 Statistical Representation of Soil Data April 2007 October 2007 October 2007DNV-RP-D101 Structural Analysis of Piping Systems October 2008 – October 2008DNV-RP-D201 Integrated Software Dependent Systems October 2009 – October 2009DNV-RP-E101 Recertification of Well Control Equipment October 2008 – October 2008DNV-RP-E301 Design and Installation of Fluke Anchors in Clay 2000 – 2000DNV-RP-E302 Design and Installation of Drag-in Plate Anchors in Clay December 2002 – December 2002DNV-RP-E303 Geotechnical Design and Installation of Suction Anchors in Clay October 2005 – October 2005DNV-RP-E304 Damage Assessment of Fibre Ropes for Offshore Mooring April 2005 – April 2005DNV-RP-E401 Survey of Diving Systems – – April 2007

Table 1 Current DNV Offshore Codes (Continued)



file

DET NORSKE VERITAS


DNV-RP-E402 Naval Rescue Submersibles – October 2008April 2009

April 2009

DNV-RP-E403 Hyperbaric Evacuation Systems – April 2007October 2008October 2009

October 2009

DNV-RP-F101 Corroded Pipelines October 2004 October 2006 October 2006DNV-RP-F102 Pipeline Field Joint Coating and Field Repair of Linepipe Coating October 2003 October 2003


April 2006

April 2006

DNV-RP-F103 Cathodic Protection of Submarine Pipelines by Galvanic Anodes October 2003 April 2004October 2005


April 2008

April 2008

DNV-RP-F105 Free Spanning Pipelines February 2006 – February 2006DNV-RP-F106 Factory Applied External Pipeline Coatings for Corrosion Control October 2003 April 2004

October 2005April 2006

April 2006

DNV-RP-F107 Risk Assessment of Pipeline Protection March 2001 October 2002 October 2002DNV-RP-F108 Fracture Control for Pipeline Installation Methods Introducing

Cyclic Plastic StrainJanuary 2006 – January 2006

DNV-RP-F109 On-Bottom Stability Design of Submarine Pipelines October 2007 October 2008April 2009

April 2009

DNV-RP-F110 Global Buckling of Submarine PipelinesStructural Design due to High Temperature/High Pressure

October 2007 – October 2007

DNV-RP-F111 Interference Between Trawl Gear and Pipelines October 2006 April 2007April 2009

April 2009

DNV-RP-F112 Design of Duplex Stainless Steel Subsea Equipment Exposed to Cathodic Protection

October 2008 – October 2008

DNV-RP-F113 Pipeline Subsea Repair October 2007 – October 2007DNV-RP-F116 Integrity Management of Submarine Pipeline Systems October 2009 – October 2009DNV-RP-F201 Design of Titanium Risers October 2002 – October 2002DNV-RP-F202 Composite Risers May 2003 April 2009 April 2009DNV-RP-F203 Riser Interference April 2009 – April 2009DNV-RP-F204 Riser Fatigue July 2005 April 2009 April 2009DNV-RP-F205 Global Performance Analysis of Deepwater Floating Structures October 2004 April 2009 April 2009DNV-RP-F206 Riser Integrity Management April 2008 – April 2008DNV-RP-F301 Subsea Separator Structural Design April 2007 – April 2007DNV-RP-G101 Risk Based Inspection of Offshore Topsides Static Mechanical

EquipmentApril 2009 October 2009 October 2009

DNV-RP-G103 Non-intrusive Inspection – – October 2007DNV-RP-H101 Risk Management in Marine and Subsea Operations January 2003 – January 2003DNV-RP-H102 Marine operations during Removal of Offshore Installations April 2004 – April 2004DNV-RP-H103 Modelling and Analysis of Marine Operations April 2009 – April 2009DNV-RP-O401 Safety and Reliability of Subsea Systems April 1985 – April 1985DNV-RP-O501 Erosive Wear in Piping Systems 2005 – 2007

Table 1 Current DNV Offshore Codes (Continued)



file

DET NORSKE VERITAS


SECTION 2OFFSHORE CLASS RELATED DOCUMENTS

PUBLISHED ELECTRONICALLY

New update schemeSince they are fully electronic and not printed, the class relateddocuments shown in Table 1 follow a different update schemethan the other offshore documents (shown in Sec.1 Table 1):

1) Whenever revised, or undergoing significant editorialchanges, a class related document will be given a new edi-tion date and the main changes will be described on Page3 of that document. The corresponding Adobe PDF filewill be made available form the Webshop and the date ofthe “Current edition” column of Table 1 will be updated.

2) If, at a later date, the need arises for insignificant editorialcorrections to the document, the electronic file will be up-dated, but the edition date will be retained. However, anew Adobe PDF file will be generated and made available

from the Webshop. The date of the PDF file will appear inthe right most column of Table 1.

3) The next time the document is subject to revision or signif-icant editorial changes, step 1) is repeated. In addition, thedate(s) in right most column will be deleted.

When step 2) is relevant, no description of the related insignif-icant editorial corrections is deemed necessary and is omittedfrom Sec.3 and 4. If, for some reason, such corrections are ofinterest, these may be provided on request.In order to ensure a practical transition from the “print” schemeto the “electronic” scheme, all documents in Table 1 have beengiven the edition date “October 2008”.

Table 1 Offshore class related documents only published electronically (not printed)

DNV Offshore Documents Previous edition

Current edition 1)

Editorial corrections,

Adobe PDF file updates 1) 2)

Offshore Service SpecificationsDNV-OSS-101 Rules for Classification of Offshore Drilling and Support Units April 2009 October 2009 –DNV-OSS-102 Rules for Classification of Floating Production, Storage and

Loading UnitsOctober 2008 October 2009 –

DNV-OSS-103 Rules for Classification of LNG/LPG Floating Production and Storage Units or Installations

May 2001 October 2008 October 2009

DNV-OSS-121 Classification based on Performance Criteria Determined from Risk Assessment Methodology

May 2001 October 2008 –

DNV-OSS-201 Verification for Compliance with Norwegian Shelf Legislation October 2007 October 2008 October 2009DNV-OSS-202 Verification for Compliance with UK Shelf Regulations March 2001 October 2008 –Offshore StandardsDNV-OS-A101 Safety Principles and Arrangement October 2005 October 2008 October 2009DNV-OS-B101 Metallic Materials October 2008 April 2009 –DNV-OS-C101 Design of Offshore Steel Structures, General (LRFD method) April 2004 October 2008 October 2009DNV-OS-C102 Structural Design of Offshore Ships April 2004 October 2008 October 2009DNV-OS-C103 Structural Design of Column Stabilised Units (LRFD method) April 2004 October 2008 October 2009DNV-OS-C104 Structural Design of Self-elevating Units (LRFD method) October 2004 October 2008 April 2009DNV-OS-C105 Structural Design of TLPs (LRFD method) October 2005 October 2008 October 2009DNV-OS-C106 Structural Design of Deep Draught Floating Units/Spars (LRFD

and WSD Method)January 2001 October 2008 October 2009

DNV-OS-C107 Structural Design of Ship-shaped Drilling and Well Service Units

April 2008 October 2008 October 2009

DNV-OS-C201 Structural Design of Offshore Units (WSD method) April 2005 October 2008 October 2009DNV-OS-C301 Stability and Watertight Integrity January 2001 October 2008 October 2009DNV-OS-C401 Fabrication and Testing of Offshore Structures October 2008 October 2009 –DNV-OS-D101 Marine and Machinery Systems and Equipment October 2005 October 2008 October 2009DNV-OS-D201 Electrical Installations January 2008 October 2008 October 2009DNV-OS-D202 Automation, Safety, and Telecommunication Systems April 2008 October 2008 –DNV-OS-D301 Fire Protection October 2005 October 2008 October 2009DNV-OS-E101 Drilling Plant October 2008 October 2009 –DNV-OS-E201 Oil and Gas Processing Systems October 2005 October 2008 October 2009DNV-OS-E301 Position Mooring October 2004 October 2008 October 2009DNV-OS-E302 Offshore Mooring Chain – October 2008 October 2009DNV-OS-E304 Offshore Mooring Steel Wire Ropes – April 2009 October 2009DNV-OS-E401 Helicopter Decks March 2001 October 2008 October 2009DNV-OS-E403 Offshore Loading Buoys April 2005 October 2008 –1) The latest PDF file updates are available for download from http://webshop.dnv.com/global/.2) All editorial corrections have been incorporated (no description of these corrections is found in Sec.3 or 4).

DET NORSKE VERITAS

http://webshop.dnv.com/global


SECTION 3AMENDED OFFSHORE SERVICE SPECIFICATIONS

Note: Changes to class related documents (documents published electronically only) are not included. See Sec.2.

DNV-OSS-302: Offshore Riser Systems, October 2003

Changes Published April 2009

GeneralAny reference to Classification Notes No. 30.5 has been cor-rected to DNV-RP-C205.

DNV-OSS-305: Rules for Certification and Verification of Diving Systems, January 2004

Changes Published October 2009

Sec.1 Page 9DNV-RP-A201 has been re-established, and as a result, sub-section element C300 has been amended as follows:C 300 Recommended practices301 The latest revision of the following documents apply:


General“DNV Rules for Certification of Lifting Appliances” has beenreplaced by the “DNV Standard for Certification No. 2.22 Lift-ing Appliances” and the references have been changed accord-ingly.


Sec.2 Page 12Item C701 has been amended and now reads:701 DNV Classification is described in Sec.2 G of this OSS,in DNV-OSS-101 "Rules for Classification of Offshore Drill-ing and Support Units" and in DNV Rules for Ships.


Sec.1 Page 9Due to the withdrawal of DNV-RP-A201 (replaced by Guide-line No. 17), item C300 has been amended as follows:C 300 DNV Guidelines301 The latest revision of the following documents apply:

DNV-OSS-308: Verification of Lifting Appliances for the Oil and Gas Industry, June 2005


App.B Page 13“DNV Rules for Certification of Lifting Appliances” has beenreplaced by the “DNV Standard for Certification No. 2.22 Lift-ing Appliances” and the reference in item D401 has beenchanged accordingly.

DNV-OSS-309: Verification, Certification and classifica-tion of gas Export and receiving terminals, January 2005


Sec.4 Page 17DNV-RP-A201 has been re-established, and as a result, therow concerning Guideline no. 17 in Table C2 has been amend-ed as follows:


Sec.4 Page 17In Table C2, the row covering DNV-RP-A202 has been deletedand the row covering DNV-RP-A201 has been changed to:


Sec.2 Page 9In item A102, under “Statutory Certification”, the reference toSec.2 C300 has been corrected to Sec.4 A300.Sec.4 Page 15In item B601, the numbering of “Table A3” has been correct-ed to “Table B3”.

DNV-OSS-401: Technology Qualification Management, July 2006


Sec.3 Page 11In item A401, the text “product pertification” has been cor-rected to “product certification”.

Table C3 Recommended practicesReference TitleDNV-RP-A201 Plan Approval Documentation Types –

Definitions

Table C3 DNV GuidelinesReference TitleGuideline No. 17 Plan Approval Documentation Types –

Definitions

DNV-RP-A201 Plan Approval Documentation Types – Definitions

Guideline No. 17 Plan Approval Documentation Types – Definitions

DET NORSKE VERITAS


SECTION 4AMENDED OFFSHORE STANDARDS

Note: Changes to class related documents (documents published electronically only) are not included. See Sec.2.

DNV-OS-C501: Composite Components, January 2003



DNV-OS-C502: Offshore Concrete Structures, April 2007



DNV-OS-C503: Concrete LNG Terminal Structures and Containment Systems, October 2004




Sec.6 Page 26The reference in item B602 is corrected to read:DNV-OS-C502 P500App.D Page 52The reference in item A402, list item b),ii), is corrected to read:Sec.8 B

DNV-OS-E303: Offshore Mooring Fibre Ropes, October 2008


Ch.1 Sec.1 Page 9The title of A 500 has been changed and now reads:A 500 Types of Offshore Mooring Fibre Rope Assemblies

A new item A505 has been added as follows, and succeedingitems have been renumbered:

505 Termination hardware is required to fit and support theeye and should be made of steel.

In item A506 (prev. A505), the word “steel” has been deleted:

Item A507 (prev. A506), has been amended and now reads:507 If the fibre-rope segment is connected directly to an H-link, then the H-link (with pin) is considered ‘terminationhardware’.

Guidance note:For other types of fibre-rope terminations than the spliced eye,none exist at the time of this standard with an appropriate levelof qualification as defined in DNV-RP-A203. The same appliesto other materials for termination hardware than steel.The fibre-rope assembly includes fibre rope with spliced eyesand termination hardware. Normally thimbles are used in thespliced eyes, and then the connecting shackles (or H-links) areoutside the scope of this standard.

---e-n-d---of---G-u-i-d-a-n-c-e---n-o-t-e---

A new item A508 has been added as follows, and succeedingitems have been renumbered:508 Shackles and H-links shall comply with DNV-OS-E302.

Ch.1 Sec.1 Page 10In the Guidance note in item A701 the text “Annex D of” hasbeen deleted:In Table B1 the following reference has been added:

The Guidance note below Table B1 has been deleted.

Ch.1 Sec.1 Page 11In item C213, first sentence, the word “assembly” has beenchanged to “segment”:

Ch.2 Sec.2 Page 16The title of Section 2 has been changed to: DESIGN VERIFICATIONIn item A103, first line, the word “review” has been changedto “verification”.The upper part of Table A1 has been amended and now reads:

DNV-OS-B101 Metallic Materials

Table A1 Documentation requirements - End UserUser specification issued to Rope Manufacturer.In-service condition control scheme including use of inserts.Mooring-system lay out and type of service.

DET NORSKE VERITAS


Table A2 has been amended and now reads as follows:

New Sub-sections A400 and A500 have been added and suc-ceeding subsections have been renumbered. Items A401 andA501 are moved from the previous A202 and A203 respectively:A 400 User specification401 The user specification shall contain all informationabout required strength, service life, change-in-length per-formance, length of segments etc. that is required for the ropemanufacturer to make the right rope for the application.A 500 In-service Condition Assessment scheme501 The in-service condition assessment scheme shall com-pletely describe the methods and techniques for assessing thecondition of the fibre-rope assemblies during service. Exami-nations and tests to be performed on inserts shall be described,together with plan for retrieval and evaluation criteria. Instruc-tions for ROV checking of the termination areas shall includedimensional verification of the eyes and splices, their seatingand alignment on the termination hardware and checks for po-tential chafing.

Ch.2 Sec.2 Page 17A new Sub-section A900 has been added. Items A901 and A902are moved from the previous A604 and A605 respectively:

A 900 Handling and Installation procedure901 The procedure for handling and installation shall containthe necessary instructions and limitations set to protect the in-tegrity of the fibre-rope assemblies between manufacture andinstalled condition.902 Restrictions with respect to sea-bed contact shall be con-spicuously stated.

Ch.2 Sec.3 Page 18In the Guidance note in item A101 the text “, Sec. 4.1.1, page 3,”has been deleted:Sub-section B200 has been amended and now reads:B 200 Thimbles201 The material in thimbles shall comply with the require-ments to mechanical properties of grades NV D as given inDNV-OS-B101.202 Manufacturing by welding shall comply with DNV-OS-C401.203 Other materials, such as polymers and fibre-reinforcedcomposites can be used if they have been qualified based onDNV-RP-A203.

Guidance note:Which set of mechanical properties should be chosen for thethimble material will depend on the loading. Two examples aregiven below.If the mechanical properties of NV D620 are used as basis, thenthe thimble material shall meet the following requirements:

If the mechanical properties of NV DW32 are used as basis, thenthe thimble material shall meet the following requirements:

The NV D steel grades are defined in DNV-OS-B101 for rolledsteels; however for the purpose of DNV-OS-E303 the mechani-cal properties are applicable to all steels applied in thimbles.Guidance on composite components may be found in DNV-OS-C501.


In the Guidance note in item C102 the last paragraph has beenamended and now reads:It is a requirement of ISO 18962 that the load-bearing ropeshould have a resulting tenacity not less than 0.47 N/tex. Therequired strength for different sizes of rope is tabulated.

Ch.2 Sec.3 Page 19In the Guidance note in item C302 the last paragraph has beenamended and now reads:For determination of the optimum size of a rope, normalisationwith the average strength 'AVS' can be useful since this is aproperty of the rope.

Ch.2 Sec.4 Page 22In the Guidance note in item A202 the last paragraph has been

Table A2 Documentation requirements - Rope ManufacturerProcedure for handling and installation.Manufacturing specification describing how the rope is manufac-tured including manufacturing specification for splices.Rope design specification:1) Type of fibre rope construction2) Type of termination3) Linear density and weight pr. unit length of fibre rope in sea water4) Minimum Breaking Strength5) Post-Installation Stiffness6) Static Stiffness7) Storm Stiffness8) Performance criteria for insert material during design life,

at time of extraction.9) Residual Performance - End of design life10) Total Elongation of Fibre Rope Segments.Testing specification:The testing specification shall be specific to the tests that shall be per-formed, i.e. there shall be no room for interpretation of standards etc.Test reportsQuality plan for rope manufacturing.Specification of load bearing yarns.Documentation of approval of load-bearing yarns.Load bearing yarn properties, manufacturer’s doc.Load bearing yarn properties, verification of yarn supply.Documentation of material for the fibre rope sheathing, consisting of soil-ingress barrier and jacket.— Manufacturer and manufacturing plant— Designation— Sheathing weight/thickness— Permeability— UV resistance— Hydrolysis resistance— Resistance to chemicals.Materials for spliced-eye protection.Documentation of the termination hardware material, production and repair methods.Documentation of the termination hardware’s structural strength.Certificates for termination hardware.Description of rope manufacturer’s quality system.Rope manufacturer’s approval of sub contractors’ quality system.

Tensile strength: 720 - 890 MPaYield stress: 620 MPaElongation: 15%Average longitudinal impact toughness: 62 J at -20°C Average transverse impact toughness: 41 J at -20°C

Tensile strength: 440 - 590 MPaYield stress: 270 MPaElongation: 22%Average transverse impact toughness: 44 J at -20°C Single transverse impact toughness: 31 J at -20°CAverage through thickness ductility: 35%

DET NORSKE VERITAS


amended and now reads:The gauge length for stretch measurements needs to be commen-surate with the accuracy of the length-measurement device. Ad-vice is provided in CI 1500.In item B102 the reference to “Appendix II” has been deleted.In item D103 the word “overnight” has been deleted.Ch.2 Sec.4 Page 23In item D202 the reference to “section B.3” has been deleted.Item D601 has been amended and now reads:601 Suitable methods for this measurement may be found inCI 1500 or ISO 18692.Sub-section E has been amended and now reads as follows:

E. Termination hardware

E 100 Testing as part of fibre-rope assembly101 One set of the termination hardware shall be tested aspart of fibre-rope assembly during break testing and fatiguetesting.E 200 Testing of thimbles201 The requirements to non-destructive testing of thimblesare given in DNV-OS-E304. Requirements to NDT for manu-facturing by welding are given in DNV-OS-C401.202 The methods for mechanical testing of thimbles are giv-en in DNV-OS-B101. For thimbles manufactured by weldingthe test methods are given in DNV-OS-C401.203 It is the responsibility of the rope manufacturer to definethe critical sections of the thimbles, and to ensure that suffi-cient materials testing is carried out on sacrificial item(s) pro-duced as part of the actual delivery.204 It shall be demonstrated that the sacrificial item(s) arerepresentative of the entire production series.

Ch.3 Sec.1 Page 27The title of Sub-section B. has been changed to: B. Mooring analysisItem B101 has been amended and now reads:101 Mooring system analysis is covered in DNV-OS-E301.The technical provisions are given in Chapter 2 and the certifica-tion and classification requirements are given in Chapter 3.In item C201 the word “assessment” has been changed to“verification” (twice).

Ch.3 Sec.2 Page 28In item A101, list-item “Design review” has been changed to“Design verification”.In item B101, first line, the word “assessment” has beenchanged to “verification”.

Ch.3 Sec.2 Page 29In item D104, Guidance note, the two last paragraphs have beenamended and now reads as follows:Examples on change-in-length tests can be found in API RP2SM, ISO 18692 or in CI 1500.Examples of torque-measurement testing and soil-ingress re-sistance testing can be found in ISO 18692. Item E102 has been amended and now reads as follows:102 This documentation shall be submitted in due time to al-low sufficient verification and comments with subsequent im-plementation.

Item F104 has been amended and now reads as follows:104 Prior to start of testing, the attending surveyor and theresponsible test engineer should review the approved testingspecification together.

Ch.3 Sec.2 Page 30Figure 1 have been slightly modified:

Figure 1 Documentation for certification of fibre-rope assemblies in moor-ing systems.

New items H202 and H203 have been added:202 Thimbles shall be certified according to the require-ments of this standard.203 Shackles and H-links shall be certified in accordancewith DNV-OS-E302.A New item H301 has been added, and previous item H301 hasbeen renumbered H302:301 The yarns that are to be used to make the fibre-rope seg-ments shall be approved.In item H302 (prev. H301), “3.1” has been changed to “3.2”.Item H401 has been amended and now reads:401 Fibre-rope assemblies will be furnished with DNV cer-tificates, issued by the DNV Surveyor.

Ch.3 App.E and App.F Page 37 and 38The two example certificates have been amended with a new“Certificate No.” in the upper right corner.

DNV-OS-E402: Offshore Standard for Diving System, January 2004

Changes Published October 2009Sec.1 Page 8DNV-RP-A201 has been re-established, and as a result, sub-section element B300 has been amended as follows:

DNV Certificates from Survey Stationfor fibre-rope assemblies.

Design Verification Report.

Test Reports- Strength.- Stiffness.- Fatigue, etc.

DNV certificates fortermination hardware.

Survey Report.

Manufacturer’sdocumentation.

User documentation- Specification.- Inspection

scheme.

Overview of surveyactivities per fibre-

rope segment.

Yarn certificates:- Producer.- Survey of

testing.

QA/QC review.

Production surveytowards

manufacturing spec.

DET NORSKE VERITAS


B 300 Recommended practices301 The latest revision of the following documents apply:

Sec.3 Page 24The Guidance note in B105 has been deleted.App.A Page 53The references to item B103 in App.A items A101, A202, B201,B303 and C102 have been corrected to “B102”.




General“DNV Rules for Certification of Lifting Appliances” has beenreplaced by the “DNV Standard for Certification No. 2.22 Lift-ing Appliances” and the references have been changed ac-cordingly.


Sec.1 Page 8Due to the withdrawal of DNV-RP-A201 (replaced by Guide-line No. 17), item B300 has been amended as follows:B 300 DNV Guidelines301 The latest revision of the following documents apply:


Sec.4 Page 31Table D1 has been deleted and Item E301 has been amendedas follows:301 In addition to the requirements in E105 all penetrationsfor lines designed for gas distribution (e.g. supply, exhaust andequalisation) shall be fitted with non-return valves or flow fus-es as approriate for the direction of gas flow. Lines specificallydesigned for non distribution purposes (e.g. analysis) shall bekept to the minimum diameter possible and limited to a maxi-mum of 5 mm.


Appendix A Page 54Previous item B103 “Motions of ship shaped support vessels”,has been renumbered 102.Appendix A Page 55In item B102, the formula for az has been corrected as follows:


Appendix A Page 54Under sub-section element A200, add the following item:202 Parameters applied for correction of units in empiricalformulae:

h1 = 1 m -1

L1 = 1 m -1u1 = 1 m/su2 = 1 m

DNV-OS-F101: Submarine Pipeline Systems, October 2007


Sec.1 Page 15In Sub-section B300, in the reference to DNV-RP-F112, thetext “Draft Issue April 2006” has been deleted.


GeneralThe D/t application range has been changed to D/t2 through-out the document.Sec.1 Page 15In sub-section B600, the following reference has been added:

Sec.1 Page 16In sub-section B600, the following reference has been added:

Sec.1 Page 22In items C332 and C333, the reference to “303”, has been cor-rected to “334”.Sec.1 Page 23 and 24In sub-section D100, the following abbreviations have beenadded:

MT Magnetic Particle TestingPT Penetrant TestingVT Visual Testing

and the following abbreviation has been changed:

EC Eddy Current Testing

Sec.5 Page 44The paragraph in Table 5-3, column 4, third row has been cor-rected and now reads:Special evaluation of accidental loads or other external loadsand excessive corrosion shall be included in the determinationof minimum required wall thicknessIn note 4) under Table 5-5, “U” has been corrected to “αU”.

Table B3 Recommended practicesReference TitleDNV-RP-A201 Plan Approval Documentation Types –

Definitions

Table B3 DNV GuidelinesReference TitleGuideline No. 17 Plan Approval Documentation Types –

Definitions

az5 h1 hs 0.02 h1 hs L1 L 1+–( ) g⋅

100-------------------------------------------------------------------------------------- {m/s2}=

ASTM A370 Standard Test Methods and Defini-tions for Mechanical Testing of Steel Products

ISO 8501-1 Preparation of steel substrates before application of paints and related prod-ucts -- Visual assessment of surface cleanliness -- Part 1: Rust grades and preparation grades of uncoated steel substrates and of steel substrates after overall removal of previous coatings

DET NORSKE VERITAS


Sec.5 Page 45In Table 5-6, the text “Supplementary requirement αU” hasbeen corrected to “Supplementary requirement U”.Sec.5 Page 47Equation 5.19a and b has been amended as follows:

The following has been added below Eq. 5.19b:Applies for D/t2 ≤ 45, Pi > Pe

Sec.5 Page 48Definition of “normalised effective force” (Under Eq. 5.21),has been corrected to:

SSd’ = SSd/Sp (normalised effective force)

Definition of “qh” (Under Eq. 5.21), has been deleted.

Eq. 5.23 has been corrected to:




Sec.5 Page 52In item E411, the last sentence: “The static analyses methodmay be expressed by:” has been deleted.Sec.6 Page 61In item D204, the reference to E205 has been corrected to 602.Sec.6 Page 62In item D402, the dash list has been changed to an alpha nu-meric list.

In item D405, the reference to “E502 Guidance Note” hasbeen corrected to “502 Guidance Note”.In item D406, the reference to “E403 and E605-E606” hasbeen corrected to “403 and 605-606”.Sec.6 Page 63In item D507, the reference to E505 and E506 has been cor-rected to 505 and 506.Sec.7 Page 67In item A605, the text “SMYS 485 MPa” has been corrected to“SMYS > 485 MPa”.Sec.7 Page 68In item B332, the definition of sr has been changed as follows:

sr = |Da - Db| / DbSec.7 Page 71In Table 7-5, the 2nd and 3rd bullet point under Note 4 has beenmerged.In Table 7-5, 3rd (prev. 4th) bullet point under Note 4, the text,“strip test pieces” has been changed to “rectangular test pieces”.Sec.7 Page 72In item B507, “heat” has been changed to “test unit” (Twoplaces).Sec.7 Page 78In item D303, the reference to A610 has been corrected toA609.The heading above item D405 has been corrected and nowreads:General requirements to manufacture of clad linepipe

In item D416, the reference to B331 has been corrected toB332.Sec.7 Page 84In item H102, the reference: “see B200” has been changed to:ref. B200, C200 and D200.The reference to “Table 6-1” in Table 7-20, has been correct-ed to “Table 7-1” (two places).Sec.7 Page 85In item I112, the reference to “E700” has been corrected to“D700”.In item I117, the following references have been added: “7-14and 7-15”.In item I118, the text “test unit” has been changed to “castingsequence”.A new paragraph has been added to item I201as follows:Testing shall be according to Table 7-24.Sec.7 Page 87In Table 7-25, Note 3 has been corrected and now reads:

3) Not more than 100 pipes with D < 508 mm and not morethan 50 pipes for D ≥ 508 mm.

Sec.7 Page 88In Table 7-26, four references to “Note 2” have been added.Sec.8 Page 89In item A201, the word “Subsection” has been changed to“Section”.In item A203, the reference to “Sec.6 B500” has been changedto “Sec.6”.In item B102, the reference “B400 - B700” has been correctedto “B300 - B600”.

(5.19a)

(5.19b)

(5.23)

(5.24)

(5.29)

(5.30)

( )( )

( ) ( ) 12

2

22

22

≤⎟⎟⎠

⎞⎜⎜⎝

⎛⋅−

⋅+⎪⎭

⎪⎬⎫

⎪⎩

⎪⎨⎧

⎪⎭

⎪⎬⎫

⎪⎩

⎪⎨⎧

⋅⋅⋅

+⋅

⋅⋅tp

pptS

pStM

M

bc

eip

pc

iSdSCm

pc

SdSCm α

ααγγ

αγγ

( ) ( )( ) 1,''

2

2

22

22 ≤⎟⎟⎠

⎞⎜⎜⎝

⎛⋅−

⋅+⎪⎭

⎪⎬⎫

⎪⎩

⎪⎨⎧

⎭⎬⎫

⎩⎨⎧ ⋅⋅

+⋅⋅tp

pptpStM

bc

eip

c

iSdSCm

c

SdSCm α

αα

γγα

γγ

⎪⎪⎩

⎪⎪⎨

⎧

≥−

⎟⎟⎠

⎞⎜⎜⎝

⎛ −−−

<−

−=

32131

321

b

ei

b

ei

b

ei

p

ppp

ppp

ppp

β

βα

⎪⎪⎩

⎪⎪⎨

⎧

>

≤≤⎟⎠⎞

⎜⎝⎛ −

<

=

60/0

60/1590

/6015/5.0

2

22

2

tDfor

tDfortD

tDfor

β

D/t ≤ 45, pi ≥ pe( )

εγεεε ec

RdSdppt −

=≤ min2 ,

( ) gwhb

eec tp

ppDtppt ααε ⋅⋅⎟⎟

⎠

⎞⎜⎜⎝

⎛ −⋅+⋅⎟

⎠⎞

⎜⎝⎛ −⋅=− − 5.1min

min 75.5101.078.0),(

DET NORSKE VERITAS


Sec.8 Page 90In item B312, the word “HOLD” has been deleted from the lastparagraph.Sec.8 Page 91In item B413, 6th list-item, “DP” has been corrected to “PT”.Sec.8 Page 95In item D101, the reference to “B400 and B500” has beenchanged to “B300 and B400”.The list in item D104, has been reformatted to improve thereadability”.Sec.8 Page 96In item E101, “lot” has been changed to “test unit”.Sec.8 Page 97In Table 8-4, the reference to “E109” has been corrected to“E108”, and the reference to “C200” has been corrected to“C500”.Sec.13 Page 134Table 13-3 has been corrected for misprints and now reads:

Sec.13 Page 135Eq. 13.10 has been corrected as follows:

Sec.13 Page 136 and 137In Eq. 13.15 and 13.16, the letter “e” has been corrected togreek “ε”.The first occurence of “εcc” in the definitions under Eq 13.16,has been corrected to “γcc”.App.B Page 156In item A408, the definition of gauge length has been correctedto .App.B Page 157In item A604, definition of “e”, the reference to “Table 23”has been corrected to “Table 23 of ISO 3183”.App.C Page 167In item C201, the text “Is” has been corrected to “Si”.In item C302, the reference to “D200” has been corrected to“B700”.App.C Page 170In item D807, the text “high and low input” has been changedto “high and low heat input”.App.C Page 174In item E304, the reference to “Sec.6 D207” has been deleted.In item E309, the reference to “E705” has been correctedto”D705”.

App.C Page 177In item F109, the extra “t” in front of the word “grinding” hasbeen deleted.App.C Page 178In item F304, the word “HOLD” has been deleted.App.C Page 179In item F315, the reference to “Sec.5 E302” has been correct-ed to”Sec.6 B302”.App.C Page 180In item F501, “Ohm” has been added after 0.1.App.C Page 181In Table C-7, The column heading “CRA/Duplex SS” has beenchanged to “CRA/Duplex SS 1)”.App.C Page 183Item H101, third list item has been corrected and now reads:

— the minimum time period of backing gas application afterwelding.

App.C Page 184In item H116, “xx mm” has been changed to “25 mm”, andthe text “(solution annealing)” has been added after "postweld heat treatment".

DNV-OS-F201: Dynamic Risers, 2001


Sec.1 Page 10In Subsection element D200, the following symbols have beenadded:

intercept of S-N curve

intercept of right leg of bilinear S-N curve

intercept of left leg of bilinear S-N curve

m inverse S-N curve slopem1 inverse S-N curve slope for right leg of bilinear S-N

curvem2 inverse S-N curve slope for left leg of bilinear S-N

curveSSW stress range at knee of bilinear S-N curve

Sec.1 Page 11In Subsection element D300, the following symbol has beenadded:

λn nth order spectral moment

App.B Page 70Items C203 and C204 have been corrected and now reads:203 For an S-N curve which is bilinear on log-log scale, thefatigue damage becomes

where G1 and G2 are the complementary incomplete Gamma

Table 13-3 "Usage factors" η for pressure containmentUtilisation factor,αU

Safety Class Pressure testLow Medium High

1.00 0.8473(0.843)

0.802 0.6981 0.96

0.96 0.8133(0.838)

0.77 0.672 0.96

1) In location class 1, 0.802 may be used2) In location class 1, 0.77 may be used3) Effectively this factor since the pressure test is governing

(13.10)( ) ( )( ) ( ) ( )( ) ( ) ( ) ( )tDftptptptptptptp pelcpcelc ⋅⋅⋅⋅=−⋅− 0

22

5.65 S0

)log(a

)log( 1a

)log( 2a

( )

( )⎪⎭

⎪⎬⎫

⎪⎩

⎪⎨⎧

⎟⎟⎠

⎞⎜⎜⎝

⎛

σ⎟⎠⎞⎜

⎝⎛ +⋅

σ⋅+

⎪⎭

⎪⎬⎫

⎪⎩

⎪⎨⎧

⎟⎟⎠

⎞⎜⎜⎝

⎛

σ⎟⎠⎞

⎜⎝⎛ +

σ⋅=

2

sw22

2

m

0

2

sw11

1

m

0

22S

;2

m1G

a22f

22S;

2m1G

a22f

D

2

1 (B.14)

DET NORSKE VERITAS


function and incomplete Gamma function, respectively

and where and m1 are the intercept and inverse slope ofthe right leg of the bilinear S-N curve, and m2 are theintercept and inverse slope of the left leg of the bilinear S-Ncurve, and SSW is the stress range at the knee of the bilinearS-N curve.204 The fatigue damage is hence directly expressed by thestandard deviation and zero-crossing frequency of the stressresponse process This formulation is of special conveniencefor frequency domain analyses where results from the globalanalyses are expressed in terms of the autospectral density,Sσσ(ω), of the stress response process.The standard deviation, σ and zero crossing frequency f0 arehence given as:

where λn is the nth order spectral moment of the response,given by

App.B Page 71In item D301, equation (B.24) has been corrected and nowreads:


Sec.4 Page 24Replace item B501 as follows:B501 Design based on response statistics is generally therecommended procedure for consistent assessment of charac-teristic load effects.Sec.4 Page 25Replace item C201 as follows:C201 Fatigue analysis of the riser system shall consider allrelevant cyclic load effects including:Sec.5 Page 29In Table 5-2, the NOTES and subscripts 1) and 2) refer to theULS condition only. Replace Table 5-2 as follows:

Sec.5 Page 34The denominator of the second term on the right hand side ofequation (5.30) should read 2 t3 instead of t3. Replace equation(5.30) as follows:

Appendix A Page 55In item B401, the list numbering has been updated as follows:

1) Geometric stiffness (i.e. contribution from effective ten-sion to transverse stiffness). Tension variation is hence anonlinear effect for risers;

2) Hydrodynamic loading. Nonlinearities are introduced bythe quadratic drag term in the Morison equation expressedby the relative structure-fluid velocity and by integrationof hydrodynamic loading to actual surface elevation;

3) Large rotations in 3D space;4) Material nonlinearities, and5) Contact problems in terms of seafloor contact (varying lo-

cation of touch down point and friction forces) and hull/slender structure contact.

Appendix B Page 70The term in equation (B.19) should read . Replaceequation (B.19) as follows:

Appendix B Page 70The denominator in equation (B.21) should read 2α, instead ofα. Replace equation (B.21) as follows:

Appendix B Page 71-73Delete items E100, E101, E102, E103 and equation (B.25) andTable B-2. Reference is made to DNV-RP-C203 for relevantSN curves and applicable SCF.

∫

∫−−

∞−−

=

=x

t

x

t

dttexG

dttexG

0

12

11

),(

),(

ϕ

ϕ

ϕ

ϕ(B.15)

)log( 1a)log( 2a

(B.16)0λσ =

(B.17)0

20 2

1λλ

π=f

(B.18)∫∞

=0

)( ωωωλ σσ dSnn

40

221λλ

λε −= (B.24)

Table 5-2 Load effect factors

Limit stateF-load effect

E-load effect

A-load effect

γF γE γAULS 1.11) 1.32) NAFLS 1.0 1.0 NASLS & ALS 1.0 1.0 1.0NOTES

1) If the functional load effect reduces the combined load effects, γF shall be taken as 1/1.1.

2) If the environmental load effect reduces the combined load effects, γE shall be taken as 1/1.3.

(5.30)

(B.19)

(B.21)

( )( )

( )( )43

43

33 232

tDDtDM

ttDTe

⋅−−⋅

−⋅⋅+

⋅−⋅=

ππσ

1−βs 1−βas

⎟⎟⎠

⎞⎜⎜⎝

⎛⎟⎠⎞

⎜⎝⎛−= −−

βββ

αβα a

aaSs

ssf exp)( 1

( )

( )⎪⎭

⎪⎬⎫

⎪⎩

⎪⎨⎧

⎟⎠

⎞⎜⎝

⎛⎟⎟⎠

⎞⎜⎜⎝

⎛+⋅

⋅+

⎪⎭

⎪⎬⎫

⎪⎩

⎪⎨⎧

⎟⎠

⎞⎜⎝

⎛⎟⎟⎠

⎞⎜⎜⎝

⎛+

⋅=

β

β

αβα

αβα

2;1

2

2;1

2

22

2

0

11

1

0

2

1

swm

swm

SmG

af

SmG

af

D

DET NORSKE VERITAS



Sec.5 Page 33In item D604 an absolute value operator is missing for the mo-ment value, M in the equation (5.29). Replace equation (5.29)as follows:

DNV-OS-J101: Design of Offshore Wind Turbine Structures, October 2007

Changes Published November 2009

Page 3 ChangesInformation about an ongoing revision has been added as fol-lows:November 2009 - Section 9 is under revision w.r.t. axial ca-pacity Rev.1DNV has identified that the established industry practice forcalculating the axial load capacity of grouted connections doesnot fully represent their physical behaviour. In some cases thismay result in an overestimation of calculated axial capacity ofgrouted connections.DNV has together with the industry initiated work to achieve abetter understanding of long term behaviour of grouted con-nections and to establish a reliable method for estimation of ax-ial load capacity which can be used for offshore wind turbinestructures. The new learning from this work will be document-ed in a guideline, and applied as basis for revising “OffshoreStandard DNV-OS-J101 Design of Offshore Wind TurbineStructures”.Until this work is completed and a revision of DNV-OS-J101has been issued, Section 9 “Design and Construction of Grout-ed Connections” in DNV-OS-J101 needs to be used with theabove in mind. Until the new revised standard is in place, thecapacity of grouted connections in offshore wind turbines willbe assessed on a case-by-case basis for certification purposes.Sec.9 Page 87In item A101, the following Guidance note has been added:

Guidance note:Until a new revision of DNV-OS-J101 become available, seepage 3, the following guidance on design of grouted connectionsapply:

— Grouted connections with plane sections (without shearkeys) with constant radius over the height of the connection(pile and transition piece) should be designed with a low uti-lisation ratio (UR = design shear stress divided by the designultimate capacity = τsaγm/τk) with respect to axial capacity

if the design methodology described in B102 is followed.By a low utilisation ratio is understood UR ≤ 200/Rp whereRp is given in mm.

— Grouted connections with a conical geometry on the pile andthe transition piece should be designed with a utilisation ra-tio UR ≤ 1.0. By conical connections are here understoodcones with angles in the order of 1° or larger where the ver-tical capacity can be documented by well defined structuralmechanics.

— The long term friction coefficient between steel and groutapplied in design should not exceed 0.4, unless documentedotherwise.


Changes Published December 2008

Sec.10 Page 96In item C204, requirement (1), the word “characteristic” hasbeen corrected to “design”.


General“DNV Rules for Certification of Lifting Appliances” has beenreplaced by the “DNV Standard for Certification No. 2.22 Lift-ing Appliances” and the references have been changed ac-cordingly.


Sec.1 Page 11In Table C3, the reference to NORSOK G-CR-001 has beencorrected to NORSOK G-001.Sec.3 Page 38In Item G106, the reference to NORSOK G-CR-001 has beencorrected to NORSOK G-001.

DNV-OS-J102: Design and Manufacture of Wind Turbine Blades, Offshore and Onshore Wind Turbines, October 2006


Sec.2 Page 15In item B206, the reference to Section 1 F300 has been correct-ed to Section 1 E300.App.F Page 46In item A201, the reference to Section 3 H has been correctedto Section 3.

(5.29)42

2

min

22

)(η≤⎟⎟

⎠

⎞⎜⎜⎝

⎛ −+

⎟⎟

⎠

⎞

⎜⎜

⎝

⎛⎟⎟⎠

⎞⎜⎜⎝

⎛+⎟

⎟⎠

⎞⎜⎜⎝

⎛

tppp

TT

MM

c

e

k

e

k

DET NORSKE VERITAS


SECTION 5AMENDED RECOMMENDED PRACTICES

DNV-RP-B401: Cathodic Protection Design, January 2005


Sec.6 Page 14In item 6.4.2, the text “coating lifetime” has been changed to“coating age”.Sec.6 Page 15At the end of item 6.9.4, a new sentence has been added as fol-lows:For any current drain to the steel armouring of flexible pipe-lines, 0.0005 A/m2 (based on the external pipe surface) is rec-ommended.Sec.7 Page 18In item 7.9.5, the word “and” has been removed between“long (and) flush”.Sec.8 Page 20In item 8.6.1, the end of first sentence has been changed toread:"…except that for aluminium based anodes, two samples shallbe collected for all heats exceeding 500 kg (unless otherwiseagreed)".Sec.10 Annex A Page 24In Table 10-8, The table cell for Anode Type “Long flushmounted” has been corrected as follows:


Sec.6 Page 14In item 6.4.5, “fc = 1” has been corrected to “fcf = 1”.Sec.7 Page 17In item 7.8.6, the following text has been added at the end ofthe paragraph:For any specific protection object (or CP unit, ref. 7.2.1) thehighest anode current output to net anode mass ratio should notexceed that of any other anode by more than 50 %. For all an-odes to be utilised for the full design life, the ratio between netanode mass (kg) and design life (yrs) should be minimum 0.5and 1.0 for Al-based and Zn-based anodes, respectively.Sec.7 Page 18In item 7.9.5, the word “radius” has been changed to“radius (= width/2)”.

In item 7.11.3, first sentence, the word “shall” has beenchanged to “should”.Sec.10 Annex A Page 24In Table 10-7, a reference to Note 2) has been included forboth “stand off anodes” (long and short).


Sec.5 Page 10In item 5.5.7 ASTM A182 has been replaced by ASTM A193.

Sec.6 Page 13The amendment dated October 2005 (item 6.3.11) has been re-placed by:For internally heated components, the design current densityshall be increased by 0.0002 A/m2 for each °C that the metal /seawater is assumed to exceed 25°C.Sec.8 Page 21Under item 8.6.7, in the third paragraph: ≤ 1.05 V has beenchanged to ≤ -1.05 V, and in the fifth paragraph: ≤ 1.00 V hasbeen changed to ≤ -1.00 V.Aluminium based anodes:electrochemical capacity: minimum 2,500 Ah/kg, closed circuit potential: ≤ -1.05 V at end of the 4th testing pe-riod.Zinc based anodes: electrochemical capacity: minimum 780 Ah/kg, closed circuit potential: ≤ -1.00 V at end of the 4th testing pe-riod.


Sec.1 Page 7In item 1.2.5, at the end of the paragraph, a new sentence hasbeen added as follows:However, this RP is applicable for CP of components of apipeline system installed on template manifolds, riser basesand other subsea structures when such components are electri-cally connected to major surfaces of structural C-steel.Sec.6 Page 15Item 6.9.4 has been amended as follows:6.9.4 Current drain to anchor chains shall be accounted for by30 m of chain for systems with mooring point topside only. Forsystems with mooring point below the water level, the seawa-ter exposed section above this point shall also be included. Acurrent drain of 30 m of chain shall also be included for CP ofanchoring arrangements using chains.Sec.7 Page 18 Item 7.11.3, in the Guidance note, the text “or less” has beenchanged to “or more”.Sec.10 Annex A Page 24Table 10-7, the table cell starting with “Long flush mounted”,has been changed as follows:Long flush mounted 2)L ≥ 4 · width andL ≥ 4 · thickness


Sec.2 Page 8In the Sec.2 title, the word Normative has been deleted.Sec.5 Page 11A new item 5.8.3 has been added, and the succeeding itemshave been renumbered accordingly:5.8.3 For large and complex structures like e.g. multi-wellsubsea production units, extensive use of coating is required tolimit the overall current demand and to ensure adequate currentdistribution. The CP design procedure in this document doesnot account for a voltage drop in the seawater remotely fromanodes.

Long flush mounted 2)L ≥ 4 · width andL ≥ 4 · thickness

DET NORSKE VERITAS


To compensate for this, the design coating breakdown factorsto be used for CP design are deliberately selected in a conserv-ative manner to ensure that a sufficient total final current out-put capacity is installed. As a consequence, any calculations ofthe electrolytic voltage drop away from the anodes (e.g. bymeans of finite or boundary element analyses) and using thesecoating breakdown factors may result in excessively high elec-trolytic voltage drops, indicating marginal or even insufficientcathodic protection in terms of the estimated protection poten-tial. This will primarily apply to relatively long design lives whenthe calculated coating breakdown, and hence current demandsand electrolytic voltage drop increase exponentially. Sec.6 Page 13A new sentence has been added at the end of item 6.3.11 as fol-lows:For internally heated components, the design current densityshall be increased by 0.002 A/m2 for each °C that the metal /seawater is assumed to exceed 25°C.

Sec.6 Page 14A new sentence has been added at the end of item 6.4.3 as fol-lows:The coating breakdown factors as established in Annex A arebased on considerations addressed in 5.8.3.


Sec.7 Page 17Equation (3), in item 7.8.2 has been corrected as follows:

Sec.8 Page 21Item 8.7.3, has been amended to read:8.7.3 Contractor shall issue an inspection document accordingto EN 10204 or ISO 10474, inspection certificate 3.1.B.

DNV-RP-C103: Column-Stabilised Units, February 2005




Sec.4 Page 23Item 4.8.4 has been clarified and now reads as follows:4.8.4 Boundary conditionsTo avoid rigid body motion of a global structural model at least6 degrees of freedom have to be fixed.Fixed boundary conditions may be used for a statically deter-mined set of boundary conditions while spring stiffness ismore appropriate for a statically undetermined set of boundaryconditions. A statically determined set of boundary conditions is illustrat-ed in Figure 4-19, with the following restraints:

— 3 vertical restraints (Z)— 2 transversal horizontal restraints (Y)

— 1 longitudinal horizontal restraint (X).

Note that in the figure the two points with fixation in Y musthave the same Y-coordinate and all three points must have thesame Z-coordinate.Any unbalance in loads of significance (hydrodynamic pres-sure vs. model acceleration) should be dealt with to avoid un-physical support reactions. Inertia relief can be used to achievethis. This method involves adjustment of model accelerationsto get zero support reactions. It is important that the inertia re-lief function is applied only as minor adjustment to the modelaccelerations, i.e. the initial model is in reasonable balance.Figure 4-20 illustrates a statically undetermined set of bound-ary conditions with spring stiffness. The total vertical stiffnessshould be according to the water plane area. Using spring stiff-ness is appropriate when a significant unbalance in loads can-not be resolved, e.g. when inertia relief cannot be used. Thereshould be enough springs so as to distribute the unbalance overseveral points. The higher unbalance the more springs. Andthese springs should be at "strong" points in the model so as tolimit the effect of unphysical support reactions.

Figure 4-19Statically determined boundary conditions

Figure 4-20Statically undetermined boundary conditions with springs

DNV-RP-C201: Buckling Strength of Plated Structures, October 2002


Part.1 Sec.3 Page 7In item 3.4 the reference to Chapter 0 has been corrected toChapter 10.Part.1 Sec.7 Page 18In Figure 7-3, in the lower left figure, the placement of the

(3)Ic N Ia⋅N Ec° Ea°–( )

Ra--------------------------------- N ΔE°⋅

Ra-------------------= = =

DET NORSKE VERITAS


measuring line for ef has been corrected:

Figure 7-3 Cross-sectional parameters for stiffeners andgirders

Part.1 Sec.7 Page 19Equation 7.36 has been corrected, and now reads:

Equation 7.40 has been corrected, and now reads:

Part.1 Sec.8 Page 22In item 8.1, line three, the reference to equation 7.62 has beencorrected to 7.64.

Equation 8.1 has been corrected, and now reads:

Part.1 Sec.8 Page 24Equation 8.29 has been corrected, and now reads:

Part.2 Sec.1 Page 29Item 1.1.5 has been amended as follows:1.1.5 The PULS code is programmed in a Visual basic (VB)environment. Two separate user interfaces are available usingthe same input/output file format, see Sec. 1.6.

Part.2 Sec.1 Page 32A new Item 1.5.8 has been added as follows:

1.5.8 The offshore WSD format in PULS terminology impliesthat η < ηp where ηp is permissible usage factor given in theoffshore standard DNV-OS-C201 and η is the actual usagefactor as calculated by the PULS code.Section 1.6 has been changed as follows:1.6 PULS software features1.6.1 The PULS code is supported by two separate stand-aloneuser interfaces applying the same input/output file format(pbp):

— Advanced Viewer (AV): Simple cell input of data with ba-sic result presentation. More results available such as 3Dgraphics of buckling deflections, redistributed stresses, ca-pacity curves for combined loads etc.

— Excel spread sheet: Simple data input and output line byline. A special option for systematic variation of main de-sign parameters such as stiffener height etc. is available.

1.6.2 The PULS code is also available in a dll format (Puls-ComClasses) for implementation as a post-processor in linearFE codes or similar analyses tools.1.6.3 The software features and basic theoretical backgroundis found in Ref.[3]. More details, publications, papers etc. canbe found on the DNV internet site www.dnv.com

In section 1.7, the third reference has been changed as follows:

/3/ NAUTICUS HULL, User Manual - PULS, July 2007,DNV Software.


Part.1 Sec.6 Page 12In item 6.5, after the sentence: σx,Rd is given by eq. (6.1) andσy,Rd is given by eq. (6.5)., a new sentence has been added asfollows:Part.1 Sec.7 Page 16In item 7.2, after equation 7.10, the following sentence hasbeen added:p0 = 0 in case σy,Sd is in tension along the whole length of thepanel.Part.1 Sec.7 Page 17In item 7.4, equation 7.18 has been changed as follows:

Part.1 Sec.8 Page 23The text in the paragraph before equation 8.21, has beenchanged as follows:If the σy stress in the girder is in tension due to the combinedgirder axial force and bending moment over the total span ofthe girder CyG may be taken as:Part.1 Sec.8 Page 24Equation 8.21 has been changed to: CyG = 1.0


Part.1 Sec.6 Page 11In the paragraph above figure 6-1, “Chapter 0” has beenchanged to “Chapter 10”.Part.1 Sec.7 Page 16In item 7.2, right column, line 4,“Chapter 0” has been changedto “Chapter 10”.

AB

tw

c

e

t

z p

z t

f

bC

h

wt

t fc

tw

b

wt

b

ft

.

c

A = centroid of stiffener with effective plate flange.B = centroid of stiffener exclusive of any plate flange.C = centroid of flange.

a

w wh

whwh

ef

( )η1tt

sh

C3

w

w −⎟⎟⎠

⎞⎜⎜⎝

⎛=

c1

c

Epτ

Sdc

Epy

Sdy,c

Epx

Sdx,

Sdj,

y2e

fτ

fσ

fσ

σf

λ⎟⎟⎟

⎠

⎞

⎜⎜⎜

⎝

⎛

⎟⎟⎠

⎞⎜⎜⎝

⎛+⎟

⎟⎠

⎞⎜⎜⎝

⎛+⎟

⎟⎠

⎞⎜⎜⎝

⎛=

( )GSdy,Sdy, AtσN += l

( )6.035.0μ TG −= λ

M

yRdSd

γ3

fττ

⋅=≤

DET NORSKE VERITAS


Part.1 Sec.7 Page 20In item 7.7.1, right column, last paragraph,“Chapter 0” hasbeen changed to “Chapter 10”.


Part.1 Sec.3 Table 3.1 Page 9In Table 3.1, line for ‘Longitudinal stiffened plate panel’, col-umn ‘Clause reference’ replace “7” with “5 and 7“.In Table 3.1, line for ‘Girder supporting stiffened panel’, col-umn ‘Clause reference’ replace “8” with “5 and 8“.In case of tension, apply fy/γM.Part.1 Sec.7 Equation 7.63 Page 20In “ limitation for use” just ahead/ introducing formula (7.63)substitute the balancing sign within the mathematical expres-sion from “greater or equal to” i.e.≥ , replacing it with “lessthan” i.e. < .

DNV-RP-C202: Buckling Strength of Shells, October 2002


Sec.1 Page 4Figure 1.1-1 has been changed:

Sec.1 Page 4The following section has been added in order to clarify howthis RP shall be used in Working Stress Design (WSD):1.2 Working Stress DesignThis Recommended Practice is written in the load and resist-ance factor design format (LRFD format) to suit the DNV Off-shore Standard DNV-OS-C101. This standard makes use ofmaterial- (resistance) and loadfactors as safety factors. DNV-RP-C202 may be used in combination with workingstress design format (WSD) by the following method: For the formulas used in DNV-RP-C202, including eq. 3.1.3,use a material factor γM=1.15. The utilisation checks should bemade using a modified permissible usage factor ηp=1.15βη0,see DNV-OS-C201 Sec. 2 Table E1 for η0 and Sec. 5 Table C1for β.Sec.2 Page 8Equation 2.2.7 has been corrected as follows:

Sec.3 Page 16 and 17Under Section 3.9, in the paragraph below equations 3.9.5 and

3.9.7, “fET” has been corrected to “fET“.Sec.3 Page 17Below equation 3.9.9, under the paragraph in the definition oflT, “lT” has been corrected “lT”.

DNV-RP-C203: Fatigue Design of Offshore Steel Structures


Sec.2 Page 18A new sentence has been added to the last paragraph in item2.9.1 as follows:The membrane stress in the considered section should be usedfor calculation of local bending stress over the thickness to-gether with stress concentration factor from equation (2.9.1).Sec.3 Page 25Equations in item 3.3.7 have been corrected as follows:(Equation 3.3.4)

where

(Equation 3.3.5)

(Equation 3.3.6)

Sec.4 Page 32The second and third equation in item 4.3.4 has been correctedas follows:

App.D Page 115A number of references to figures have been corrected.

(2.2.7)

r

sRING FRAME

LONGITUDINALSTIFFENER

L

l

2

1

X

l

l

N

TQ1

θM1

M2

Q2

σx

σh

τ

P

cosθtrπSd2,Q

sinθtrπ

Sd1,Q

SdQ,τ +−=

(3.3.4)

(3.3.5)

(3.3.6)

α-0t e

tT1

1t

)6(1SCF β

δδδ

⎟⎠⎞

⎜⎝⎛+

−++= m

β

⎟⎠⎞

⎜⎝⎛+

⋅=

tT1

1tD

1.82Lα

β 1.5 1.0

Log Dt----⎝ ⎠

⎛ ⎞--------------------– 3.0

Log Dt----⎝ ⎠

⎛ ⎞ 2----------------------------+=

α-t e

tT1

1t

)6(1SCF βδδ

⎟⎠⎞

⎜⎝⎛+

−−= m

α-t e

tT1

1t

61SCF βδ

⎟⎠⎞

⎜⎝⎛+

+=

( ) 2//

2//

//1 4

21

2τσσ

σσσ Δ+Δ−Δ+

Δ+Δ=Δ ⊥

⊥

( ) 2//

2//

//2 4

21

2τσσ

σσσ Δ+Δ−Δ−

Δ+Δ=Δ ⊥

⊥

DET NORSKE VERITAS


DNV-RP-C204: Design against Accidental Loads, Novem-ber 2004


Sec.3 Page 14The second equation in Section 3.7.2 has been corrected as fol-lows:

Sec.4 Page 20In Section 4.2, the formula for sc, has been corrected as follows:

Sec.6 Page 32Equation 6.11 in Section 6.10.2 has been corrected as follows:

DNV-RP-C205: Environmental Conditions and Environmental Loads, April 2007

Changes Published June 2009

Sec.3 Page 36Item 3.5.11.3 has been amended and now reads as follows:3.5.11.3 Some characteristic measures for the extreme maxi-mum xe in the sea state are:

It follows that: .

In item 3.5.11.5, the following has been added after the equation:“where ρ is the band width parameter given in 3.5.9.2.”

Sec.3 Page 37The last equation in item 3.5.12.2 has been corrected and now

reads:

Sec.3 Page 43Under References, ref. no. 61 has been modified (Yearchanged to 1993).

Sec.4 Page 44Item 4.1.1.3 has been amended and now reads:4.1.1.3 Information on statistical distribution of currents andtheir velocity profile is generally scarce for most areas of theworld. Current measurement campaigns are recommendedduring early phases of an offshore oil exploration develop-ment. Site specific measurements should extend over the watercolumn and over the period that captures several major stormevents. Some general regional information on current condi-tions are given in ISO 19901-1 (2005) “Metocean design andoperating considerations”.

Sec.5 Page 48In item 5.4.1 the reference in the first paragraph has beenchanged to Figure 6-6.

Sec.5 Page 49In Table 5-2, first row, “∞ (deg)” has been corrected to “α(deg)” (twice).

Sec.6 Page 56In item 6.7.2.4, second paragraph, “∞c > 0.3” has been correct-ed to “αc > 0.3”.

Sec.6 Page 59The last but one equation in item 6.10.1.2 has been correctedand now reads:

Sec.6 Page 60The last equation in item 6.11.3.2 has been corrected and nowreads:

Sec.8 Page 77Item 8.2.7.1 has been amended and now reads:8.2.7.1 Wave-current interactions should be taken into accountfor strong currents in relatively steep waves. No exact criteriafor when this effect is important in terms of current velocityand wave frequencies can be given. A measure of linear wave-current interaction effects is given by the Brard number τ =Ucω /g where Uc is current velocity, ω is the wave angular fre-quency and g is the acceleration of gravity.

Sec.9 Page 89The figure caption to Figure 9-3 has been modified and nowreads:“Added mass variation with reduced velocity found fromforced oscillations (Gopalkrishnan, 1993) and free oscillationtests (Vikestad, et.al., 2000)”

plastic collapse resistance in bending for the member, for the case that contact point is at midspan

= characteristic distance

(6.11)

Quantity Value FE(xe)Mode

xc0.368

N → ∞

Mean xmean

N large

0.570N → ∞

p-fractile xp

p

Median xmedian

p = 0.5

Std.dev.

N large

lP1Mc4R 0 =

)m

Vρ2g(1

)ma(1v

ACρams

w

2t

pdw −

+=

+=c

2EAk1

k1

node

l+=

βαγ /1)(ln N⋅+

⎟⎟⎠

⎞⎜⎜⎝

⎛+⋅+

NN

ln577.01)(ln /1

βαγ β

[ ] βαγ /1/1 )1ln( Np−−+

[ ] βαγ /1/1 )1ln( Np−−+

11

)(ln6

−

⋅ β

βαπ

N

meanmedianc xxx <<

12| THH

C sHT ⋅=σ

Ds C

Dxx 4+=

VNm

CTaT

A ρ=

DET NORSKE VERITAS



Sec.3 Page 27In item 3.3.2.1 the first formula has been corrected and nowreads as follows:

Sec.3 Page 34In item 3.5.5.4 the last line has been substituted with the fol-lowing:For γ = 3.3; Tp = 1.2859Tz and T1= 1.0734TzFor γ = 1.0 (PM spectrum); Tp = 1.4049Tz and T1= 1.0867Tz


Sec.3 Page 30In item 3.4.6.2 the reference to Figure 3-9 has been corrected:Figure 3-8.Sec.3 Page 37In item 3.5.13.2, 2nd sentence, Cmax/Hs > 2 has been correctedto: Cmax/Hs > 1.3.Sec.3 Page 38In item 3.6.3.4, the definition of ‘σ' has been corrected to:

Sec.7 Page 68In item 7.3.5.4, the definition of ‘vij' has been corrected to:vij = kij coth(kijT)Sec.8 Page 80Figure 8-5 has been corrected as follows:

Figure 8-5Definition of wetted length and vertical velocity in wave formax vertical impact force


App.D Page 117In Table D-2, row: “Bodies of revolution“, the figure under“Spheroids” has been replaced as follows:

The rightmost formula in the same row has been corrected asfollows:

η1 t( ) Ak cos ωkt εk+( )k 1=

N

∑=

[ ] hbz ebbTstd 2

10ln +==σ

L

Vertical velocity,vz

Wetted length = L

η

Wave propagation

Wave heading

Wetted lengthL

Wet deck area

Wave heading

Wetted lengthL

Wet deck area

Wave heading

Wetted length = L

Wet deck area

lateral

axial

2a

2b2b

ab2

34

π

DET NORSKE VERITAS



Sec.3 Page 32In Table 3-1, row: “Vertical particle acceleration, “, thetwo leftmost formulas have been corrected as follows:

DNV-RP-C206: Fatigue Methodology of Offshore Ships, October 2006


Sec.4 Page 26In item 4.4.4, second and third listitem, the references havebeen corrected to 4.2.2 and 4.2.3 respectively.Sec.6 Page 33Equation (10) has been corrected as follows:

Sec.10 Page 51Figure 10-1 has been corrected as follows:

Figure 10-1Preferred weld shape at bracket toes and grinding directionAppendix B Page 63In item B.2.2, third listitem, the reference has been correctedto A.1.2.

DNV-RP-C207: Statistical Representation of Soil Data, April 2007


Sec.2 Page 16In Table 2-2, some of the numbers i the middle column hasbeen corrected:

DNV-RP-E402: Naval Rescue Submersibles, April 2004



Changes Published October 2008General“DNV Rules for Certification of Lifting Appliances” has beenreplaced by the “DNV Standard for Certification No. 2.22 Lift-ing Appliances” and the references have been changed accord-ingly.

DNV-RP-E403: Hyperbaric Evacuation Systems, December 2006

Changes Published October 2009Sec.3 Page 30The Guidance note in B104 has been deleted.

Changes Published October 2008General“DNV Rules for Certification of Lifting Appliances” has beenreplaced by the “DNV Standard for Certification No. 2.22 Lift-ing Appliances” and the references have been changed accord-ingly.


Sec.1 Page 16In item D299 the reference to Appendix 1 has been correctedto Appendix A.Sec.7 Page 52In item B109 the references has been corrected to:Sec.3 B204 and B205.

DNV-RP-F101: Corroded Pipelines, October 2004


General - Page 2The previous acknowledgement has been re-introduced as fol-lows:AcknowledgementsThis Recommended Practice is based upon a project guideline developed in a co-operation between BG Technology andDNV. The results from their respective Joint Industry Projects (JIP) have been merged and form the technical basis for thisRecommended Practice.We would like to take this opportunity to thank the sponsoring companies / organisations for their financial and technicalcontributions (listed in alphabetical order):

— BG plc— BP Amoco— Health and Safety Executive, UK— Minerals Management Service (MMS)— Norwegian Petroleum Directorate (NPD)— PETROBRAS— Phillips Petroleum Company Norway and Co-Ventures— Saudi Arabian Oil Company

(10)

Table 2-2 Coefficient c1−α(n) for XC defined as the 5% quantile of X

n 1− α = 0.75 1− α = 0.90 1 − α = 0.953 3.17 5.33 7.665 2.47 3.41 4.2110 2.11 2.57 2.9115 1.99 2.34 2.5720 1.94 2.21 2.4030 1.88 2.08 2.22∞ 1.64 1.64 1.64

w&

( )[ ] θπ cos)sinh(

sinh22

2

kddzk

TH +– θπ cos2

2

2kze

TH–

5.0

min1.02 ⎟

⎠⎞⎜

⎝⎛ ⋅⋅= g

LT π

DET NORSKE VERITAS


— Shell UK Exploration and Production, Shell Global Solu-tions, Shell International Oil Products B.V.

— Statoil— Total Oil Marine plc

DNV is grateful for valuable co-operations and discussions with the individual personnel of these companies.Sec.3 Page 13In Table 3-11, the second last row has been replaced by:

(the value of γm in the right-most cell has been changed from0.72 to 0.73).

DNV-RP-F102: Pipeline Field Joint Coating and Field Repair of Linepipe Coating, October 2003


Sec.3 Page 9The definition of “Owner” has been added as follows:

Sec.3 Page 9In the definition of “Purchaser”, the text “pipeline operator”has been replaced by “Owner”.Sec.5 Page 11In item 5.4.6, the first sentence is changed to:5.4.6 Certain properties related to raw materials “as delivered”for coating shall be certified per batch or lot (i.e by an “inspec-tion certificate” - type 3.1.B according to EN 10204 orISO 10474), in accordance with section 2, column “Produc-tion”, of the ‘data sheet’ in ANNEX 1 and ANNEX 2.Sec.5 Page 11In item 5.4.7, the text “type 4.2” has been deleted.


Sec.2 Page 7In the Sec.2 title, the word Normative has been deleted.Sec.6 Annex 1 Page 15In the heading for 2nd column from the right, after the textCoating Material Qualification, the text and PQT has beenadded.This change has also been applied to all the other tables inAnnex 1.FJC/CFR Data Sheet No. 3A Page 25In item 3.1, row starting with “Salt contamination”, Third col-umn has been changed to max. 20 mg NaCl/m2.


FJC/CFR Data Sheet No. 1B Page 17In item 2.1, Lap shear strength has been corrected to:≥ 30 N/cm2

FJC/CFR Data Sheet No. 3A Page 26In item 3.2, row starting with “Hot water soak test” has been

corrected as follows:


GeneralIn all references involving Section 4 in the printed issue, Sec-tion 4 shall be corrected to Section 5.

DNV-RP-F103: Cathodic Protection of Submarine Pipe-lines by Galvanic Anodes, October 2003


Sec.5 Page 10In item 5.5.1, 2nd paragraph, the reference to 5.6.10 has beencorrected to 5.6.11.

In item 5.6.4, Eq. (10) (Eq. 9 in the printed 2003 version), hasbeen corrected (apostrophes removed) as follows:

f'cf = fcf (linepipe) + r · fcf (FJC) (10)The same correction has been made at the end of the Guidancenote (apostrophes removed):... f'cf = fcf (linepipe) + 0.033 fcf (FJC).

Sec.5 Page 12In item 5.6.10, "ohm·m·106" has been changed to “10-6·ohm·m” (three places).


Sec.8 Page 16In table A.1, the row starting with “Single or Dual Layer FBE”has been corrected from the April 2006 amendment, and nowreads as follows:


Sec.1 Page 5In item 1.1.2, a new paragraph has been added and the Guid-ance note has been amended as follows:For pipelines in CRA's susceptible to hydrogen induced stresscracking (HISC) by CP, this concept has the main advantagethat the installation of anodes on the pipeline itself can be fullyavoided for shorter lines.

Guidance note:Apparently all failures of CRA pipelines due to HISC have beenrelated to the welding of anodes to the pipeline causing stressconcentrations, susceptible microstructure and defect coating.The concept of installing anodes on adjacent structures also hasthe advantage that the complete anode surfaces are exposed toseawater, increasing the anode electrochemical performance andthe anode current output compared to those for anodes partly orfully covered by seabed sediments. Moreover, the potential fordamage to the pipeline coating during installation is reduced.


Relative (e.g. MFL) γm = 0.82 γm = 0.77 γm = 0.73

Owner party legally responsible for design, con-struction and operation of the pipeline

Hot water soak test (FJC only)

GBE/CW6Part 1, App. Eor other agreed procedure

according to standard

by agreement

by agreement

Single or Dual Layer FBE

No. 1 yes 90 1 0.03

DET NORSKE VERITAS


Sec.1 Page 5In item 1.1.3, the text “hydrogen induced stress cracking(HISC)” has been changed to “HISC”.Sec.1 Page 5In item 1.2.2, The second sentence (added during Amendmentsand Corrections, April 2004), has been amended as follows:For CP of subsea manifold templates, riser bases and othersubsea structures where components of a pipeline system areelectrically connected to major surfaces of structural C-steel,use of DNV-RP-B401 is recommended for CP design (see1.5.3).Sec.1 Page 6A new item 1.3.3 has been added as follows, and the succeed-ing items have been renumbered accordingly.1.3.3 CP design, anode manufacture and anode installation aretypically carried out by three different parties (all referred to asContractor in this RP). The party issuing a contract (Purchaser)may be either the installation contractor or Owner. For defini-tion of contacting parties and associated terms, see Sec.3.Sec.1 Page 6Item 1.5.3 has been amended as follows:1.5.3 DNV-RP-B401 “Cathodic Protection Design” (2005) cov-ers CP of other offshore structures than pipelines. However, it isapplicable for certain components of a pipeline system likethose installed on manifold templates and riser bases (see 1.3.1).Sec.3 Page 7The definition of “Owner” has been added as follows:

Sec.3 Page 7In the definition of “Purchaser”, the text “pipeline operator”has been replaced by “Owner”.Sec.5 Page 8In item 5.2.4, a new sentence has been added before the lastsentence:For any larger surfaces, DNV-RP-B401 is recommended forcalculations of CP current demands.In item 5.2.4, first Guidance note (added during Amendmentsand Corrections, April 2004), the text “pipeline owner” hasbeen changed to “Owner/Purchaser”.Sec.5 Page 10In item 5.6.1, Guidance note (added during Amendments andCorrections, October 2005), a new sentence has been added asfollows:Except for very long design lives (> 30 years), a typical brace-let anode size (i.e. convenient for casting) will then give an in-stalled anode net mass that exceeds the calculated required netanode mass.Sec.5 Page 11In item 5.6.9, Guidance note (added during Amendments andCorrections, October 2005), the reference to eqn. (16) hasbeen corrected to equation (17).Sec.6 Page 12Item 6.1.1 has been amended as follows:6.1.1 This section covers the manufacturing of galvanicanodes, including preparation of anode cores. The require-ments and guidelines in this section are in compliance withthose in ISO 15589-2, Sec. 8 and Sec. 9, giving some amend-ments, mostly related to quality control. This section is prima-rily intended for manufacturing of pipeline (bracelet type)anodes. For manufacture of other anodes located on adjacent

structures electrically connected to the pipeline and intendedfor pipeline CP, see DNV-RP-B401.Sec.7 Page 15In item 7.6.3, the reference to DNV-RP-F106 has been correct-ed to DNV-RP-F102.Sec.7 Page 15In item 7.7.2, the reference to DNV-RP-F106 has been correct-ed to DNV-RP-F102.Sec.8 Page 16In table A.1, the row starting with “Single or Dual Layer FBE”has been amended as follows:

Sec.8 Page 16In table A.2, the row starting with “3A FBE” has been amend-ed as follows:


Sec.1 Page 6In item 1.3.1, the Guidance note has been deleted.Sec.2 Page 7In the Sec.2 title, the word Normative has been deleted.Sec.5 Page 8In item 5.2.2, a new sentence has been added to the Guidancenote as follows:For CP calculations, a minimum cut-back length of 0.20 mshould be applied.Sec.5 Page 9In item 5.2.9, a new Guidance note has been added as follows:

Guidance note:ISO 15589-2 recommends constants a and b in eqn (2) for gener-al types of pipeline coating systems assuming that the reductionof current demand for CP (i.e. per surface area) is the same forlinepipe and FJC (quote: field joints having a quality equivalentto factory-applied coatings). This RP, however, refers to specific combinations of linepipe andFJC coating and takes into account their relative surface area(eqn. 9). The calculated FJC coating breakdown factor may thenbe 3-30 times higher than for the linepipe coating. For certaincombinations of parent and linepipe coating, the calculated over-all coating breakdown using the constants in Annex 1 may be sig-nificantly lower than in the ISO standard. This is justified by the specific requirements to coating designand quality control of coating application in the referenced DNV-RP-F102 and DNV-RP-F106; the ISO standard referring to thegeneric type of coating (e.g. fusion bonded epoxy) or purpose ofcoating (e.g. thermal insulation) and to (quote:) commonly ap-plied industry standards. The constants recommended in Annex 1 are only applicable if theactual coating specifications are in general compliance with thereferred DNV RP's. However, for certain combinations of coat-ing systems (e.g. asphalt and coal tar enamel plus FJC based ontape or sleeves with infill), the CP system can readily be designedso that the current demands of both standards are fulfilled (see also Guidance notes to 5.4.1 and 5.6.9).


Sec.5 Page 9In item 5.3.2, the following text has been added at the end ofthe Guidance note: (See also Guidance note to 5.2.9).


Single or Dual Layer FBE

No. 1 no 90 3 0.1

3A FBE none 90 CDS no. 1 3 0.3

DET NORSKE VERITAS


Sec.5 Page 9In item 5.4.1, a new Guidance note has been added as follows:

Guidance note:The total net anode mass calculated from eqn. (5) may be consid-ered as an absolute minimum value. If a default anode distanceof 300 m is adopted (5.6.1), typical bracelet anode dimensionswill normally give a significantly higher anode mass to be in-stalled. Any excess anode mass installed can be utilised as a con-tingency in case the calculated current demand wasunderestimated due to e.g. pipeline components not included inthe current demand calculations, or unforeseen mechanical dam-age to the coating during installation and/or operation, or if thedesign life of the pipeline is extended. (For inclusion of contin-gency in pipeline CP design, see Guidance note to 1.2.1).



Guidance note:For medium and long distance export pipelines with concretecoating, the concept of using pre-installed anodes and with a de-fault maximum distance of 300 m is adequate for most purposes.(See Guidance note to 5.4.1)"



Guidance note:Also the ISO 15589-2 encourages CP of short pipelines by an-odes located at each end of the pipeline. To calculate the protec-tive length of such anodes, this standard recommends so-calledattenuation calculations contained in an Annex A. These formu-las are fairly complicated and contain the pipe-to-electrolyte in-sulation resistance as the most critical parameter and which(quote:) should be selected based on practical experience. ThisRP, however, offers a simplified approach with specification ofall required design parameters.


In item 5.6.4, in the Guidance note, the word minimum hasbeen inserted after “..0.20 m, a default”.Sec.5 Page 11In item 5.6.9, a new Guidance note has been added as follows:

Guidance note:The minimum anode distance (L) calculated from eqn (16) maybe considered as an absolute minimum value and not an optimumdistance. The definition of distance between bracelet anodes (i.e.other than the default value of 300 m recommended in 5.6.1) willbe dependant on the anode design, the installation concept (on-shore/offshore installation) and the minimum net anode mass re-quired (see 5.4.1).


Sec.6 Page 13Item 6.7.3, has been changed as follows:6.7.3 Contractor shall issue an inspection document corre-sponding to the requirements given in EN 10204 or ISO 10474,inspection certificate 3.1.B.Sec.8 Page 16At the bottom of Tables A.1 and A.2 the following text has beenadded:Note: x100 in the heading of the two column to the rightmeans that all figures in these columns have been multipliedby a factor of 100; i.e. before use in eqns. (2) or (4), the num-bers shall be multiplied with a factor 10-2.


Sec.5 Page 8After Table 5-1, a new Guidance note has been added:

Guidance note:The design current densities in Table 5-1 are applicable inde-pendent of geographical location and depth but should be consid-ered as minimum values. Based on special considerations, thepipeline owner may chose to specify higher design values thanthose in Table 5-1.


Sec.5 Page 10The equation in item 5.6.3, that wrongly has the number“7”(same as the equation in 5.5.3), has been renumbered “8”.The succeeding equations has been renumbered accordingly.Sec.5 Page 10In item 5.6.4, the Guidance note has been amended to read:

Guidance note:The length of cut-back refers to the corrosion protective coating.For cutbacks with length < 0.20 m, a default value of 0.20 m isrecommended. With this default value, and for a pipeline sectionwith all joints of 12 m length approximately, r = 0.033 and f'cf = f'cf (linepipe) + 0.033 f'cf (FJC).


Sec.5 Page 11In item 5.6.9, the 2nd last paragraph, the text “becomes 4L instead of 2L” is corrected to “becomes L in stead of 2L”.Sec.8 Page 16A new row has been added at the bottom of table A.1 with thetext:Note that the values for 'a' and 'b' in the two columns to theright have been multiplied by a factor 100.Sec.8 Page 16In Table A.2, FJC Type 1A, 3rd column from right, the text“CDS no. 5 and 6” is corrected to “CDS no. 5 and 6 with con-crete”.Sec.8 Page 16In Table A.2, FJC Type 2A, 3rd column from right, the text“CDS no. 5 with concrete” is corrected to “CDS no. 2 withconcrete”.

DNV-RP-F106: Factory Applied External Pipeline Coat-ings for Corrosion Control, October 2003


Sec.3 Page 9The definition of “Owner” has been added as follows:

Sec.3 Page 9In the definition of “Purchaser”, the text “pipeline operator”has been replaced by “Owner”.Sec.5 Page 11In item 5.4.6, the first sentence is changed to:5.4.6 Certain properties related to raw materials (as-delivered)for coating shall be certified per batch / lot (i.e. by an “inspec-tion certificate” type 3.1.B according to EN 10204 orISO 10474), in accordance with section 2, column “Produc-tion”, of the relevant ‘coating data sheet’ (CDS) in ANNEX 1.


DET NORSKE VERITAS


Sec.5 Page 11In item 5.4.7, the text “type 4.2” has been deleted.Sec.6 Annex 1 Page 18In the first column, third row from below, “110°C” has beenchanged to “80°C” (two places).


Sec.2 Page 7In the Sec.2 title, the word Normative has been deleted.Sec.5 Page 13Item 5.9.4, has been amended as follows:5.9.4 Contractor shall issue an inspection document corre-sponding to the requirements given in EN 10204 or ISO 10474,inspection certificate 3.1.B.Sec.6 Annex 1 Page 15In the heading for 2nd column from the right, after the textCoating Material Qualification, the text and PQT has beenadded.This change has also been applied to all the other tables inAnnex 1.Sec.6 Annex 1 Page 16In item 3.2, row starting with Hot water soak test, the text inthe third column has been changed to “according to standard”.Sec.6 Annex 1 Page 17In the first column, 2.2.1 and 2.2.2 have been changed to 2.1.3and 2.1.4 respectively.Sec.6 Annex 1 Page 18In the first column, after 3.2.2 and 3.2.3, PP has been changedto PE.Sec.6 Annex 1 Page 23In the row starting with 3.2.1, the text CDS 3, 3.2 has beenchanged to CDS 1, 3.2 (four locations).Sec.6 Annex 1 Page 23In the row starting with 3.2.2, the text CDS, 3.2.2 has beenchanged to CDS 1, 3.2.2 (four locations).


Sec.5 Page 10In the Guidance note in item 5.2.3, the text “line spread“ hasbeen changed to “line speed“.

DNV-RP-F107: Risk Assessment of Pipeline Protection, March 2001


Equation (22) Page 27The equation should read:

(The righthand factors are to be multiplied rather than added.)

DNV-RP-F109: On-Bottom Stability Design of Submarine Pipelines, October 2007




Sec.1 Page 7In item 1.5.1, the definition of M* has been corrected to read:

Sec.1 Page 8In item 1.5.2, the following has been added:

The definition of τ has been changed as follows:

Sec.3 Page 11Equation 3.3 has been replaced as follows:

Sec.3 Page 12Equation 3.15 has been replaced as follows:

Sec.3 Page 14In equations 3.25 and 3.26 the letter “G” has been changedto”GC”.Sec.3 Page 15Equation 3.29 has been replaced as follows:

In the paragraph above Figure 3-10, the reference to Eq.(3.38) has been corrected to (3.31).Sec.3 Page 16In the paragraph above Equation 3.34, the greek letter “δ” hasbeen changed to the word “displacement”.

FColl_Riser FHit_Platform × 14--- Pj

j Riser_i=∑⎝ ⎠

⎜ ⎟⎛ ⎞

=

M* Steady to oscillatory velocity ratio for single design oscillation V* /U*.

μ Coefficient of friction.

Number of oscillations in the design bottom velocity spectrum = T / Tu

(3.3)

(3.15)

(3.29)

τ

cr

rcc

zz

zD

Dz

zVV θsin1ln

11ln1)(

0

0

0

⋅

⎟⎟⎟⎟⎟

⎠

⎞

⎜⎜⎜⎜⎜

⎝

⎛

⎟⎟⎠

⎞⎜⎜⎝

⎛+

−⎟⎟⎠

⎞⎜⎜⎝

⎛+⋅⎟

⎠⎞

⎜⎝⎛ +

⋅=

⎟⎠⎞

⎜⎝⎛

⋅+⋅⋅==

ττ

ln25772.0ln2

21*

sU U

Uk

7.03.02.33.0

062.00071.0 ⎟⎟⎠

⎞⎜⎜⎝

⎛⋅+⎟⎟

⎠

⎞⎜⎜⎝

⎛⋅=

c

c

c

cpi GGDz

κκ

DET NORSKE VERITAS


Equation 3.34 has been replaced as follows:

Table 3-4 has been replaced as follows:

Sec.3 Page 17Figure 3-12 has been replaced as follows:

Figure 3-12Minimum weight, L10/(2 + M)2, for pipe on sandEquations 3.36 and 3.37 have been replaced as follows:

Sec.3 Page 18In the 2nd paragraph below Equation 3.41 the reference to3.4.3 has been corrected to 3.4.2.The 3rd paragraph below Equation has been deleted.In the paragraph above Table 3-9 the reference to 3.6.5 has

been corrected to 3.4.5.Sec.3 Page 19The formula in Figures 3-15 and 3-16 has been replaced asfollows:

AppA GeneralIn all the tables, the upper left cell has been corrected from“0.2” to “≤ 0.2”.In all the tables and figure titles, the letter “G” has beenchanged to “Gc”.AppA Page 21The following sentence has been added to the end of the firstparagraph:Linear interpolation can be applied in the region 0.003 < N <0.006.AppA Page 21Table A-3 has been replaced as follows:

DNV-RP-F111: Interference Between Trawl Gear and Pipelines, October 2006




Sec.4 Page 19In item 4.4, the paragraph under equation 4.18 has been clar-ified as follows:While the maximum downward force (i.e. negative sign) be-comes:Sec.4 Page 20In item 4.6, the paragraph under equation 4.23 has been cor-rected as follows:where, as for trawl boards and beam trawls, δp is the displace-ment of the pipe at the point of interaction which is unknownprior to response simulations. Therefore, the value of δp/Vmust be assumed (e.g. δp/V = 0.1Fp/ (kw · V)) and may be cor-rected after response simulations in some sort of iterative ap-proach.

(3.34)

Table 3-4 Minimum weight, L10/(2 + M)2, for pipe on sandK

M= 5 10 15 20 30 40 60 ≥ 100

≤ 0.2 0.20 0.41 0.61 0.81 0.69 0.69 0.69 0.690.4 0.31 0.62 0.93 0.81 0.75 0.72 0.70 0.700.5 0.34 0.69 1.03 0.93 0.83 0.78 0.75 1.000.6 0.79 1.20 1.13 1.10 1.07 1.05 1.03 1.020.8 0.85 1.40 1.37 1.35 1.33 1.33 1.32 1.311.0 1.60 1.50 1.47 1.45 1.43 1.43 1.42 1.411.5 1.80 1.70 1.67 1.65 1.63 1.63 1.62 1.612.0 1.90 1.80 1.77 1.75 1.73 1.73 1.72 1.714.0 2.10 2.00 1.97 1.95 1.93 1.93 1.92 1.91≥ 10 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50

(3.36)

(3.37)

τττ ⋅+=⋅−+= 0095.05.0

1000)5.010(5.0Y

K

210

)2( ML+

0.0

0.2

0.4

0.6

0.8

1.0

1.2

1.4

1.6

1.8

2.0

2.2

2.4

2.6

2.8

3.0

0 20 40 60 80 100

M ≤ 0.2

M = 0.5

M = 0.8

M = 2.0

M = 10

)(90 67.0 MfKN

GL cstable ⋅

⋅=

⎪⎪⎩

⎪⎪⎨

⎧

<+

≥+=

+bC

b

bC

KKforKCC

KKforKCC

ML

3

3

21

21

210

)2(

Table A-3 Parameters for calculating minimum weight, L10/(2 + M)2, for pipe on clay, Gc = 0.222

Gc = 0.222

MN ≤ 0.003 0.006 ≤ N ≤ 0.024

C1 C2 C3 Kb C1 C2 C3 Kb≤ 0.2 0.1 8 0.5 15 0.1 8 0.5 100.4 0.1 7 0.5 10 -0.3 8 0.5 100.5 0.1 7 0.5 10 -0.1 7 0.5 100.6 0.1 7 0.5 10 0.0 7 0.5 100.8 0.1 7 0.5 5 0.1 6 0.5 51.0 0.1 7 0.5 5 0.1 6 0.5 51.5 0.1 7 0.5 5 0.5 3 0.5 52.0 0.1 7 0.5 5 0.9 2 0.5 54.0 0.1 7 0.5 5 1.7 0 0.5 5

≥ 10 0.1 7 0.5 5 1.7 0 0.5 5

2* )( MkL

U +

DET NORSKE VERITAS


Sec.6 Page 22In Table 6-2, second row, the text in the rightmost cell has beenclarified as follows:

Sec.6 Page 23Under Figure 6-1, a new Guidance Note has been added forclarification:

Guidance note:The annular trawling frequency threshold level where trawl pull-over loading may be disregarded is one order of magnitude belowthe acceptance criteria on total probability of failure, given inDNV-OS-F101. This is to account for that the considered pipe-line section may be exposed to additional accidental loads thantrawling.


DNV-RP-F202: Composite Risers, May 2003



DNV-RP-F204: Riser Fatigue, July 2005



DNV-RP-F205: Global Performance Analysis of Deepwater Floating Structures, October 2004



DNV-RP-G101: Risk Based Inspection of Offshore Top-sides Static Mechanical Equipment, April 2009


App.A Page 30In Table A-9, 4th row, 2nd column, the text “0.0067 × ln(T)-0.3000” has been corrected to “0.0067 × T + 0.3000”.

Frequency class Usage Dent depth, Hpc [%] of D

DET NORSKE VERITAS

Download

Business

naval rescue

det norske

normalised

technology

hyperbaric

onshore wind

closed circuit

inputoutput