DNV OFFSHORE CODES

AMENDMENTS AND CORRECTIONS

OCTOBER 2005DET NORSKE VERITAS

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A) Qualification, Quality and Safety MethodologyB) Materials TechnologyC) StructuresD) SystemsE) Special FacilitiesF) Pipelines and RisersG) Asset OperationH) Marine OperationsJ) Wind TurbinesComments may be sent by e-mail to rules@dnv.comFor subscription orders or information about subscription terms, please use distribution@dnv.comComprehensive information about DNV services, research and publications can be found at http://www.dnv.com, or can be obtained from DNV, Veritasveien 1, NO-1322 Hvik, Norway; Tel +47 67 57 99 00, Fax +47 67 57 99 11.

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DNV Offshore Codes, Amendments and Corrections, October 2005 Contents Page 3CONTENTS

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

Sec. 2 Amended Offshore Service Specifications.......... 7DNV-OSS-101: Rules for Classification of Offshore Drilling and Support Units, October 2003 ............................................................. 7DNV-OSS-102: Rules for Classification of Floating Production and Storage Units, October 2003.............................................................. 7DNV-OSS-103: Rules for Classification of LNG/LPG Floating Production and Storage Units or Installations, May 2001 ................. 7DNV-OSS-309: Verification, Certification and classification of gas Export and receiving terminals, January 2005................................... 7

Sec. 3 Amended Offshore Standards ............................. 8DNV-OS-C101: Design of Offshore Steel Structures, General (LRFD Method), April 2004 ................................................ 8DNV-OS-C102: Structural Design of Offshore Ships, April 2004 .10DNV-OS-C103: Structural Design of Column-stabilised Units (LRFD method), April 2004 ............................................................ 10DNV-OS-C104: Structural design of self-elevating Units (LRFD-method), October 2004 ....................................................... 10DNV-OS-C106: Structural Design of Deep Draught Floating Units (LRFD method), January 2001......... 10DNV-OS-C201: Structural Design of Offshore Units (WSD Method), April 2005 ............................................................. 10DNV-OS-C401: Fabrication and Testing of Offshore Structures, April 2004 ........................................................................................ 10DNV-OS-C502: Offshore Concrete Structures, July 2004.............. 11DNV-OS-C503: Concrete LNG Terminal Structures and Containment Systems, October 2004............................................... 11DNV-OS-D201: Electrical Installations, January 2005................... 11

DNV-OS-D202: Instrumentation and Telecommunication Systems, October 2000 ................................... 11DNV-OS-E402: Offshore Standard for Diving System, January 2004.................................................................................... 12DNV-OS-F101: Submarine Pipeline Systems, 2000....................... 12DNV-OS-F201: Dynamic Risers, 2001........................................... 18DNV-OS-J101: Design of Offshore Wind Turbine Structures, June 2004 ........................................................................................ 19

Sec. 4 Amended Recommended Practices................... 20DNV-RP-A202: Documentation of Offshore Projects, January 2001.................................................................................... 20DNV-RP-B401: Cathodic Protection Design, January 2005.......... 20DNV-RP-C201: Buckling Strength of Plated Structures, October 2002 ................................................................................... 20DNV-RP-C202: Buckling Strength of Shells, October 2002 .......... 21DNV-RP-C203: Fatigue Design of Offshore Steel Structures, August 2005................................................................... 21DNV-RP-C204: Design against Accidental Loads, November 2004 ............................................................................... 21DNV-RP-F102: Pipeline Field Joint Coating and Field Repair of Linepipe Coating, October 2003 ............................ 22DNV-RP-F103: Cathodic Protection of Submarine Pipelines by Galvanic Anodes, October 2003...................................................... 22DNV-RP-F105: Free Spanning Pipelines, March 2002 .................. 23DNV-RP-F106: Factory Applied External Pipeline Coatings for Corrosion Control, October 2003 .................................................... 23DNV-RP-F107: Risk Assessment of Pipeline Protection, March 2001...................................................................................... 23DET NORSKE VERITAS

DNV Offshore Codes, Amendments and Corrections, October 2005Page 4 ContentsDET NORSKE VERITAS

DNV Offshore Codes, Amendments and Corrections, October 2005 Sec.1 Page 5SECTION 1CURRENT DNV OFFSHORE CODES

DNV Offshore Codes Date of issueDate of

amendmentOffshore Service SpecificationsDNV-OSS-101 Rules for Classification of Offshore Drilling and Support Units October 2003 April 2004DNV-OSS-102 Rules for Classification of Floating Production and Storage Units October 2003 April 2004DNV-OSS-103 Rules for Classification of LNG/LPG Floating Production and Storage Units or Instal-

lationsMay 2001 October 2001

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

May 2001

DNV-OSS-201 Verification for Compliance with Norwegian Shelf Legislation July 2003 DNV-OSS-202 Verification for Compliance with UK Shelf Regulations March 2001 DNV-OSS-300 Risk Based Verification April 2004 DNV-OSS-301 Certification and Verification of Pipelines October 2000 DNV-OSS-302 Offshore Riser Systems October 2003 DNV-OSS-305 Rules for Certification and Verification of Diving Systems January 2004 DNV-OSS-306 Verification of Subsea Facilities June 2004 DNV-OSS-307 Verification of Process Facilities June 2004 DNV-OSS-308 Verification of Lifting Appliances for the Oil and Gas Industry June 2005 DNV-OSS-309 Verification, Certification and Classification of Gas Export and Receiving Terminals January 2005 April 2005Offshore StandardsDNV-OS-A101 Safety Principles and Arrangement October 2005 DNV-OS-B101 Metallic Materials January 2001 DNV-OS-C101 Design of Offshore Steel Structures, General (LRFD method) April 2004 April 2005DNV-OS-C102 Structural Design of Offshore Ships April 2004 April 2005DNV-OS-C103 Structural Design of Column Stabilised Units (LRFD method) April 2004 April 2005DNV-OS-C104 Structural Design of Self-elevating Units (LRFD method) October 2004 April 2005DNV-OS-C105 Structural Design of TLPs (LRFD method) October 2005 DNV-OS-C106 Structural Design of Deep Draught Floating Units (LRFD method) January 2001 April 2005DNV-OS-C201 Structural Design of Offshore Units (WSD method) April 2005 October 2005DNV-OS-C301 Stability and Watertight Integrity January 2001 DNV-OS-C401 Fabrication and Testing of Offshore Structures April 2004 April 2005DNV-OS-C501 Composite Components January 2003 DNV-OS-C502 Offshore Concrete Structures July 2004 October 2004

October 2005DNV-OS-C503 Concrete LNG Terminal Structures and Containment Systems October 2004 October 2004DNV-OS-D101 Marine and Machinery Systems and Equipment October 2005 DNV-OS-D201 Electrical Installations January 2005 April 2005

October 2005DNV-OS-D202 Instrumentation and Telecommunication Systems October 2000 October 2001DNV-OS-D301 Fire Protection October 2005 DNV-OS-E101 Drilling Plant October 2000 DNV-OS-E201 Oil and Gas Processing Systems October 2005 DNV-OS-E301 Position Mooring October 2004 DNV-OS-E401 Helicopter Decks March 2001 DNV-OS-E402 Offshore Standard for Diving Systems January 2004 April 2004

October 2004DNV-OS-E403 Offshore Loading Buoys April 2005 DNV-OS-F101 Submarine Pipeline Systems 2000 April 2002,

April 2003,October 2003

April 2004October 2005

DNV-OS-F201 Dynamic Risers 2001 October 2001,October 2003

DNV-OS-J101 Design of Offshore Wind Turbine Structures June 2004 October 2004April 2005DET NORSKE VERITAS

DNV Offshore Codes, Amendments and Corrections, October 2005Page 6 Sec.1Recommended PracticesDNV-RP-A202 Documentation of Offshore Projects January 2001 October 2001DNV-RP-A203 Qualification Procedures for New Technology September 2001 DNV-RP-B401 Cathodic Protection Design January 2005 April 2005

October 2005DNV-RP-C102 Structural Design of Offshore Ships February 2002 DNV-RP-C103 Column Stabilised Units February 2005 DNV-RP-C201 Buckling Strength of Plated Structure October 2002 April 2003

April 2004October 2004

DNV-RP-C202 Buckling Strength of Shells October 2002 April 2005DNV-RP-C203 Fatigue Design of Offshore Steel Structures August 2005 October 2005DNV-RP-C204 Design against Accidental Loads November 2004 April 2005DNV-RP-E301 Design and Installation of Fluke Anchors in Clay 2000 DNV-RP-E302 Design and Installation of Drag-in Plate Anchors in Clay December 2002 DNV-RP-E303 Geotechnical Design and Installation of Suction Anchors in Clay October 2005 DNV-RP-E304 Damage Assessment of Fibre Ropes for Offshore Mooring April 2005 DNV-RP-E305 Onbottom Stability Design of Submarine Pipelines October 1988 DNV-RP-E402 Naval Rescue Submersibles April 2004 DNV-RP-F101 Corroded Pipelines October 2004 DNV-RP-F102 Pipeline Field Joint Coating and Field Repair of Linepipe Coating October 2003 October 2003

April 2004October 2005

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

DNV-RP-F104 Mechanical Pipeline Couplings 1999 DNV-RP-F105 Free Spanning Pipelines March 2002 October 2003DNV-RP-F106 Factory Applied External Pipeline Coatings for Corrosion Control October 2003 April 2004

October 2005DNV-RP-F107 Risk Assessment of Pipeline Protection March 2001 October 2002DNV-RP-F201 Design of Titanium Risers October 2002 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 Topside Static Mechanical Equipment January 2002 DNV-RP-H101 Risk Management in Marine and Subsea Operations January 2003 DNV-RP-H102 Marine operations during Removal of Offshore Installations April 2004 DNV-RP-O401 Safety and Reliability of Subsea Systems April 1985 DET NORSKE VERITAS

DNV Offshore Codes, Amendments and Corrections, October 2005 Sec.2 Page 7SECTION 2AMENDED OFFSHORE SERVICE SPECIFICATIONS

DNV-OSS-101: Rules for Classification of Offshore Drill-ing and Support Units, October 2003Ch.2 Sec.1 Page 32 (Amended April 2004)A new item C202 has been inserted as follows:202 Rolled, forged or cast elements of steel and aluminiumfor structural application shall be supplied with DNV's materi-al cetificates in compliance with the requirements given inDNV-OS-B101. Ch.2 Sec.2 Page 36 (Amended April 2004)In item E201, the reference has been corrected to DNV-OS-D301, Ch.2 Sec.6.Ch.3 Sec.1 Page 52 (Amended April 2004)In Table C2, column Remarks, row 6, the reference hasbeen corrected to Sec.2 J.Ch.3 Sec.2 Page 69 (Amended April 2004)In item J301, the reference to Appendix A has been correct-ed to Appendix B.

DNV-OSS-102: Rules for Classification of Floating Pro-duction and Storage Units, October 2003Ch.2 Sec.1 Page 32 (Amended April 2004)A new item C202 has been inserted as follows:202 Rolled, forged or cast elements of steel and aluminiumfor structural application shall be supplied with DNV's materi-al cetificates in compliance with the requirements given inDNV-OS-B101.

Ch.2 Sec.2 Page 37 (Amended April 2004)A new item C202 has been inserted as follows:202 Rolled, forged or cast elements of steel and aluminiumfor structural application shall be supplied with DNV's materi-al cetificates in compliance with the requirements given inDNV-OS-B101. Ch.3 Sec.1 Page 54 (Amended April 2004)In Table C2, column Remarks, row 6, the reference hasbeen corrected to Sec.2 J.Ch.3 Sec.2 Page 72 (Amended April 2004)In item J301, the reference to Appendix A has been correct-ed to Appendix C.

DNV-OSS-103: Rules for Classification of LNG/LPG Floating Production and Storage Units or Installations, May 2001Sec.2 Page 7 (Amended October 2001)In item E201 2) the references F200, F300 and F400 should becorrected to DNV-OS-D301 Sec.7 F200, DNV-OS-D301 Sec.7F300 and DNV-OS-D301 Sec.7 F200, respectively.

DNV-OSS-309: Verification, Certification and classifica-tion of gas Export and receiving terminals, January 2005Sec.2 Page 9 (Amended April 2005)In item A102, under Statutory Certification, the reference toSec.2 C300 has been corrected to Sec.4 A300.Sec.4 Page 15 (Amended April 2005)In item B601, the numbering of Table A3 has been correct-ed to Table B3.DET NORSKE VERITAS

DNV Offshore Codes, Amendments and Corrections, October 2005Page 8 Sec.3SECTION 3AMENDED OFFSHORE STANDARDS

DNV-OS-C101: Design of Offshore Steel Structures, Gen-eral (LRFD Method), April 2004General (Amended April 2005)The text daily mean has been changed to mean dailythroughout the document.Sec.1 Table B1 Page 8 (Amended April 2005)Title for CN 30.1 has been changed to "Buckling StrengthAnalysis of Bars and Frames, and Spherical Shells".Sec.1 Table B3 Page 8 (Amended April 2005)Table row "ISO 13819-1 Petroleum and natural....., has beendeleted.Sec.1 Page 8 (Amended April 2005)In item C207, the text "during some reference period" has beenchanged to "during the applicable reference period.In item C220, the text "Information in the standard in order"has been changed to "Information in the standard added in or-der".Sec.1 Page 9 (Amended April 2005)In item C227, the text "ships, transit waterline.." has beenchanged to "ships, wet transit waterline..".Sec.1 Page 10 (Amended April 2005)In item D201, the symbol "kr correction factor" has been re-moved from the list.Sec.2 Page 12 (Amended April 2005)In item B105, the last sentence has been changed to: "Fatiguelife improvements based on mean stress level should not be ap-plied for welded structures, ref. DNV-RP-C203."Sec.2 Page 13 (Amended April 2005)In item D204, the parameter , has been removed from the for-mula.Sec.3 Page 16 (Amended April 2005)Item D301 has been deleted and the following items has beenrenumbered accordingly.In item D306 (previously 307), the reference 309 has beenchanged to 308.In item D307 (previously 308), at the end of the definition ofhop, the text: "operational draught, has been added.Sec.3 Page 17 (Amended April 2005)Item E201 has been changed to new E201 and E202 as fol-lows:201 The design of mobile offshore units shall be based on themost severe environmental loads that the structure may expe-rience during its design life. The applied environmental condi-tions shall be defined in the design basis or design brief, andstated in the unit's Operation Manual.202 The North Atlantic scatter diagram should be used inULS, ALS and FLS for unrestricted world wide operation.Sec.3 Page 17 (Amended April 2005)Item E505 has been changed as follows:505 For slender structures (typically chords and bracings,tendons, risers) where the Morison equation is applicable, thewave loads should be estimated by selection of drag and inertiacoefficients as specified in Classification Note 30.5.A new item E506 has been added as follows:

ing the free field wave kinematics, the presence of the adjacentstructures may be considered by radiation and diffraction anal-yses for calculation of the wave kinematics.Sec.3 Page 18 (Amended April 2005)In item E703, the text "is in general not to be taken" has beenchanged to "shall not be taken".In item E1202, the text "procedure is" has been changed to"procedures are".Item E1203 has been changed as follows:1203 When determining wind and hydrodynamic load, pos-sible increases of cross-sectional area and changes in surfaceroughness caused by icing shall be considered, where relevant.Item E1600 has been deleted, and item E1601 has been movedto new item E410.Sec.3 Page 19 (Amended April 2005)Item F101 has been changed to new F101 and F102 as follows,and the subsequent items has been renumbered accordingly:101 Where applicable data are available joint probability ofenvironmental load components, at the specified probabilitylevel, may be considered. Alternatively, joint probability of en-vironmental loads may be approximated by combination ofcharacteristic values for different load types as shown in TableF1.102 Generally, the long-term variability of multiple loadsmay be described by a scatter diagram or joint density functionincluding information about direction. Contour curves maythen be derived which give combination of environmental pa-rameters, which approximately describe the various loads cor-responding to the given probability of exceedance.Item H301 has been changed as follows:301 Settlement of the foundations into the sea bed shall beconsidered for permanently located bottom founded unitsSec.4 Page 23 (Amended April 2005)In item D305, the text "regions" has been changed to "structur-al parts".In item D401, the first paragraph has been changed as follows:For units which are intended to operate continuously at thesame location for more than 5 years, FM testing shall be in-cluded in the qualification of welding procedures for jointswhich all of the following apply:A new paragraph has been added at the end of item D401:For details on FM testing methods, see DNV-OS-C401 Ch.2Sec.1 C800.In item D501, the text "continuously at the same location for"has been added, and the reference to Sec.1 has beenchanged to Sec.2.Sec.5 Page 24 (Amended April 2005)Item A103 has been changed as follows:103 Structural capacity checks of all structural componentsshall be performed. The capacity checks shall consider bothexcessive yielding and buckling.Item A105 has been changed to new A105 and A106 as fol-lows:105 Gross scantlings may be utilised in the calculation ofhull structural strength, provided a corrosion protection systemin accordance with Sec.10 is installed and maintained.106 In case corrosion protection in accordance with Sec.10DET NORSKE VERITAS

506 In the case of adjacent large volume structures disturb- is not installed (and maintained) corrosion additions as given

DNV Offshore Codes, Amendments and Corrections, October 2005 Sec.3 Page 9in Sec.10 B500 shall be used. The corrosion addition shall notbe accounted for in the determination of stresses and resistancefor local capacity checks.Item A401, Guidance note item b), has been changed as fol-lows:

b) In case local plate bending stresses are of importance foryield check, e.g for lateral loaded plates, yield check maybe performed according to DNV-RP-C201 Sec.5.

Item A403 has been deleted and item 404 has been renumbered403.Sec.5 Page 25 (Amended April 2005)Item A501 has been changed as follows:501 Elements of cross sections not fulfilling requirements tocross section type III shall be checked for local buckling.Cross sectional types are defined in Appendix A.The Guidance note in item A505 has been changed as follows:

Guidance note:If buckling resistance is calculated in accordance with DNV-RP-C201 for plated structures, DNV-RP-C202 for shells, or Classi-fication Note 30.1 for bars and frames, the tolerance require-ments given in DNV-OS-C401 should not be exceeded, unlessspecifically documented.

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

In item C101, the text "cylindrical and un-stiffened conical"has been added.In items D101 and E102, the reference to Sec.2, has beendeleted.Sec.5 Page 26 (Amended April 2005)The parameter kr has been removed from the formula and fromthe list. rc has been removed from the list.Item F402, first paragraph has changed as follows:The requirement in 401 applies to an axis parallel to the plat-ing. For stiffeners at an oblique angle with the plating an ap-proximate requirement to standard section modulus may beobtained by multiplying the section modulus from 401 with thefactor:Sec.5 Page 27 (Amended April 2005)In item G302, the text "will be required" has been changed to"shall be carried out".In item G303, the references to "600 or 700" has been correct-ed to "400 and 500".Sec.6 Page 30 (Amended April 2005)In item A101 the text of offshore structures has been added.Item A104 has been changed as follows:104 The S-N curves shall in general be based on a 97.6 %probability of survival, corresponding to the mean-minus-two-standard-deviation curves of relevant experimental data.New items A107 and A108 has been added as follows:107 The analyses shall be performed utilising relevant sitespecific environmental data for the area(s) in which the unitwill be operated. The restrictions shall be described in the Op-eration Manual for the unit.108 For world wide operation the analyses shall be per-

spectrum) given in Classification Note 30.5. The North Atlan-tic scatter diagram shall be utilised.Item A201 has been changed as follows:201 Design fatigue factors (DFF) shall be applied to reducethe probability for fatigue failures.In item A205, the text "joint" has been changed to "element"and the first sentence in the Guidance note has been changedto:Units intended to follow normal inspection schedule accordingto class requirements, i.e. the 5-yearly inspection interval insheltered waters or drydock, may apply a Design Fatigue Fac-tor (DFF) of 1.Item A207 has been changed as follows:207 Welds beneath positions 150 m below water levelshould be assumed inaccessible for in-service inspection.In item A302, the text "short" has been changed to "below theacceptable limit".Sec.9 Page 37 (Amended April 2005)In item C502, the parameter fr has been inserted in front of t0in the equation, and the following definition has been added:

Sec.11 Page 45 (Amended April 2005)In item E302, the following paragraph has been added:See also requirements to tension piles in C107.Sec.11 Page 46 (Amended April 2005)Item E501 has been changed as follows:501 Suction anchors are vertical cylindrical anchors withopen or (normally) closed top, which are installed initially byself-weight penetration followed by application of underpres-sure (suction) in the closed compartment. The failure mechanism in the clay around an anchor will de-pend on various factors, like the load inclination, the anchordepth to diameter ratio, the depth of the load attachment point,the shear strength profile, and whether the anchor has an openor a closed top.Items E502 to E505 have been added as follows:502 If the load inclination is close to vertical, the anchor willtend to move out of the ground, mainly mobilising the shearstrength along the outside skirt wall and the inverse bearing ca-pacity of the soil at skirt tip level. If the anchor has an open top,the inverse bearing capacity will not be mobilised if the insideskirt friction is lower than the inverse bearing capacity at skirttip level.503 If the load inclination is more towards the horizontal,the resistance at the upper part of the anchor will consist of pas-sive and active resistances against the front and back of the an-chor, and side shear along the anchor sides. Deeper down, thesoil may flow around the anchor in the horizontal plane, or un-derneath the anchor.504 For intermediate load inclinations, there will be an inter-action between the vertical and the horizontal capacities. Thisinteraction may lead to vertical and horizontal failure loadcomponents that are smaller than the vertical and horizontalfailure loads under pure vertical or horizontal loading, see

fr = strength ratio as defined in 104DET NORSKE VERITAS

formed utilising environmental data (e.g. scatter diagram, Fig.1.

DNV Offshore Codes, Amendments and Corrections, October 2005Page 10 Sec.3Figure 1 Schematic resistance diagram for suction anchor.

505 It is important that the limiting equilibrium model repre-sents properly the failure mechanisms described above and ac-counts for the interaction that may occur between the verticaland horizontal failure modes.Previous item E502 has been replaced by new E506 as fol-lows:506 The soil material coefficients to be applied to the resist-ance of suction anchors are set equal to:

M = 1.20 for ULS Consequence Class 1 (CC1) and 2 (CC2)= 1.20 for ALS CC2, and= 1.00 for ALS CC1

In the calculation of the anchor resistance, strength anisotropyand the effects of cyclic loading on the undrained shearstrength shall be accounted for. The characteristic undrainedshear strength shall be taken as the mean value with due ac-count of the the quality and complexity of the soil conditions.Previous items E503, E504 and E505 have been renumberedE507, E508 and E509 respectively.

DNV-OS-C102: Structural Design of Offshore Ships, April 2004Ch.1 Sec.2 Page 16 (Amended April 2005)In A501, the text daily mean has been changed to meandaily.Ch.2 Sec.2 Page 38 (Amended April 2005)In A301, the text daily mean has been changed to meandaily.Ch.2 Sec.2 Page 38 (Amended April 2005)Item B301 has been changed as follows:103 The inspection category for units covered by this stand-ard shall relate to the structural category as shown in Table B1.

DNV-OS-C103: Structural Design of Column-stabilised Units (LRFD method), April 2004Sec.2 Page 9 (Amended April 2005)In C201, the text daily mean has been changed to meandaily two places.

DNV-OS-C104: Structural design of self-elevating Units (LRFD-method), October 2004Sec.2 Page 10 (Amended April 2005)In C201, the text daily mean has been changed to meandaily two places.

DNV-OS-C106: Structural Design of Deep Draught Float-ing Units (LRFD method), January 2001Sec.2 Page 8 (Amended April 2005)In C201, the text daily mean has been changed to meandaily.

DNV-OS-C201: Structural Design of Offshore Units (WSD Method), April 2005Sec.5 Page 26 (Amended October 2005)In A106, the reference has been corrected to: Sec.10 B407.Sec.11 Page 47 (Amended October 2005)In C701, the reference has been corrected to: Sec.3 E800.Sec.14 Page 77 (Amended October 2005)In K303, the second reference has been corrected to: Sec.11 D500

DNV-OS-C401: Fabrication and Testing of Offshore Structures, April 2004Ch.1 Sec.1 Page 10 (Amended April 2005)New items D209 to D216 have been added as follows:209 Structural testing is a hydrostatic test, carried out in or-der to demonstrate the tightness of the tanks and the structuraladequacy of the design. Where hydrostatic testing is not prac-tically feasible, hydropneumatic testing may be carried out in-stead under provision that the test is simulating, as far aspracticable, the actual loading of the tank. 210 Leak testing is an air or other medium test, carried out inorder to demonstrate the tightness of the structure.211 Hydropneumatic testing is a combination of hydrostaticand air testing, carried out in order to demonstrate the tightnessof the tanks and the structural adequacy of the design.212 Hose testing is a water test carried out to demonstratetightness of structural items.213 Shop primer is a thin coating applied after surface prep-aration and prior to fabrication as a protection against corro-sion during fabrication.214 Protective coating is a final coating protecting the struc-ture from corrosion215 Watertight means capable of preventing the passage ofwater through the structure under a head of water for which thesurrounding structure is designed.216 Weathertight means that in any sea conditions water willnot penetrate into the ship.

Table B1 Inspection categoriesInspection category Structural category

I SpecialII Primary

III 1) Secondary1) NDT acceptance criteria for ship side shall be taken according to In-

0

0,2

0,4

0,6

0,8

1

0 0,2 0,4 0,6 0,8 1

R h / R h,max

R v/R

v,m

axDET NORSKE VERITAS

Ch.2 Sec.4 Page 39 (Amended April 2005)spection category II.

DNV Offshore Codes, Amendments and Corrections, October 2005 Sec.3 Page 11A new item B105 has been added as follows:105 For hose testing, the hose pressure shall be at least200kN/m2 and applied at a maximum distance of 1.5 m. Thenozzle inside diameter shall be at least 12.0 mm.

DNV-OS-C502: Offshore Concrete Structures, July 2004Sec.6 Page 38 (Amended October 2004)The reference in item B304 is corrected to read:Sec.4 F.The reference in item B305 is corrected to read:Sec.4 G.Sec.6 Page 45 (Amended October 2004)The reference in item E113 is corrected to read:E110.Sec.6 Page 56 (Amended October 2005)In item M202, the line starting with is the stress .., hasbeen corrected to read: is the stress variation of the reinforcement (MPa)Sec.6 Page 58 (Amended October 2004)The reference in item O105 is corrected to read:B607.The reference in item O201 is corrected to read:Sec.4.Sec.6 Page 61 (Amended October 2004)The reference in item P503 is corrected to read:B607.Sec.7 Page 81 (Amended October 2004)The references to Sec.6, B407 in item P503, is corrected toread:Sec.6, B607.App.B Page 91 (Amended October 2004)The reference in item A117 is corrected to read:Sec.5 B900.

DNV-OS-C503: Concrete LNG Terminal Structures and Containment Systems, October 2004Sec.6 Page 26 (Amended October 2004)The reference in item B602 is corrected to read:DNV-OS-C502 P500App.D Page 52 (Amended October 2004)The reference in item A402, list item b),ii), is corrected to read:Sec.8 B

DNV-OS-D201: Electrical Installations, January 2005Ch.2 Sec.9 Page 64 (Amended April 2005)In Item D201, list item c), the reference to Table D3 has beencorrected to Table D1.Ch.2 Sec.2 Page 16 (Amended October 2005)Under item A204, bullet point b) has been replaced by:

b) The requirement for maximum transient voltage shall alsobe complied with due to load shedding or tripping of con-sumers. The requirement for maximum transient voltage

Ch.2 Sec.2 Page 24 (Amended October 2005)Under E102 bullet point a), the reference to 103 has been cor-rected to 101.Ch.2 Sec.2 Page 24 (Amended October 2005)Under F103 bullet point c), the SOLAS reference has been cor-rected to II-1/41.5.1.1. And, bullet point e) has been replacedby:

e) For High Speed and Light Craft category B, each part ofthe main bus bars with its associated generators shall bearranged in separate compartments. For these vessels, c)will not apply.

Ch.2 Sec.2 Page 24 (Amended October 2005)Under item F201 in the paragraph titled Exception, the ref-erence to d) has been corrected to e).Ch.2 Sec.2 Page 33 (Amended October 2005)Under item I403 in the first line of bullet point e), kVA hasbeen corrected to kVAh.Ch.2 Sec.2 Page 34 (Amended October 2005)Under item J102 bullet point c), the following new item hasbeen added to the short-dash list:- remote emergency stop/shutdown arrangements for systems

which may support the propagation of fire and or explosion(IACS UR E 15).

Also, the related Guidance note has been changed to:Guidance note:Examples of high fire risk areas are apart from machinery spaceof category A, galleys and pantries containing cooking applianc-es, laundry with drying equipment, spaces defined by paragraphs(8), (12) and (14) of SOLAS Ch.II-2 Reg. 9.2.2.3.2.2 for shipscarrying more than 36 passengers (IACS UR E 15), and areaswith fuel handling equipment.

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Ch.2 Sec.5 Page 52 (Amended October 2005)Item B102 has been changed to (bullet point b) and c) havebeen deleted):102 Automatic voltage regulatorThe AVR shall be capable of keeping the voltage within thevalues specified for stationary and dynamic variations.Ch.2 Sec.5 Page 54 (Amended October 2005)In Table C1, the item 12 Task description has been changed to:A.C. generator: Measuring of voltage regulation during steady andtransient loading and unloading, see B202 and B203.And, the footnotes of the table have been changed to:

1) Measuring of air gap only for machines of size 1.5 MVAand above.

Ch.2 Sec.9 Page 62 (Amended October 2005)Under item B201, bullet point b) has been corrected to:

b) Electrical and mechanical characteristics shall complywith the specifications of table 2, 3 and 4, respectively ofIEC 60092-351(2004-04).

DNV-OS-D202: Instrumentation and Telecommunication Systems, October 2000Ch.1 Sec.1 Page 9 (Amended October 2001)In Table C1 the explanation of UID should read: User inputDET NORSKE VERITAS

is not applicable for failure conditions. device.

DNV Offshore Codes, Amendments and Corrections, October 2005Page 12 Sec.3Ch.2 Sec.2 Page 16 (Amended October 2001)Item A302 should read:302 One command location is to be designated as the maincommand location. The main command location is to be inde-pendent of other command locations.Ch.2 Sec.4 Page 24 (Amended October 2001)In item C103 the number should not read 200 kW but be cor-rected to: 200 k.Ch.3 Sec.1 Page 37 (Amended October 2001)In item D102 the reference should be corrected to: C100.In item D201 the reference should be corrected to: Ch.2 Sec.1F500.

DNV-OS-E402: Offshore Standard for Diving System, January 2004Appendix A Page 54 (Amended April 2004)Under sub-section element A200, add the following item:202 Parameters applied for correction of units in empiricalformulae:

h1 = 1 m -1L1 = 1 m -1u1 = 1 m/su2 = 1 m

Appendix A Page 54 (Amended October 2004)Previous item B103 Motions of ship shaped support vessels,has been renumbered 102.Appendix A Page 55 (Amended October 2004)In item B102, the formula for az has been corrected as follows:

DNV-OS-F101: Submarine Pipeline Systems, 2000Spine (Amended April 2002)Replace spine with: DNV-OS-F101 Submarine Pipeline Systems, 2000Page iv, Acknowledgement (Amended April 2003)The text concerning cooperative organisations should read:The Standard has been circulated on extensive internal and ex-ternal hearing. The following organisations have made majorcontributions to the hearing process:

Allseas EngineeringAndrew Palmer & AssociatesBHP SteelBP Amoco ExplorationBritish SteelBrown & RootCoflexip Stena OffshoreDSNDDSTEMCEuropipeExxon Prod. Research CompanyITOCHUJP Kenny LtdKawasaki SteelMentor Project Eng.

NirasNorsk HydroNPDPhillips PetroleumRambll Oil & GasReinertsen EngineeringRntgen Technische Dienst bvSaga PetroleumSalzgitterSeaflexShaw Pipeline Services Ltd.ShellSOFREGAZStatoilStolt Comex SeawayVallourec & Mannesman Tubes

DNV is grateful for the valuable co-operations and discussionswith the individual personnel of these companies.General (throughout the document) (Amended April 2002)Yield strength should read yield stress.Sec.1 Page 6 (Amended April 2002)after C279 add:279(b) Pressure, shut-in: The maximum pressure that can beattained at the wellhead during closure of valves closest to thewellhead (wellhead isolation). This implies that pressure tran-sients due to valve closing shall be included.Sec.1 Page 7 (Amended April 2002)Replace C301 to C302 as follows:301 Splash Zone Lower Limit (LSZ) is determined by:

LSZ = |L1| - |L2| - |L3|L1 = lowest astronomic tide level (LAT)L2 = 30% of the splash zone wave-related height defined

in 303L3 = upward motion of the riser, if applicable302 Splash Zone Upper Limit (USZ) is determined by:

USZ = |U1| - |U2| - |U3|U1 = highest astronomic tide level (HAT)U2 = 70% of the splash zone wave-related height defined

in 303U3 = settlement or downward motion of the riser, if appli-

cable.To item D100 add:

BM Base materialL Load effectPWHT Post weld heat treatmentRT Radiographic testingST Surface testingToFD Time of flight detectionUT Ultrasonic testingSec.1 Page 7 (Amended April 2004)To item D100 add:

DWTT Drop Weight Tear TestLBZ Local Brittle ZonesWM Weld MaterialSec.5 Page 32, (of the reprint January 2003 edition) (Amended April 2004)Equations 5.1 and 5.2 have been corrected as follows:

az5 h1 hs 0.02 h1 hs L1 L 1+( ) g

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

(5.1)

(5.2)

plt 1.05pliplt 1.03pliDET NORSKE VERITAS

Navion

DNV Offshore Codes, Amendments and Corrections, October 2005 Sec.3 Page 13Sec.5 Page 33, (of the reprint January 2003 edition)(Amended April 2003)Table 5-2 page 33 should read

Sec.5 Page 34 (Amended April 2002)Add the following Guidance note to item D204:

Guidance note:For the system pressure test condition, the local test pressure isconsidered as incidental pressure. In order to calculate the corre-sponding pld, included in pd above, the local test pressure shallbe calculated as:

where href is the vertical distance between the point in questionand the reference height and inc should be 1.1. The same ap-proach applies to when the shut-in pressure is used.

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Sec.5 Page 35 (Amended April 2002)In item D301, delete the following sentence:The load effect factors apply to all design formats unless ex-plicitly stated.Sec.5 Page 36 (Amended April 2002)In item D505, replace as follows:

pb(t2) = Burst pressure Eq. (5.15)c = Flow stress parameter accounting for strain harden-ing given by:

but maximum 1.20

Sec.5 Page 37 (Amended April 2002)Add the following Guidance note item D507:

Guidance note:The maximum yield to ultimate stress ration, h, is found in Ta-ble 6-3 and Table 6-6. The increase of this factor with 0.02 in ac-cordance with footnote 5 and 3 in these tables respectively doesnot apply since it is already included in the factor 0.78.

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Replace item D510 as follows:

buckling has occurred. In case the external pressure exceedsthe criteria given below, buckle arrestors should be installedand spacing determined based on consequences of failure. Thepropagating buckle criterion reads:

Sec.5 Page 37 (Amended April 2004)In the Guidance note in D508, d/t has been replaces by D/t.Sec.5 Page 38 (Amended April 2004)The list of references in D701 has been amended as follows:

CN 30.5 Environmental Conditions and EnvironmentalLoads.

DNV-RP-C203 Fatigue Strength Analysis of OffshoreSteel Structures

DNV-RP-F105 Free Spanning Pipelines

In D710, the reference to DNV Guideline No. 14 has beenreplaced by DNV-RP-105.Sec.5 Page 41 (Amended April 2002)Add the following to Table 5-10:

Sec.5 Page 42 (of the reprint January 2003 edition)(Amended October 2005)In item D1203, Pf1/2Di has been corrected to Pf | Di.Sec.5 Page 43 (of the reprint January 2003 edition)(Amended October 2003)In item E401, correct the definition for as follows: = Lateral soil friction coefficientSec.6 Page 47 (Amended April 2002)Replace item A404 as follows:404 Linepipe formed from strip (skelp) and welded with onelongitudinal seam, without the use of filler metal. The longitu-dinal seam is generated by high frequency current (minimum100 kHz) applied by induction or conduction. The weld area(heat affected area) or the entire pipe shall be heat treated. Theforming may be followed by cold expansion to obtain the re-quired dimensions.Sec.6 Page 48 (Amended April 2002)Replace item C104 as follows:104 If materials shall be used at a design temperature above50C, the yield strength at the Tmax may be determined duringthe qualification of the manufacturing procedure specification.This information shall be obtained either by use of the curvesin Sec.5 B600 or by testing.Sec.6 Page 51 (Amended April 2002)Replace (footnote reference) in Table 6-3 as follows:

Sec.6 Page 51 (of the reprint January 2003 edition)(Amended October 2003)In the heading of Table 6-6, replace YS(Rr0.5) as follows:

Table 5-2 Characteristic material strength, fy,fuProperty ValueCharacteristic yield stress fy = (SMYS - fy,temp)UCharacteristic tensile strength fu = (SMTS - fu,temp)UA

pd ppt

inc--------- tghref pe+ =

c 1 ( ) fufy----+=

0.4 qh for D/t2 15

=

qh

pld pe( )pb t2( )

----------------------- 23

------- for pld pe>0 for pld pe

=

10-2 - 10-3 To be evaluated on a case by case basis

Charpy V-notch energy (KVT) minimum J 6)

ppr 35fyfabt2D----

2.5=

peppr

msc-------------DET NORSKE VERITAS

510 Propagation buckling cannot be initiated unless local YS(Rt0.5)

DNV Offshore Codes, Amendments and Corrections, October 2005Page 14 Sec.3Sec.6 Page 51 (Amended April 2004)In the heading of Table 6-6, replace in the fourth column asfollows:

Sec.6 Page 53 (Amended April 2002)Replace item C515 as follows:515 The hardness of base material, cladding material, HAZ,weld metal and the metallurgical bonding area shall meet therelevant requirements of this standard (see Table 6-3 and 6-6).Sec.6 Page 59 (Amended April 2002)Replace item E504 as follows:504 Plates and strip shall be subject to 100% visual examina-tion on both sides. The inspection shall be performed in a suf-

ficiently illuminated area (approximately 500 lx) by trainedpersonnel with sufficient visual acuity (e.g. Jaegar J-w eye-sight test at 300 mm within the last 12 months). The surfacefinish produced by the manufacturing process, shall ensure thatsurface imperfections can be detected by visual inspection. Sec.6 Page 63 (Amended April 2002)Replace part of Table 6-11 as follows:

Add footnote:HFW, EBW and LBW pipes, only.Sec.6 Page 60 (of the reprint January 2003 edition)(Amended April 2004)In table 6-13, the row starting with Transverse imper ...shall read:

Sec.6 Page 64 (Amended April 2002)In item E1003 replace the unit m with mm.Sec.6 Page 65 (Amended April 2002)Replace part of item E1011 as follows:1011 Repair welding of the weld seam is allowed for SAWLand SAWH pipes only and shall be performed in accordancewith qualified welding repair procedures. Requirements forwelding repair procedures are given in Appendix C. Repairwelding may only be performed subject to the following limi-tations:Sec.6 Page 66 (Amended April 2002)Replace part of item E1205 as follows:1205 The out-of-roundness for pipe ends shall be calculatedby the following formula:Sec.6 Page 67 (Amended April 2002)Replace part of Table 6-14 as follows:

Sec.6 Page 68 (Amended April 2002)Replace parts of Table 6-15 as follows:

Sec.7 Page 71 (Amended April 2004)In B307, the title of the referenced DNV-RP-F104 has beenchanged from Submarine Pipeline Couplings to Mechani-cal Pipeline Couplings.Sec.7 Page 71 (Amended April 2002)Replace Table 7-2 as follows:

Sec.7 Page 74 (Amended April 2002)Replace item D203 as follows:203 The chemical composition, taken from the product anal-ysis, of material for hot-formed components, castings andforgings, shall not exceed the values given in Table 7-4. Thenotes given in Table 7-5 shall apply, except Note 9 and Note10. Replace item D205 as follows:205 For material to be quenched and tempered, the contentof hardening elements Cr, Mo, Cu and Ni shall be sufficient toobtain the desired microstructure in the centre of the compo-nent. The selected chemical composition shall have adequatehardenability to ensure through thickness hardening of the re-spective component. Sec.7 Page 79 (Amended April 2002)Replace item G107 as follows:107 Mother pipe in C-Mn steels shall be delivered in the nor-malised, quenched and tempered or TMCP condition.Sec.7 Page 80 (Amended April 2002)Replace item G301 as follows:301 In general all the requirements given in Sec.6 D100 shallapply. The chemical composition of pipe for bends shall com-ply with Table 6-7 and Table 6-8 as relevant.Sec.7 Page 81 (Amended April 2002)Replace item G401 as follows:401 In situations where dedicated mother pipes are not avail-able for manufacturing of bends, the factors given in G100 andG200, especially G108, should be considered in order to selectthe most appropriate pipe for bend manufacturing.Sec.7 Page 83 (Amended April 2002)Replace in item G905 as follows:Tensile testing:

Base material in the arc outer radius longitudinal andtransverse (total 2 specimens)

Base material in the start transition area outer radius lon-gitudinal and transverse (total 2 specimens) unless 903 isapplicable.

Charpy V-notch impact testing:

Base material in the arc outer radius longitudinal and

YS Rt0.5( )UTS Rm( )------------------------

max

h( )3 )Metallographic examination

Pipe bodyWeldment

Q(&P9)Q

Q&PQ&P

Q&PQ&P

Transverse imperfections in weld 3) UT 100% 5% 100%

Greatest difference in pipe diameter between pipe ends (each pipe meas-ured)

R 2) 12.5% t

Greatest difference in pipe diameter between pipe ends (each pipe measured)

10% 10% t, but maximum 3 mm

Diameter pipe body 310 < D 1) < 610 mm

10% 0.75% D 1), but maximum 3.0 mm

Table 7-2 Bolts and nuts for subsea useBolt Nut Size rangeASTM A320, Grade L7

ASTM A194, Grade 4/S3 (Low-temperature requirement for Grade 4 and Grade 7 nuts)

< 50 mm

ASTM A320, ASTM A194, Grade 7 < 100 mmDET NORSKE VERITAS

transverse (total 2 sets)Grade L43

DNV Offshore Codes, Amendments and Corrections, October 2005 Sec.3 Page 15 Base material in the start transition area outer radius lon-gitudinal and transverse (total 2 sets) unless 903 is appli-cable.

Sec.7 Page 84 (Amended April 2002)Replace in item G906 as follows:Tensile testing:

Cross weld tensile testing in the arc area (one specimen) Cross weld tensile testing in the start transition area (one

specimen) unless 903 is applicable

Charpy V-notch impact testing:

Weld metal, FL, FL + 2 mm and FL + 5 mm in the arc (4sets)

Weld metal in the start transition area (1 set) unless 903 isapplicable.

Sec.8 Page 90 (Page 80 of the reprint January 2003 edition)(Amended October 2005)In item D107, the reference see B103 and 0 has been correctedto see B103 and Sec.1 C299.

Sec.8 Page 92 (Amended April 2002)Replace existing F204 with the following:204 The concrete coating shall be reinforced by steel barswelded to cages or by wire mesh steel. The following recom-mendations apply: For welded cages, the spacing between cir-cumferential bars should be maximum 120 mm. Steel barsshould have a diameter of 6 mm minimum. The average crosssectional area of steel reinforcement in the circumferential di-rection should be minimum 0.5% of the longitudinal concretecross section. The corresponding cross sectional area of steelreinforcement in the longitudinal direction should be minimum0.08% of the transverse concrete cross section.Sec.9 Page 98 (of the reprint January 2003 edition)(Amended October 2005)In item O403, the text ..through a 50 m filter.., has been cor-rected to ..through a 50m filter...Sec.12 Page 127 (Amended April 2002)Replace Table 12-1 as follows:

Table 12-1 Index and cross referencesKey word Reference Comment or aspectCharacteristic material strength

Sec.5 B600 fkSec.5 B604 Relation to supplementary requirement USec.5 B604 Guidance note

Proposed (conservative) de-rating stresses

Sec.5 B606 Reduction due to the UO/UOE processSec.5 D505 and Sec.5 D506

Reduction in longitudinal direction

Crossing Sec.2 B303 Evaluation of risksSec.3 C204 SurveySec.5 B102 Minimum vertical distanceSec.9 B300 Specification

Golden weld Sec.9 A807 RequirementsInstallation Sec.2 C400 Safety class

Sec.5 H100(D) Design criteriaSec.5 H200 Pipe straightnessSec.9 Installation phase

Linepipe NDT Level Sec.5 B500 Design generalSec.6 B100 General introduction and designationTable 6-13 NDT requirements

Mill pressure test Sec.1 C200 DefinitionSec.5 B200 Link between mill pressure test and designSec.5 D401 Reduced mill test pressure implication on pressure containment capacitySec.6 E1104 Basic RequirementSec.6 E1105 Maximum test pressureSec.6 E1108 Waiving of mill test UOE-pipes, conditions

Minimum wall thick-ness

Sec.5 B400 Minimum 12 mm and when it appliesSec.5 C300 When to use minimum wall thickness, relation to nominal thickness and corrosion allow-

anceOvality Eq. (5-18) and Eq. (5-

21)Minimum allowed ovality for collapse

Sec.5 D800 Maximum allowed ovality, as installedTable 6-14 and Table 6-15

Maximum allowed ovality, line pipe specification

Pressure - general Sec.1 C200 DefinitionsSec.3 B300 Pressure control system Table 3-1 Choice of PressureTable 5-7 Pressure load effect factors Table 3-1 Choice of PressureSec.4 B202, Sec.4 B203

Characteristic valuesDET NORSKE VERITAS

DNV Offshore Codes, Amendments and Corrections, October 2005Page 16 Sec.3Add the following new Table 12-1 b:

Sec.12 Page 107 (of the reprint January 2003 edition)(Amended October 2005)In table 12-1 b, first column, h(P)1 has been corrected toh(P).

(Amended April 2004) Equation 12.1 shall read as follows:

Pressure - incidental Sec.12 F600 Benefit of lower incidental pressureSec.3 B300 Pressure control systemTable 3-1 Selection of incidental pressure during pressure test and for full shut-in pressure

Reeling Sec.5 D1006 Fracture assessment when supplementary requirement P comes into forceSec.5 D1100 Engineering criticality assessmentEq. (5-25) Capacity formulaTable 5-8 Condition factorSec.6 D300 Supplementary requirement PSec.6 D400 Supplementary requirement DSec.9 E Testing

Spiral welded Sec.5 A204 RequirementsStrain hardening Eq. 5.26 In capacity formula; strain

Eq. 5.24 Capacity formula SMYS/SMTS - (in c)Table 6-3 SMYS and SMTSTable 6-3 h (YS/UTS)

System pressure test Sec.1 C200 DefinitionSec.5 B200 Link to designSec.5 B202 RequirementsSec.5 B203 Waiving of system pressure testSec.5 B204 Safety class during system pressure testSec.5 D400 Limit state check - pressure containmentSec.5 D500 Limit state check -local bucklingSec.9 O500 Execution of the test(filling, holding time etc)

Weld onto pipe Sec.7 B1203 Requirements for doubler plates etc.

Table 12-1 Index and cross references (Continued)

Table 12-1 b Characteristic material properties for design

Symbol Description ReferencePressure contain-

ment

Local buckling

Col-lapse

Load Control-

led

Dis-place-ment

Control-led

Propa-gating

buckling

Elastic propertiesE Youngs modulus X Poissons ratio X Temperature expansion, as function of the

temperature (within the actual temperature range)

X

Plastic propertiesSMYS Specified minimum yield stress Table 6-3 and Table 6-6 X X X X Xfy, temp Yield stress temperature derating value Sec.5 B603, Table 5-2

and Fig. 5-1 X X X X X

SMTS Specified minimum tensile strength Table 6-3 and Table 6-6 X - X - -fu, temp Tensile strength temperature derating value Sec.5 B603, Table 5-2

and Fig. 5-1 X - X - -

A Ultimate strength anisotropy factor Table 5-2 and Table 6-3 Note 4 - - X - -

fab Fabrication factor Table 5-3 - X (X) (X) XPlastic properties depending on additional requirementsu(U) increased utilisation Table 5-2 X X X X Xh(P)1 Strain hardening value Table 6-3, Table 6-6

and Sec.6 D304 - - - X -

c(U) Flow stress parameter Eq. 5.23 - - X - -

(12.1)pli pe( )D t12 t1--------------

2 U3 m SC

------------------------------- SMYS fy temp,( )DET NORSKE VERITAS

Sec.12 Page 109 (of the reprint January 2003 edition)

DNV Offshore Codes, Amendments and Corrections, October 2005 Sec.3 Page 17Equation 12.4 shall read as follows:

Sec.12 Page 128 (Amended April 2004)In E100, the definition of pt has been changed as follows:

pt = 1.05 pinc (if defined in the highest point of the pipe-line system)

Sec.12 Page 132 (Amended April 2002)Replace item F1100 as follows:Even though the safety factor is provided in the propagatingpressure formula, it is recommended to decrease this with 15%(from 35 to 30) for the propagating pressure resistance of thebuckle arrestor. This to decrease the failure probability to theunconditioned safety level in line with normal ULS checks.Sec.12 Page 132 (Amended April 2002)Replace item F1400 as follows:

Sec.12 Page 133 (Amended April 2002)Replace item G100 as follows:Assessment at Level 2 is considered safe provided that thegirth welds will not be subjected to conditions during operationthat may lead to failure by fatigue crack growth or unstablefracture.Sec.12 Page 134 (Amended April 2002)Replace part of item G301 as follows:If the total displacement, Vg, is measured at a distance z 0.2afrom the physical crack mouth then the CMOD can be calcu-lated from:Sec.12 Page 134 (Amended April 2002)Replace formula for in item G302 as follows:

Sec.12 Page 134 (Amended April 2002)In item H101 replace footnote to Table 12-4 as follows:ksi = 6.895 MPa; 1 MPa = 0.145 ksi; ksi = 1000 psi (lb f/in2)Sec.12 Page 134 to 135 (Amended April 2002)Delete second, fourth, fifth and second last paragraphs in itemI200 (are given in Sec.5 G200)Sec.12 Page 136 (Amended April 2002)Replace the text in Fig. 12-3 as follows:Displacement controlled condition = NDT level 1Sec.12 Page 137 (Amended April 2002)Replace in MDS sheet, 3rd line:DNV-OS-F101 Submarine Pipeline SystemsSec.12 Page 138 (Amended April 2002)Add after first paragraph in item K300 text as follows:

limit states for Concrete Crushing (K200), Fatigue (Sec.5D700) and Rotation (Sec.5 H203) shall be satisfied. Referenceis further made to Endal et. al. (1995) for guidance on the Ro-tation limit state.Sec.12 Page 138 (Amended April 2002)Replace the first paragraph after sub-heading Overbend initem K300 as follows:For static loading the calculated strain shall satisfy Criterion Iin Table 12-5. The strain shall include effects of bending, axialforce and local roller loads. Effects due to varying stiffness(e.g. strain concentration at field joints or buckle arrestors)need not be included.Sec.12 Page 138 (Amended April 2002)Replace the first paragraph after sub-heading Sagbend initem K300 as follows:For combined static and dynamic loads the equivalent stress inthe sagbend and at the stinger tip shall satisfy the allowablestress format ASD as given in F1200, however, shall be 0.87.Appendix A Page 142 (Amended April 2002)Add:B 1000 Mill pressure test1001 The mill test pressure is lower in ISO than in this stand-ard. The ISO requirement is:

This hoop stress formula for the ISO mill pressure test is dif-ferent from the formula in ISO 13623 and DNV (which areidentical). Hence, the mill test pressure difference compared tothis standard depends on D/t.Appendix B A402 Page 143 (Amended April 2002)Add the following Guidance note:

Guidance note:This conversion is not applicable to API 5L type specimens

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Appendix C Page 128 (of the reprint January 2003 edition)(Amended October 2005)In Table C-1, in the table-cell below Wall Thickness (mm), thetext t < 0 has been corrected to t < 20.Appendix C C400 Page 156 (Amended April 2002)Replace:C400 Batch testing Girth welds(Clarification)Appendix C Page 165 (Amended April 2004)The last sentence in F309 has been corrected to:Any requirement for fracture arrest properties as listed in Ta-ble 6-9 shall not apply for the weld and HAZ.Appendix D Page 178 (Amended April 2002)Replace item D205 as follows:205 The type and number of ultrasonic probes shall be suffi-cient to ensure that the base material, or the weld and the areaadjacent to the weld, is:

scanned from both sides of the weld for flaws oriented par-allel to the longitudinal weld axis

scanned from both directions approximately parallel tolongitudinal weld axis for flaws oriented transverse to the

(12.4)pdD t12 t1-------------- SMYS fy temp,( )

f0f0 0.030 1

D120t-----------+ 2c

Dt----

2+

1PePc-----

------------------------------------------------------------------------------ (12.12)=

Jm

YS TS+2

---------------------------------------------------------=

p 0.952tmin

D------------- SMYS=DET NORSKE VERITAS

In addition to the simplified stress criteria given below, the longitudinal weld axis

DNV Offshore Codes, Amendments and Corrections, October 2005Page 18 Sec.3 fully covered by ultrasound beams that are approximatelyperpendicular to the surface of flaws that are reflecting theultrasound.

It may be necessary to include tandem, TOFD and/or focusedprobes in order to enhance the probability of detection or char-acterisation of flaws.Appendix D Page 180 (Amended April 2002)Replace last paragraph of item E205 as follows:The maximum allowable flaw sizes from the ECA shall be re-duced in length and height with a flaw sizing error, that basedon the data from the qualification testing will give a 95% con-fidence against under sizing of flaws.Appendix D Page 180 (Amended April 2002)Replace item F105 as follows:105 Equipment and procedures used for the ultrasonic test-ing shall comply with the requirements of subsection D. Therequirements for automated NDT processes given in subsec-tion D are additional to the requirements of any code or stand-ard referred to in this subsection where automated NDTmethods are prescribed or optional.Appendix D Page 181 (Amended April 2002)Replace item F301 as follows:301 For ultrasonic testing of the base material the require-ments of F100 and F200 shall apply.Appendix D Page 182 (Amended April 2002)Replace the second bullet point in item G503 as follows:

a sample pipe shall be fitted with one 3.0 mm throughdrilled hole at each end. The distance from the pipe end tothe hole shall be equal to the length not covered by the ul-trasonic testing equipment during production testing. Priorto start of production the pipe shall be passed through theultrasonic testing equipment at the operational scanningvelocity. For acceptance of the equipment both holes needto be detected by all probes. At the manufactures optionthese holes may be included in the reference block.

Appendix D G614 Page 185 (Amended April 2002)Replace the last part of item G614 as follows:The acceptance criteria are:

Table D-4 and lack of fusion and lack of penetration arenot permitted.

Appendix D Page 185 (Amended April 2002)Replace item G710 as follows:The length of the N5 notches shall be 1.5 times the probe (crys-tal) element size or 20 mm, whichever is the shorter. Thelength does not include any rounded corners. The width of theN5 notches shall not exceed 1 mm.Appendix D, Table D-3 Page 190 (Amended April 2002)Replace Table D-3 as follows:

Appendix D Page 193 (Amended April 2002)In item I301 replace N5 notches with N3 (3% of thickness)

Appendix E Page 196 (Amended April 2002)Replace item B408 as follows:408 The recording or marking system shall clearly indicatethe location of imperfections relative to the 12 o'clock positionof the weld, with a 1% accuracy. The system resolution shallbe such that each segment of recorded data from an individualinspection channel does not represent more than 2 mm of cir-cumferential weld distance.

DNV-OS-F201: Dynamic Risers, 2001Sec.4 Page 24 (Amended October 2003)Replace 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 25 (Amended October 2003)Replace item C201 as follows:C201 Fatigue analysis of the riser system shall consider allrelevant cyclic load effects including:Sec.5 Page 29 (Amended October 2003)In Table 5-2, the NOTES and subscripts 1) and 2) refer to theULS condition only. Replace Table 5-2 as follows:

Sec.5 Page 33 (Amended October 2001)In 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:

Sec.5 Page 34 (Amended October 2003)The 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 55 (Amended October 2003)In 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 by

Undercut, if meas-ured by mechanical means

IndividualDepth dd > 1.0 mm1.0 mm d 0.5 mm0.5 mm d 0.2 mm< 0.2 mm

Permitted lengthNot permitted50 mm100 mmunlimited

Accumulated length in any 300 mm length of weld: < 4 t, maximum 100 mm

Table 5-2 Load effect factors

Limit stateF-load effect

E-load effect

A-load effect

F E AULS 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, F shall be taken as 1/1.1.

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

(5.29)

(5.30)

42

2

min

22

)(

+

+

tppp

TT

MM

c

e

k

e

k

( )( )

( )( )434 333 232

tDDtDM

ttDTe

+= DET NORSKE VERITAS

notches the quadratic drag term in the Morison equation expressed

DNV Offshore Codes, Amendments and Corrections, October 2005 Sec.3 Page 19by 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 70 (Amended October 2003)The term in equation (B.19) should read . Replaceequation (B.19) as follows:

Appendix B Page 70 (Amended October 2003)The denominator in equation (B.21) should read 2, instead of. Replace equation (B.21) as follows:

Appendix B Page 71-73 (Amended October 2003)Delete 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.

DNV-OS-J101: Design of Offshore Wind Turbine Struc-tures, June 2004Sec.3 Page 26 (Amended October 2004)

The first equation in item C302 has been corrected as follows:

The last equation in item C302 has been corrected as follows:

Sec.7 Page 66 (Amended October 2004)Item J203 is amended to read:203 The maximum vertical deflection is:

App.A Page 101 (Amended October 2004)

App.G Page 120 (Amended October 2004)The equation in item B101 has been corrected as follows:

App.G Page 121 (Amended April 2005)The equation in item C101 has been corrected as follows:

(B.19)

(B.21)

1s 1as

=

a

aaSsssf exp)( 1

( )( )

++

+=

2;1

2

2;1

2

22

2

0

11

1

0

2

1

swm

swm

SmGa

f

SmGa

fD

max = the sagging in the final state relative to the straight line joining the supports

0 = the pre-camber 1 = the variation of the deflection of the beam due to the permanent loads immediately after loading

2 = the variation of the deflection of the beam due to the variable loading plus any time dependent de-formations due to the permanent load.

=

2

5.0exp45

4

2

45exp

)2()(

p

pfff

p

fffgfS