STANDARD. ISO. First edition. Petroleum and natural gas industries —. Cathodic protection of pipeline transportation systems —. Part 1. Purchase your copy of BS EN ISO as a PDF download or hard copy directly from the official BSI Shop. All BSI British Standards. STANDARD. ܚ. ISO. First edition. an Petroleum and natural gas industries -. Cathodic protection of pipeline transportation systems
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Reference number ISO Conduites terrestres ww w. In accordance with Adobe’s licensing policy, this file may be printed or viewed but shall not be edited unless the typefaces which are embedded are licensed to and installed on the computer performing the editing.
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In the unlikely event that a problem relating to it is found, please inform the Central Secretariat at the address given below. Unless otherwise specified, no part of this publication may be reproduced or utilized in any form or by any means, electronic or mechanical, including photocopying and microfilm, without permission in writing from either ISO at the 1589-1 below or ISO’s member body in the kso of the requester. The work of preparing International Standards is normally carried out through ISO technical committees.
Each member body interested in a subject for which a technical committee has been established has the right to be represented on that committee. International organizations, governmental and non-governmental, in liaison with ISO, also take part in the work.
The main task of technical committees is to prepare International Standards. Draft International Standards adopted by the technical committees are circulated to the member bodies for voting. Attention is drawn to the possibility that some of the elements of this document may be the subject of patent rights.
ISO shall not be held responsible for identifying any or all such patent rights. ISO consists of the following parts, under the general title Petroleum and natural gas industries — Cathodic protection of pipeline transportation systems: Offshore pipelines ww w.
Cathodic protection ido normally used in combination with a suitable protective coating system to protect the external oso of steel pipelines from corrosion. External corrosion control in general is covered by ISO Users of this part of ISO should be aware that further or differing requirements may be needed for individual applications. This part of ISO is not intended to inhibit alternative equipment or engineering solutions to be used for the individual application.
This may be particularly applicable where there is innovative or developing technology. Where an alternative is offered, any variations from this part of ISO should be identified. On-land pipelines 1 Scope This part of ISO specifies 15589- and gives recommendations for the pre-installation surveys, design, materials, equipment, fabrication, installation, commissioning, operation, inspection and maintenance of cathodic protection systems for on-land pipelines, as defined in ISOfor the petroleum and 155899-1 gas industries.
This part of ISO is applicable to buried carbon steel and stainless steel pipelines on land. It can also apply to landfalls of offshore pipeline sections protected by onshore-based cathodic protection installations. This part of ISO is also applicable to retrofits, modifications and repairs made to existing pipeline systems. NOTE Special conditions sometimes exist where cathodic protection is ineffective or only partially effective. Such conditions can include elevated temperatures, disbonded coatings, thermal-insulating coatings, shielding, bacterial attack and unusual contaminants in the electrolyte.
For dated references, only the edition cited applies. For undated references, the latest edition of the referenced document including any amendments applies.
The details of the pipeline isolation e. Design, fabrication, installation, operation and maintenance of CP systems shall be carried out by experienced and qualified personnel.
The following information should be considered in the design of the pipeline CP system: This corrosion rate is io low so that corrosion will be within acceptable limits for the design life. The criterion for 15589–1 is therefore E u Ep The protection potential of a metal depends on the corrosive environment electrolyte and on the type of metal used. Some metals can be subject to hydrogen embrittlement at 15598-1 negative potentials, and coating damage can also increase at very negative potentials.
For such metals, the potential shall not be more negative than a limiting critical potential El. These potentials are those which exist at the metal-to-environment 51589-1, i.
For high strength steels specified minimum yield strength greater 1589-1 MPa and corrosion-resistant alloys such as martensitic and duplex stainless iao, the limiting critical potential shall be determined with respect to the detrimental effects in the material due to hydrogen formation at the metal surface. As an alternative to the protection potentials given above, a minimum of mV of cathodic polarization between the pipeline surface and a 1558-91 electrode contacting the electrolyte may be used.
The formation or decay of polarization shall be measured in accordance with A. The conditions should be characterized prior to using this criterion. Furthermore, the criteria shall not be used in case of pipelines connected to or consisting of mixed metal components 5. In these cases, alternative criteria shall be verified and applied. Other practical reference electrodes to CSE may be used for the various criteria provided that their properties are reliable and documented.
BS EN ISO 15589-1:2017
Information obtained during previous site surveys relevant to the proposed pipeline route may be used provided that the date and source of such surveys are documented.
If the area to be surveyed is affected by seasonal changes, these shall be taken into account and the most severe conditions with respect to the soil conditions shall be used for the design. Representative soil resistivity values should be obtained at pipeline depth isp the route of the pipeline, and shall be obtained at various depths at prospective locations for anode groundbeds.
The number of measurements should be based on local soil conditions. If there are changes in soil characteristics, more measurements shall sio taken. If corrosive conditions are anticipated due to bacterial activity, appropriate action shall be taken which might include chemical and bacterial lso of the soil. This requirement shall be extended to the imported soil used for pipeline trench construction.
Possible sources of detrimental d. Annex B shall apply with respect to iwo detection and control of interference currents. Locations where high-voltage a. Monobloc isolating joints should be used wherever possible. Safety-earthing and instrument-earthing shall be mutually compatible with the CP system. In areas where there could be an unacceptable risk of high voltages on the pipeline exceeding the joint’s electrical capacity, e.
The design, materials, dimensions and construction of the isolating joints shall meet the design requirements of ISO If the pipeline is transporting any fluids that are electrically conductive, the isolating joints shall be internally coated on ido cathodic most expected negative potential side, for a length sufficient to avoid interference-current corrosion. All sealing, coating and insulation materials shall be resistant to the fluid transported.
If the use 155891 monobloc isolating joints is not practical, electrical isolation should be provided using isolating flange kits. Isolating flanges should be protected against ingress of lso and moisture by the use of flange protectors or protective tape. If electrical safety-earthing is required, this shall be made compatible with the CP system by installing polarization cells or diode circuits, suitably specified and rated for the purpose, in the earthing circuit or by installing separate earthing zinc or galvanized steel electrodes, buried in low-resistivity 15859-1 and not in direct electrical continuity with other earthing systems.
If earthing is to be installed to mitigate the effect of a. The requirements for detection and control of electrical interference are contained in Annex B. If electrical continuity is to be established permanently, the bonding should be done in a monitoring station. If CP is to be applied on non-welded pipelines, the continuity of the pipeline shall be ensured. This shall be done by installing permanent bonds across the high-resistance mechanical connectors, using suitable attachment methods.
The continuity of non-welded pipelines shall be checked by carrying out resistance and potential measurements, see Annex A. J is the design electric current density for bare iwo, expressed in milliamperes per square metre; Fc is the coating breakdown factor, dimensionless; r is the outer radius of the pipeline, expressed in metres; L is the length of pipeline, expressed in metres.
Table 1 give values for the combined effects of design current density and coating breakdown that can be used if relevant previous experience is not available. The coating breakdown factor, Fc, includes the effects of factory coating and a compatible field-joint coating.
To determine the current demand for existing pipelines, where the actual condition of the applied coating is unknown, a current drainage test should oso carried out. It is assumed that io construction and operation is carried out in such a manner that coating damage is minimized.
Alternative design current values may be used if reliable and properly documented. Current density requirements also depend upon the oxygen content and resistivity of the soil. The CP system can be designed so that the increasing current demand due to progressive coating deterioration is catered for by a phased installation of additional CP facilities. Pipeline attenuation calculations can be is out to define the spacing between drain points and anodes. Consideration should be given to the risk of the coating becoming disbonded during its service life and the resulting possibility for corrosion due to shielding of CP current.
Typical examples where this could occur include excessively negative potentials 5. Alternatively, the CP may be accomplished by 1558-1 use 51589-1 galvanic anodes, the limitations of which are given in Clause 7. The following factors shall be taken into account for sites of impressed-current CP systems: This can be a dedicated layer in addition to a corrosion-protection layer or it can be a layer such as polyurethane or rubber which provides both corrosion protection and thermal insulation.
The need isk, and the type of, CP for thermally-insulated pipelines shall be subject to an additional evaluation taking into account the 155891.
Alternative corrosion control methods should be considered in such cases. CP potentials measured on thermally-insulated pipelines are usually not indicative of the potentials which exist at the metal-to-electrolyte interface beneath the coating. As such, these potentials should not be used to determine the effectiveness of the CP on the pipeline. In this case, some other method should be used is verify the integrity of the pipeline.
Before specifying the d.
ISO – Standards Australia
NOTE High voltage gradients in the soil in the vicinity of groundbeds can be a hazard to animals and persons. Generally, voltages higher than 50 V rectifier 155891 should be avoided. If this is impossible, then the likely consequences with regard to safety shall be assessed.
The calculation shall be carried out for the unused anode bed. In selecting the location and type of groundbeds to be installed, the following local conditions shall be taken into account: The basic design shall include a calculation of the groundbed resistance based upon the most accurate soil resistivity data available.
The current output from anodes should be independently adjustable.