lOMoARcPSD|28844136
Electrical Engineering Design DEP
Digital Design using Verilog On FPGA (National Institute of Technology Karnataka)
Studocu is not sponsored or endorsed by any college or university
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP SPECIFICATION
Copyright Shell Group of Companies. No reproduction or networking permitted without license from Shell. Not for resale
ELECTRICAL ENGINEERING DESIGN
DEP 33.64.10.10-Gen.
February 2014
DESIGN AND ENGINEERING PRACTICE
DEM1
© 2014 Shell Group of companies
All rights reserved. No part of this document may be reproduced, stored in a retrieval system, published or transmitted, in any form or by any means, without the prior
written permission of the copyright owner or Shell Global Solutions International BV.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 2
PREFACE
DEP (Design and Engineering Practice) publications reflect the views, at the time of publication, of Shell Global Solutions
International B.V. (Shell GSI) and, in some cases, of other Shell Companies.
These views are based on the experience acquired during involvement with the design, construction, operation and
maintenance of processing units and facilities. Where deemed appropriate DEPs are based on, or reference international,
regional, national and industry standards.
The objective is to set the standard for good design and engineering practice to be applied by Shell companies in oil and
gas production, oil refining, gas handling, gasification, chemical processing, or any other such facility, and thereby to help
achieve maximum technical and economic benefit from standardization.
The information set forth in these publications is provided to Shell companies for their consideration and decision to
implement. This is of particular importance where DEPs may not cover every requirement or diversity of condition at each
locality. The system of DEPs is expected to be sufficiently flexible to allow individual Operating Units to adapt the
information set forth in DEPs to their own environment and requirements.
When Contractors or Manufacturers/Suppliers use DEPs, they shall be solely responsible for such use, including the
quality of their work and the attainment of the required design and engineering standards. In particular, for those
requirements not specifically covered, the Principal will typically expect them to follow those design and engineering
practices that will achieve at least the same level of integrity as reflected in the DEPs. If in doubt, the Contractor or
Manufacturer/Supplier shall, without detracting from his own respons bility, consult the Principal.
The right to obtain and to use DEPs is restricted, and is typically granted by Shell GSI (and in some cases by other Shell
Companies) under a Service Agreement or a License Agreement. This right is granted primarily to Shell companies and
other companies receiving technical advice and services from Shell GSI or another Shell Company. Consequently, three
categories of users of DEPs can be distinguished:
1)
Operating Units having a Service Agreement with Shell GSI or another Shell Company. The use of DEPs by these
Operating Units is subject in all respects to the terms and conditions of the relevant Service Agreement.
2)
Other parties who are authorised to use DEPs subject to appropriate contractual arrangements (whether as part of
a Service Agreement or otherwise).
3)
Contractors/subcontractors and Manufacturers/Suppliers under a contract with users referred to under 1) or 2)
which requires that tenders for projects, materials supplied or - generally - work performed on behalf of the said
users comply with the relevant standards.
Subject to any particular terms and conditions as may be set forth in specific agreements with users, Shell GSI disclaims
any liability of whatsoever nature for any damage (including injury or death) suffered by any company or person
whomsoever as a result of or in connection with the use, application or implementation of any DEP, combination of DEPs
or any part thereof, even if it is wholly or partly caused by negligence on the part of Shell GSI or other Shell Company. The
benefit of this disclaimer shall inure in all respects to Shell GSI and/or any Shell Company, or companies affiliated to these
companies, that may issue DEPs or advise or require the use of DEPs.
Without prejudice to any specific terms in respect of confidentiality under relevant contractual arrangements, DEPs shall
not, without the prior written consent of Shell GSI, be disclosed by users to any company or person whomsoever and the
DEPs shall be used exclusively for the purpose for which they have been provided to the user. They shall be returned after
use, including any copies which shall only be made by users with the express prior written consent of Shell GSI. The
copyright of DEPs vests in Shell Group of companies. Users shall arrange for DEPs to be held in safe custody and Shell
GSI may at any time require information satisfactory to them in order to ascertain how users implement this requirement.
All administrative queries should be directed to the DEP Administrator in Shell GSI.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 3
TABLE OF CONTENTS
1.
1.1
1.2
1.3
1.4
1.5
1.6
1.7
INTRODUCTION ........................................................................................................ 5
SCOPE........................................................................................................................ 5
DISTRIBUTION, INTENDED USE AND REGULATORY CONSIDERATIONS ......... 5
DEFINITIONS ............................................................................................................. 5
CROSS-REFERENCES ............................................................................................. 9
SUMMARY OF MAIN CHANGES ............................................................................. 10
COMMENTS ON THIS DEP ..................................................................................... 11
NON NORMATIVE TEXT (COMMENTARY) ............................................................ 11
2.
2.1
2.2
2.3
2.4
2.5
DESIGN AND ENGINEERING PRINCIPLES .......................................................... 12
STANDARDS, CODES, REGULATIONS AND TECHNICAL ASSURANCE ........... 12
OPERATIONAL SAFETY AND RELIABILITY .......................................................... 12
PROTECTION AGAINST EXPLOSION AND FIRE HAZARDS ............................... 13
STANDARDISATION OF EQUIPMENT AND MATERIALS ..................................... 14
CERTIFICATES, DECLARATIONS AND TEST REPORTS .................................... 14
3.
3.1
3.2
3.3
3.4
3.5
3.6
3.7
3.8
3.9
3.10
ELECTRICAL SYSTEM DESIGN............................................................................. 15
GENERAL ................................................................................................................. 15
ELECTRICAL LOADS AND ELECTRICITY CONSUMPTION ................................. 16
SYSTEM VOLTAGES AND FREQUENCY .............................................................. 19
SYSTEM POWER FACTOR ..................................................................................... 20
SUPPLY CAPACITY ................................................................................................. 21
SHORT CIRCUIT RATINGS ..................................................................................... 25
ELECTRICAL PROTECTION ................................................................................... 26
SYSTEM EARTHING ................................................................................................ 27
ELECTRICITY SUPPLY FOR VITAL SERVICES .................................................... 29
CONTROL OF FREQUENCY, VOLTAGE AND REACTIVE POWER ..................... 33
4.
4.1
4.2
4.3
4.4
4.5
4.6
4.7
4.8
4.9
4.10
4.11
DESIGN AND SELECTION REQUIREMENTS FOR EQUIPMENT AND
CABLES ................................................................................................................... 35
GENERATORS ......................................................................................................... 35
SWITCHGEAR .......................................................................................................... 37
POWER TRANSFORMERS ..................................................................................... 37
UPS EQUIPMENT .................................................................................................... 38
CAPACITORS ........................................................................................................... 39
ELECTRIC MOTORS ............................................................................................... 40
ELECTRICAL NETWORK MONITORING AND CONTROL (ENMC) SYSTEM ...... 41
CABLES, WIRES AND ACCESSORIES .................................................................. 42
OVERHEAD LINES .................................................................................................. 45
LIGHTING AND SMALL POWER EQUIPMENT ...................................................... 47
ELECTRIC HEATING EQUIPMENT ......................................................................... 49
5.
5.1
5.2
5.3
5.4
5.5
ENGINEERING AND INSTALLATION REQUIREMENTS ...................................... 51
GENERAL ................................................................................................................. 51
MAIN EQUIPMENT ................................................................................................... 51
CABLING AND WIRING ........................................................................................... 53
LIGHTING AND SMALL POWER INSTALLATIONS ................................................ 60
EARTHING AND BONDING ..................................................................................... 62
6.
DESIGN AND ENGINEERING REQUIREMENTS FOR PARTICULAR
INSTALLATIONS ..................................................................................................... 64
SUBSTATIONS ......................................................................................................... 64
ADDITIONAL REQUIREMENTS FOR OFFSHORE INSTALLATIONS ................... 68
OVERHEAD LINES .................................................................................................. 72
LABORATORIES ...................................................................................................... 75
ANALYSER BUILDINGS .......................................................................................... 75
JETTIES .................................................................................................................... 76
NON-INDUSTRIAL BUILDINGS ............................................................................... 76
PLANT LIFT INSTALLATIONS ................................................................................. 77
TEMPORARY ELECTRICAL INSTALLATIONS ....................................................... 77
6.1
6.2
6.3
6.4
6.5
6.6
6.7
6.8
6.9
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 4
7.
7.1
7.2
7.3
7.4
7.5
DOCUMENTS AND DRAWINGS ............................................................................. 81
GENERAL ................................................................................................................. 81
SUMMARY OF ELECTRICAL ENGINEERING ........................................................ 81
DEP STANDARD REQUISITION SHEETS .............................................................. 81
DESIGN DRAWINGS ............................................................................................... 81
EQUIPMENT AND CABLE NUMBERING ................................................................ 84
8.
REFERENCES ......................................................................................................... 85
APPENDICES
APPENDIX 1
SELECTION OF ELECTRICAL APPARATUS FOR EXPLOSIVE GAS
ATMOSPHERES ............................................................................................. 94
APPENDIX 2
SYSTEM NEUTRAL EARTHING DIAGRAMS ............................................... 96
APPENDIX 3
CONTROLS, INSTRUMENTS, INDICATIONS AND ALARMS...................... 97
APPENDIX 4
ILLUMINATION LEVELS .............................................................................. 106
APPENDIX 5
EQUIPMENT AND CABLE NUMBERING .................................................... 109
APPENDIX 6
DECISION PROCEDURE FOR ABOVE-GROUND OR UNDERGROUND
CABLE ROUTING ......................................................................................... 111
APPENDIX 7
DELIVERABLE DOCUMENTS ..................................................................... 115
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 5
1.
INTRODUCTION
1.1
SCOPE
This DEP specifies requirements and gives recommendations for the design, engineering
and installation of electrical facilities, which comprise all fixed electrical installations for
power and lighting up to and including main supply facilities for instrument and process
control equipment and safeguarding systems, cathodic protection equipment,
telecommunication equipment, fire-fighting and alarm equipment, etc.
This DEP excludes facilities located in North America. Refer to DEP 33.64.20.10-Gen.,
Electrical engineering design for North America Application.
This DEP contains mandatory requirements to mitigate process safety risks in accordance
with Design Engineering Manual (DEM) 1 – Application of Technical Standards.
This is a revision of the DEP of the same number dated February 2011; see (1.5) regarding
the changes.
1.2
DISTRIBUTION, INTENDED USE AND REGULATORY CONSIDERATIONS
Unless otherwise authorised by Shell GSI, the distribution of this DEP is confined to Shell
companies and, where necessary, to Contractors and Manufacturers/Suppliers nominated
by them. Any authorised access to DEPs does not for that reason constitute an
authorization to any documents, data or information to which the DEPs may refer.
This DEP is intended for use in facilities related to oil and gas production, gas handling, oil
refining, chemical processing, gasification, distribution and supply/marketing. This DEP
may also be applied in other similar facilities.
When DEPs are applied, a Management of Change (MOC) process shall be implemented;
this is of particular importance when existing facilities are to be modified.
If national and/or local regulations exist in which some of the requirements could be more
stringent than in this DEP, the Contractor shall determine by careful scrutiny which of the
requirements are the more stringent and which combination of requirements will be
acceptable with regards to the safety, environmental, economic and legal aspects. In all
cases the Contractor shall inform the Principal of any deviation from the requirements of
this DEP which is considered to be necessary in order to comply with national and/or local
regulations. The Principal may then negotiate with the Authorities concerned, the objective
being to obtain agreement to follow this DEP as closely as possible.
1.3
DEFINITIONS
1.3.1
General definitions
The Contractor is the party that carries out all or part of the design, engineering,
procurement, construction, commissioning or management of a project or operation of a
facility. The Principal may undertake all or part of the duties of the Contractor.
The Manufacturer/Supplier is the party that manufactures or supplies equipment and
services to perform the duties specified by the Contractor.
The Principal is the party that initiates the project and ultimately pays for it. The Principal
may also include an agent or consultant authorised to act for, and on behalf of, the
Principal.
The word shall indicates a requirement.
The capitalised term SHALL [PS] indicates a process safety requirement.
The word should indicates a recommendation.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 6
1.3.2
Specific definitions
Refer to IEC 60050 for definitions not listed below.
Term
Definition
Autonomy time
(of a battery)
The autonomy time is the duration for which the battery can supply its
rated load within its specified voltage limits, following a prolonged
period, i.e., not less than one year, of battery float-charge operation.
Certificate
Document issued by a recognised authority certifying that it has
examined a certain type of apparatus and, if necessary, has tested it
and concluded that the apparatus complies with the relevant standard
for such apparatus.
Certificate of
conformity
Certificate stating that the electrical apparatus complies with the
relevant standards for apparatus for potentially explosive atmospheres.
Declaration of
compliance
Document issued by the Manufacturer declaring that the electrical
apparatus complies with the requirements of IEC 60079-15.
Electrical
installation
Civil engineering works, buildings, machines, apparatus, lines and
associated equipment used for the generation, conversion,
transformation, transmission, distribution and utilisation of electricity.
Electrical
Network
Monitoring and
Control (ENMC)
A computerised system that is dedicated to monitoring and controlling
defined aspects of an electrical network.
Emergency
lighting
Lighting provided for use at emergency response locations when the
supply to the normal lighting fails.
Escape lighting
Part of Emergency Lighting provided to ensure that the escape route is
illuminated in the event of a major incident.
Essential
service
A service, which, if it fails in operation or when called upon, will affect
the continuity, quality or quantity of the product.
Firm capacity
The installed capacity less the stand-by capacity.
High Voltage
(HV),
601-01-27,
IEC 60050
The set of voltage levels in excess of low voltage.
Installed
capacity
The sum of the rated powers of equipment of the same kind
(generators, transformers, converters, etc.) in an electrical installation.
Instrumented
Protective
Function (IPF)
A function comprising the initiator function, logic solver function and final
element function for the purpose of preventing or mitigating hazardous
situations. (Ref: DEP 32.80.10.10-Gen)
NOTE:
NOTE:
Although not covered by an IEC definition, it has become industry practice to
use the term Medium Voltage (MV) for voltages from 1 kV up to 52 kV.
Previously the term safeguarding was used.
Interruptible,
maintained
electricity
supply
A source of electrical power which is backed up by a second
(emergency) source of power, such as to provide a supply of electricity
that may be interrupted for no more than 15 s.
Low Voltage
(LV), 601-01-26,
IEC 60050
A set of voltage levels used for the distribution of electricity and whose
upper limit is 1000 V AC
Non-essential
service
A service that is neither vital nor essential.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 7
Term
Definition
Non-hazardous
area,
426-03-02,
IEC 60050
An area in which an explosive gas atmosphere is not expected to be
present in quantities such as to require special precautions for the
construction, installation and use of electrical apparatus.
Point of
Common
Coupling (PCC)
The point of coupling at the public utility networks, to which the system
under consideration is, or is to be, connected. Other systems
(consumers) may also be connected to or near this point.
Process Safety
Process Safety is the management of hazards that can give rise to
major accidents involving the release of potentially dangerous materials,
release of energy (such as fire or explosion) or both.
Safety Switch
A switch in the vicinity of a consumer used to disconnect the equipment
for safeguarding purposes.
Site conditions
The external factors, e.g. altitude, air temperature, wind velocity,
vibrations, earthquakes, black body temperature, relative humidity, etc.,
which may influence the operation of a machine or apparatus.
Spare capacity
The difference between firm capacity and the maximum calculated
(peak) load.
Stand-by
capacity
The capacity provided for the purpose of replacing equipment which
may be withdrawn from service under planned or unplanned
circumstances.
Test report
Document prepared by the Manufacturer indicating in detail the tests
and verifications to which the electrical apparatus has been subjected,
and their results.
Uninterruptible,
maintained
electricity
supply
A source of electrical power which is backed up by a second
(emergency) source of power, such as to provide a supply of electricity
that may be interrupted for no longer than 0.5 ms.
AC uninterruptible, maintained electricity supplies incorporate a battery
to provide power in the event of failure of the mains electricity supply.
The power supply is uninterrupted in the event of mains supply failure
and is maintained throughout the battery discharge period.
DC uninterruptible, maintained electricity supplies are derived from
battery-rectifier units (DC UPS units) or from rectifier units energised
from one or more AC uninterruptible, maintained supply sources (AC
UPS units).
Very toxic
(substances)
Substances very hazardous for the environment or human health, as
specified in DEP 01.00.01.30-Gen. (which also identifies "toxic"
substances by reference to chemical substances databases).
Vital service
A service which, if it fails in operation or when called upon, can cause
an unsafe condition of the process and/or electrical installation,
jeopardise life, or cause major damage to the installation.
NOTE: In Marine and Offshore applications, some services defined here as “vital” may be
referred to as “Essential services”.
Zone 0 (in the
classification of
hazardous gas
areas),
426-03-03,
IEC 60050
An area in which an explosive gas atmosphere is present continuously,
or is present for long periods.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 8
1.3.3
Term
Definition
Zone 1 (in the
classification of
hazardous gas
areas),
426-03-04,
IEC 60050
An area in which an explosive gas atmosphere is likely to occur in
normal operation.
Zone 2 (in the
classification of
hazardous gas
areas),
426-03-05,
IEC 60050
An area in which an explosive gas atmosphere is not likely to occur in
normal operation and if it does occur it will exist for a short period only.
Zone 20 (in the
classification of
hazardous dust
areas), 426-0323, IEC 60050
An area in which combustible dust, as a cloud, is present continuously
or frequently, during normal operation, in sufficient quantity to be
capable of producing an explosive concentration of combustible dust
mixed with air, and/or where layers of dust of uncontrollable and
excessive thickness can be formed.
Zone 21 (in the
classification of
hazardous dust
areas), 426-0324, IEC 60050
Areas not classified as Zone 20, in which a combustible dust cloud is
likely to occur during normal operation, in sufficient quantities to be
capable of producing an explosive concentration of combustible dust
mixed with air.
Zone 22 (in the
classification of
hazardous dust
areas), 426-0325, IEC 60050
Areas, not classified as Zone 21, in which combustible dust clouds may
occur infrequently, and persist for only a short period, or in which
accumulations or layers of combustible dust may be present under
abnormal conditions and give rise to combustible mixtures of dust in air.
Where, following an abnormal condition, the removal of dust
accumulations or layers cannot be assured, the area shall be classified
Zone 21.
Installation and equipment definitions
Term
Definition
Bus coupler
circuit breaker,
605-02-40,
IEC 60050
In a substation a circuit breaker which is located between two busbars
and which permits the busbars to be coupled; it may be associated
with selectors in case of more than two busbars.
Bus section
circuit breaker
(= switched
busbar circuit
breaker),
605-02-41,
IEC 60050.
In a substation a circuit breaker, connected in series within a busbar,
between two busbar sections.
Distributed
Control System
(DCS)
Distribution
substation /
switchboard
Sub-distribution
switchboard
A configurable microprocessor-based (process) control system.
A substation/switchboard mainly used for distributing power to several
plant substations.
A switchboard, fed by a distribution switchboard, used for distributing
low voltage power to a number of users.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 9
Term
Definition
A substation/switchboard at which the supply provided by the public
utility is interconnected with the site's electrical distribution system.
Intake
substation /
switchboard
NOTE:
Integrated Motor
Control System
(IMCS)
A converter for conversion from DC to AC
Plain feeder
A feeder, which consists of a cable or an overhead, line only and does
not have an interconnected transformer.
Plant substation
/ switchboard
A substation/switchboard mainly used for feeding one process or utility
plant.
A substation/switchboard to which generators and outgoing feeders are
connected.
NOTE:
An intake substation and a power plant substation may be combined as a
single substation.
Rectifier
A converter for conversion from AC to DC
Remote Control
Unit (RCU)
A control device in the vicinity of a consumer for operation of the
remotely installed controlgear of the consumer.
Switchroom
A room in a substation or building intended exclusively for the
installation of one or more switchboards, distribution switchboards etc.
Variable Speed
Drive System
(VSDS)
1.4
A system comprising control modules, central unit(s), a serial bus
connecting the control modules to the central unit and a
communication facility enabling connection of the central unit to a
distributed control system (DCS) and/or a Supervisory Control and
Data Acquisition System (SCADA).
Inverter
Power plant
substation /
switchboard
1.3.4
An intake substation and a power plant substation may be combined as a
single substation.
A line-fed AC to AC conversion system consisting of all facilities
required to operate its electric motor at variable speeds.
Abbreviations
Term
Definition
A/G
above ground
swbd
switchboard
U/G
underground
CROSS-REFERENCES
Where cross-references to other parts of this DEP are made, the referenced section or
clause number is shown in brackets ( ). Other documents referenced by this DEP are listed
in (8).
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 10
1.5
SUMMARY OF MAIN CHANGES
This DEP is a full revision of the DEP of the same number dated February 2011. The
following are the main, non-editorial changes.
Section/Clause
Change
General
Statements with “shall” and “should” challenged/verified (for reduction in
the number of “shall” statements)
Comments from the DEP feedback system are incorporated
SHALL [PS] statement added 2.3.2 – 3 for selection, specification and
installation of equipment suitable for combustible dust risks
SHALL [PS] statement removed 3.9.1, wording incorporated in 3.2.1 – 3
SHALL [PS] statements in 6.6 rationalised to refer to specific ISGOTT
requirements
2.3.2
IEC standard for area classification for combustible dust hazards
corrected
3.3.1
Requirements for evaluation of 690 V system added
3.5.3
Clarification on dynamic response margin given, with requirement to
study in DEFINE phase for large island power systems
3.5.5
Clarification on selection of double busbar systems given
3.8.2
Neutral earthing resistor for HV transformers and directly connected HV
generators changed from FLC to 100A, to reduce the risk of machine
core damage during earth faults
3.9.2
Duplicate AC UPS requirement changed; options given
3.9.3
Duplicate DC UPS requirement changed; removed “N+1” wording
3.9.4
Clarification on battery autonomy times given
3.10
New Section added to enable retirement of DEP 33.64.10.12-Gen.
4.8.7
Clarification given on standards for cables with increased fire withstand
capabilities
4.10.3
Option to consider LED lighting given for control room buildings and nonindustrial locations
4.11.
Requirement for separate control and trip switching devices added for
directly-fed process heaters
5.1
Minimum IP ratings given for common equipment and locations
5.2.3
Fire walls for intake and large transformers added
5.3.1.1
Section added to show requirements for single core cables
5.3.2.1
Generic statements about cable sizing requirements removed to
Informative
5.3.4.1
Advice use metallic cable ties for permanent fixings
5.5
Many requirements moved to EMC DEP 33.64.10.33-Gen.
6.1.3.1
Requirement added to consider very early smoke detection systems for
critical air-insulated switchboards
6.1.3.4
Requirements for doors for battery rooms clarified
Appendix 3.7
Section added for monitoring of large HV induction motors
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 11
1.6
Section/Clause
Change
Appendix 5
“Appendix 5 - Assessment of need for lightning protection” deleted and
moved to DEP Informative 5.5.4
Appendix 6
Update to table in Section C) under “Level of congestion within plant
area” addressing risk of disturbing/damaging cables if laid U/G.
Appendix 7
Description of deliverable documents clarified
SAFOP requirement in DEFINE phase clarified
System Commissioning Philosophy added
Ex register added
Clarified that Area Classification is THSE deliverable
COMMENTS ON THIS DEP
Comments on this DEP may be submitted to the Administrator using one of the following
options:
Shell DEPs Online
(Users with access to
Shell DEPs Online)
Enter the Shell DEPs Online system at
https://www.shelldeps.com
Select a DEP and then go to the details screen for
that DEP.
Click on the “Give feedback” link, fill in the online
form and submit.
DEP Feedback System
(Users with access to
Shell Wide Web)
Enter comments directly in the DEP Feedback
System which is accessible from the Technical
Standards Portal http://sww.shell.com/standards.
Select “Submit DEP Feedback”, fill in the online form
and submit.
DEP Standard Form
(Other users)
Use DEP Standard Form 00.00.05.80-Gen. to record
feedback and email the form to the Administrator at
standards@shell.com.
Feedback that has been registered in the DEP Feedback System by using one of the above
options will be reviewed by the DEP Custodian for potential improvements to the DEP.
1.7
NON NORMATIVE TEXT (COMMENTARY)
Text shown in italic style in this DEP indicates text that is non-normative and is provided as
explanation or background information only.
Non-normative text is normally indented slightly to the right of the relevant DEP clause.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 12
2.
DESIGN AND ENGINEERING PRINCIPLES
2.1
STANDARDS, CODES, REGULATIONS AND TECHNICAL ASSURANCE
2.1.1
General
This DEP is based on the publications of the International Electrotechnical Commission
(IEC) and on the relevant documents issued by the European Committee for
Electrotechnical Standardisation (CENELEC). Where relevant, the specific publications
are referenced in this DEP.
2.1.2
2.2
1.
The design and engineering of the electrical installation shall satisfy all statutory
requirements of the national and/or local authorities of the country in which the
electrical installation will be located.
2.
The electrical installation shall be suitable for the site conditions as specified by the
Principal.
3.
Where necessary, special attention shall be paid to the selection and installation of
electrical equipment suitable for seismic conditions.
4.
Furthermore, the contents of this DEP and of standards and publications referred to
herein shall be adhered to, except where amended by specific requirements given by
the Principal relating to a particular installation, and as far as is permitted under the
statutory requirements mentioned above.
5.
Electrical equipment and materials shall comply with the relevant DEP specifications,
which are supplementary to IEC equipment standards.
6.
CENELEC or national standards of the country in which the installation will be located
may be used in lieu of IEC standards for the design and engineering of the electrical
installation, provided they are not less stringent in their total requirement.
7.
In the event of contradiction between the requirements of DEP specifications and IEC,
CENELEC or national standards, the former shall prevail, provided the statutory
obligations in the country of installation are satisfied.
8.
In the event of contradiction between the requirements of this DEP and those of DEP
specifications referenced in this DEP, the more recently published document shall
prevail, except where otherwise specified by the Principal for a particular installation.
9.
As far as is applicable, Standard Drawings in groups S 64, S 67, S 68 and S 69 shall
be followed.
Technical assurance
1.
The design of electrical installation shall be subjected to a formal technical assurance
process.
2.
The technical assurance process shall include the requirement for a SAFOP (safety
and operability) assessment.
OPERATIONAL SAFETY AND RELIABILITY
1.
Electrical Safety Rules (ESRs) shall be in accordance with DEP 80.64.10.10-Gen.
2.
To mitigate the increased risks present in temporary installations, the specific
requirements associated with the design and installation of temporary facilities shall be
in accordance with (6.9).
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 13
2.3
PROTECTION AGAINST EXPLOSION AND FIRE HAZARDS
2.3.1
Flammable gas/vapour hazards
1.
To permit the proper selection of electrical apparatus for areas where flammable gas
or vapour risks may arise, area classification drawing(s) SHALL [PS] be prepared.
•
Unless otherwise advised by the Principal, IP Model Code of Safe Practice Part 15,
Area Classification Code for Petroleum Installations, as amended/supplemented by
DEP 80.00.10.10-Gen, shall be used.
2.
Control rooms and Substations should be located in non-hazardous areas.
3.
Where electrical equipment has to be installed in hazardous areas, equipment with a
type of protection suitable for the relevant zones SHALL [PS] be selected, specified
and installed.
•
Unless otherwise advised by the Principal, IEC 60079-14 and IEC 60079-17 shall
be used.
4.
(Appendix 1) summarises the various types of protection of electrical equipment that
are permissible in hazardous areas. The specification or procurement of equipment
complying with standards different from the above shall require the specific approval of
the Principal.
5.
The following applies to the final selection for Zone 1:
a. LV motors and all inherently non-sparking equipment, (e.g. junction boxes,
terminal boxes and luminaires), shall have type of protection 'e'.
b. HV motors and all inherently sparking equipment, e.g. switchgear and controlgear,
shall have type of protection 'd'.
c. Where such type of protection is not available (e.g. large high speed HV motors),
type of protection 'p' shall be used.
d. HV motors with type of protection 'e' shall not be used.
6.
The following applies to the final selection for Zone 2:
a. Motors and inherently non-sparking equipment should have type of protection 'n',
albeit equipment approved for Zone 1 is also acceptable.
b. Inherently sparking equipment shall have type of protection 'd' or 'p', as stated for
Zone 1.
c. HV motors with type of protection 'n' or 'e' SHALL [PS] not be installed in Zone 2
areas where:
i. the motor voltage exceeds 6.6 kV, or
ii.
the motor drives a centrifugal/screw hydrocarbon and/or hydrogen gas
compressor.
d. These motors SHALL [PS] have type of protection 'd' or 'p'.
7.
For the purpose of commonality of spares and to cater for the possibility of reclassification of areas, the same equipment suitable for use in Zone 2 locations shall
be installed within process installations in non-hazardous areas.
NOTE:
8.
This applies specifically to motors, luminaires, RCUs and power and convenience outlets. Refer
to (4.10.2).
Electrical equipment installed indoors, in non-hazardous areas within process areas
shall be of a standard industrial type as specified in the relevant equipment DEPs.
Small power and lighting equipment in such indoor areas should be either of the
industrial weatherproof type or of the domestic type depending on the function of the
area (6.1).
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 14
9.
2.3.2
Equipment installed in non-hazardous areas outside process installations, e.g. offices,
gatehouses, etc. should be of a normal industrial/domestic type in accordance with
national standards of the country of installation.
Combustible dust hazards
1.
To permit the proper selection of electrical apparatus for areas where combustible dust
risks may arise, area classification drawing(s) SHALL [PS] be prepared.
•
Unless otherwise advised by the Principal, IEC 60079-10-2 shall be used.
2.
Control rooms and Substations should be situated in non-hazardous areas.
3.
Where electrical equipment has to be installed in hazardous areas, equipment with a
type of protection suitable for the relevant zones SHALL [PS] be selected, specified
and installed.
•
4.
Unless otherwise advised by the Principal, IEC 60079-14 and IEC 60079-17 shall
be used.
For the purpose of commonality of spares and to cater for the possibility of reclassification of areas, the same equipment suitable for use in Zone 22 locations
should be installed within process installations.
NOTE:
2.4
STANDARDISATION OF EQUIPMENT AND MATERIALS
1.
2.5
This applies specifically to motors, luminaires, RCUs and power and convenience outlets. Refer
to (4.10.2).
Equipment of similar nature and incorporating similar or identical components and of
similar or identical construction should be from the same Manufacturer (e.g. power and
convenience outlets, luminaries, junction boxes, RCUs, switches etc.).
CERTIFICATES, DECLARATIONS AND TEST REPORTS
1.
For all major equipment, the Contractor shall obtain at least the Manufacturer's test
reports in accordance with the equipment DEP specifications, e.g. for generators,
motors, VSDS, HV and LV switchgear, UPS equipment, and transformers.
2.
Further certificates or declarations relating to the application of equipment for use in
hazardous areas may be required by local authorities, according to the following rules:
a. For electrical apparatus in Zone 0, Zone 1 and Zone 2 areas, a certificate of
conformity shall be obtained from the Manufacturer.
i. In addition for EU regions, electrical apparatus with a category indication
1 or 2, a certificate of a Notified Body and a CE Declaration of
conformity shall be obtained from the Manufacturer.
b. For electrical apparatus in Zone 2 areas, which has type of protection 'n', a
declaration of compliance may be accepted instead of a certificate of conformity.
i. In addition for EU regions, electrical apparatus with a category indication
3, a certificate of an independent authorisation authority and a CE
Declaration of conformity shall be obtained from the Manufacturer.
3.
The Contractor shall obtain the Manufacturer's requirements for installation from the
certificate or declaration of conformity and incorporate these in the design and
engineering for installation.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 15
3.
ELECTRICAL SYSTEM DESIGN
3.1
GENERAL
3.1.1
Design philosophy
1.
The design shall meet the specific design criteria, philosophy and/or objective stated in
the project definition phase, e.g. in the basis of design document and/or project
specification, relating to a particular plant or facility.
For instance, it may be defined by plant lifetime, skill of operating and
maintenance personnel, operational flexibility, extension possibilities or noise
limitations, etc.
2.
If specified by the Principal, the design of the electrical installation shall comply with
the project Design Class. Refer to DEP 00.00.07.10-Gen.
3.
The philosophies to be employed will depend on the size and complexity of the
installation; those approved for a specific project shall be set down clearly during the
project definition phase.
4.
The conceptual designs and philosophies relating to the electrical system shall be
documented by a system design description, a key line diagram, basic layout drawings
and functional/outline specifications.
The overall design intent is a suitably robust system, with reduced energy
consumption through the selection and utilisation of efficient electrical equipment.
5.
When electrical power systems are designed, the following alternatives for the
electricity supply should be considered: own generation, public utility supply, or a
combination of these within the limits and possibilities given by the Principal.
6.
Generating sets should normally be in an electrically centralised location with a radial
distribution system. Ring distribution systems are preferred for residential/industrial
facilities located at relatively large distances from the power source or from each other.
7.
A key line diagram of the electrical power system shall be prepared and kept up-todate.
8.
System studies and protection reports, including software files etc., shall be provided
in support of the design, for approval by the Principal. Depending on the type, size and
complexity of the installation, such studies may comprise the following as listed in
(Appendix 7):
a. Load flow studies;
b. Short circuit studies complying with IEC 60909 Parts 0, 1, 2, 3, 4.
c. System dynamic stability (transient stability) studies under three phase fault
conditions;
d. Dynamic performance studies under motor starting and/or loss of generation
conditions;
e. Protection grading studies, including relay setting schedules; an arc flash study
should be carried out for low voltage switchboards and for high voltage
switchboards only if the protection grading studies show that arcing faults cannot
be cleared within the Internal Arc Classification time of the switchgear.
f.
Harmonic analysis studies;
g. Motor re-starting and re-acceleration;
h. Vital Supply recovery following total power failure, including emergency diesel
generator(s), UPS, instrumentation, DCS and IMCS.
10. The scope and timing of the system studies shall be defined by the Principal and
agreed with the Contractor before their commencement.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 16
11. The Vital Supply Recovery Study shall document the principle of recovery from total
power failure and must identify vital drives and circuits that must be restored and the
source of the restoring supply or command. Examples of restoring sources include:
a. Emergency diesel generator systems;
b. Process control (DCS), safeguarding (IPF), integrated motor control (IMCS);
c. UPS, battery supplies;
d. Manual operation.
3.1.2
Islanding
1.
Before implementing a facility for transition to island operation, an assessment shall be
made demonstrating clearly the expected increase in availability and the economic
benefits.
2.
Where statistical analysis is needed, it shall be based on sufficient local data to make
such an analysis valid.
3.
As a minimum, the assessment should address the following:
a. The effects and expected frequency of voltage dips and their duration caused by
disturbances in the external network. The duration will be obtained from the
settings of protective devices in the external network while the frequency
distribution of voltage dips will be acquired from statistical analysis.
b. The effects and expected frequency distribution of outages of the power supply
from the external network. The frequency distribution will be acquired from
statistical analysis.
c. The technical and economic consequences of unplanned failures of the power
supply caused by external faults.
d. An analysis of the expected system behaviour during and after external
disturbances.
e. The expected success rate of island initiation after a transient disturbance.
f.
The expected technical and economic benefits gained by the implementation of a
control and protection system for the transition to island operation.
3.2
ELECTRICAL LOADS AND ELECTRICITY CONSUMPTION
3.2.1
Classification of loads
3.2.1.1
General
3.2.1.2
1.
Electrical loads SHALL [PS] be classified as performing a service, which is 'vital',
'essential', or 'non-essential', as defined in (1.3.2).
2.
An electrical power system of enhanced reliability and having duplicate energy sources
SHALL [PS] be provided to energise loads forming part of vital services; refer to
(3.2.1.2) and (3.9).
3.
An electrical power system of suitable reliability shall be provided for ‘essential', or
'non-essential' services; refer to (3.2.1.3) and (3.2.1.4).
Vital service
1.
For vital services, complete duplication of the energy source, of the lines of supply and
of the equipment is necessary.
Examples:
•
Boiler feed water supply system by means of one electrically driven and
one steam driven pump, or two electrically driven pumps supplied from
independent sources;
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 17
•
Life support systems, e.g. electric motor driven fire pumps on offshore
installations supplied from independent sources;
•
One or more uninterruptible power supply (UPS) units to provide electrical
supply to protection systems and process control systems;
•
Emergency lighting and escape lighting.
NOTE:
3.2.1.3
The economic consequences of electricity supply interruptions to essential services generally
justify the provision of stand-by feeder capacity to facilitate the isolation of individual circuits for
the purpose of equipment maintenance (of on-load tap-changers, circuit breakers, etc.),
functional testing (of protective relays and trip circuits, etc.) and possible repair (of cables and
cable terminations, etc.) while maintaining electrical services operational.
Essential service
1.
For essential services, the economics of partial or complete duplication of the energy
source, of the lines of supply or of the equipment, or the introduction of automatic
restarting or changeover facilities etc. shall be evaluated in relation to the
consequences of service interruptions.
Examples:
3.2.1.4
•
Product transport by means of duplicated pump sets with account being
taken of pump maintenance requirements;
•
Power supply to process analysers by means of a duplicate supply
system with changeover facility;
•
Power supply to security lighting and plant area lighting.
Non-essential service
Examples of non-essential services are power and lighting supplies to offices,
warehouses, residential areas, etc.
3.2.2
Load assessment and electricity consumption
1.
A schedule of the installed electrical loads, the maximum normal running plant load
and the peak load, expressed in kilowatts and kilovars and based on the plant design
capacity when operating under the site conditions specified, shall be prepared using
Standard Form DEP 05.00.10.80-Gen.
2.
Above schedule of loads shall be prepared and updated regularly throughout the
design phases of the project and will form the basis for provision of the necessary
electricity supply and distribution system capacity (3.5).
3.
During the early phases of a project development, a separate allowance shall be made
to account for an increase in the electrical load owing to uncertainties in the process
design.
NOTE:
4.
This is particularly important where own generation is the main source of electricity. Refer also
to (3.5.2). Typically, this allowance may be in the order of 10 % to 25 %, depending on how
much of the process design is based on existing operating experience. The allowance is
normally reduced at distinct project phases as the design develops.
Standard Form DEP 05.00.10.80-Gen. gives formulae for determining the total
electrical loads:
-
Maximum normal running plant load = x(%)E + y(%)F
-
Peak load = x(%)E + y(%)F + z(%)G
where
E = sum of all continuously operating loads
F = sum of all intermittent loads
G = sum of all stand-by loads
x, y and z are diversity factors
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 18
5.
Values of the diversity factors (x, y, and z) shall be appropriate to the type of plant and
shall be determined by the Principal.
6.
Values of the diversity factors (x, y and z) shall take account of the individual drives or
consumers which make up the continuous, intermittent and stand-by loads,
respectively. For example, y(%)F or z(%)G cannot be less than the largest individual
intermittent or stand-by drive or consumer.
7.
The various loads shall be classified as follows:
E - "Continuous"
All loads that may continuously be required for normal
operation, including lighting and workshops
F - "Intermittent"
Loads required for intermediate pumping, storage, loading, etc.
G -"Stand-by"
All loads required in emergencies only, such as fire-water
pumps or those of normally not running electrically driven units
in stand-by mode for normally running steam-driven ones, e.g.
charge pumps, boiler feed pumps, etc.
Spare pumps etc., e.g. the “B” pump of an A-B combination,
are not to be considered as “Stand-by” loads.
8.
Even though not to be considered as stand-by loads, the largest motor of the spare
duty shall be considered in the motor start studies in (3.1) with the duty motor running.
9.
Subject to the above considerations, the following default values may be used for initial
load assessments, or if the diversity factors have not been finalised:
x
=
100 %.
At rated plant throughput all driven equipment is assumed to be operating at its
duty point. However, some diversity may be applied to non-process loads, e.g.
offices and workshop power and lighting, typically 90 %.
y
=
30 %.
z
=
10 %.
10. A separate schedule shall be prepared for each switchboard, the total of all
switchboard loads being summarised as required to arrive at the maximum normal
running and peak loads for each substation and for the plant overall.
11. All loads to be shed during an underfrequency condition shall be identified as such in
the 'remark' column.
12. All loads to be automatically restarted after a voltage dip shall be identified as such in
the 'restarting' column.
13. Where a group of drives operate as a unit, it shall be considered as an individual
consumer.
14. The power consumption of electric motors shall be based on motors rated in
accordance with the requirements of DEP 33.66.05.31-Gen.
NOTE:
The percentage of total intermittently operating load that contributes to the maximum normal
running load will depend on plant operations.
NOTE:
Depending on steam/electricity supply availability, the use of non-electrical drivers for stand-by
duties and the total number of units installed, only a small number of the largest electrical standby units may have to be considered when establishing the peak load.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 19
3.3
SYSTEM VOLTAGES AND FREQUENCY
3.3.1
General
1.
The selection of system frequency and voltages shall be determined by the Principal;
voltages shall be selected from IEC 60038, subject to compatibility with any existing
installation with which interconnection is intended.
NOTE:
2.
On 50 Hz systems the nominal LV power supply voltage for new plants of shall be
400/230 V three phase and neutral as recommended in IEC 60038. This voltage
should be used for extensions to existing plants requiring new LV distribution systems.
3.
A study should be carried out during the SELECT or early in the DEFINE phase of the
project for the possible selection of 690 V for supply of large numbers of larger LV
motors, once the number and size of drivers is known.
NOTE:
3.3.2
The frequency for onshore installations shall be that used by the local public utility.
690 V / 60 Hz is a permissible voltage / frequency combination for offshore facilities.
4.
Nominal system voltage(s) and frequency and the positive phase sequence of three
phase systems shall be indicated on the key line diagram.
5.
The phase sequences shall be specified in the order L1, L2, L3, each phase reaching
its maximum in time sequence in that order.
Deviations in supply voltage and frequency
1.
During normal system operation and under steady-state conditions, the voltage at
generator and consumer terminals shall not deviate from the rated equipment voltage
by more than 5 % and the system frequency shall not deviate from the rated frequency
by more than 2 %.
2.
The combined voltage and frequency deviations shall lie within Zone A as described in
IEC 60034-1.
3.
All loads should be distributed (balanced) so that the negative phase sequence
components of voltage and current at any point in the system do not exceed the values
quoted in IEC 60034-1.
4.
During starting or reacceleration of direct on line motors, either singly or in a group, the
voltage at the motor terminals shall not deviate by more than +10 % or –20 % from
rated equipment voltage.
5.
Transient voltage deviations occurring at switchgear busbars during motor or group
motor starting/reacceleration shall be such as to maintain a minimum of 85 % voltage
on switchgear busbars, and at least 80 %, but not more than 110 %, of rated
equipment voltage on all other consumers.
6.
Notwithstanding the above requirements, the limits set by the public utility regarding
the maximum voltage deviations that a consumer is permitted to cause at the point of
common coupling (PCC), e.g. due to the starting of electric motors, shall be adhered
to.
7.
Equipment having special requirements with respect to variations in voltage and/or
waveform shall be provided with a power supply that is adequately stabilised and/or
filtered.
8.
The following criteria apply with respect to voltage dips or interruptions such as those
arising as a consequence of system short circuits or disturbances from grid intake
supplies:
a. Voltage dips resulting in consumer terminal voltages down to 80 % of rated
equipment voltage shall not affect plant operations;
b. Voltage dips resulting in consumer terminal voltages below 80 % of rated
equipment voltage for a duration of not more than 0.2 s shall result in the ridethrough of selected consumers performing a vital and/or essential service;
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 20
c. Voltage dips resulting in consumer terminal voltages below 80 % of rated
equipment voltage for a duration between 0.2 s and 4 s shall, on voltage
restoration, result in a sequential re-start of selected consumers.
9.
3.3.3
Ride-through and re-start requirements are to be agreed with Process and Utility
disciplines. Implementation of sequential re-energisation may be done using the DCS
or IMCS. The constraints imposed by the electrical system will determine the extent to
which ride through and re-starting may be applied.
Deviations and variations in supply waveform
1.
Electrical loads having non-linear characteristics such as to produce voltage and
current waveform distortion of a magnitude detrimental to the lifetime or performance
of system electrical equipment shall not be utilised unless appropriate measures are
taken to render harmless the effects of such distortion, e.g. by filtering or phase
displacement, etc.
2.
Two levels of distortion are recognised:
a. The distortion level for extensions to an existing electrical system:
i. The Total Harmonic Distortion (THD) and individual harmonic voltage
distortions at any point of the system up to a voltage of 36 kV shall not
exceed the levels as defined in IEC 61000-3-6 Table 1.
NOTE:
IEEE 519 standard and the harmonic values contained therein may be substituted by
the Principal.
b. The distortion level for new projects or developments
i. For new projects the planning levels for Total Harmonic Distortion (THD)
and individual harmonic voltage are defined in IEC 61000-3-6 Table 2.
THD for system voltages up to 36 kV shall not exceed 6.5 %. THD for
system voltages higher than 36 kV shall not exceed 3 %.
3.
3.4
Equipment, which produces a continuous DC component in the AC supply system,
shall not be utilised.
SYSTEM POWER FACTOR
1.
The overall system power factor, inclusive of reactive power losses in transformers
and other distribution system equipment, should not be less than 0.8 lagging at rated
design throughput of the plant.
2.
The power factor shall be determined at:
a. the terminals of the generator(s), when power is supplied from own generation,
b. the PCC, when power is supplied from a public utility. The plant power system
shall be designed so that the power factor stated by the public utility is achieved
with a design margin of at least 2 %. The measured power factor is an average
value determined over the metering integration period, typically 15 min or 30 min.
3.
Any improvement of power factor beyond that necessary to achieve the above should
be considered on an economic basis, e.g. reduction in distribution system equipment
ratings, reduction in kVAr charges.
4.
The requirement for power factor correction shall be agreed with the Principal at the
DEFINE phase of the project.
5.
Where necessary, power factor correction shall be done by one or more of the
following methods, which are stated in order of preference. The method selected
depends on reliability and economic considerations.
a. Variation of the excitation of synchronous generators.
b. Variation of the excitation of synchronous motors.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 21
c. Permanently energised static capacitor banks connected to distribution
switchboards or group motor control centres via suitably protected switching
devices (4.5).
3.5
SUPPLY CAPACITY
3.5.1
General
1.
The distribution system shall be capable of supplying continuously the peak load,
assessed according to the applicable load data (3.2.2).
2.
The design of new facilities shall ensure that the firm capacity of the main HV
distribution system (power plant switchgear, and/or grid intake transformers,
distribution switchgear and interconnecting cabling, excluding process plant) has spare
capacity as indicated in Figure 1, unless otherwise instructed by Principal.
Spare
Capacity
25%
20%
15%
10%
5%
20
Figure 1
3.5.2
40
60
80
Firm Capacity in MVA
100
120
Spare capacity requirements
3.
The spare capacity at Plant Substations shall be a minimum of 10 % of peak load at
the end of the EXECUTE phase, unless otherwise instructed by the Principal.
4.
The provision of stand-by capacity shall be considered in relation to safety, reliability
and the requirements with respect to continuity of plant operations.
5.
Moreover, the reliability of distribution systems shall be at least comparable to that of
their supply systems, each incorporating sufficient stand-by capacity to enable
maintenance work, tests and inspection checks to be carried out.
6.
Electrical system maintenance requirements should be considered in relation to plant
shutdowns for overhaul of process units.
7.
General rules relating to the provision of necessary spare and stand-by capacity, and
to the rating of supply and distribution equipment for each part of the electrical system,
are given in subsequent sections.
Grid intake systems
1.
Grid intake circuits shall be controlled by circuit breakers, fitted with the protection,
control, alarms, instruments and meters specified below and in (Appendix 3).
2.
The overall design of grid intake circuits shall be carried out in close liaison with the
public utility, so that both parties' requirements, including provision for disconnection,
isolation and earthing, are satisfied. For typical single line and protection diagrams,
refer to Standard Drawing S 67.060.
3.
Where the grid intake circuits comprise transformer feeders and the transformers are
fitted with on-load tap changers, automatic voltage control equipment shall be provided
to control the intake substation switchboard voltage.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 22
3.5.3
4.
Grid intake circuits, which are required to operate in parallel with own generation, shall
be provided with manual synchronising facilities, a check synchronising relay and a
dead-bus override. These synchronising controls should be located with the frequency
and voltage controls of the generators.
5.
Where applicable, the requirements for an islanding system shall be incorporated in
the design, with provision for re-synchronisation of islanded system with grid.
Power generation
1.
Stand-by capacity (spinning reserve) shall be incorporated to fulfil the requirement of
the peak load with the largest generating set out of service.
2.
The number of generating sets and their individual ratings shall be approved by the
Principal. This depends on many factors, e.g. maintenance requirements, economic
size, future load development pattern, unit reliability, etc.
3.
In order to ensure a stable electrical power system after trip of the single largest
generating unit, spinning reserve shall be available.
4.
To achieve the preferred operating philosophy of “N+1”, the maximum operating
electrical load, in MW, should be as follows:
maximum operating electrical load ≤
(OGC x A) - LUO
D
Where:
OGC
=
Max. Operating Generation Capacity (Prime mover and generator), in MW.
LUO
=
Largest unit operating that may trip, in MW.
A
=
Availability Factor:
Fraction of the maximum generation capacity that is available to quickly ramp
up in case of a trip of a generator. Normally 1.00, but may be constrained by
limit on prime mover by process.
D
=
Dynamic Response Margin:
e.g. 1.1 to 1.2 for gas turbines. This value may be reduced if confirmed by
electrical transient stability studies, but note some smaller gas turbines with
dry low-NOx combustion systems have limited load acceptance capability
a. Above formula may also be used for networks without an external grid
connection, i.e. permanently islanded networks.
b. The dynamic response margin of larger systems may be reduced based on
experience with similar installations and supported by transient stability studies.
c.
The dynamic response margin should not be lower than 1.05 to provide an
allowance for continuous control of the remaining generators.
d. If at any time in normal operation the electrical load exceeds maximum allowed
load, than a pro-active controlled load reduction (not load shedding) should be
carried out in order to achieve N+1 operation again.
e. For systems > 100 MW, the electrical transient stability study shall be done in
the DEFINE phase.
5.
The following applies for plants with own generation capable of operating in island
mode:
a. An automatic load shedding scheme should normally be provided.
b. Isochronous control should only be used on a single generating unit in a network
that has no connection to the public network.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 23
3.5.4
Transmission and distribution systems
1.
The stand-by feeder capacity shall enable the largest supply circuit to be withdrawn
from service while satisfying the peak load requirements with the margins specified in
(3.5.1).
2.
The provision of stand-by capacity to non-essential service loads shall be evaluated
based on circuit availability for carrying out maintenance, testing and inspection.
3.
The maximum rating of transformers feeding plant substations should be such that the
rated current of their low voltage winding does not exceed 2500 A. This results in the
following maximum transformer ratings:
a. 25 MVA, if feeding a 6 kV or 6.6 kV switchboard;
b. 12.5 MVA, if feeding a 3 kV or 3.3 kV switchboard;
c. 1600 kVA, if feeding an LV (400V) switchboard.
3.5.5
4.
In order to keep the level of the prospective short circuit within the range of
commercially available switchgear, transformers with higher impedance than specified
in DEP 33.65.40.31-Gen. may be considered. Refer to (3.6).
5.
Single overhead line circuits are not acceptable as a means of supplying vital or
essential consumers. Duplication of circuits to non-essential consumers may also be
required to improve reliability and to permit regular maintenance.
6.
Single circuit lines or ring distribution circuits should only be considered for supplies to
individual plants or facilities that are periodically shut down for maintenance so as to
permit simultaneous maintenance of the feeder circuit.
Switchgear
1.
Currently available switchgear is considered to be sufficiently reliable to require no
duplication in itself. Consequently, distribution and plant switchboards, including group
motor control centres, shall have a single busbar system and a single switching device
per circuit.
2.
Double busbar systems should be selected for HV switchboards rated > 6.6 kV at grid
intake substations and power plant substations as an alternative to the above
arrangement.
3.
Switchboards with double busbar systems shall incorporate one circuit breaker per
circuit.
4.
For HV and LV switchboards, the rated short circuit withstand duration corresponding
to the rated withstand current shall be 1 s.
5.
HV switchboards shall have a maximum of three sections and, consequently, a
maximum of two bus section switches.
6.
LV switchboards shall have two, three or maximum four sections (in 'H' configuration).
Where the LV load exceeds the capacity of a four-section switchboard, additional
switchboard(s) shall be installed rather than having switchboards of more than four
sections. Special arrangements, e.g. automatic changeover, may be required for
switchboards supplying vital services, where an alternative supply is required.
7.
For design purposes normal operating position of switchboard bus section switches
shall be as follows:
a. For LV switchboards the bus section switches shall be operated normally open,
except on switchboards at the source of supply, i.e., at LV generator switchboards.
b. For HV switchboards the bus section switches shall be operated normally closed
on switchboards at intake substations, power (generation) plant substations and
distribution substations.
c. Bus section switches shall be operated normally open on switchboards at plant
substations.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 24
8.
When a switchboard panel serves a stand-by function to one or more main consumers,
it shall be connected to a different busbar section from that to which the main
consumer or consumers are connected, provided that there is no possibility of a
switchboard incoming circuit or busbar section becoming overloaded as a
consequence of selecting any main or stand-by consumers for operational use.
9.
The basic configuration for a switchboard supplying essential service loads shall be a
2-section switchboard with two 100 % rated incoming circuits and one bus section
switch:
2 section switchboard
Feeder rating:
2 x 100%
50%
Figure 2
50%
2-section switchboard
10. The transformer sizing to maintain firm capacity for 3-section switchboards shall be as
shown below:
3 section switchboard
Feeder rating:
3 x 50%
50%
0%
50%
Interlocking may be required
Figure 3
3-section switchboard
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 25
3 section switchboard
Feeder rating:
3 x 67%
33%
33%
33%
Interlocking may be required
Figure 4
3-section switchboard (option)
11. Normally open bus section switches and/or interconnectors that may have to be
operated simultaneously in the closed position, shall be rated so as to permit the
largest incoming circuit feeder to be withdrawn from service without the necessity to
de-energise any switchboard busbar section or consumer circuit.
12. The configurations of intake, power plant and distribution switchboards shall permit
one switchboard section to be taken out of service while still maintaining normal
downstream plant operations.
3.5.6
3.6
Electric motors
1.
Electric motors complying with DEP 33.66.05.31-Gen. are considered sufficiently
reliable for single essential drives. For vital services, stand-by units shall be installed,
and supplied from a separate source of supply.
2.
Where a VSDS is used for a vital or an essential service, duplication of certain
components of the system may be required to obtain an acceptable reliability level, as
stated in DEP 33.66.05.33-Gen.
SHORT CIRCUIT RATINGS
1.
All equipment shall be capable of withstanding the effects of short circuit currents and
consequential voltages arising in the event of equipment or circuit faults.
NOTE:
Damage occurring at the fault location is excluded from the above.
2.
The short circuit ratings of equipment and cables, including the short circuit making
and, where relevant, breaking capacity of circuit switching devices, shall be based on
the parallel operation of all supplies which can be operated in parallel.
3.
Distribution of short circuit current and the limiting effect of system protective devices
or control schemes, e.g. fuse links, Is-limiters, break before make automatic supply
changeover arrangements, etc., shall be applied when determining short circuit
ratings.
4.
Parallel operation includes bus section switches or interconnectors, etc. which are
intended for normally open operation and on which no (inter)locking has been provided
to prevent simultaneous closure.
5.
For new installations, including those forming part of plant extensions, the short circuit
rating of the switchgear to be installed shall be based on the sum of the short circuit
contributions from the following:
a. the maximum short circuit level at the point of supply from which the new
switchgear will be energised,
b. an electrical loading of the new installation such that the nominal capacity of the
switchboard is fully utilised,
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 26
c. future planned increases in short circuit level due to the direct or indirect
connection of machines or public utility supply.
6.
Generally the load of process facilities predominantly consists of induction motors.
When no details are known at the time of order, 90 % of the nominal capacity of the
switchboard should be taken as motor load.
7.
At the time of order, an HV switchboard at intake, power plant or distribution
substations shall have a margin of not less than +10 % between the calculated fault
level under the above-mentioned conditions and the specified short circuit rating of the
equipment.
8.
Short circuit calculations shall be based on nominal impedance values of the
equipment. The margin specified above is provided to allow for the tolerances
permitted for equipment characteristics.
9.
Mechanical interlocking of switches shall be provided, where necessary, to ensure that
equipment short circuit ratings are not exceeded, due regard being given to satisfying
the above-mentioned operational requirements with respect to the provision of firm and
stand-by capacity. The type of interlock provided shall be subject to approval by
Principal.
10. Automatic break-before-make changeover arrangements of supply capacity shall not
be introduced with the specific aim of justifying the use of equipment having a lower
short circuit rating than would otherwise be required for the parallel operation of all
available supplies.
11. The use of current-limiting reactors, Is-limiters and similar devices intended specifically
as a means of limiting the magnitude of short circuit currents shall be considered only
as a means of achieving system extensions or interconnections, which could not
otherwise be practicably or economically realised without the use of such devices.
12. The installation of current-limiting reactors, Is-limiters and similar devices should be
evaluated and documented during the conceptual design of the electrical distribution
network.
13. When equipment short circuit ratings are determined, the effects of contributions from
asynchronous and synchronous machines on the switching duties of switchgear and
on the dynamic and thermal loading of the electrical installations in general shall be
taken into account.
14. Short circuit current contributions from cage induction machines shall normally only be
taken into account for determining the necessary dynamic withstand rating of
equipment and the required making duty of circuit breakers tested in accordance with
IEC 62271-100 and IEC 60947-2.
15. However, where reliance is placed on circuit breakers having an enhanced making
capacity, the effects of asynchronous machine contributions shall be taken into
account in establishing the adequacy of the fault breaking duty of circuit breakers,
taking into account the decay of the short circuit current contribution.
16. A period of 3 cycles (60 ms for 50 Hz) after the fault shall be taken for establishing
adequacy of the breaking capacity of circuit breakers.
17. Any restrictions imposed by the public utility with respect to short circuit current infeed
to their supply network shall not be exceeded.
3.7
ELECTRICAL PROTECTION
3.7.1
General
1.
The electrical system SHALL [PS] be equipped with automatic protection to provide
safeguards in the event of electrical equipment failures or system maloperation.
2.
Automatic protective systems shall be designed to achieve selective isolation of faulted
equipment with a minimum delay and within a time corresponding to the short circuit
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 27
current withstand capability of the equipment, arc flash exposure, system stability
limits, and the maximum fault clearing times.
3.
The selection, schemes specification and settings of switching and protective devices,
control circuits and associated auxiliary equipment shall be in accordance with
DEP 33.64.10.17-Gen.
3.8
SYSTEM EARTHING
3.8.1
General
1.
3.8.2
The neutral of AC systems shall normally be earthed as stated below. These shall not
be designed for unearthed operation, unless they form an extension to an existing
unearthed system. The preferred system earthing arrangements are given in
(Appendix 2).
HV systems
1.
HV electrical systems shall be earthed by means of dedicated earth electrodes
connected to the plant main earth grid (5.5.1).
2.
HV system neutrals shall be earthed at each source of supply (transformer, directconnected generator) as shown in (Appendix 2).
3.
For grid infeed system voltages above 36 kV, the neutral point of transformers should
be solidly earthed, unless otherwise required by the public utility.
a. Where circuit breakers have to be connected to an existing solidly earthed system,
suitable CTs shall be selected so as to prevent CT saturation under earth fault
conditions.
4.
Transformer feeders to HV switchboards with a system voltage not exceeding 36 kV
shall be resistance earthed.
a. Each resistor should be sized so as to limit the earth fault current supplied by the
equipment to which the resistor is connected, to approximately 100 A, provided
that with such a resistor, sufficient current would flow under each fault condition to
ensure positive operation of earth fault protection on all circuits.
NOTES:
1. The above applies equally to the earthing of the neutral point of the HV winding of generator stepup transformers.
2, It may be necessary for HV systems feeding overhead line distribution systems to be solidly
earthed so as to allow for detection and tripping of earth faults remote from the source of supply.
5.
Where generators are to be directly connected to the main HV switchboard, i.e., not
via generator transformers, each generator should be earthed via its own earthing
resistor.
a. Generator earthing is subject to verification that the zero sequence, triplen
harmonic currents (3rd, 9th, 15th etc.) that could circulate through the resistors
under various loading conditions of the generators would not be damaging to the
resistors.
b. Each resistor should be sized so as to limit the magnitude of earth fault current to
100 A. A resistor of higher ohmic value than the aforementioned may be
considered if such a resistor would limit the magnitude of circulating harmonic
current to a harmless value.
c. The size of resistor provided shall ensure that sufficient current would flow under
each fault condition, to ensure positive operation of earth fault protection on all
circuits. If this cannot be achieved, other measures shall be adopted to limit such
circulating currents, e.g. single point earthing at one of the supply sources or
provision of controls to ensure that identical generators, each separately earthed,
remain equally loaded and excited during normal operation.
NOTE:
When more than 2 generators and/or transformers are directly connected to the same HV
switchboard, use of separate earthing transformers in zigzag connection (e.g., 1 per section),
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 28
should be evaluated for system neutral earthing, with generator single phase distribution
transformers to limit generator earth fault current to a harmless but detectable value e.g. 10 A.
6.
Where generators of dissimilar ratings, characteristics or loadings are to be operated
in parallel so as to give rise to circulating currents in the above-mentioned earthing
resistors that would exceed the thermal rating of the resistors, then the HV system
shall be earthed via one earthing resistor only.
a. Each generator shall then be provided with a suitable switching device (i.e.
remotely operated circuit breaker or latched contactor) to facilitate connection of
any machine to the single earthing resistor.
b. During normal operation, only one generator shall be connected to the resistor. If
the generator so connected is tripped for any reason, an alarm is required to
prompt manual intervention to close the neutral-earth switching device of one of
the other operating generators to facilitate earthing of the system.
7.
Where generators are connected to the main switchboard via individual generator
step-up transformers, each generator neutral point shall be individually earthed
through a single phase distribution transformer with a secondary resistor.
a. The resistor shall be rated to limit the generator earth fault current to 10 A, or to
3 x Ico where Ico is the per-phase capacitive charging current, whichever is the
greater.
NOTE:
The per-phase capacitive current is that due to the generator stator windings, generator
transformer LV winding, and generator main cable/connections.
8.
Each earthing transformer and resistor shall be rated to withstand the respective earth
fault currents for a duration of not less than 10 s. Longer withstand times may be
required, depending on the earth fault protection system applied.
9.
Resonant impedance earthing, (e.g. Peterson coil), may be considered for systems
mainly comprising overhead lines, and thus subject to transient faults, e.g. lightning.
a. In such cases, a low value earthing resistor should be installed in parallel with the
normal high impedance device so that, if a fault on an outgoing circuit is not
cleared within the allowed time, the resistor can be switched in to provide a higher
fault current to allow clearance by back-up protection.
3.8.3
3.8.4
LV systems
1.
The neutral of LV electrical systems shall be solidly earthed at each source of supply
by means of dedicated earth electrodes that have a direct, low impedance connection
to the plant main earth grid (5.5.1).
2.
The system of earthing shall be designated 'TN-S', in accordance with IEC 60364-3.
3.
For fixed LV equipment, earth loop impedances shall be such as to effect circuit
disconnection in a time not exceeding 1 s under solid (negligible impedance) earth
fault conditions, and taking into account the Manufacturer's nominal time/current
characteristic of the protective device.
UPS systems
1.
AC UPS systems shall have their neutrals solidly earthed. This applies equally to
single phase and three phase systems.
2.
DC systems supplying instrumentation loads and switchgear control and protection
loads shall be earthed through a high resistance earth fault monitoring unit with a
sensitivity of 5 mA, as shown in Standard Drawing S 67.025.
3.
DC supplies for telephone systems shall be solidly earthed at the positive pole in line
with normal telecommunication practice. DC supplies for special applications may be
earthed as required by the equipment Manufacturer.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 29
3.9
ELECTRICITY SUPPLY FOR VITAL SERVICES
3.9.1
General
3.9.2
1.
Supplies shall comply with the requirements in (3.2.1).
2.
Such supplies shall, if required by the load, be uninterrupted on failure of one energy
source. Loads which can tolerate an interruption in the power supply, but which require
restoration of the supply within a relatively short period of time, shall be energised from
an interruptible, maintained power source.
3.
To meet the above requirements, the electrical power requirements for loads forming
part of vital services are classified in three categories as specified in (3.9.2), (3.9.3),
and (3.9.5).
4.
For typical electricity supply arrangements that fulfil the requirements of each of the
following categories, refer to Standard Drawing S 67.006.
5.
The design of such systems shall be agreed with the Principal at the SELECT phase of
a project.
AC uninterruptible, maintained electricity supply
1.
AC uninterruptible, maintained electricity supply shall be either:
a. Derived from two 100% rated independent UPS units, each with its own battery,
static changeover switch and maintenance bypass switch, as shown in Standard
Drawing S 67.006.
b. or, for Design Classes 1 and 2, or when the maintenance bypass switch can be
used to release the UPS to carry out full testing and maintenance during a
shutdown of the associated process plant, a single AC UPS unit may be
considered.
NOTE:
Typical intervals for UPS maintenance are 2 yearly.
2.
Parallel static units may be used to provide a single source of uninterruptible power
with high levels of reliability and availability normally required for large indivisible loads.
However, load sharing controls shall not be subject to common mode failure problems.
Guidance on the rating and performance requirements of static AC UPS units is given
in DEP 33.65.50.32-Gen.
3.
The equipment fed from an AC uninterruptible, maintained power supply may be
suitable for receiving a single or a duplicate supply. The following are recommended
arrangements for energising equipment of each type.
4.
For equipment suitable for receiving duplicate supplies:
a. Systems or equipment requiring a duplicate AC supply shall derive one supply
from each UPS switchboard.
b. In order to preserve the high integrity of the redundant supplies shown on
Standard Drawing S 67.006, the UPS switchboards shall not be operated in
parallel.
c. The AC supplies derived from the two UPS switchboards shall also not be
operated in parallel since each uninterruptible supply may be of marginally
different frequency under certain operating conditions.
d. Equipment requiring duplicate power supplies that are required to operate in
parallel shall derive each supply via rectifiers or switch mode power supply
(SMPS) units; for example DCS systems. The rectifier or SMPS units should be an
integral part of the equipment or system being energised.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 30
5.
For equipment suitable for receiving a single supply:
a. Equipment requiring a single AC supply shall derive that supply from a distribution
switchboard which shall itself be energised from one UPS switchboard, but have
an automatic, break-before-make changeover switch to derive a supply from the
second UPS switchboard in the event of failure of the first supply.
b. The operation of the changeover switch shall create an interruption in supply
voltage to the load of not greater than 0.25 s, refer to Standard Drawing S 67.006.
6.
3.9.3
To cater for the possible, but unlikely, failure of the output of one UPS unit, loads
which have a single AC supply and which have a trip function on loss of the supply
voltage shall incorporate a time delay that will prevent tripping during operation of the
above mentioned changeover switch.
DC uninterruptible, maintained electricity supply
1.
Two 100% rated DC UPS units, including batteries shall be used for DC
uninterruptible, maintained electricity supply.
2.
Where an AC uninterruptible, maintained electricity supply is available and the DC load
does not exceed 15 % of the AC supply capacity, the DC uninterruptible, maintained
electricity supply may be derived via duplicate rectifier units fed from the AC UPS
distribution switchboards, as shown on Standard Drawing S 67.006.
3.
Requirements for DC UPS units in tripping (and closing) service of HV switchgear are
specified in DEP 33.67.51.31-Gen.
3.9.4
Battery autonomy times
3.9.4.1
General
3.9.4.2
1.
Requirements for autonomy times for batteries in tripping (and closing) service of HV
switchgear are specified in DEP 33.67.51.31-Gen.
2.
Battery autonomy times specified in 3.9.4.2 and 3.9.4.3 are minimum and may be
increased to enable combining of services aiming at a reduction in the number of UPS
systems. Timers shall not be used to selectively switch off consumers.
3.
Batteries of UPS units SHALL [PS] be rated to energise the relevant loads per the
requirements of the safety case for the installation. In the absence of such
requirements, battery autonomy times specified in 3.9.4.2 and 3.9.4.3 shall be used for
onshore and offshore installations.
Onshore installations
1.
Unless otherwise specified, battery autonomy times for onshore installations shall be
as follows:
NOTE:
Specific offshore country-specific requirements may apply.
a. 30 min for process plant shutdown, process monitoring and control systems;
b. 1 h for utility plant process monitoring and control systems;
c.
1 h for emergency lighting (refer to 5.4.2);
d. 10 min for non-process computer installations;
e. 8 h for fire-fighting and fire alarm and gas detection systems;
f.
2.
8 h for telecommunication and radio systems.
If “N+1” spared emergency generators are supplying the UPS systems, the following
changes to the battery autonomy time may be made:
a.
All vital services, with the exception of telecommunication and radio systems, may
be supplied via 100 % rated duplicate UPS systems with a battery autonomy time
of 30 min;
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 31
b.
3.9.4.3
Telecommunication systems and radio equipment shall be supplied by a dedicated
parallel or duplicate UPS system.
Offshore installations
1.
Unless otherwise specified, battery autonomy times for offshore installations shall be
as follows:
a. 30 min for emergency shutdown and depressurising systems, process monitoring
and control systems;
b. 90 min for helideck and obstruction lighting, see (6.2.4.5);
c. 3 h for public address, platform audible alarms and status lights;
d. 3 h for fire and gas detection and alarm systems;
e. 3 h for emergency and escape lighting (the latter with 1 h internal battery back-up)
(refer to 5.4.2);
f.
24 h for SOLAS (Safety of Life at Sea) communications equipment;
g. 96 h for navigational aid systems.
2.
3.9.5
The above autonomy times for offshore installations may be reduced if “N+1” spared
emergency generators are installed that feed the UPS systems, subject to approval by
the Principal.
AC interruptible, maintained electricity supply
1.
AC interruptible, maintained electricity supply is a power supply which is derived from
the main distribution system but which has back-up power supply, typically from an
automatically started, emergency diesel generator. The interruption in voltage on
mains supply failure is normally 10 s to 15 s.
2.
Switchboard configurations shall typically be as follows:
Automatic Change Over (ACO)
NC Normally Closed
NO Normally Open
G
NC
NO
Vital Load only
Figure 5
Switchboard arrangement vital loads
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 32
G
NC
Normal Load
Figure 6
NO
NC
Vital Load
Switchboard arrangement vital loads (option)
A1
A2
G
G
NO
NO
NC
NC
NC
Emergency Board
To other local
emergency boards
From Normal
supply
To other local
emergency boards
From Normal
supply
C
B
NO
NC
NO
NC
Local Emergency Boards
Vital Load
Figure 7
Vital Load
Switchboard arrangement vital loads (option)
3.
AC interruptible, maintained electricity supply is used typically for energising electric
motors associated with cooling systems of enclosures housing process control and
instrument systems, analysers, emergency lighting, etc.
4.
Standard drawing S 67.006 shows a typical arrangement of an AC interruptible,
maintained electricity supply.
5.
If mains electricity failures lasting longer than 1 h are expected to be fairly frequent,
then the emergency generator should be used to energise the AC UPS units, thereby
extending the duration of the relevant supplies beyond the UPS battery autonomy
times mentioned in (3.9.4). Standard drawing S 67.006 shows this alternative
arrangement.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 33
6.
If the emergency generator is to be used to energise UPS units then the rating of the
emergency generator shall be not less than twice the rated output of the UPS.
NOTE
This is to account for the magnitude of the harmonic currents required by the rectifier of each
UPS and consequent voltage distortion created (non-linear loads).
7.
Emergency generators shall be arranged to start automatically on detection of mains
power failure and to take over the supply of power on closing of the generator circuit
breaker.
8.
Where required, synchronising and/or synchronising check facilities shall be provided
to enable ‘make before break’ return to normal operation.
9.
Facilities shall be provided to permit periodic on-load testing of emergency generators
by enabling the generator to start and be synchronised with the mains supply.
10. Each generating set shall have sufficient fuel storage capacity for at least 8 h full load
operation. Increased fuel storage capacity may be specified for offshore and remote
land installations.
11. For offshore installations, the start sequence of the emergency generator(s) shall be
inhibited or the set(s) shut down if gas is detected in the generator room or in the
combustion air intake.
12. For onshore installations, the emergency generator should be located in a
non-hazardous area.
3.10
CONTROL OF FREQUENCY, VOLTAGE AND REACTIVE POWER
3.10.1
Frequency control
1.
Generators in parallel operation with the utility may be controlled as follows:
a. MW control, if control of grid import/export is required;
b. Back pressure control of steam turbines supplying process steam;
2.
Control shall be designed so that upon loss of grid connection, control automatically
reverts to island operation.
3.
Generators in island operation may be controlled as follows:
a. Speed control with a droop characteristic, and a secondary frequency controller to
maintain nominal frequency.
b. Individual units shall be capable to be switched to fixed MW control, e.g., due to
process or equipment constraints. However, sufficient other units shall remain in
droop control mode to maintain frequency within limits.
4.
3.10.2
Emergency generators should not be included in secondary frequency control.
Voltage control
3.10.2.1 General
1.
Voltage control shall be a primary function to maintain the main busbar voltages within
narrow, fixed limits under normal operational conditions.
2.
The bandwidth shall be such that the allowable voltage deviations within the plant
network comply with (3.3.2).
3.
Reactive power control is a secondary and tertiary voltage control function and should
be used:
a. As a secondary function to maintain generators within the operational limits. This
function may be extended to provide a constant reactive power output or a
constant power factor.
b. As a tertiary function to maintain the exchange of reactive power with an external
network within a certain bandwidth or to provide a constant power factor to the
power exchange.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 34
4.
Primary, secondary and tertiary voltage control functions shall be separated
hierarchically within a control system. As the three functions will influence each other,
stable operation can only be enforced by a distinction in time response - primary
control acting fastest and tertiary control slowest.
5.
Secondary and tertiary voltage control shall allow for the operational constraints of the
controlled unit.
6.
Emergency generation units should be excluded from tertiary voltage control.
3.10.2.2 Voltage control – Island operation
1.
Voltage control shall be assigned to the generators connected to the main busbar.
2.
A secondary control system shall maintain the reactive power distribution between the
generators in operation by adjustment of the AVR set points.
3.
If additional generators are connected at a lower voltage level, the function of voltage
control should be primarily assigned to equipment connected to the main busbar as
stated in the previous paragraph.
4.
The requirement for secondary voltage control of the additional generators shall be
determined by the Principal.
3.10.2.3 Voltage control – Parallel operation (connection to external grid)
1.
Voltage control should normally be assigned to the tap changer(s) of the
interconnecting grid transformer(s).
2.
A control system shall be used to maintain the correct tap position of parallel
transformers to eliminate circulating reactive currents (e.g. master-slave).
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 35
4.
DESIGN AND SELECTION REQUIREMENTS FOR EQUIPMENT AND CABLES
4.1
GENERATORS
4.1.1
General
4.1.2
1.
Rating, type and characteristics of the generating set shall fulfil the requirements of the
electrical power system, whether operating in island mode, in parallel with other
generating sets, in parallel with a public utility or any combination of these.
2.
Rating, type and characteristics of the generating set shall take account of factors such
as overload capabilities, load acceptance/rejection, real and reactive power sharing,
maximum speed deviations, maximum response times, reactances, inertias, etc.
3.
The kVA rating of the generator should be selected by the prime mover Manufacturer,
in line with the specified requirements, so that the generator does not limit the output
of the prime mover over the specified operating temperature range.
4.
The generator rated power factor shall be 0.8 lagging, unless otherwise specified.
Synchronous generators ≥ 1250 kVA
1.
The generator and its auxiliaries shall comply with DEP 33.65.11.31-Gen., and will
normally be used for base load generation services; however, it may also be installed
in (centralised) emergency or stand-by systems of large process facilities.
2.
Main cable termination
DEP 33.65.11.31-Gen.
arrangements
shall
be
in
accordance
with
a. For generator ratings requiring more than three cables per phase, use of phase
segregated busbar connections between the generator and its transformer or
switchgear shall be evaluated.
b. For transformer-connected generators, phase segregation shall be maintained for
all the cabling and for busbars connected to the generator, so as to minimise the
possibility of multi-phase short circuits.
3.
Each generating set should be provided with its own LV auxiliary switchboard for the
supply and control of all its motor driven auxiliaries. This switchboard shall be treated
as an essential services switchboard, (3.5.4) and be provided with a normal and a
stand-by incomer.
4.
The normal supply should be taken from a utilities switchboard in the power plant.
5.
The stand-by supply shall be taken from an interruptible, maintained electricity supply
(emergency) switchboard. The stand-by supply should be rated equal to the normal
supply.
6.
For a plant equipped with its own generation only, a minimum of two or half of the main
generating sets should be equipped with a black-start capability.
7.
In power systems with extensive distribution systems at voltages above 60 kV, light
load conditions may give rise to leading power factor operation. In such cases, the
leading power factor capability of the generator shall also be specified.
8.
Main generators shall be fitted with the following control equipment:
a. Manual and automatic synchronising with a check synchronising relay and a deadbus override.
b. Voltage control equipment consisting of automatic voltage control with a manual
control stand-by system.
i. The manual control system shall follow the setpoint of the automatic
control system to allow for automatic changeover from the automatic to
the manual control system without significant voltage transients if the
automatic control system fails.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 36
ii.
The voltage control system shall be suitable for island and parallel
operation. In island operation the voltage control system shall be
designed to maintain the voltage within 0.5 % of the operational value
during normal operational conditions.
iii. Reactive-Power sharing among sets shall be provided for the voltage
control system.
iv.
Cross-current compensation between generators employing A static
Loop Circulating Current should only be considered for extensions to an
existing power station where this feature is already provided.
c. Power factor or reactive power control equipment arranged to adjust the AVR
setpoint, so as to keep the generator power factor constant when operating in
parallel with a public utility supply.
i. For a generator connected via a unit transformer with an on-load tap
changer, in general, one AVR unit shall be the master and the other the
slave, or one shall be controlled manually while the other is on auto
mode, to prevent “voltage hunting”.
9.
Generator control panels shall be fitted with underfrequency and overfrequency
tripping devices that are set by the generator Manufacturer to protect the generator
and its prime mover.
10. There shall be a signal into the control circuits of the generator(s) to signify the change
in operating mode from grid connected to island operation, which is normally achieved
via the interconnection circuit breaker auxiliary contacts.
11. During synchronised operation with the grid, the generator governor and exciter are
set to control the generator MW output and power factor or reactive power
respectively; during island operation, the same controls will affect the frequency and
voltage respectively. This change in operating mode needs to be signalled to the
governor control.
12. Gas turbine and diesel engine driven generating sets shall be provided with automatic
control schemes. This shall include facilities for auto-starting, automatic synchronising
and automatic loading.
13. Local control of generating sets shall include all the components necessary for
commissioning, maintenance of and trouble-shooting the generating sets
independently of the rest of the power system.
14. Main generators shall be provided with the alarm equipment, indicating instruments
and integrating meters stated in (Appendix 3).
4.1.3
4.1.4
Synchronous generators < 1250 kVA (packaged units)
1.
The generator and its auxiliaries shall comply with DEP 33.65.11.32-Gen. They will
normally be used for interruptible, maintained electrical supplies, possibly together with
black-starting duties, rather than for base load generation services.
2.
The rating of these generating sets will normally be within the range of 50 kW to
1000 kW, and supply an emergency LV switchboard. However, for power plant blackstart duties and emergency or stand-by systems of large process facilities, sets with a
larger rating may be required, possibly supplying an HV system.
3.
In sizing the generating set, account shall be taken of the related motor starting
requirements and UPS loads (3.9).
4.
The generating sets shall be suitable for unattended operation and for automatic blackstarting on detection of failure of the mains supply.
Cage induction generators
1.
The generator shall comply with DEP 33.66.05.31-Gen.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 37
2.
If a Static Frequency Converter (SFC) is required to facilitate the connection to the
electrical system at its fixed frequency and voltage, it shall comply with the relevant
parts of DEP 33.66.05.33-Gen.
4.2
SWITCHGEAR
4.2.1
HV switchgear
1.
HV switchgear and controlgear shall be in accordance with DEP 33.67.51.31-Gen. or
DEP 33.67.51.32-Gen.
2.
The selection of switching media shall be:
3.
a. Vacuum
:
For system voltages up to 36 kV.
b. SF6
:
For system voltages above 36 kV
Outdoor switchgear shall only be considered for voltages exceeding 52 kV.
NOTE:
This does not preclude the use of pole-mounted isolators, fuses, etc., at voltages up to and
including 52 kV in association with overhead distribution networks in field areas.
4.2.2
LV switchgear
4.2.2.1
General
4.2.2.2
1.
LV switchgear and controlgear shall be in accordance with DEP 33.67.01.31-Gen.
2.
Where generators are directly connected to an LV switchboard, the ratio of peak to
rms short circuit current is likely to be higher than normal allowance as per
IEC standard. In these cases, the peak short circuit requirement shall be clearly stated
in the specification.
3.
For single line diagrams of switchboard panels, panel identification, etc., see Standard
Drawing group S 67. Fuse protection is preferred to moulded case circuit breakers
(MCCBs) with built-in protection.
4.
Non-metallic enclosed switchgear and controlgear is acceptable for LV sub-distribution
switchboards, providing they are protected by short circuit current limiting devices
having a maximum nominal current of 400 A.
LV feeders
1.
Plain cable feeders for LV sub-distribution shall be controlled and protected by fuseswitch combinations or by MCCBs incorporating short circuit and earth fault protective
devices.
2.
MCCBs and fuses shall coordinate with outgoing circuit protective devices on the
receiving-end sub-distribution switchboard.
3.
Similarly, the rating of any fuse-protected LV circuit, which derives a supply from a
distribution switchboard, should not exceed 50 % of the rating of a fuse-protected
LV circuit, which energises the switchboard. This is to ensure that the circuit protective
devices can be fast operating and selective in isolating short circuits.
4.3
POWER TRANSFORMERS
4.3.1
General
1.
Power
and
distribution
DEP 33.65.40.31-Gen.
transformers
shall
be
in
2.
Distribution transformers shall normally be connected Dyn with clock numbers as
advised by Principal.
3.
For primary voltages up to and including 12 kV, fused (latched) contactors shall be
used as switchgear for transformer feeders.
4.
Transformers for outdoor use and rated up to and including 3150 kVA shall be of the
oil-filled hermetically sealed type;
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
accordance
with
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 38
5.
Transformers for outdoor use and rated above 3150 kVA shall be of the oil-filled
conservator type.
NOTE:
The type of enclosure is only dependent on the kVA rating and not on the transformer voltages.
6.
For use in high-humidity tropical areas, a conservator that prevents contact between
the oil in the transformer tank and the ambient air should be used. This may be either
the membrane type or multi-compartment type of split conservator.
7.
In locations where fire risk is required to be minimised, e.g. in buildings, on offshore
platforms, etc., the dielectric/cooling liquid of transformers shall be synthetic with
reduced ignitability and flame-retardant characteristics, e.g. silicone fluid. In the above
locations, dry-type transformers having cast resin encapsulated windings may also be
used.
8.
Transformers shall be selected according to their annual operating cost versus capital
investment, as stated in DEP 33.65.40.31-Gen.
9.
The voltage ratio of generator transformers should be selected so as to avoid the need
for an on-load tap changer, e.g., 34.5/11 kV for connection of an 11 kV generator to a
33 kV system.
10. For motor unit transformers, tap changers should be avoided. If adjustment of the
voltage is required, a tap changer with bolted connections should be installed, rather
than one with a switching mechanism.
4.3.2
On-load tap changers
1.
On-load tap changers shall be specified for grid intake transformers, unless the public
utility can guarantee a voltage variation range of less than ± 5 %.
NOTE:
On-load tap changers are not normally required on island-operation generator transformers.
4.4
UPS EQUIPMENT
4.4.1
General
1.
UPS equipment shall be selected according to the preferred arrangements for AC and
DC uninterruptible, maintained electricity supplies for process control and safeguarding
systems, as shown in Standard Drawings S 67.006, S 67.024, S 67.025 and S 67.080.
The same arrangements shall, in general, also be applied in power plants and utilities
systems.
2.
Uninterruptible, maintained electricity supply distribution switchboards and the
associated UPS units should be located as close as possible to the loads supplied.
3.
Sub-distribution circuits fed by DC or AC UPS systems should be protected by fuse
against short circuits. MCCBs may be used if protected against risk of inadvertent
operation due to accidental touch.
NOTE:
4.4.2
4.4.3
The maximum size of fuses or MCCBs used should take into account the limited short circuit
output of the UPS and the design intent to avoid switching to Bypass to clear large faults
AC UPS units
1.
Static AC UPS units shall comply with DEP 33.65.50.32-Gen. and be capable of
fulfilling all the vital power requirements.
2.
Parallel static UPS units may be used to provide a single AC source of power to an
indivisible load, e.g. at computer centres.
3.
The required limits on the output conditions of voltage, phase symmetry, frequency
and distortion are stated in DEP 33.65.50.32-Gen.
DC UPS units
1.
Static DC UPS units shall be in accordance with DEP 33.65.50.31-Gen.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 39
4.4.4
Batteries
1.
4.5
DEP 33.65.50.32-Gen. specifies the alternative types of battery that are technically
acceptable for UPS duty.
CAPACITORS
1.
Capacitors for power factor correction shall be of the low-loss, metal-enclosed,
hermetically-sealed type. LV capacitors shall be of the self-healing type complying with
IEC 60831, and may be of either single-phase or three-phase unit construction. HV
capacitors shall comply with IEC 60871.
2.
All capacitor units shall have individually fused elements; if this is not feasible for
certain types of LV capacitor, internal overpressure disconnectors shall be provided.
3.
Internal fuses and internal overpressure disconnectors shall comply with IEC 60931-3
or IEC 60871-4, as applicable for the voltage rating.
4.
HV capacitor banks shall normally be installed outdoors.
5.
HV capacitor banks shall comprise individually fused capacitor units. The fuses shall
comply with IEC 60549 and should be easily accessible for inspection and
replacement.
6.
Capacitor failure shall trip the bank and provide an alarm indication. If recommended
by the Manufacturer, overpressure switches shall be fitted to HV capacitor units and
connected to trip the capacitor bank.
7.
Individual capacitors shall be controlled by contactors, circuit breakers or, for LV
applications, fused switch units, approved for this duty by the switchgear Manufacturer.
They shall be rated for at least 1.5 x In , and able to withstand transient inrush currents
up to 100 x In (Where In is nominal current of connected capacitor banks).
8.
In those cases where a capacitor is connected in parallel with an electric motor, a
single switching device and associated relays and/or fuses that control and protect
both the motor and the capacitor shall be provided.
9.
High inrush currents can occur particularly when paralleled with already energised
capacitors. If required, air-cored reactors may be installed in HV capacitor banks to
limit the inrush currents. See IEC 60831 or IEC 60871.
10. Capacitors have relatively long discharge times (from the operating voltage down to
75 V) allowed in the relevant IEC standards, i.e., 3 min for LV capacitors and 10 min
for HV capacitors. Shorter discharge times shall be specified where necessary to
satisfy national or local requirements.
11. A clear warning notice shall be posted on any cubicle or compartment containing
capacitors. An interlock system shall be provided for all automatically controlled
capacitor banks to prevent re-energisation when the residual voltage is above
10 % Un.
12. Where motors have individual capacitors, long discharge times may affect the restart
after e.g. a power interruption. This shall be addressed during the DEFINE phase of
the project.
13. With regard to design of capacitors used in harmonic filter applications
recommendations from a specialist consultant or suppliers shall be followed.
14. Large capacitor banks (e.g. harmonic filters) may cause overvoltages during switching.
Studies shall be carried out to determine if remedial measures are required, e.g. inrush
limiters.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 40
4.6
ELECTRIC MOTORS
4.6.1
General
1.
Electric drives shall be controlled by fused contactors. When motor rating exceeds
max rating of a fused contactor, a circuit breaker shall be used.
2.
The minimum/maximum power ratings of electric motors in relation to system voltage
are stated in DEP 33.66.05.31-Gen.
3.
The selection of motor voltages and power ratings for DOL starting should conform to
the following:
Switchboard nominal
voltages
Maximum LV
motor rating
400 V
185 kW
690 V
1
Minimum HV
motor rating
315 kW
6600 V
NOTE 1:
160 kW
Refer to (3.3.1).
4.
Any motor driven auxiliaries associated with the main motor or its driven equipment
shall be fed from a nearby switchboard, which shall have a load classification (3.2.1)
equal to or better than that of the main drive.
5.
The auxiliary drives shall be connected to a section of the switchboard which is fed
from the same supply source and supply circuit as the main unit in order to obtain
optimum availability of the total system.
6.
For low speed applications and for installations in which power factor compensation is
beneficial, synchronous motors of less than 5 MW may be economically justifiable.
Synchronous motors should not be considered at ratings below 2 MW.
NOTE :
Cage induction motors are preferred on account of their simple robust construction and lower
capital cost. Synchronous motors are more efficient than cage induction motors (of equal rating),
but they have a higher capital cost. The use of synchronous motors will normally be cost
effective at ratings exceeding 5 MW, depending on speed, Manufacturer, etc.
7.
The generation of pulsating torques by a synchronous motor during run-up may need
to be addressed by the driven equipment Manufacturer.
8.
For very large high speed motors, the use of magnetic bearings may be considered.
The specification of these shall be agreed with all parties involved, including the
machine and driven equipment manufacturers.
9.
Integrated Motor Control Systems (IMCS), shall be considered, provided it can be
demonstrated that they are cost effective over the total life cycle in comparison with
conventional LV motor starters. The IMCS shall comply with Appendix 1 of
DEP 33.67.01.31-Gen. Life cycle cost comparison shall be based on periodic
replacement of the IMCS system due to obsolescence at around 12 years.
10. For motors in services classified as vital (e.g. Fire water pumps), the control circuits
shall be hardwired and not via IMCS.
11. Electric drives shall be provided with a local emergency stop. A Remote Control Unit
(RCU) mounted local to the motor is preferred but alternative schemes may be
considered where remote control and indication is provided e.g. DCS.
NOTE:
With an RCU, motors can be started/stopped and, in the "0" (neutral) position, automatically
controlled. Examples of control circuits are shown in Standard Drawings S 67.004, S 67.028 and
S 67.071.
11. If automatic control is provided, then the auto on/off control signals shall be given via
an IMCS or interposing relays. Similarly, for HV motors, control may be provided via
protection devices (Intelligent Electronic Device – IED) or interposing relays.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 41
12. Motors that are mounted above grade, e.g. fin-fan cooler motors, and controlled from
grade level for operational convenience, shall have safety switches located near the
motors.
13. Where motors are fitted with anti-condensation heaters, a heater safety switch shall be
installed adjacent to the motor's RCU.
4.6.2
Synchronous motors
1.
The synchronous motor and its related equipment shall comply with
DEP 33.65.11.31-Gen., and fulfil the requirements imposed upon it by the power
system and its operational requirements, overload capabilities, load/speed/time
responses, etc.
2.
Synchronous motors shall be equipped with the following control equipment:
a. voltage control/excitation control equipment;
b. equipment for controlled start-up, e.g. via start switch;
c. equipment for controlled shutdown, e.g. via normal stop switch;
d. equipment for crash shutdown, e.g. via emergency stop switch.
4.6.3
4.6.4
4.6.5
Cage induction motors
1.
The cage induction motor and all its related electrical auxiliary equipment shall comply
with DEP 33.66.05.31-Gen.
2.
Cage induction motors shall normally be switched direct on line. If this is impractical or
uneconomic, current-restricting start-up equipment shall be used.
3.
Motors with auxiliary equipment, water cooling or special detection facilities, e.g.
cooling air/water temperature detectors, water leakage detectors, etc., shall be
connected to an alarm annunciation system with first failure alarm.
Special motors
1.
Submerged motors driving sump pumps shall be fed by flexible oil-resistant cables
with earth connector shielding around each core.
2.
DC motors shall generally be specified by the relevant driven equipment supplier to
fulfil the duty required at the minimum specified DC system voltage.
3.
DC motors shall comply with the relevant sections of DEP 33.66.05.31-Gen., e.g.
enclosure classification, bearing requirements, etc.
Variable speed drive systems (VSDS)
1.
The VSDS with all its related equipment shall comply with DEP 33.66.05.33-Gen.
2.
The application of a VSDS shall be considered where it can be demonstrated that the
VSDS will benefit the design (avoid gearbox), operation, maintenance and energy
efficiency of the plant.
3.
These considerations shall be reviewed by an appropriate multi-disciplinary team.
Examples of the types of drives where a VSDS can be beneficial are:
a. centrifugal pumps, including submersible pumps;
b. recycle gas compressors and booster compressors;
c. fin-fan coolers;
d. extruders.
4.7
ELECTRICAL NETWORK MONITORING AND CONTROL (ENMC) SYSTEM
1.
A dedicated ENMC system for the electrical supply and distribution system should be
considered during the SELECT phase if centralised electrical system supervisory
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 42
control and data acquisition is required to ensure efficient and stable operation of the
power system. Refer to DEP 33.64.10.32-Gen.
2.
4.7.1
The overall monitoring and control philosophy of the electrical supply and distribution
system, including interfaces to package units, shall be established and documented in
the DEFINE phase of the project and is subject to specific approval by Principal.
Annunciator panels
1.
Each substation with HV switchgear and/or any electricity generation capacity installed
shall be provided with a system to monitor and store the individual alarm and trip
functions of the substation equipment.
2.
It shall be possible to access the data at the substation without the need for additional
devices, e.g. a portable computer.
3.
Microprocessor-based systems are preferred. The system shall provide common and
selected alarms to the DCS for display in a manned control room. Reference is made
to (Appendix 3).
4.
The system shall either be supplied from an uninterruptible, maintained electricity
supply or have internal rechargeable batteries.
4.8
CABLES, WIRES AND ACCESSORIES
4.8.1
General
1.
For process plant on-plot power and instrumentation cabling, a decision on
underground or above-ground cable routing shall be taken early in the DEFINE project
phase to ensure plant layout, route design and construction schedule is optimised.
2.
The method described in (Appendix 6) shall be used to decide on underground or
above-ground cable routing. If this does not result in a clear driver for the decision then
underground cabling should be adopted because of the better protection against fire
and mechanical damage.
3.
Lead-covered underground cables should be avoided due to their higher cost,
environmental issues, restricted availability and additional handling (weight and special
terminations).
4.
Consequently, if lead-covered underground cables would be required to comply with
present or future contaminated ground requirements defined below, above-ground,
cabling shall be selected unless there are other overriding drivers (refer to
Appendix 6).
5.
Once a decision is made, the plant layout, route design, construction method and
schedule shall be optimised for the adopted policy, in order to minimise the risk of
major disruption to the project schedule and increased costs.
6.
For areas where there is a possibility of soil contamination or chemical attack and
above-ground cable routing is not practical or prohibitively expensive, only then shall
cables be provided with a lead sheath, in compliance with EEMUA 133.
7.
For non-load carrying cables, alternative forms of protection against chemical attack
may be used if approved by the Principal. Such cables may become also available for
load carrying cables, but shall only be used if tests have proven that the cable is fit for
purpose when operating under full load at its maximum temperature.
8.
Non-lead-sheathed cables may be used in areas where the probability of hydrocarbon
or chemical contamination of the ground is very low, for example in gas plants
(LNG/NGL).
9.
For above-ground and offshore installations, the use of non-armoured cable may be
considered.
a. The design of non-armoured cable non-armoured cable systems should take into
account the specific earthing and bonding requirement for electrical safety and
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 43
EMC.
b. For EMC reasons, any non-armoured cabling shall be adequately protected by
means of cable ladders or cable trunking.
c. Particular attention shall be paid to segregation of power cables and (instrument)
signal lines.
d. The use of non-armoured cable systems requires the approval of the Principal at
the DEFINE phase of the electrical system design.
10. Multicore cables are preferred to single-core cables. However, single-core cables may
be used in the following situations:
a. for practical and/or economic reasons on short runs, e.g. generator and
transformer secondary cables;
b. in the case of high current ratings where two parallel multicore cables of the
largest cross section permitted would not suffice;
c. for cables with high current ratings connected to HV switchgear that is specifically
designed for connection with single-core cables, e.g. GIS.
11. Cables for protection, controls, indications and alarms for a particular item of plant or
circuit (e.g. generator, motor, transformer, etc.) shall be dedicated to that item of plant
or circuit.
NOTE:
This requirement does not apply to 4-20 mA transducer signals.
12. Individual cables shall be used for each of the following:
a. CT secondary circuits;
b. VT secondary circuits;
c. interlock/intertrip circuits;
d. pilot wire differential circuits.
13. The requirements of (4.8.1 part 13) do not apply to motor control and ammeter circuits
to an RCU, nor to combined power and control circuits to small LV motors in
accordance with Standard Drawing S 67.004.
14. Fibre optic cables, or alternatively fibre optic cores in composite cables, or ducts may
be used for the transmission of signals and data as part of, e.g. an ENMC system.
15. All power, lighting, control and earthing cables shall have copper conductors.
16. In specific cases, cables with aluminium conductors may be used, in particular for long
distribution feeders, if economic and approved by the Principal. Precautions to prevent
galvanic corrosion should be taken with the installation of bi-metallic terminations.
4.8.2
HV cables
4.8.2.1
Three core cables
1.
Three core HV cables shall be dry cured, cross-linked polyethylene (XLPE) insulated,
(if specified, lead sheathed), single galvanised steel wire armoured and PVC
oversheathed.
2.
Depending on the cable construction and voltage level, a copper screen may be
installed over each insulated conductor. If the location of the installation permits, the
lead sheath may be omitted (4.8.1).
3.
Cables with ethylene propylene rubber (EPR) insulation may be specified where a
greater flexibility is required, e.g. on offshore installations.
4.
HV multicore cables shall have a minimum cross sectional area of 25 mm² and a
maximum cross sectional area of 300 mm².
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 44
4.8.2.2
Single-core cables
1.
Single core HV cables shall be either XLPE insulated or ethylene propylene rubber
(EPR) insulated, screened, unarmoured and PVC oversheathed.
2.
These cables shall be installed only above ground or in preformed trenches, where
access is restricted.
3.
Single-core cables, which are directly buried or installed outside the restricted access
area, shall have a copper earth-screen. The cables shall have a high density
polyethylene (HDPE) outer sheath. No aluminium or copper armour is required since it
does not provide additional mechanical protection over and above that provided by the
HDPE outer sheathing.
4.8.3
LV cables
4.8.3.1
Twin and multicore cables
4.8.3.2
1.
Twin and multicore power, lighting and control cables shall be cross-linked
polyethylene (XLPE) insulated, galvanised steel wire armoured (or braided for sizes up
to and including 10 mm²; larger sizes with braiding may be considered for offshore
application) and PVC oversheathed. These cables may be used for above-ground and
underground installations. Cables with EPR insulation may be specified where a
greater flexibility is required, e.g. on offshore installations.
2.
Maximum cross-section shall be 185 mm² for motor cables and 240 mm² for
distribution cables.
3.
For power, lighting and control cables the minimum cross section shall be 2.5 mm²,
except for signalling and indication purposes, where a minimum cross section of
1.5 mm² may be used.
4.
Mineral-insulated metal-covered cables shall not be used, except with the specific
approval of the Principal.
Single-core cables
1.
Single-core cables for above-ground connections between transformers and LV
switchgear shall be XLPE or EPR insulated, PVC sheathed.
2.
For standardisation purposes, HV single-core cables may be used for this application.
NOTE:
4.8.4
4.8.5
4.8.6
In this case the LV cables will have an outer sheath colour-standardised for HV cables.
Earthing cables
1.
Above-ground earthing cables shall be PVC sheathed, coloured yellow/green, as a
protection against electrolytic corrosion.
2.
Underground earthing cables should be of the same type. However, where the
requirements of this DEP with respect to earth resistance values (5.5.1) or EMC (5.5.6)
cannot be met, underground earthing cables may be bare (uninsulated), following
approval by the Principal.
Flexible cables
1.
Flexible cables for voltages up to 450 V to earth shall be heavy duty neoprene rubber
insulated, PVC sheathed.
2.
Flexible cables used in hazardous classified area shall meet requirements of
IEC 60079-14.
Wires in conduit
1.
Wiring shall be PVC insulated in accordance with IEC 60227.
2.
Minimum cross-section shall be 2.5 mm², except for the phase connection between a
switch and a luminaire, where 1.5 mm² may be applied, taking into account the correct
current rating and the maximum voltage drop.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 45
3.
Wiring colours shall be:
a. blue
- neutral;
b. brown
- phase;
c. black
- switched phase;
d. green/yellow - earth.
4.
4.8.7
Local rules requiring other colours shall prevail.
Cables with increased fire withstand capabilities
1.
The following types of cables shall be used in circumstances requiring an increased
fire withstand capability depending upon the application:
a. Reduced flame propagation (per IEC 60332), zero halogen (with a minimum light
transmission value of 60% per IEC 61034-2), low smoke (with a maximum halogen
gas emission of 0.5%, per IEC 60754-1 and IEC 60754-2).
These cables shall be installed in normally-manned areas where escape to an
area with clean air is not possible, typically in accommodation areas on offshore
platforms and in non-ventilated, indoor operational areas on offshore platforms.
b. Fire resistant per IEC 60331, zero halogen, low smoke.
These cables shall be installed in those facilities, which are required to continue in
operation during a fire, typically for fire fighting equipment.
4.8.8
2.
Since cables are normally installed as a single unjointed length, the type of cable
selected from the above shall be that applicable to the most arduous conditions along
the cable route.
3.
Where fire-resistant properties are required for the above-ground section of
underground type cables, proprietary fire proofing may be applied to standard
underground cables types providing that the applicable cable length does not exceed
10 % of overall cable length, if approved by the Principal.
Cable accessories
1.
Cable glands for hazardous areas shall comply with IEC 60079.
2.
Glands shall be selected to suit the type of cable and termination box/enclosure, and
shall be of the appropriate type of protection, e.g. Ex'd', Ex'e'.
3.
Effective earth continuity shall be ensured between the cable armour/braid and the
gland plate or the internal earth terminal.
4.
Cable glands for non-hazardous areas shall comply with EN 50262.
5.
For standardisation purposes, and to reduce the risk of errors, the same “Ex” glands
shall be adopted for all process plant areas.
6.
Metallic cable glands shall be used with metallic termination boxes. Depending on the
type of cable, brass compression glands with an armour clamping feature may be used
as an alternative to the method described below for non-metallic termination boxes.
7.
Non-metallic cable glands may be used with non-metallic termination boxes to
terminate braided or non-armoured cable; suitable arrangements shall be made to
terminate the braiding at the internal earth terminal.
4.9
OVERHEAD LINES
4.9.1
General
1.
Conductors, insulators, support and all related equipment shall be designed to provide
adequate protection against the adverse effects of all prevailing site conditions, e.g.
wind loading, lightning, icing, polluting atmospheres, etc.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 46
2.
4.9.2
The design of overhead lines should take into account local utility practice in
determining the type of construction and the selection of materials, if there is no
previous experience in the locality.
Supports
NOTE:
4.9.3
4.9.4
1.
The supports may either be wood, steel or concrete poles or lattice steel towers,
whichever is the most economic after the technical design parameters have been
satisfied.
2.
Wood poles shall comply with BS 1990-1, concrete poles shall comply with EN 12843.
Steel poles and towers should comply with Manufacturers' standards.
4.
For wood poles, defects such as splits and shakes are unacceptable. Commonly used
soft woods such as fir, pine and larch require impregnation with creosote, anti-termite
repellents if they are to be used in tropical countries to prevent decay.
5.
Supports shall be designed to take account of the mechanical forces that will be
encountered in operation and shall incorporate the specified factors of safety (6.3.4):
6.
Pole supports for sections and deviations shall be stayed. For non-conducting
supports, the staywire shall be fitted with a long staywire insulator.
7.
The installation of anti climbing guards shall be considered.
8.
The design of tower supports should be proof tested, i.e., at a tower testing station.
Conductors
1.
Phase and earth conductors should be aluminium alloy, although ACSR (aluminium
conductor steel reinforced) may be considered for reasons of standardisation with
existing lines. Galvanised steel may also be considered for the earth conductors.
2.
Conductors shall comply with IEC 61089.
3.
ACSR conductors should not be used in coastal or corrosive environments.
Insulators
1.
Post insulators and pin insulators shall be glazed porcelain, complying with IEC 60383.
They should be used as intermediate support insulators at voltages up to and including
36 kV. Semi-conducting glazes should not be used.
2.
Cap and pin insulator discs shall be toughened glass, complying with IEC 60383 and
IEC 60120. They should be used in suspension insulator strings on intermediate
supports at higher voltages, and in tension insulator strings at all voltages.
NOTE:
Insulators of different mechanical and electrical strengths will normally be required for different
duties.
3.
The insulator profile shall be selected to suit the site conditions, e.g. aerofoil profile in a
desert environment or anti-fog profile in Northern European conditions.
4.
The insulator creepage length shall also be selected to suit the site conditions, typically
35 mm/kV in a desert environment. In the absence of any site specific information,
refer to IEC 60815 for guidance.
NOTE:
5.
4.9.5
Depending on the topography and soil conditions, pole supports (rather than steel towers) will
generally be economic at all the voltages covered by these guidelines, except in the case of
double circuit lines at 72 kV and above.
The specific creepage length is the ratio of the leakage distance measured between phase and
earth over the r.m.s. phase to phase value of the highest system voltage for the equipment.
Consideration may also be given to the use of polymeric long rod insulators, complying
with IEC 60433.
Steel components
1.
All steel components, including fasteners, shall comply with a relevant international or
national standard and be hot-dip galvanised after fabrication in accordance with
ISO 1461.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 47
4.9.6
4.9.7
4.9.8
Lightning arresters
1.
Lightning arresters with counters complying with IEC 60099-1 shall be installed at
every cable termination and at every equipment connection point, e.g. transformer teeoff.
2.
The current rating of the lightning arresters shall be selected to suit the system short
circuit rating, and the voltage rating shall be determined as part of the insulation coordination, in accordance with IEC 60071.
Road crossings
1.
Where the overhead line route is planned to cross roads, consideration should be
given to the routing of the line either by an overhead route or by a buried cable section.
2.
Given that the breakdown of overhead line cable terminations is the cause of many
line failures, then, if the design clearances can be achieved, an overhead route is
preferred.
3.
Overhead road crossing goal posts shall be erected at both sides of the overhead line,
at a distance of 75 m from the overhead line.
4.
Warning signs, indicating the maximum height permitted shall be erected at both sides
of the road, between the goal posts.
5.
The protective wire between the goal posts shall be installed at the permitted
maximum height.
6.
If a buried cable section is selected, then the underground cable shall be installed
through a PVC pipe to avoid road damage in case of cable repair and replacement
work.
7.
Surge arrestors shall be fitted to either end of the cable section.
Vibration dampers
1.
4.9.9
A study shall be carried out to determine the need for, location and design of dampers
used to mitigate the effects of Aeolian and other forms of vibration.
Communications
1.
Overhead line towers and “H” frame portal designs may be utilised to carry
communications systems.
4.10
LIGHTING AND SMALL POWER EQUIPMENT
4.10.1
General lighting requirements
1.
Industrial fluorescent lighting in 'white' colour shall be used for illumination.
NOTE:
In low ambient temperatures (sub-zero) fluorescent lighting is not effective; other sources should
be used.
2.
Long life lamps in combination with electronic ballasts shall be used, to take advantage
of their increased lumen efficiency and economic life.
3.
High pressure discharge lamps should be used to light tall buildings or large areas. In
view of the restarting time of this type of lighting after a voltage dip, however, sufficient
fluorescent luminaires shall be installed for basic lighting requirements of the area,
equivalent to emergency lighting requirements (5.4.2).
4.
Floodlighting shall be used at the perimeter of process and production plants.
5.
Maintenance free, sealed-for-life, discharge lamps and associated luminaires may be
considered with account being taken of their total life-cycle cost. These types of
luminaires are available in industrial and Ex protected executions.
6.
Low pressure sodium discharge lamps shall not be used.
7.
Incandescent lighting shall be applied only for decorative lighting.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 48
4.10.2
4.10.3
4.10.4
Plant lighting
1.
For standardisation reasons, the same type of Ex luminaires shall be used in all plant
areas, using the Ex protection method and gas or dust group selected for the most
hazardous Zone classification.
2.
If fluorescent luminaires with type of protection Ex'e' are used, the ballast shall have
end of lamp life protection.
3.
An isolating switch shall be included within the fitting to prevent the luminaire from
being energised when it is not fully assembled.
4.
If high pressure discharge luminaires are used, they shall have type of protection
Ex 'de'.
Building lighting
1.
Luminaires in closed buildings that are classified non-hazardous areas, e.g. control
rooms and substations, shall be fluorescent bi-pin, switch-start, industrial pattern.
2.
Non-industrial luminaires may be used in office buildings. LED lighting for control
rooms and non-industrial locations may be considered after agreement by the project
Human Factors Engineering Technical Authority and if approved by the Principal.
Special lighting
1.
4.10.5
Special lighting such as navigation aids, obstruction warning lights and aircraft warning
lights shall comply with DEP 33.80.00.30-Gen. and the applicable national and/or
international rules and standards.
Portable lamps and tools
1.
Hand-held lamps shall be rated for maximum 50 V AC supply.
2.
The types of portable equipment to be used in both industrial and non-industrial areas
(except in restrictive conductive locations as referred to below) shall be one or more of
the following:
a. Double or reinforced insulation equipment, Class 2 of IEC 61140 and IEC 60364,
connected to the mains via a 30 mA RCCB, protecting both the supply cord and
the equipment;
b. 24 V or 50 V equipment, Class 3 of IEC 61140 and IEC 60364, connected to a
safety extra-low-voltage circuit by using double-wound safety isolating
transformers, complying with IEC 61558 (SELV system).
c. For the supply to portable hand lamps and safety tools, an adequate number of
suitably rated single phase double-wound portable safety isolating transformers,
having a secondary no-load voltage of not more than 50 V, fully insulated from
earth, shall be provided. The primary side of these transformers shall be provided
with a suitable length of flexible cable and a plug for connection to a convenience
outlet
NOTE:
Standard ratings for these transformers are 250 VA, 630 VA and 1600 VA.
3.
Hand torches shall be provided at all locations where operating personnel may be
present at all times, e.g. control rooms, fire station, watchman's offices, etc.
4.
The number of hand torches per location shall not be less than the number of
personnel present per shift.
5.
The equipment shall consist of fixed charging units with sockets and plug-in hand
torches suitable for Zone 1 use, and be provided with rechargeable batteries. Only
batteries that are certified for a particular torch shall be used.
6.
In areas with excessive dust, the torches shall also be suitable for Zone 21.
7.
Battery powered hand lamps shall be installed inside substations and switchhouses
near all entrances. For plant substations, they shall be suitable for Zone 1 use and
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 49
provided with wall-mounted bracket-type battery charger and, in manned locations,
undervoltage relay for emergency lighting duty.
4.10.6
Power and convenience outlets
4.10.6.1 General
1.
For maintenance purposes, three phase and neutral power outlets for movable
equipment, and single phase and neutral convenience outlets for the supply of
portable tools and hand lamps, shall be provided.
2.
The number and location of outlets shall be based on the maintenance activity
expected in the area and input from the human factors engineering study.
3.
Convenience outlets for portable igniting equipment of boilers and furnaces shall be
provided in the vicinity of the burners.
4.
The outlets shall be standardised for each rating and type throughout the complex and
shall have an earth connection incorporated.
5.
The outlets shall comply with IEC 60309 or local standard. The use of local standard
material, however, requires the approval of the Principal.
6.
Plugs shall not be interchangeable with sockets of a different voltage or current rating,
nor shall it be possible to insert an industrial type of plug into a Zone 1 classified outlet.
7.
Each LV power and convenience outlet circuit shall be protected by phase short circuit
protective devices and by current-operated earth leakage protective devices, which are
in accordance with IEC 60947-2, i.e., residual current circuit breakers (RCCB).
8.
The RCCB operating current shall be 30 mA for circuits of less than 125 A and 300 mA
for circuits equal to or greater than 125 A.
4.10.6.2 Power and welding outlets
1.
Power outlets shall have a standard supply voltage equal to the LV supply voltage
selected for the complex. Power outlets in plants with a LV system of more than 500 V,
e.g. 690 V, shall have a voltage of 400/230 V.
2.
Power outlets shall be rated for at least 125 A and be suitable for outdoor installation.
3.
Power outlets shall be located in a safe area along the battery limits, spaced in such a
way that, with the aid of extension cables feeding movable secondary supply panels,
all points can be served conveniently.
4.
Power outlets shall be connected so as to have the same phase rotation, ensuring that
correct rotation of moveable equipment is obtained from all outlets.
4.10.6.3 Convenience outlets
4.10.7
1.
Convenience outlets shall have a standard supply voltage equal to the voltage
selected for normal lighting.
2.
For industrial areas, the outlets shall be rated for at least 16A and be suitable for
outdoor installation in Zone 1 areas.
3.
In workshops, the outlets shall be of industrial pattern, where specified.
Other electrical equipment
1.
Padlockable isolating devices shall be provided for equipment, such as trace heating
systems and, cathodic protection equipment. Isolating devices shall be located near
the equipment or on the appertaining control panels.
4.11
ELECTRIC HEATING EQUIPMENT
4.11.1
Process heaters
1.
Process heaters, with or without thyristor control, shall be in accordance with
DEP 33.68.30.33-Gen.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 50
4.11.2
2.
Feeders to the power and control assemblies of the heaters directly connected to the
LV system shall have two switching devices; one for control and the other for tripping.
3.
Instantaneous earth-fault-protection shall be provided, adjustable to a maximum of
100 mA in compliance with IEC 60079-14 section 7.4.
Heaters for frost heave prevention
1.
4.11.3
Heaters for frost heave prevention of LNG/LPG concrete tank bases shall be in
accordance with DEP 33.68.30.31-Gen.
Electrical trace heating
1.
Electrical trace heating systems shall comply with DEP 33.68.30.32-Gen.
2.
The following types of trace heating shall be used in order of preference:
a. self-regulating heaters;
b. constant wattage parallel heaters;
c. mineral insulated heaters (M.I. cable).
3.
For all-welded pipelines without flanges, a system of skin electric current tracing
(S.E.C.T.) heaters shall be evaluated. Alternatively, for high temperature applications
on long pipelines, impedance heating systems may be considered.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 51
5.
ENGINEERING AND INSTALLATION REQUIREMENTS
5.1
GENERAL
1.
For commissioning of
DEP 63.10.08.11-Gen.
electrical
equipment,
reference
is
also
made
to
2.
Where necessary, the Principal or the Contractor shall submit Manufacturers' test
reports, equipment certificates and site reports, etc., for approval by local authorities.
3.
Unless otherwise specified, the minimum ingress protection level for equipment in
plant areas shall be:
a. IP 54 for equipment installed outdoors (excluding jetties and offshore);
b. IP 41 for equipment installed indoors;
c. IP 2X for exposed parts of equipment that has to be accessible during normal
operation.
5.2
MAIN EQUIPMENT
5.2.1
General
5.2.2
5.2.3
1.
Equipment shall be installed in accordance with the installation instructions and
supporting drawings provided by the Manufacturer.
2.
Foundation drawings, together with information on mass and loading data, shall be
provided for all electrical equipment, to permit correct civil design of the relevant
buildings and foundations.
3.
In the case of switchboards comprising switchgear and/or controlgear from more than
one Manufacturer, one composite foundation drawing shall be supplied for the
complete switchboard.
4.
Equipment arrangement and layout drawings shall also be obtained from the
Manufacturer or supplier, so that they can be incorporated into overall plant
arrangement drawings, cabling design, etc.
5.
Any main equipment modifications required during installation shall be approved by the
Principal prior to implementation. All modifications shall be recorded and the
information incorporated in the 'as-built' drawings (7.1).
6.
Electrical equipment should be located so as to minimise the risk of damage due to
vibration. If such locations cannot be avoided, anti-vibration mountings shall be used
where practical.
7.
If pipes must be run adjacent to electrical equipment there should be no joints in the
immediate vicinity of the equipment.
8.
Electrical equipment shall be installed so that there is sufficient space, as defined by
Manufacturer, to facilitate maintenance requirements.
Generators
1.
Generators shall be installed in a non-hazardous area.
2.
Generators should be located close to their associated step-up transformers, if any, so
as to minimise the length of heavy current connections.
3.
The generator cooling system shall be independent of the acoustic enclosure
ventilation systems.
Transformers
1.
Oil-filled power transformers shall be installed outdoors in a fenced-in area of the
substation. The fences shall have at least two lockable gates, when more than one
transformer is installed.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 52
2.
Each transformer shall have a minimum of 1 m clear space all round; For transformers
with liquid volume of more than 1000 litres, the separation distance between
transformers shall be in accordance with IEC 61936-1, clause 8.7.2.1 – Table 3. Fire
or blast walls are not required for HV/LV transformers.
3.
If it is not practical or economic to allow for adequate clearance as indicated in
Table 3, then a fire-resistant separating wall with specification and dimensions
complying with IEC 61936-1, clause 8.7.2.1 and Figure 6 shall be installed.
4.
For main intake substations with HV/HV transformers and for transformers 100 MVA
and above, a fire-resistant separating wall with specification and dimensions complying
with IEC 61936-1, clause 8.7.2.1 and Figure 6 shall be installed.
5.
Transformers should be installed so that the cable boxes of adjacent units do not face
each other. Refer to Standard Drawing S 68.040.
6.
Transformers shall be mounted on a flat concrete base.
7.
Non-sealed type transformers shall be surrounded by a gravel-filled or gravel-covered
oil catchment pit, which is sized to contain the total oil content of the largest
transformer plus rain water. The catchment pit should be:
a. connected to the oily water drains system in a wet climate;
b. arranged for pumping out by a suction tanker in a dry climate;
c. connected to the storm water drains system through an oil/water separator, as
determined by the Principal.
8.
Holding down and/or grouting of transformers is not required.
9.
Transformers should be positioned and oriented in such a way as to minimise cable
crossings, especially when multiple single-core cables are required.
10. If a dry-type transformer does not have an integral metal enclosure, it shall be installed
within an earthed, demountable metal barrier or fence of at least 1.8 m high on all
sides. The fence shall have warning signs and a lockable personnel access gate with
1 m clearance from the extremities of the transformer and its cable terminations to
allow safe access for visual inspection of the live transformer.
11. Due account should be taken of the magnetic field surrounding the transformer in the
positioning of any sensitive electronic equipment and the designing of any adjacent
metallic building structures. If necessary, a magnetic flux plot should be obtained from
the Manufacturer.
5.2.4
5.2.5
Switchgear
1.
Switchgear shall only be installed when the switchroom civil and building works are
complete, so as to minimise the ingress of dust and dirt during or after erection.
2.
Switchgear foundations, including any inserts to be cast in, shall be in accordance with
the Manufacturer's drawings and within specified tolerances.
3.
Substation floors shall be smooth and level to permit the handling of equipment on
rollers, regardless of whether crane facilities are provided.
4.
Concrete floors shall have a surface protection layer to avoid formation of dust.
Electric motors
1.
Whilst in outdoor storage and depending on the period of storage before
commissioning, motors shall be provided with initial and thereafter periodic
preservation procedures in accordance with the Manufacturer's instructions.
a. As a minimum, preservation procedures shall include proper sealing of the motor
shaft and cable entries, turning of shafts and, for HV motors, the energisation of
the anti-condensation heaters.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 53
2.
The location of the motor RCU and/or safety switch should be on the opposite side
from the terminal box and not be further away from the motor than 1.5 m. The operator
should be able to see the ammeter (if installed) when operating the (discharge) valve.
3.
Noise hoods shall in no way obstruct the free flow of cooling air to the motor or the
motor heat exchanger.
4.
Where required, shim plates should be of non-magnetic material. Dowel pins may be
installed to facilitate reinstallation after maintenance or repair.
5.3
CABLING AND WIRING
5.3.1
General
5.3.1.1
General
1.
In the DEFINE phase of the area plot plan development, reservation of appropriate
routings and adequate space for underground and/or above-ground cable installations
shall be made in cooperation with the other engineering disciplines concerned.
2.
A dimensional cable routing plan shall be made (7.4.2.6).
3.
When requisitions for cables and wires are prepared, the total measured length
required in accordance with the layouts and drawings, for each type and size, should
be increased by 5 % of the total for each type and size, to allow for slack, jointing and
termination.
4.
For new plant construction, joints in cabling shall only be permitted where the route
length exceeds commercially available cable drum lengths. Teed cable joints shall not
be used. Cable joints shall be recorded and their locations marked accurately on the
'as-built' drawings.
5.
During transport, storage, and installation, cable ends of all types of cable shall be
suitably sealed to avoid ingress of water.
6.
Changes of direction in cable trenches and on racks or trays shall cater for the
minimum cable bending radii advised by the manufacturer; otherwise as follows
(where D is the overall diameter of the cable):
a. cables LV (armoured)
All
8D
b. cables HV
Single core
20 D
Multi-core
12 D
7.
For special types of cable construction and for cables rated at voltages above 36 kV,
refer to the Manufacturer for minimum installation bending radii.
8.
At the end of hard-floored cable trenches, short ducts or pipes shall slope down into
the surrounding soil, to avoid cable damage at the edges owing to settling of the soil.
9.
Cables should enter buildings above ground level, but where they have to enter below
ground level, a watertight seal shall be provided, e.g. multi-cable transit blocks.
Bonding of all incoming cables at this point shall comply with the EMC mitigation
measures specified in DEP 33.64.10.33-Gen.
10. The installation of cables for vital equipment, e.g. life support equipment, requires
special attention in order that possible damage to these cables is minimised.
11. Instrument, telecommunication and computer/data cables shall be laid in trenches or
on trays separated from those used for HV and or LV cables. For further instructions,
refer to DEP 32.37.20.10-Gen.
12. Open pipe trenches shall be crossed by cable bridges and installed in accordance with
(5.3.3) or be constructed from reinforced concrete.
13. Where cable trenches cross roads, an additional number of pipes (ducts), e.g. 20%,
minimum 1, at normal cable laying depth, shall be provided to accommodate future
cables.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 54
14. Detailed cross-sectional drawings shall be prepared (7.4.2.6).
15. The armouring and lead sheath, if any, of multicore cables shall be solidly bonded at
both ends. Details of bonding, e.g. the location, type and length of the bonding
conductor, are specified in DEP 33.64.10.33-Gen.
5.3.1.2
Single core cables
1.
Single-core cables of one three phase circuit shall be laid together and separated from
multicore cables. They should be laid in trefoil formation, rather than laid flat (5.3.3.1),
except in the case of short cable runs, e.g. transformer secondary cables within
substations. Refer to Standard Drawing S 68.022.
2.
The lead sheath or the copper earth screen of single-core cables should normally be
solidly bonded at both ends, see (6) below.
3.
The bonding clamps shall be of a type that maintains the required pressure, i.e. spring
loaded, to cater for possible movement or shrinkage of the cable.
NOTE:
In solidly bonded single-core cables, the current flowing in the lead sheath and/or screen causes
additional heating, which results in a de-rating of the cable in comparison with single point
bonded or cross-bonded installations. This is normally taken into account in the rating factors
given by the cable Manufacturer. The use or non-use of armouring on single core HV cables is
covered in (4.8.2)
4.
For single point bonded installations, the bond should be at the substation end of the
circuit unless required to be at the field end for other reasons e.g., to retain Ex
equipment certification. In this case, insulated cable glands shall be provided at the
switchboard termination and additional measures taken to retain electromagnetic
compatibility.
5.
Standing voltages on the armouring, if applied, at the insulated glands shall not
exceed:
a. 60 V under conditions of rated full load current, nor;
b. 430 V under conditions of maximum short circuit current.
6.
Where the standing voltage limits specified above can be exceeded, the armouring,
lead sheath or screen shall be cross-bonded. This alternative should only be
considered for circuit lengths exceeding approximately 500 m.
7.
For single point bonded installations, high frequency phenomena like lightning-induced
transient voltages shall also be taken into account.
8.
For EMC mitigation measures related to single-core cable installation, refer to
DEP 33.64.10.33-Gen.
5.3.2
Sizing of cables
5.3.2.1
General considerations
1.
5.3.2.2
Cable sizing shall include the maximum cable loop impedance for earth faults in
accordance with (3.8.3).
Short circuit current rating
1.
The short circuit rating of cables shall be determined in accordance with:
a. the rated short circuit breaking current of the source switchboard also taking into
account the short circuit limiting characteristics of, e.g. fuses;
b. the fault clearance time associated with the operation of the primary, i.e., not backup protection.
5.3.2.3
Voltage drop
1.
The voltage drop in AC cables shall not be more than 5 % based on continuous
maximum current loading and rated voltage.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 55
2.
Moreover, during starting or re-acceleration, the voltage dip at the terminals of any
motor shall not be more than 20 % of the rated equipment voltage.
NOTE:
3.
5.3.2.4
The voltage drops stated above relate to the total voltage drop up to the terminals of the end
user equipment, and assume that the associated main switchboard from which that equipment is
controlled will normally be operated at nominal voltage (3.3.2).
The voltage drop in DC cables shall be consistent with the minimum system voltage at
the switchboard the minimum equipment operating voltage, but should not exceed 5 %
in any case.
Current rating
1.
Current ratings and rating factors for cables shall be calculated in accordance with the
cable Manufacturer's declared current ratings, rating factors derived from the laying
pattern, and local environmental conditions. De-rating factors are given in the
IEC 60502-2 Appendix B for onshore applications and IEC standard 61892-4 for
mobile and fixed offshore units. Reference is also made to ERA report 69-0030.
2.
De-rating factors shall be defined for a) depth of laying, b) ground/ambient
temperature, c) soil thermal resistivity, and d) grouping of cables with an assumed load
factor of 100%.
3.
In the absence of specific site environment data, typical factors given in IEC 60502-2
(by country) may be used.
4.
In sizing plant cables, the maximum sustained nameplate rating of the equipment shall
be taken. For distribution cables current loadings in accordance with (3.5) shall be
applied.
5.
A positive tolerance of 5 % to 10 % may be allowed on the overall rating factor
because:
a. cable sizes are selected as the next larger standard size;
b. not all motors are fully loaded at the same time;
c. spare units are installed.
6.
Where different overall rating factors apply to different parts of a route, the lowest
factor shall be applied.
7.
For plant cabling, complying with the preferred installation methods in (5.3.3.2) or
(5.3.4.2), the worst case overall de-rating factor shall not be lower than:
8.
Climate as defined
in IEC 60287-3-1
Direct buried
de-rating factor
In air
de-rating factor
Tropical
0.40
0.60
Temperate
0.60
0.80
If the initially calculated overall de-rating factor is worse the values above, the cable
route design shall be amended so that the value is higher than the minimum
acceptable values given above.
NOTE:
An overall de-rating factor worse than above would be considered an inefficient design resulting
in unnecessarily large cables.
5.3.3
Underground cabling
5.3.3.1
General
1.
All cables shall follow a direct and logical route without infringing on the battery limits
of unrelated plants and facilities.
2.
General distribution cables shall run alongside the roads, and not through plant areas.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 56
5.3.3.2
3.
Through cables, which are not related to a particular plant or tank farm, shall be routed
around such installations.
4.
Plant cables shall run in either of the two directions formed by the main axes of the
plant, avoiding as much as possible crossings with instrument cable trenches and
pipelines, and preferably away from heavy-load-bearing restricted areas, e.g.
transformer bays.
5.
Furthermore, underground cable routes shall be designed to avoid close pipe
crossings and adjacent runs with underground pipelines so that a clear distance of at
least 300 mm between cable and pipe (including insulation) is maintained.
6.
Cables should cross underneath buried pipelines except where the depth measured at
the top of the pipeline is more than 1 metre.
7.
If close crossings with underground pipelines carrying hot liquids or gases, or which
are regularly steam-cleaned, cannot be avoided, the pipeline shall be insulated in
order to limit its outside temperature to a maximum of 60 °C, and the clear distance
increased to 600 mm. In such cases cables may need to be run above pipelines in a
sand-filled concrete bridge (5.3.1).
8.
Cable crossings shall be made either in the cable area directly under the
corresponding switchgear panel or at the branching-off point of the particular cable
from the main trench.
9.
Single-core cables, when laid in trefoil formation, shall be braced by preformed nonmagnetic clamps or ties and laid in their own individual trench with a minimum
separation of 600 mm from other cables.
Laying pattern
1.
As a standard, load-carrying cables shall be laid in a single layer formation, and may
only be laid in a double layer with the approval of the Principal. Cables to spare drives
shall also be regarded as load-carrying.
2.
Non-load-carrying cables should be installed either as an additional layer on top of the
load-carrying cables or as a block adjacent to the load-carrying cables.
NOTE:
5.3.3.3
Load-carrying cables are those which may be expected to carry a continuous load during
operation. Non-load-carrying cables are for instance MOV power supply cables, welding
switchgear feeder cables and combined motor power/control cables of 2.5 mm2.
3.
HV cables may be laid in the same trench with LV cables. HV distribution cables shall
be separated from LV cabling, e.g. by means of a continuous row of cable tiles placed
vertically between the two cable types, by any other suitable barrier or by a clear
space of at least 600 mm.
4.
In plant areas, the associated control cable may be installed in the space between the
power cables. Typical arrangements for a number of formations are shown in Standard
Drawing S 68.009.
5.
Specific measures shall be taken to ensure required separation of cables is maintained
in the vicinity of substations and at other areas of congestion. These measures can
include additional layering, splitting of cables using above ground cable trays, etc.
Cable trenches
1.
Cables shall be buried directly in the ground, whenever possible, i.e., not in preformed
trenches or pipes.
2.
Cable trenches in unpaved, brick-paved or tiled areas and crossing roads shall be in
accordance with Standard Drawing S 19.002.
3.
The cables shall be laid on and covered by a clean sandfill, free from stones, duly
compacted and protected by protection tiles (e.g. purpose-made PVC cable protection
tiles with caution warning). The top finish over the protection tiles may be in
accordance with the surrounding area.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 57
4.
Cable trenches in concrete paved areas shall be in accordance with Standard Drawing
S 19.001. Cable trenches wider than 1 m shall be permanently covered by heavy-duty
or light-duty paving compatible with the surrounding pavement, but coloured red.
NOTE:
Trenches for instrumentation cables have a green coloured paving.
5.
If permanently covered cable trenches are used, sandfilled dummy trenches normally
600 mm, but maximum 1 m, wide should be provided for future cabling. These shall be
covered with a red-coloured concrete top.
6.
All cable trenches covered by concrete shall be completely filled with clean sand and
compacted. No protection tiles need be installed.
7.
Trenches with solid concrete floors shall not be used except when unavoidable, e.g.
cable bridges, etc.
8.
Except for short lengths near the termination points of the cables in the plant area,
underground cable pipes (ducts) should be avoided, since relatively long pipes and
ducts will affect the cable current rating unfavourably.
9.
For cables rated for direct burial, further derating is unnecessary for part installation in
pipes, e.g. at road crossings, provided the pipe length does not exceed 7 m. If longer
runs are necessary, then the cable shall be rated for installation in pipes.
10. In order to facilitate cable laying before the concrete paving is finished, the expansion
seams in concrete floors should be located on either side of the cable trenches. The
location of sleeves at termination points of cables shall be indicated on the civil
drawings.
11. HV cables shall be terminated directly in the equipment terminal box.
12. LV and auxiliary cables shall be terminated directly in the equipment terminal box,
except that Ex'e' junction boxes may be installed between the underground and aboveground cables under the following circumstances:
a. to provide a smooth construction interface, i.e., avoiding long coiled ends of
underground cabling awaiting above-ground installation;
b. to reduce the cross-sectional area of that part of the cable route installed above
ground, when the underground cable is significantly derated, i.e., below the overall
rating factors given as a guidance in (5.3.2.4);
c. to facilitate the replacement of the final cable connection to the equipment terminal
box, if frequent disconnection is required or expected;
d. to provide for expected settlement of the ground.
13. In order to protect against lightning-induced currents, in all cable trenches at least one
separate earthing wire, also referred to as Parallel Earthing Conductor (PEC), shall be
installed. For more details refer to DEP 33.64.10.33-Gen.
5.3.4
Above-ground cabling
5.3.4.1
General
1.
Above-ground cables shall be supported by cable racks, trays or cable ladders all the
way up to their terminations.
2.
The cable racks, trays or ladders shall be bonded to the metallic equipment
enclosures, junction boxes or structures where the cables are terminated.
3.
Individual cables may be fixed directly to the main structures, walls, ceilings or
columns by means of proper fixing and supporting materials. A maximum of two cables
may be so installed along a common route.
4.
Plastic cable ties (also known as tie-wraps) should not be used as permanent fixings.
Metallic cable ties should be used, suitably protected against UV radiation and
corrosion, if required e.g., coated stainless steel metallic cable ties used on galvanised
steel cable trays.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 58
5.
5.3.4.2
5.3.4.3
All conduit and cable entries into outdoor equipment shall be from the bottom or side.
Laying pattern
1.
Multicore cables on racks or trays may be bunched in a maximum of two layers.
2.
HV and LV single-core cables shall be laid in trefoil groups with 150 mm clear spacing
between trefoils.
3.
On trays or racks HV cables shall be segregated from the LV cables.
4.
Individual cables emerging from floors or soil shall be protected against mechanical
damage by means of galvanised steel pipes or rigid PVC pipes. Single-core cables
emerging from floors or soil shall be protected by rigid PVC pipes that extend at least
100 mm above ground or floor level.
5.
Grouped cables emerging from floors or soil shall be protected collectively by a
properly designed metal shield or duct in such a way that heat dissipation from the
sustained load-carrying cables is not hampered.
6.
The propagation of fire from one space to the other shall be prevented by the proper
sealing of openings around cables.
7.
To avoid oil or chemicals leaking into the cable trench, the above-mentioned cable
protection shall be sealed at the top around the cable(s) with a suitable sealing
compound.
8.
Cables or cable supports shall not be fixed directly or indirectly to plant, equipment or
process piping which may require routine removal or replacement.
9.
Cables shall be laid on racks or trays strictly in accordance with the laying patterns
stated on the layout drawings. Metal parts of the cable racks and trays shall be bonded
and connected to the common earthing grid.
Cable support structures
1.
All cabling support materials, e.g. ladders, trays and relevant fixing materials, used
throughout the plant shall be hot-dip galvanised to ISO 1461 unless the environment is
so saliferous or sulphurous as to justify the use of materials offering a higher degree of
corrosion resistance. In the latter case, specific plants or areas shall utilise stainless
steel (grade 304).
2.
For offshore installations stainless steel (grade 316) is preferred. However, if approved
by the Principal, non-metallic materials may be used offshore if the installation is in
accordance with EMC requirements stated in DEP 33.64.10.33-Gen., Section 5.8 with
a minimum 0.5 m segregation between different EM (Electromagnetic) levels.
3.
The following are minimum requirements for non-metallic cable support materials in
offshore facilities:
a. Ultra Violet (UV) protection coating of 25 µm (1 mil) applied to the entire surface.
UV resistance in accordance with ASTM D2565
b. Anti static properties, tested in accordance with IEC 61340-2-1
c.
Fire performance to ASTM E84 Class 1, Rating < 25
d. Self extinguishing to ASTM D635 Appendix XI
e. Chemical resistance when subjected to spills, splashes or fumes of chemicals
specified for the area as verified by testing to ASTM C581
4.
Bends and corners in the cable racks, trays or ladders shall take account of the
minimum cable bending radii (5.3.1).
5.
Cable racks and trays shall be closed by removable top covers, allowing adequate
ventilation, in situations where:
a. mechanical damage of the cables is likely to occur during plant maintenance
activities,
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 59
b. oil or chemical spillages on the trays can be expected,
c. shielding is required against direct solar radiation,
d. protection is required for the effects of lightning, particularly in areas with a high
lightning intensity.
5.3.5
6.
Vertical cable rack risers shall not be installed in front of, or over, pipe risers.
7.
For specific requirement related to EMC and in particular bonding and segregation
aspects, refer to DEP 33.64.10.33-Gen.
Flexible cabling
1.
The use of flexible cables in industrial plants and installations shall be limited to:
a. welding cables;
b. trailing cables, e.g. for movable equipment, hand tools, hand lamps;
c. winches, hoists, soot blowers, and electric motors, if connected by means of a
nearby intermediate junction box;
d. submerged pumps
e. battery cabling between cells and to the battery bank isolation point.
2.
5.3.6
5.3.7
An earth continuity conductor, equal in cross-sectional area to the largest phase
conductor, shall be provided. This requirement applies even when the cable is
armoured.
Wires in conduit
1.
Wires in conduit systems shall be used only for lighting, communication and
convenience outlets in closed buildings in non-hazardous areas.
2.
Conduit installations should be made with rigid PVC conduit and non-metallic conduit
boxes.
3.
Conduit box covers should remain accessible. Where local regulations permit,
unarmoured round installation cable may be used in cable ducts.
4.
Tee or straight-through joints should be made in connection boxes.
Cable marking/numbering
1.
Cable numbers shall be marked on the cables along their routes and at both
termination points. For underground cabling, the spacing between cable numbers
along the route should not exceed 10 m, and for above-ground cabling, 25 m.
2.
Cable numbers shall be marked on the cables along at both termination points, at
entry to MCTs and where required to aid construction.
3.
Cables shall also be numbered where they branch off from a main route and at both
sides of a road crossing.
4.
For underground cable marking purposes non-corroding strips shall be used, each
having ample length to be wrapped twice around the cable and in which the cable
number has been imprinted by means of letter/cipher punches.
5.
For above-ground cabling, plastic markers resistant to the site conditions shall be
strapped round the cables.
6.
Cable numbering shall be in accordance with (7.5) and (Appendix 5).
7.
For underground cabling, above-ground route markers shall also be provided at every
change of direction in the routing and at both sides of road or pipeline crossings,
except when cable routing is already indicated by coloured concrete pavement.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 60
5.4
LIGHTING AND SMALL POWER INSTALLATIONS
5.4.1
Plant lighting
1.
Plant lighting circuits shall be fed from dedicated lighting distribution switchboards
installed in the plant substations.
2.
Plant lighting circuits shall be single phase and neutral or three phase and neutral, and
should be protected with maximum 16 A fuses or MCBs, but not be loaded higher than
12 A.
3.
Plant lighting distribution switchboards shall include 10 % spare outgoing circuits.
4.
The lighting switchboard and its control circuits shall be arranged as shown in
Standard Drawing S 67.022.
5.
Adjacent luminaires shall, as far as practical, not be supplied from the same circuit, or
in the case of three phase circuits, from the same phase.
6.
Lighting installations shall be designed to obviate stroboscopic effects.
7.
Luminaires on structures shall be located so that maintenance and lamp changing can
be done without the use of ladders or scaffolding.
8.
Where a luminaire mounted from an elevated walkway or platform does not overhang
it, the lamp post shall be arranged to swivel for maintenance purposes.
9.
In tall buildings, such as compressor and turbo-generator houses, maintenance and
lamp-changing by means of the overhead crane shall be possible.
10. Where no structure is available to support luminaires, fixed lighting poles of adequate
length with high pressure discharge floodlighting shall be used to supplement the
fluorescent luminaires.
2
11. Lighting poles shall be hot-dip galvanised to a minimum of 275 g / m .
12. Luminaires shall generally be mounted as shown in Standard Drawing S 69.001 or
S 69.003, as appropriate.
NOTE:
For fixed floodlighting columns, lamps are changed with the aid of a mobile platform, e.g. vehicle
mounted. Alternatively, hinged lighting columns may be used, if space is available for the
columns to be lowered.
13. Outdoor lighting circuits shall be designed for automatic switching via photo-electric
relays. Control circuits for photo-electric relays shall be 'fail-safe', i.e., to switch the
lights on if a fault occurs in the photo-electric relay.
14. The plant lighting shall be designed in such a way that in daytime the lighting of
furnaces, boilers and the ground level plant can be switched on by means of a switch
overriding the appropriate photo-electric relay contact.
15. The remaining photo-electric relay-operated plant lighting shall be able to be switched
off at night-time. These override switches shall be located either outside the plant
substation or in the control room, as required by plant operations.
16. Moreover, the lighting switchboard shall be provided with an override switch for
maintenance purposes.
17. Level gauge lights shall normally be on, not be switched by photo-electric relays and
with no maintenance override switches.
18. Internal lighting of non-process buildings and substations shall be switched inside the
building.
19. Lighting near navigational waters, e.g. jetties and loading platforms, shall not hinder
navigation in any way.
20. The lighting installation in the control rooms shall be designed so that ceiling lighting
groups can be switched off independently to suit operators' needs.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 61
21. Electronic dimmer control shall be provided to adjust the illumination level smoothly
down to 40 % of the specified illumination.
22. The luminaires shall be situated in such a way that reflection on VDUs, instrument
windows and displays is avoided.
5.4.2
Emergency and escape lighting
1.
Fixed emergency lighting shall be installed at strategic points, including control rooms,
switchrooms, fire stations, first-aid rooms, watchmen's offices, the main entrances, and
all other buildings and areas where required for safety reasons.
2.
Location and electrical arrangement shall be such that danger to personnel in the
event of a power failure is prevented, and escape routes are lit.
3.
The emergency lighting system shall consist of a number of standard luminaires of the
normal lighting installation, fed via circuits having a stand-by supply from an
emergency generator or from an inverter having a battery with an autonomy time given
in (3.9.4). In remote areas, where only a few fittings are required, self-powered
emergency luminaires may be used, subject to economic considerations.
4.
If power is supplied by an emergency generator, a number of luminaires in the control
room and the basement of the control room, as well as field auxiliary rooms, shall have
a stand-by supply from an independent source with battery back-up to avoid complete
darkness during start-up of the diesel engine.
5.
The number of emergency luminaires in relation to the total number of fittings shall be
determined as follows:
a. utility area
20 %
b. process area
10 %
c.
5.4.3
administrative area
5%
d. control room and auxiliary rooms including 10 %
connected to inverter system)
50 %
e. substations, field auxiliary rooms, compressor and
generator buildings
30 %
6.
Escape luminaires shall be provided in all buildings to light the way for personnel
leaving a location or building along defined escape routes to defined muster points,
which shall also be illuminated.
7.
The escape luminaires shall be part of the emergency installation, but in addition the
luminaires shall have integral batteries rated to maintain the lighting for at least 30 min
for onshore and 60 min for offshore installations.
Street and fence lighting
1.
Street and fence lighting shall be fed from lighting distribution switchboards installed in
a conveniently located plant substation. These lighting distribution switchboards may
either be dedicated to street and fence lighting, or be one or more sub-sections of a
plant lighting switchboard.
2.
This lighting shall be photo-electric relay controlled and provided with a maintenance
override switch, as for ground level plant lighting, in accordance with Standard
Drawing S 67.022.
3.
Generally, for street/fence lighting a three phase and neutral LV supply should be
used.
4.
Each lighting pole shall include a fuse box as well as a four-pole terminating box for
looping the feeder cable. Use of teed joints may be approved by the Principal for ease
of construction.
5.
Adjacent luminaires shall not be supplied from the same phase.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 62
6.
Fence lighting shall be placed in such a way that the fence as well as the area outside
the fence are illuminated, leaving the patrol road in comparative darkness.
7.
Normally fence lighting intensity shall be equivalent to the street lighting intensity
stated in (Appendix 4).
8.
If special security fence lighting is required, a floodlight installation shall be designed
based on high pressure discharge lighting with a minimum illumination of 5 lux at any
point in the area between the fence and 5 m outside the fence, unless otherwise
specified.
5.4.4
Special lighting
5.4.4.1
General
1.
5.4.4.2
5.4.4.3
5.4.5
Navigational aids for
DEP 33.80.00.30-Gen.
offshore
structures
shall
be
in
accordance
with
Aviation warning lighting
1.
Aviation warning lights shall be installed in accordance with Volume 1 Chapter 6 of
ICAO Annex 14.
2.
The luminaires shall each consist of a double lamp unit with automatic changeover to
the stand-by lamp upon failure of the operating lamp.
Illumination of areas to be observed by means of CCTV monitors
1.
The lighting installation for areas that require surveillance by closed circuit television
monitors shall be designed in particular with regard to uniformity of the level of
illumination as well as to the location of the individual luminaires.
2.
The direct visibility of light-emitting bodies and/or reflections from covers of the
luminaires shall be checked before commissioning of the plant.
Power and convenience outlet
1.
Power and convenience outlets should be supplied from the lighting switchboard in the
plant substation.
2.
The circuits shall be manually controlled with RCDs, as shown in Standard Drawing
S 67.022.
3.
Power and convenience outlets shall be mounted approximately 1 m above grade
level, either on a free-standing support, on structural steelwork or on a building wall.
5.5
EARTHING AND BONDING
5.5.1
General
1.
A single integrated earthing system shall be installed, in compliance with
DEP 33.64.10.33-Gen., to reduce and control voltages to an acceptably low level for:
a. electrical safety, i.e., to reduce touch and step voltage in case of earth faults;
b. lightning and static electricity protection (prevention of fire and dangerous touch
voltage);
c. intrinsic safety (avoiding ignition sources in hazardous areas);
d. EMC (reducing disturbing voltages at the terminals of electronic equipment).
5.5.2
Earthing requirements for substations, switchrooms and control rooms
1.
5.5.3
For the earthing facilities to be provided in substations and switchrooms, refer to
drawing S 68.030.
Earthing of plant equipment and structures
1.
The metallic enclosures of electrical equipment SHALL [PS] be bonded to the plant
earth grid.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 63
2.
The metallic enclosures of non-electrical equipment, e.g. vessels, shall also be bonded
to the plant earth grid or be provided with their own duplicate earth electrodes; in the
latter case, the combined resistance to the general mass of earth shall not exceed
10 Ω.
3.
Plant earth grid conductors shall have a cross-sectional area of 70 mm².
4.
The cross-sectional area of branch conductors connecting equipment and structures to
the plant earth grid shall be in accordance with DEP 33.64.10.33-Gen., Section 3.2.4
and Section 3.5.
NOTE:
5.
5.5.4
5.5.5
The armouring of the cable shall not be used as the sole means of providing earth
continuity.
Lightning and static electricity
1.
Lightning protection systems shall be installed if required in accordance with local
regulations.
2.
In the absence of such regulations, the need for lightning protection shall be
determined, and the system designed and installed in accordance with IEC 62305, as
supplemented by DEP 33.64.10.33-Gen.
3.
The mitigation and avoidance of the hazards created by the effects of static electricity
shall be in accordance with DEP 80.64.10.11-Gen.
Electronic equipment
1.
5.5.6
The earthing grid conductors, comprising the plant earth grid conductors and the branch
conductors, are supplementary to the protective earth conductor or the metallic sheath and/or
armouring of the electrical equipment supply cable(s).
Earthing arrangements for computer systems and instrumentation and process control
systems (DCS) shall follow DEP 33.64.10.33-Gen.
Electromagnetic compatibility (EMC)
1.
EMC aspects should be an integral part of the electrical engineering and installation
requirements.
2.
The Contractor shall prepare, present and implement an EMC management plan,
describing the specific EMC requirements during the engineering, procurement,
construction and commissioning phase of the project.
3.
The EMC plan should also address any interfacing between new and existing facilities.
4.
Measures to achieve
DEP 33.64.10.33-Gen.
EMC
should
be
chosen
in
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
accordance
with
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 64
6.
DESIGN AND ENGINEERING REQUIREMENTS FOR PARTICULAR INSTALLATIONS
6.1
SUBSTATIONS
6.1.1
General
1.
The substations should be located near the centre of the load they are required to
supply.
2.
These substations should also be located so that interference between HV/LV cables,
instrument cables and other services, e.g. pipelines, is minimised.
3.
In exceptional cases, e.g. in view of restricted space on offshore platforms, electrical
substations may be located in a hazardous area classified as Zone 2, subject to
approval by the Principal. The following requirements shall then apply:
a. The interior of the building to be pressurised in accordance with IEC 60079-13;
b. An overpressure of at least 50 Pa (0.5 mbar) to be maintained by a duplicate fan
system with a suitable dry element dust filtering system to ensure a supply of
clean air, each fan system being capable of supplying the required pressure;
c. The fan systems to be suitable for a Zone 1 area and to be supplied from two
independent sources of electricity;
d. Both fans to be normally in operation and to have individual alarms to indicate
failure in a manned control centre.
6.1.2
4.
If substations form part of an overhead line distribution system, and depending on the
location of the substation, available space and local pollution, outdoor switchgear
installations may be considered.
5.
The most demanding local environmental and climatic conditions shall be adopted for
specifying the equipment.
6.
In all other cases, for reasons of reliability and serviceability the electrical switchgear
installations shall be located indoors in dedicated and, if need be, heated and/or airconditioned buildings.
7.
The locks on access gates or doors of substations shall be of a special series, different
from locks used for non-electrical buildings, premises or yards.
8.
Each substation, and each building (or part of a building) in which electrical equipment
is installed, shall be numbered in accordance with (7.5) and (Appendix 5).
Outdoor substations
1.
HV outdoor open terminal switchgear installations shall be designed to IEC 61936-1,
with unrestricted walking access to the whole site.
2.
Open terminal outdoor substations shall be sited at least 15 m from process unit
battery limits or from the defined perimeter of non-hazardous area classification,
whichever is the greater.
3.
The location should be selected so as to provide adequate access for maintenance,
i.e., roads/tracks for personnel access and the removal of large equipment items.
4.
The insulation of all components shall be fully co-ordinated in accordance with
IEC 60071.
5.
The insulation class and creepage distances of insulators shall be selected in
accordance with the expected pollution and the likelihood of reduced maintenance.
Unless otherwise specified, a minimum creepage distance of 40 mm/kV shall be
applied for insulators.
NOTE:
6.
For further guidance, refer to IEC 60815 and, if necessary, consult with the local public utility.
Busbars and the connections to the equipment shall be made of copper or aluminium
tubes, with bi-metallic connectors used at joints between dissimilar metals.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 65
7.
Equipment support structures and line portals shall be of hot-dip galvanised steel, with
integral climbing facilities for cleaning and repair purposes.
8.
A 2.4 m high, unclimbable perimeter fence with (pad)lockable access gates shall be
provided, but no internal fencing, e.g. around transformers, is required, provided the
ground and safety clearances stated in the above-mentioned standards are satisfied.
9.
Third parties, e.g. Supply Authority / Utility company personnel, shall be able to access
the substation without entering the process facilities.
10. Control and auxiliary cables shall be installed in hard-covered, pre-cast concrete cable
trenches, the top of which shall be above the surrounding ground (gravel) level. The
trenches shall be well drained and not sand-filled.
11. The substation neutral system earth(s) and all metal supporting structures and
equipment shall be earthed to the substation earthing system.
12. The perimeter fence shall be earthed so as to avoid the danger of touch and
transferred voltage, per the guidance of IEEE 80.
13. If lightning protection is required in accordance with (5.5.4), protection against direct
lightning strikes shall be provided by means of overhead earth wires and/or lightning
rods attached to substation structures.
14. The substation equipment shall be protected against lightning and switching
overvoltages by lightning arresters.
15. Control, protection and auxiliary power supply equipment associated with outdoor
switchgear shall be installed in a building complying with the relevant requirements of
(6.1.3). This substation building, if suitably sub-divided, may also accommodate other
switchgear and controlgear at lower voltages.
6.1.3
Indoor substations, switchrooms and battery rooms
6.1.3.1
Switchrooms in indoor substations
1.
Onshore, indoor substations shall be single storey buildings with a general layout and
construction
in
accordance
with
Standard
Drawing
S 68.040
and
DEP 34.17.00.32-Gen.
2.
HV switchgear at voltages above 52 kV shall be located in a separate room.
3.
An equipment access door shall lead directly to the outside from each switchroom;
internal personnel doors may connect adjacent rooms. All access doors shall be fitted
with internal panic bolts for emergency exit.
4.
There shall be at least space for two additional panels for future extension at each end
of each switchboard.
5.
Floors shall be smooth and level to permit the handling of equipment on rollers,
regardless of whether craneage is provided.
6.
Where ‘computer floors’ are installed, the electrical equipment, e.g. switchboards,
control panels, etc., shall be installed on free standing steel structures of sufficient
stability.
7.
If electrical equipment is installed on the roof of the substation, e.g. air-conditioning
compressor/condensers, a cage ladder shall be provided leading from an entrance
platform to the roof. Where required, measures, e.g. barriers and/or fencing, shall be
taken to eliminate the risk of falls.
8.
In the cable vault underneath the substation, cable tray/racks shall be installed for all
cables to the LV switchgear and for all interconnecting auxiliary cables between
switchgear, panels, etc. For the power cables to the HV switchgear vertical cable
supports should be installed.
9.
All cable entry holes in the substation floor or walls shall be suitably sealed. Where
such cable entry holes are required to be gas tight and/or fire resistant, multi-cable
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 66
transits blocks shall be installed, or silicone foam, weak-mix concrete (in floors only) or
a chemical compound with subliming heat resistant and fire retardant properties may
be used.
10. Instrumentation and control system interface panels should be located in the same
switchroom as the associated switchboard.
11. Substation lighting and small power installations shall comply with (4.10) and (5.5).
12. To provide the required environmental conditions in which electrical equipment is to
operate in accordance with the DEP requirements and the IEC recommendations,
electrical substations and switchhouses shall be complete with heating, ventilation
and/or air-conditioning installations in accordance with DEP 31.76.10.10-Gen.
13. If air conditioning is provided to cool and dry the substation air, provision shall be
made to avoid warm, humid, outside air making direct contact with electrical
equipment, causing condensation.
14. A smoke detection system comprising of point detectors or beam detector(s) shall be
installed in substations. A common alarm shall be routed from each substation direct to
the plant's central fire and gas alarm system, i.e., independently of the substation
alarm annunciator.
15. The requirement for a Very Early Smoke Detection and Alarm system shall be
considered in the DEFINE phase of the project for main intake or main power
generation switchboards of air-insulated switchgear.
16. One hand-held extinguisher shall be provided near each door.
17. No fixed or automatic firefighting facilities shall be provided.
6.1.3.2
Specific requirements for switchrooms with SF6 Gas Insulated Switchgear (GIS)
6.1.3.2.1
SF6 gas concentration
1.
6.1.3.2.2
Reference is made to IEC 61634 that gives the following maximum SF6 gas
concentration in the swtchroom:
a. Leakage under normal service conditions
:
200 ppm
b. To allow restorative work after a fault
:
20 ppm
GIS at voltages up to and including 52 kV
1.
For GIS systems at voltages up to and including 52 kV, loss of pressure detection in all
the individual compartments may be used to indicate loss of SF6 Gas.
2.
When a loss of pressure is detected, an alarm display, e.g. flashing light, at the outside
of the switchroom near the entrance doors shall be activated.
3.
Inside the switchroom an audible alarm shall be activated and a common alarm raised
in a manned control room.
4.
Warning plates shall be provided at the outside of the switchroom, instructing people
not to enter without personal protection when the alarm display is on.
5.
The switchroom shall then be ventilated prior to restorative work. The installation of a
forced ventilation and exhaust system is not normally necessary.
6.
Where GIS is installed in rooms that have a small volume relative to the volume of the
GIS, calculations as specified in IEC 61634 shall be done to prove that the
concentration of SF6 is below the threshold in case of a leakage in one of the
compartments.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 67
6.1.3.2.3
6.1.3.3
GIS at voltages higher than 52 kV
1.
For GIS at voltages higher than 52 kV, the equipment room shall have a gas detection
and alarm system which shall provide for audible alarm inside and an alarm display at
the outside near the entrance doors, and a remote alarm in a manned control room.
2.
An extraction system shall be installed which shall automatically be switched on in the
event of a gas release.
3.
The inlet shall be at floor level, and the exhaust shall be directed to the outside of the
building at a location where the gas will be quickly diluted with air.
4.
The extraction system shall be capable of operating when the GIS is de-energised.
5.
Warning plates shall be provided at the outside of the building, instructing people not
to enter without personal protection when the alarm display is on.
6.
For GIS installations at voltages higher than 52 kV, all related auxiliary equipment, e.g.
protection and control systems, should be installed in a separate room.
Switchgear in plant rooms
In this context, a plant room is a room in a building other than a substation, e.g., an
administration building, workshop, etc., which contains service plant and equipment for
that building, e.g., HVAC plant.
1.
In general, only LV switchboards and, where required, associated indoor transformers
shall be installed in these rooms in accordance with (6.1.3.1), but subject to the
following additional requirements.
a. Switchboards shall be installed back to the wall with at least 1.5 m free space in
front for safe operational and maintenance access.
b. Service lines, e.g. fuel, water and air lines, shall not be routed over the switchgear,
and fuel and water lines should be positioned at least 2 m clear of it.
6.1.3.4
Battery installation and battery rooms
1.
When the total capacity of vented batteries exceeds 20,000 VAh, a separate battery
room shall be provided in the substation for the battery bank(s) only. Vented batteries
with a total capacity not exceeding 20,000 VAh, and valve-regulated batteries of any
capacity, do not require a separate battery room.
2.
The size of the room shall be adequate to allow safe access to each battery bank for
normal maintenance activities such as checking / cleaning battery links, making cell
voltage measurements and topping up of cells.
3.
The access shall be such as to avoid need for reaching over the cell bank terminals.
4.
All battery rooms shall be provided with one (external) equipment access door; large
rooms, exceeding 6 m in length, shall also be provided with a personnel access door.
All doors shall be lockable and fitted with an internal panic bolt.
5.
The ceiling shall be flat.
6.
An eye-wash facility shall be provided; to include a water tap, eye-wash basin, sink
and drain; the Principal may approve the use of portable eye-wash stations depending
on the size of battery room and the number of batteries installed in the room.
7.
All non-current-carrying metalwork in the room, e.g. cable tray, battery stands, etc.,
shall be bonded to earth. All metalwork shall be protected against corrosion.
8.
Heating, ventilation and/or air-conditioning of battery rooms shall be included in the
HVAC system of the building, in accordance with DEP 31.76.10.10-Gen.
9.
Exhaust fan motors shall have type of protection Ex 'e' or Ex 'd', gas group IIC,
exhausting to the outside of the battery room. Battery room ventilation shall be
designed so that the volume of hydrogen stays below 1% of the room volume.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 68
10. The luminaires and convenience outlets shall be suitable for Zone 1, gas group IIC
(Hydrogen).
11. Flexible cables to the batteries may be installed provided they are the EPR or
H07 RN-F type or equivalent.
12. Battery
stands
(tiers)
DEP 33.65.50.32-Gen.
shall
comply
with
DEP 33.65.50.31-Gen.
or
13. The civil requirements of the battery room shall comply with DEP 34.17.00.32-Gen.
a. Batteries installed outside battery rooms, e.g. in switchrooms, shall be installed in
naturally-ventilated cabinets, containing the battery alone or the battery plus
associated battery charger.
6.1.4
Package substations
1.
Package substations may be used for temporary or permanent installation.
2.
Temporary package substations may be used for temporary construction supplies and
comprise LV distribution switchboards and, optionally, transformers and HV ring main
switchgear. Refer to (6.9).
3.
Package substations shall be supplied as complete factory assembled and tested
transportable units.
4.
The HV switchgear, transformers and LV switchgear shall be located in separate
compartments, each accessible from the outside by lockable doors.
5.
Space shall be available in the compartments to terminate cables and to operate the
switchgear safely.
6.
The compartments shall be at least protected to IP 55. The transformer compartment
of oil-filled transformers shall be equipped with a leak-proof oil containment area.
7.
Dry-type transformers may be mounted en suite with the LV switchgear or in a
separately fenced enclosure in the LV switchgear compartment (5.2.3).
8.
Heating, ventilation and/or air-conditioning shall be provided in the substation as
appropriate and necessary to ensure that specified operating temperature limits of the
installed equipment are not exceeded.
9.
Each compartment shall be provided with luminaires and convenience outlets of the
weatherproof, industrial type.
6.2
ADDITIONAL REQUIREMENTS FOR OFFSHORE INSTALLATIONS
6.2.1
General
6.2.2
1.
Refer to (3.1), which also covers the general requirements for the design of electrical
systems for offshore installations and which forms the basis of these engineering and
installation requirements.
2.
Refer to IEC 61892 (all parts).
Main equipment
1.
Generators and distribution switchgear shall be monitored for fire by smoke detection
systems. Local offshore safety legislation and the safety case may dictate tripping of
non-essential loads upon fire detection.
2.
Electrical substations and switchhouses shall be complete with heating, ventilation
and/or air-conditioning installations in accordance with DEP 37.76.10.10-Gen.
3.
Liquid-filled transformers, where allowed, shall be installed in outdoor enclosures
which have a watertight floor bunded to hold the total volume of transformer coolant.
4.
Drain facilities shall be provided.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 69
6.2.3
Cabling and wiring
6.2.3.1
Cable selection and sizing
6.2.3.2
1.
Cable selection shall be governed by the locations and environments through which
the cable will be routed.
2.
The cables shall satisfy the requirements of (4.8.7). Cables installed in the drilling
areas shall also have increased resistance to oil and/or mud contamination in
accordance with BS 6883.
Cable identification, routing and segregation
1.
The whole of the cabling on an offshore platform, i.e., cabling for the electrical,
instrumentation and telecommunications systems shall be designed to form one
integrated system, so as to ensure suitable cable routing and adequate segregation
(for reasons of safety, circuit integrity and interference prevention) of the different
cable types.
2.
Cable routes shall be selected, as far as is practicable, so as to facilitate installation of
as much cable as possible onshore in order to minimise offshore hook-up time.
3.
Cables shall be segregated and suitably identified in the applicable cable category, i.e.
a. Power (HV and LV);
b. Instrumentation (DCS and safeguarding);
c. Fire and gas (detection and protection);
d. Telecommunications (CCTV and security systems).
4.
The above-mentioned categories shall be further sub-divided into normal and
intrinsically safe circuits.
5.
Within the power cable category, cable separation shall be as stated in (5.3.4), except
that HV multicore cables may be laid in one layer touching, and LV multicore cables in
up to a maximum of two layers touching, with the applicable group rating factor applied
and a maximum of 25 % spare rack capacity.
6.
Cables shall be arranged so that the density of combustible material in an array does
not exceed the recommended loading in relation to the reduced flame propagation
classification (IEC 60332-3).
7.
If the proposed cable routing cannot be made to accommodate those requirements,
the hazards shall be reduced to an acceptable level by one or more of the following:
a. alternative cable routing;
b. alternative means of escape;
c. screening the cables to keep escape routes clear of smoke or fumes;
d. installing fire protection or detection systems for the cables.
8.
If cables are to be routed through restricted openings, care must be taken to ensure
that fire is not intensified or readily channelled along the cable route. In general all
bulkheads and deck penetrations shall be fitted with 1-hour (A60) rated multi-cable
transits. This arrangement applies to:
a. fire walls;
b. walls between hazardous and non-hazardous areas;
c. through walls, roofs and floors to the open air.
NOTE:
H60 fire rating may be necessary if the switchroom is close to a hazardous area.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 70
6.2.4
Lighting and small power
6.2.4.1
General lighting
1.
General lighting shall provide the required level of illumination within the utility,
production, deck areas and walkways in accordance with (Appendix 4).
2.
General lighting shall be fed from the normal platform power supply in compliance with
(5.4.1) except that maximum use should be made of floodlights where possible.
3.
The preferred type of floodlight is high pressure sodium, which shall be used except
where instant relight is required, e.g. on helidecks (4.10.1).
NOTE:
4.
6.2.4.2
Typical areas where floodlights can be employed in preference to fluorescent luminaires are
open or high-bay production and utility areas, wellheads, cranes, overside legs and moorings,
underside and obstructions.
Floodlight luminaires may be used to illuminate the sea beneath the lifeboats and vent
stack structure.
Emergency lighting
1.
Emergency lighting shall provide sufficient level of illumination (150 lux – refer to
(Appendix 4)) to permit minimum operation of the platform and at evacuation assembly
areas such as offshore platform escape capsule areas / boat landings.
2.
The emergency lighting luminaires shall comprise up to 25 % of the total number of
luminaires.
3.
Emergency lighting shall be fed from the emergency switchboard but shall also have a
stand-by supply from an independent source with battery back-up to avoid complete
darkness during start-up of the emergency generating set.
4.
Emergency lighting shall be provided to allow limited operational lighting for inspection,
testing, emergency support, and the starting of the emergency generator.
NOTE:
Typical applications are obstruction lights on vent stacks and crane booms, perimeter lights on
helidecks, and key operational areas such as the control room, radio room, and crane access
ladders.
5.
The luminaires shall be suitable for Zone 1 areas.
6.
Emergency lighting shall also be installed in main switchgear and generator rooms,
accommodation and workshop areas.
7.
Portable emergency lighting units shall be provided at the exit doors of all nonhazardous area modules, e.g. installation control centre, switchrooms, utility areas,
and emergency team muster points.
8.
Each portable emergency lighting unit shall comprise a fixed wall-mounted battery
charger and hand lamps suitable for use in Zone 1 areas.
a. The unit shall be kept on float charge when not in use and be fed from the
emergency lighting switchboard.
b. The battery shall be rated to energise the hand lamp for not less than 6 h.
6.2.4.3
Escape lighting
1.
Escape lighting shall form part of the emergency lighting system and be located so as
to illuminate the escape routes, ladders and walkways to allow safe movement of
personnel to the muster points, lifeboats, etc.
2.
All obstacles on the escape route shall be lit. Additionally, platform status lights shall
be provided at strategic locations to be defined by the Principal to indicate the state of
platform security.
3.
Escape lighting shall be fed and equipped in the same fashion as the rest of the
emergency lighting except that, for normally unmanned installations, a central
uninterrupted maintained power supply should be provided with battery back-up for a
24 h autonomy time.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 71
4.
Escape lighting units shall have integral batteries that provide an (additional) autonomy
time of 60 minutes.
5.
Escape luminaires shall be installed at the following locations:
a. every exit doorway;
b. every sleeping cabin;
c. external escape ways (stairways and walkways);
d. internal escape ways (escape routes in modules or deck areas, accommodation
area corridors, and galley);
e. embarkation areas (access to helideck and survival craft stations);
f.
6.2.4.4
6.
Escape luminaires installed in sleeping cabins shall only illuminate on loss of the AC
supply to the integral battery charger.
7.
Escape lighting shall be suitable for Zone 1 areas.
Navigational aids
1.
6.2.4.5
6.2.5
Navigational aids in compliance with comply with DEP 33.80.00.30-Gen. shall be
provided on all offshore structures.
Helideck lighting
1.
6.2.4.6
muster areas (helicopter waiting room, cinema, lounge, dining room and the
emergency response team muster points).
Helideck lighting shall comply with DEP 33.80.00.30-Gen.
Power and convenience outlets
1.
Power and convenience outlets in plant areas shall be suitable for Zone 1 areas, fitted
with padlocking facilities and trip interlocked with the fire and gas shutdown system.
2.
Power and convenience outlets shall be equipped with 4-pole or double pole switches
respectively.
3.
In non-hazardous indoor areas, e.g. utility areas, switchrooms, etc., convenience
outlets of the industrial type should be installed where required.
4.
Domestic pattern convenience outlets shall only be fitted in the accommodation areas.
Earthing and bonding
The steel deck and structure of an offshore installation is an inherently very low
impedance structure capable of conducting earth fault currents as well as high
frequency disturbing currents from lightning strikes without giving rise to sparks,
dangerous touch voltages or transients that are destructive for electronic equipment.
1.
In an offshore facility, good electrical continuity should be achieved by intimate metalto-metal contact through equipment fixing bolts, clamping, riveting or welding, so that
earth bonding cables need not be used between pieces of non-electrical equipment
and between equipment and the steel deck.
2.
Earthing conductors are required to bond the main components of the generation and
distribution systems (namely HV and LV generators, transformers, reactors,
switchboards, motors and UPS units) to the platform steelwork. They shall be
individually identified, and recorded on drawings.
3.
For a typical installation refer to Standard Drawing S 68.031.
4.
The metallic sheath and armour of a submarine cable shall be solidly bonded to the
platform steelwork at both ends of the cable.
5.
For further details regarding earthing and bonding, reference is made to
DEP 33.64.10.33-Gen.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 72
6.3
OVERHEAD LINES
6.3.1
General
6.3.2
1.
The overhead lines shall be designed by a specialist Contractor, approved by the
Principal.
2.
This DEP applies to HV lines up to 145 kV. For the design of lines at higher voltages,
advice shall be sought from the local public utility and/or a specialist Contractor.
3.
The Contractor shall produce a fully detailed design, based on a detailed route survey
(6.3.6).
Conductor sizing
1.
The required conductor sizing shall be determined taking account of:
a. the thermal short circuit withstand requirement of both phase and earth
conductors;
b. the maximum permissible voltage drop;
c. the maximum continuous load current;
d. the maximum conductor temperature appropriate to the conductor material
(typically 75°C);
e. the maximum ambient temperature;
f.
the maximum solar radiation;
g. the minimum wind speed (typically 0.5 m/s).
NOTE:
6.3.3
The maximum continuous current rating may vary seasonally and may depend on outage conditions.
Type of construction
1.
Single circuit construction is preferred.
2.
With double circuit construction, the circuits shall be on opposite sides of the support
and spaced sufficiently far apart for maintenance to be carried out on one circuit while
the adjacent circuit is still live.
3.
Lines shall be divided into sections by straight line section supports or deviation
supports, so as to minimise the extent of the damage in case of failure of a support or
of one or more conductors. This should be done every ten spans or 2 km line length,
whichever is the shorter.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 73
6.3.4
Factors of safety
1.
The minimum factors of safety shall be as follows:
ITEM
FACTOR OF
SAFETY
Phase and earth conductor tension at maximum wind speed and
minimum ambient temperature, including, if relevant, ice loading
2.5, based on
UTS
Phase and earth conductor tension at everyday temperature and still air
5.0, based on
UTS
Supports
3.0, based on
UFS
wood poles
steel
towers or
poles
Support foundations against overturning or uplift at
maximum wind speed and maximum conductor
tension
Staywire foundations
Crossarms
intermediate
straight line
supports
2.0, based on
UTS
other supports
2.5, based on
UTS
intermediate
straight line
supports
2.0
other supports
2.5
intermediate
straight line
supports
2.0
other supports
2.5
intermediate
straight line
supports
2.0, based on
UTS
other supports
2.5, based on
UTS
Insulators
3.0
Midspan or dead end joints
2.5, based on
elastic limit
NOTES:
1. UFS = Ultimate F bre Strength
2. UTS = Ultimate Tensile Strength
2.
The number of broken conductors which can be tolerated without failure of the
supports shall be specified.
NOTE: This is typically two conductors on one side of a section or deviation support and one conductor at an
intermediate support.
3.
6.3.5
Under broken conductor conditions, some of the factors of safety stated above may be
reduced, but not to less than 1.25.
Line route
1.
The initial line route, which forms the basis of the detailed route survey (6.3.6), shall be
established by the Contractor and agreed by the Principal.
2.
Line routes shall be accessible, and make maximum use of existing roads and tracks
for both construction and maintenance access.
NOTE:
3.
In this context, access will normally require the use of four wheel drive vehicles.
Where line routes run parallel to existing roads and tracks, a minimum clearance of
20 m shall be maintained between the nearer edge of the road or track and the
centreline of the overhead line.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 74
4.
Where two lines run parallel with one another, they shall be spaced sufficiently far
apart so that a falling support from one line cannot damage the adjacent line, i.e., a
clear space not less than the height of the taller line supports.
5.
Where two lines cross one another, the higher voltage line shall be erected over the
lower voltage line, or the lower voltage line shall be run in underground cable for at
least 20 m on either side of the crossing.
6.
Lines should not be routed parallel to, and in close proximity with, metal pipelines,
telephone lines, etc. to avoid that the maximum voltages which can be induced in the
parallel service could exceed the acceptable levels laid down by national or
international standards, e.g. CCITT 'Directives'.
a. If this is not possible or practical, induced voltages shall be calculated and
appropriate measures (e.g. drainage diodes) taken.
7.
Lines shall not be routed through production or process areas; they should be routed
at least 50 m outside the boundary fence or plot limit.
8.
Lines feeding such facilities should be terminated at least 20 m from the boundary
fence with a cable connection to the plant substation.
9.
Lines shall be routed clear of wellheads, etc., by at least 50 m, so as not to obstruct
maintenance access.
10. Lines shall not be routed over buildings.
11. Additionally, an access track at least 5 m wide should be cleared immediately adjacent
to the line route.
12. Overall planning of lines within well areas shall take account wherever possible of “rig
moves” and access corridors provided to allow the movement of rig vehicles through
the well areas.
13. Branch lines shall be fitted with, as a minimum, fused isolators, located close to the
main line.
14. If the justified by the effects of power loss, local field mounted switchgear, complete
with an overcurrent and earth fault relay device should be provided on branch lines.
15. For high production areas or other areas deemed critical, ring circuits shall be used to
enhance power system reliability; these ring circuits shall be fitted with adequate
means of isolation and system protection
6.3.6
6.3.7
Line route survey
1.
The line route shall be surveyed in sufficient detail to produce the line route plans and
line profile drawings, typically at a scale of 1:2000 horizontally and 1:200 vertically.
2.
The drawings shall locate all supports and all obstructions, and show the profile of the
lowest conductor (6.3.8).
3.
The position of all supports shall be pegged. A soil survey shall be carried out to
determine the foundation design parameters for both the supports and the staywire
anchors, if required.
Ground clearance
1.
The minimum ground clearance at any point in a span shall not be less than the
minimum value prescribed in the national or local regulations for the relevant line
voltage.
2.
The clearance shall in any event exceed 6 m.
3.
For road crossings, the minimum ground clearance shall be increased to suit the type
of traffic expected (typically 12 m) or the line may be cabled underground.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 75
4.
6.3.8
The ground clearance is determined relative to the lowest conductor at maximum
conductor temperature and in still air. An allowance should be included for long-term
creep, e.g. over a period of 10 years.
Sag and pre-stress charts
1.
Sag and pre-stress charts shall be prepared for the conductor(s) being used, covering
the range of spans required:
a. at maximum conductor temperature, so as to design the line profile;
b. over the range between maximum and minimum ambient temperatures, so as to
tension up the conductors correctly during erection.
2.
6.3.9
During erection, the conductors shall be overtensioned for a short period (about 1 h) to
minimise creep prior to making them off permanently.
Earthing and bonding
1.
All lines shall be provided with one or two overrunning earth conductors, which provide
a shielding angle of not more than 30°.
NOTE:
6.4
The earth conductor may be omitted for wood pole lines at voltages of 36 kV and below.
2.
All conducting support structures and all apparatus mounted on non-conducting
support structures shall be earthed at the foot of the support.
3.
The earth electrodes should have a maximum resistance of 10 Ω to the general mass
of earth.
4.
All non-current-carrying metalwork on non-conducting supports shall be bonded
together to prevent pole fires.
5.
For further details regarding EMC aspects of overhead lines and parallel pipelines,
cathodic protection and instrument systems, refer to DEP 33.64.10.33-Gen.
LABORATORIES
1.
Electrical installations may be of normal industrial design, provided that they are
located in non-hazardous areas and the quantities of flammable gases present inside
these buildings are insufficient to constitute a hazard.
a. If one of the above conditions is not fulfilled, the electrical installation shall conform
to the installation practice recommended in IEC 60079-14.
6.5
2.
The electrical installations in bottle wash rooms, drying and fume cabinets, enclosed
sample rooms, receiving rooms, stores rooms for chemicals and closed hoods shall be
suitable for Zone 1 areas.
3.
HVAC shall comply with DEP 31.76.10.10-Gen.
4.
Each work bench should be equipped with sufficient single phase industrial pattern
convenience outlets with supply voltage stated in (4.10.6.3) to supply the test
equipment.
5.
The outlets shall all be supplied from the same phase and each circuit protected by a
30 mA RCCB.
ANALYSER BUILDINGS
1.
Analyser buildings shall comply with DEP 32.31.50.13-Gen. and HVAC requirements
with DEP 31.76.10.10-Gen.
2.
Electrical installations in analyser buildings, which are intended to continue operation
during an analyser house ventilation failure, shall have a type of protection suitable for
a Zone 1 hazardous area.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 76
3.
6.6
All equipment not suitable for Zone 1 areas shall be connected via convenience
outlets, which shall be automatically isolated by a safeguarding system when
ventilation fails.
JETTIES
1.
Ship/Shore electrical isolation and earthing/bonding of jetties SHALL [PS] comply with
the requirements of sections 17.5 and 17.6 of the International Safety Guide for Oil
Tankers and Terminals (ISGOTT).
These rules specify electrical isolation between ship and jetty installations,
regardless of whether or not the jetties are cathodically protected.
6.7
2.
The minimum insulation resistance for insulating flanges or joints used in pipe and/or
hose connections between the ship and the jetty shall be 10 kΩ measured with an
insulation resistance tester at a minimum of 50 V DC.
3.
The maximum insulation resistance shall be 100 MΩ to prevent static build-up.
4.
A ship-to-jetty bonding cable and a jetty mounted Ex 'd' isolating switch may only be
provided for each berth if specifically required by the local authority regulations.
5.
The design of the jetty cathodic protection system, if any, should take account of the
leakage current to the shore earthing system.
NON-INDUSTRIAL BUILDINGS
NOTE:
Non-industrial buildings comprise all buildings outside the process areas, e.g. workshops,
warehouses, canteens, administration buildings, fire stations, training centres, gatehouses,
chemical stores, etc.
1.
Non-industrial buildings should be classified non-hazardous with the possible
exception of chemical stores, depending on the chemicals and the method of their
storage and handling.
2.
The design and installation of the power, lighting and earthing systems shall comply
with IEC 60364, the relevant parts of this DEP, and the local regulations in the country
of installation, whichever are the most stringent.
4.
The power supply voltage to each building shall be the same as the LV supply to the
plant. Except for very small total loads, e.g. less than 15 kVA, a three phase and
neutral supply should be installed.
5.
Normal and interruptible, maintained electricity supplies for lighting and small power
should be in accordance with (5.4) and Standard Drawing S 67.022.
6.
Emergency lighting shall be installed in the building switchroom(s).
7.
Escape lighting shall be installed along all the emergency exit routes from the building
by means of luminaires with integral battery back-up (5.4.2). The selection of
luminaires shall be in accordance with (4.10).
8.
Illumination levels shall be as stated in (Appendix 4).
9.
Twin outlets of the domestic pattern standard to the country of installation shall be
used. Industrial pattern convenience outlets (4.10.6.3) and power outlets (4.10.6.2)
shall be provided, e.g. in workshops, as applicable.
10. Earthing, bonding and lightning protection shall comply with (5.5).
11. Power supplies to lifts shall be derived directly from the main switchboard.
12. Power supplies to central air-conditioning units shall be arranged as radial feeders
from the main switchboard, and those to fan-coil units from a sub-distribution
switchboard of the air-conditioning system.
13. Cabling and wiring shall be installed in accordance with the methods stated in (5.3).
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 77
6.8
PLANT LIFT INSTALLATIONS
1.
Lift installations shall comply with EN 81, as supplemented by local or national
regulations of the country of installation.
2.
Sufficient luminaires should be connected to an interruptible, maintained electrical
supply to permit emergency operation and escape from the lift car up the lift shaft.
3.
The lift shaft lighting shall be automatically switched on when the lift car escape hatch
is opened.
6.9
TEMPORARY ELECTRICAL INSTALLATIONS
6.9.1
General
6.9.2
6.9.3
1.
All local statutory regulations and the following additional requirements are mandatory.
However, in the event of inconsistency, the more stringent shall apply.
2.
For semi-permanent parts of the site installation such as site offices and ancillary
buildings, the local regulations, if any, shall be adhered to. In the absence of local
regulations, generally accepted standards, e.g. IET wiring regulations, NEN 1010, shall
be followed.
3.
A single line diagram and layout drawing shall be prepared for the temporary power
system.
4.
All equipment and cabling shall be uniquely numbered and clearly marked in a
prominent manner.
Supply arrangements
1.
HV supplies should be in the form of a ring circuit, operated open at one point, with HV
switchgear, e.g. ring main unit (tee-off fuse switch and two ring circuit isolators), local
to each transformer.
2.
LV supplies shall be arranged as a TN-S system, with radial feeders from a main
distribution switchboard, e.g. local to each transformer or to the generating sets, to
sub-distribution switchboards close to the work areas.
3.
The HV distribution equipment, the transformers and the main LV distribution
switchboards shall be accessible to authorised persons only.
4.
Power supplies should be provided with Class 2 kilowatt-hour metering at source of
supply, except where generating sets are used.
Generating sets
1.
The diesel generating sets should be installed at a single, reasonably central location.
NOTE:
6.9.4
Only at a very widespread site may they be installed at more than one location, in which case they
should supply a number of separate temporary power systems.
2.
The generating sets shall be complete with a circuit breaker and all necessary control
equipment, and shall be suitable for parallel operation where more than one set is
installed.
3.
The generators shall be star connected and their neutral points shall be solidly
earthed.
HV Switchgear
1.
The main HV switchboard, if required, shall comply with IEC 62271 – part 200 and
have single section busbars with one incoming switch, together with a number of
outgoing feeder circuit breakers for ring distribution or fuse switches for radial
distribution.
2.
Each outgoing feeder circuit breaker shall be protected with IDMT overcurrent and
earth fault protection. The incoming switch should not require any protection.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 78
6.9.5
6.9.6
3.
Switchgear and protection, which does not require any DC tripping supplies should be
used. Circuit earthing facilities shall be provided.
4.
If a ring distribution system is used, HV switchgear at each transformer substation
shall comprise ring main units.
5.
The switchgear shall be suitable for outdoor use or mounted in a packaged
weatherproof enclosure, with adequate access for operating/maintenance personnel.
Transformer substations
1.
Transformers shall comply with IEC 60076, connected preferably delta-star and the LV
neutral points shall be solidly earthed.
2.
Packaged substations complying with (6.1.4) should be used where possible.
3.
The transformer, together with the associated HV switchgear and LV main distribution
switchboard, whether separate or packaged units, shall be mounted on concrete
plinths within a fenced enclosure with padlockable gates.
4.
The cornerposts shall protect the substation equipment from vehicle impact. The
substation should be located at least 5 m clear from the edge of any road.
LV distribution switchboards
1.
All distribution switchboards shall comply with IEC 61439-4.
2.
Main LV distribution switchboards supplied by one or more generating sets shall have
an incoming switch for each generator. The outgoing circuits shall be protected by
fuses or MCCBs having a maximum rating/setting of 400 A.
3.
Sub-distribution switchboards shall additionally comply with the requirements specified
in DEP 33.67.01.31-Gen.
4.
Each sub-distribution switchboard shall be provided with one incoming switch.
5.
Each outgoing feeder shall be provided with a switching device with short circuit and
residual current protection. The maximum outgoing feeder rating shall be 125 A.
6.
The sensitivity of the residual current circuit breakers shall be as follows:
a. 30 mA for circuits below 125 A;
b. 300 mA for circuits of 125 A.
7.
Fuses shall be accessible only if the fuse bases are protected to at least IP 2X, or if
interlocking exists so that the fuse base is electrically isolated first.
6.9.7
Temporary cabling
6.9.7.1
General
6.9.7.2
1.
Temporary cables may be installed above-ground or underground, subject to the site
circumstances. The method of installation shall be chosen so as to minimise the risk of
damage.
2.
The temporary cable installation shall comply with the requirements specified below.
Underground cables
1.
Temporary cables shall not be installed in the same trench as any permanent project
cabling or other services. A minimum separation of 2 m should be maintained.
2.
HV and LV cables shall be buried at a minimum depth of 0.8 m and 0.5 m respectively,
to avoid being damaged by any disturbance of the ground likely to occur during the
construction period.
3.
Cables should be installed underground at road crossings.
4.
Underground cables shall be provided along the routing with the marking 'Temporary
cable', also indicating the applicable project number.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 79
6.9.7.3
Above-ground cables
1.
Where the use of overhead road and route crossings is unavoidable, the cables shall
be erected with the following minimum clear height:
a. 6.0 m, where the roads and routes are designated for use by vehicular traffic;
b. 3.5 m, where vehicular traffic is prohibited.
6.9.8
6.9.9
2.
Above-ground cables shall be fixed on site so that they are clear of building operations
or engineering construction work and are not a hazard. They should be installed clear
of passageways, walkways, ladders, stairs, etc.
3.
Overhead cables crossing passages shall be bound with yellow/black coloured tapes.
Alternatively, freely moving strips of coloured fabric or plastic may be attached to
attract attention. In some circumstances protective barriers may be required.
4.
All cables shall be installed in such a way that they are at least 150 mm clear of piped
services such as steam, gas and water.
5.
Apparatus and accessories other than lampholders shall not be suspended from
electric cables.
6.
All cables that are likely to be frequently moved in normal use shall be flexible, of the
heavy-duty neoprene rubber type or equivalent.
Earthing
1.
For the purpose of earthing, the electrical system and equipment for the installation
shall have one common earthing grid connected to at least two earth electrodes, which
may form part of the permanent earthing system.
2.
The resistance to earth of this common earthing grid shall be as low as practicable and
not exceed 4 Ω.
3.
Earth wires shall be of the standard copper conductor with green/yellow PVC
sheathing. They shall be sized to carry the rated fault current of the distribution
switchgear for its rated short-time duration.
4.
For mechanical reasons main earth wires should be at least 70 mm 2 and branch earth
wires 25 mm2, unless adequate mechanical protection is provided by other means,
e.g. wire installations in conduit, or earth conductors forming part of a cable, allowing a
smaller size.
5.
The connections between earth electrode and conductors should be made so that the
earth resistance of each individual electrode can be readily inspected and tested,
without disconnecting any part from the earthing system.
6.
The earth bar in each switchboard and sub-distribution switchboard shall be connected
with two 70 mm2 earth wires each suitable for 100 % duty to the above-mentioned
common earthing grid.
Selection of components
1.
The components shall be suitable for their particular application as regards their
voltages, rated currents, service life, making and breaking capacities, short circuit
strength, etc.
2.
The components having a short circuit strength and/or a breaking capacity insufficient
to withstand the stresses likely to occur at the place of installation shall be protected by
means of current-limiting devices, e.g., fuses or MCCBs.
3.
Current-limiting devices for built-in switching devices shall not exceed the maximum
admissible values specified by the Manufacturer of the apparatus.
4.
Power and convenience outlets shall be industrial pattern complying with IEC 60309.
5.
Plugs of different rated currents or voltages shall not be interchangeable.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 80
6.
All three phase outlets shall be connected with the same phase sequence.
7.
The socket outlets and plugs shall have a degree of protection at least IP 54, both
when the plug is removed and when it is fully inserted.
8.
For portable lamps and tools, refer to (4.10.5).
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 81
7.
DOCUMENTS AND DRAWINGS
7.1
GENERAL
7.2
1.
All necessary drawings, documents, and reports relating to the design of the electrical
installation and for its operation, and all necessary drawings required for the
installation and interconnection of equipment and cabling shall form part of the design
package.
2.
The documents, reports and drawings shall be prepared and submitted for approval as
shown in (Appendix 7). These documents shall be updated when alterations to the
design are made and include additional information that is required during erection or
may be required for future maintenance, troubleshooting and operation.
3.
As-built drawings shall be prepared for the project covering all parts of the electrical
installation and related civil engineering, mechanical and instrumentation work. At the
commissioning phase temporary, marked versions of the drawings shall be available.
4.
Thereafter, the final as-built documentation shall be handed over within the time span
indicated by the Principal.
SUMMARY OF ELECTRICAL ENGINEERING
1.
A 'Summary of Electrical Engineering', using standard form DEP 05.00.54.84-Gen.,
shall be prepared as early as possible during the project. Alternative forms, e.g.
computer printout, may be used provided:
a. they contain the same information in the same order;
b. they are reproducible on a standard printing machine in A4 or A3 format, as
appropriate.
2.
The summary of electrical engineering shall register all engineering documents,
detailing references, issues, drawing, document numbers, scheduled publication
dates, etc.
3.
The summary of electrical engineering is intended for:
a. detailed recording and progress reporting during the engineering, purchasing and
erection of the electrical installations of a project;
b. giving detailed information and references concerning the electrical installations
during erection and after completion of the project.
7.3
DEP STANDARD REQUISITION SHEETS
1.
For the detailed engineering and requisitioning of equipment, the relevant DEP
standard requisition sheets shall be used.
2.
The requisition sheets to be used and the procedures to be followed are given in
DEP 30.10.01.10-Gen. Amendments/supplements to the DEPs for specific items of
electrical equipment shall be specified on the requisition form, or on supplementary
requisition form DEP 30.10.00.94-Gen. sheet 2 or 3.
7.4
DESIGN DRAWINGS
7.4.1
General requirements for the production of drawings
1.
The Principal's drawing format shall be used, reference is also made to
DEP 02.00.00.10-Gen.
2.
In general the drawings shall be provided on a PC readable device (e.g. CD-ROM).
The Principal shall advise on the software packages to be used and further details on
the management of the documentation.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 82
3.
The 'subject index reference' for drawings is:
a. 64. series - Electrical schemes;
b. 68. series - Cable/lighting layouts.
4.
SI units shall be used for the design and on the design drawings.
5.
Symbols and identification of electrical equipment shall be in accordance with
IEC 60617. Symbols not included in IEC 60617 shall be in accordance with Standard
Drawing S 64.000.
6.
Wherever possible, Standard Drawings in Groups S 67., S 68. and S 69. shall be
adhered to and quoted where applicable, i.e., not redrawn.
7.
For the preparation of diagrams, charts and tables, refer to IEC 60113.
7.4.2
Summary of drawings to be prepared
7.4.2.1
General
1.
Fully detailed construction drawings shall be provided so that the site construction
contractor can install all electrical equipment with no additional design effort.
2.
Vendor information and details shall be incorporated in the design package as soon as
it becomes available.
3.
Section 2 of standard form DEP 05.00.54.84-Gen. shall be divided into sub-sections
for ease of reference and shall contain all the relevant headings from the table in
(Appendix 7).
4.
One single line diagram and/or schedule shall be produced for each HV switchboard.
5.
For each generator, HV synchronous motor and HV VSDS or group of similar
equipment, the following diagrams shall be provided:
a. block control and protection diagram;
b. single line diagrams for main and auxiliary circuits.
6.
7.4.2.2
A protection report describing the basic philosophy, and comprising a protection key
diagram, relay setting schedules and relay discrimination curves, shall be prepared as
stated in (3.7.1).
Key line diagram
1.
The key line diagram shall show the complete AC electrical generation and distribution
system of the plant including all HV feeds, main LV feeds and sub-distribution
switchboards, together with:
a. all sources of electric power;
b. the principal supply and distribution system interconnections at each voltage level;
c. system capacities, equipment ratings and impedances, winding configuration and
earthing arrangements.
7.4.2.3
7.4.2.4
Block diagram
1.
The block diagram shall show the basic control and protection systems defining the
protection, control, trip and alarm functions to be fulfilled at the different locations.
2.
The block diagram shall also indicate the reference signals and controls needed and
all the auxiliary supplies required such as air, luboil, cooling water, electrical auxiliary
supplies, etc.
Single line diagrams
1.
The single line diagrams shall detail the main circuitry and its earthing systems.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 83
7.4.2.5
2.
The single line diagram shall also indicate the instrument transformers, relays, meters,
etc., for the control, protection and operation of the equipment together with electrical
data such as voltage, current and impedances.
3.
A single line diagram of AC and DC interruptible and uninterruptible, maintained
electricity supply systems shall be provided.
4.
The single line diagram shall detail for each system the system configuration, earthing
arrangements, UPS and emergency generator ratings, the equipment number,
function, location, nominal voltages, maximum load, number and type of battery cells
and battery autonomy time.
Switchgear drawings
1.
The following schedule and drawings shall be provided for each HV and LV
AC switchboard:
a. switchboard schedule form: DEP 33.67.01.80-Gen., DEP 33.67.01.81-Gen.,
DEP 33.67.01.82-Gen., DEP 33.67.20.80-Gen. or DEP 33.67.51.80-Gen., as
appropriate;
b. circuit/schematic or control diagram, showing in a schematic form all control circuit
details for a motor or other power device, and all information necessary for the
identification and connection of the components and wiring;
c. interconnection/connection diagram showing the external connection details of a
switchgear panel, relay box, or junction box, etc.;
d. block diagram showing the interconnection of the various equipment items of a
power system in a diagrammatic manner;
e. functional logic diagrams of (numeric) protection devices.
f.
7.4.2.6
switchboard layout showing the basic information needed for the construction,
i.e., the switchboard outline dimensions and the switchboard front outline layout.
Layout drawings
1.
A substation/switchroom layout drawing shows the physical location and the civil
provisions to be made for installing all transformers, switchgear and other electrical
power, lighting, earthing and auxiliary equipment located in a substation.
2.
The cable runs and support systems shall also be shown.
3.
Space requirements for future switchgear, and the correct location and dimensions of
transits in the substation floor for existing and future switchgear shall be shown.
4.
Power, lighting, earthing, substation, and trench layout drawings shall identify:
a. all major process equipment by their item numbers;
b. all electrical equipment and cables by their equipment and cable numbers.
5.
The power layouts shall show all power cabling, identified by cable numbers, lighting
supply cables up to the main junction boxes, and the power and convenience outlet
switchboard feeder cables.
6.
Lighting layouts shall show all luminaires (normal and emergency), all level gauges, all
power and convenience outlet distribution switchboards, and all junction boxes and
cable routing, downstream of the main junction boxes.
7.
Note that Luminaires, etc., shall be identified by a support detail reference, circuit
reference, fitting/outlet reference. If required for clarity, separate or additional layouts
should be prepared for the higher levels (above grade).
8.
Earthing layouts shall show the main earthing grid, branch connections, earth
electrodes, earth bars and conductor sizes for the entire earthing system. Bonding
details of structures, cable entry frames, cable ladders, ducts and trunking, cable
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 84
armouring, equipment cabinets, etc., shall be shown in typical drawings, examples of
which are provided in DEP 33.64.10.33-Gen.
9.
The cable trench layout shall show the physical location of all underground cable
trenches, underground pipes and ducts.
10. Cross-sectional arrangement drawings shall be provided for all cable trenches, ducts
and above-ground cable routes showing the location and number of each cable along
the routes.
7.4.2.7
7.4.2.8
Construction drawings (typical details)
1.
Construction detail drawings shall show typical construction and mounting details of
the power, lighting and earthing installations that cannot otherwise be shown on the
layouts.
2.
Each detail shall have a unique reference.
Area classification drawings
1.
7.4.2.9
Vendor drawings
1.
7.5
Refer to (Appendix 1).
Vendor drawings shall be provided to show as a minimum all the information specified
in the relevant equipment DEP and the requisition.
EQUIPMENT AND CABLE NUMBERING
1.
For plants having an existing numbering system, this system shall be followed.
Otherwise the equipment and cable numbering systems stated in (Appendix 5) shall be
used.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 85
8.
REFERENCES
In this DEP, reference is made to the following publications:
NOTES:
1. Unless specifically designated by date, the latest edition of each publication shall be used,
together with any amendments/supplements/revisions thereto.
2. The DEPs and most referenced external standards are available to Shell staff on the SWW (Shell
Wide Web) at http://sww.shell.com/standards/.
SHELL STANDARDS
DEP feedback form
DEP 00.00.05.80-Gen.
Design class tables
DEP 00.00.07.10-Gen.
Definition of temperature, pressure and toxicity levels
DEP 01.00.01.30-Gen.
Preparation of technical drawings
DEP 02.00.00.10-Gen.
Standard form: Utility data – electrical
DEP 05.00.10.80-Gen.
Standard form: Summary of electrical engineering
DEP 05.00.54.84-Gen.
General data/requisitioning sheets
DEP 30.10.00.94-Gen.
Requisition index
DEP 30.10.01.10-Gen.
Symbols and identification system – Mechanical
DEP 31.10.03.10-Gen.
Heating, ventilation and air conditioning for plant buildings
DEP 31.76.10.10-Gen.
Analyser housing
DEP 32.31.50.13-Gen.
Instrument signal lines
DEP 32.37.20.10-Gen.
Instrumented protective functions (IPF)
DEP 32.80.10.10-Gen.
Application of protective functions for electrical systems
DEP 33.64.10.17-Gen.
Electrical network monitoring and control system for industrial
networks
DEP 33.64.10.32-Gen.
Electromagnetic compatibility (EMC)
DEP 33.64.10.33-Gen.
Electrical engineering design for North American application
DEP 33.64.20.10-Gen.
Synchronous AC machines (amendments/supplements to
IEC 60034-1 and IEC 60034-14)
DEP 33.65.11.31-Gen.
Packaged alternating current generator sets
DEP 33.65.11.32-Gen.
Power transformers (amendments/supplements to IEC 60076-1 and
IEC 60076-11)
DEP 33.65.40.31-Gen.
Static DC uninterruptible power supply (DC UPS) units
DEP 33.65.50.31-Gen.
Static AC uninterruptible power supply unit (static AC UPS unit)
DEP 33.65.50.32-Gen.
Electrical machines - Cage-induction types
(amendments/supplements to IEC 60034-1 and IEC 60034-14)
DEP 33.66.05.31-Gen.
AC electrical variable speed drive systems
DEP 33.66.05.33-Gen.
Low voltage switchgear and controlgear assemblies
(amendments/supplements to IEC 61439)
DEP 33.67.01.31-Gen.
Standard form: Schedule for LV switchboard
DEP 33.67.01.80-Gen.
Standard form: Schedule for lighting distribution switchboard
DEP 33.67.01.81-Gen.
Standard form: Schedule for AC instrument distribution switchboard
DEP 33.67.01.82-Gen.
Standard form: Schedule for DC instrument distribution switchboard
DEP 33.67.20.80-Gen.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 86
High-voltage switchgear and controlgear assemblies for rated
voltages between 1 kV and 52 kV (amendments/supplements to
IEC 62271-200)
DEP 33.67.51.31-Gen.
Gas-insulated, metal-enclosed switchgear and controlgear for rated
voltages above 52 kV (amendments/supplements to
IEC 62271-203)
DEP 33.67.51.32-Gen.
Standard form: Schedule for high voltage switchgear and control
gear assemblies
DEP 33.67.51.80-Gen.
Electric heating system for frost heave prevention of refrigerated
hydrocarbon storage tanks
DEP 33.68.30.31-Gen.
Electrical trace heating
DEP 33.68.30.32-Gen.
Electrical process heaters
DEP 33.68.30.33-Gen.
Navigational aids for fixed offshore structures
DEP 33.80.00.30-Gen.
Design and engineering of buildings
DEP 34.17.00.32-Gen.
Field commissioning and maintenance of electrical installations and
equipment
DEP 63.10.08.11-Gen.
Area classification (amendments/supplements to IP 15)
DEP 80.00.10.10-Gen.
Area classification and electrical equipment spacing for North
American application
DEP 80.00.10.13-Gen.
Electrical safety rules
DEP 80.64.10.10-Gen.
Static electricity
DEP 80.64.10.11-Gen.
STANDARD DRAWINGS
Electrical and instrument cable trenches in concrete paved areas
S 19.001
Cable routing in unpaved, brick-paved or tiled areas and crossing
roads
S 19.002
Electrical standard drawings - cover sheet
S 64.000-001
Electrical standard drawings - table of contents
S 64.000-002
Electrical symbols
S 64.000-003
Schematic diagrams of control circuits for LV motors Ex. of
connection with standard motor panel terminal diagram
S 67.004
Typical instrument electricity supply systems with static components
S 67.006
Single line diagrams of LV switchboard panels
S 67.019
Single line diagram and control circuits for lighting distribution
switchboards
S 67.022
Schematic diagram and control circuits for AC instrument distribution
switchboard
S 67.024
Schematic diagram of DC distribution switchboard for process
control and safeguarding systems
S 67.025
Schematic diagrams of control circuits for HV motors (contactor
starters) example of conections with std. motor panel arrangement
S 67.028
Typical HV single line diagram, motor controlled by contactor
S 67.045
Typical HV single line diagram, motor controlled by circuit breaker
S 67.046
Typical HV single line diagram, large synchronous motor
S 67.047
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 87
Typical HV single line diagram, motor with unit transformer
S 67.048
Typical HV single line diagram, HV/LV transformer < 1600 kVA,
controlled by contactor
S 67.049
Typical HV single line diagram, HV/LV transformer < 1600 kVA,
controlled by circuit breaker
S 67.050
Typical HV single line diagram, HV/LV transformer including feeder
cable < 500 m
S 67.051
Typical HV single line diagram, HV/LV transformer including feeder
cable > 500 m
S 67.052
Typical HV single line diagram, parallel plain feeder
S 67.053
Typical HV single line diagram, single plain feeder
S 67.054
Typical HV single line diagram, generator directly connected (voltage
< 11 kV)
S 67.055
Typical HV single line diagram, generator with unit transformer
(voltage > 11 kV)
S 67.056
Typical HV single line diagram for variable speed drive system
(VSDS) with synchronous motor
S 67.057
Typical HV single line diagram for submerged motors (contactor
starter)
S 67.058
Typical HV single line diagram, overhead line circuits (33 – 132 kV)
S 67.059
Typical HV single line diagram for grid supply incomer with on site
generation
S 67.060
Typical single line and schematic diagram of control circuits for LV
emergency generator
S 67.070
Schematic diagram of control circuits for HV motors (circuit breaker
starters) Ex. of connections with std. motor panel terminal
arrangement
S 67.071
Typical instrument electrical supply systems with DC ups units
S 67.080
Typical earthing systems for tanks
S 68.001
Typical mounting details for earthing connections of plant equipment
S 68.003
Earthing boss for steel structures, tanks, vessels, etc.
S 68.004
Typical arrangements of cables trenches in plant areas
S 68.009
Selection table for transformer secondary side connecting cables
S 68.022
Typical PA6 (polyamide-6) gland installation drawing
S 68.023
Typical earthing arrangements for substations, control buildings and
field auxiliary rooms and associated typical mounting details
S 68.030
Typical earthing arrangements for offshore installations
S 68.031
Power connection for plant electrical equipment
S 68.032
Typical plant earth grid
S 68.033
Typical field auxiliary room earthing layout (cross-section)
S 68.034
Typical bonding details for field instrument cabling
S 68.035
Typical multi-point earthing systems for electrical cabling and
instrument signal lines
S 68.036
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 88
Typical drawing for electrical substation
S 68.040
Details of typical substation earthing and bonding arrangements
S 68.041
Typical mounting details for earthing connections
S 68.042
Construction and fastening of lamppost for fluorescent lighting fittings
S 69.001
Typical lighting details
S 69.003
Shell HSSE & SP Control Framework, Design Engineering Manual
(DEM) 1 – Application of Technical Standards
DEM1
http://sww.manuals.shell.com/HSSE/
AMERICAN STANDARDS
Recommended Practice for Classification of Locations for Electrical
Installations at Petroleum Facilities Classified as Class I, Division 1
and Division 2
API RP 500
Recommended Practice for Classification of Locations for Electrical
Installations at Petroleum Facilities Classified as Class I, Zone 0,
Zone 1, and Zone 2
API RP 505
Standard Practice for Determining Chemical Resistance of
Thermosetting Resins Used in Glass-Fiber-Reinforced Structures
Intended for Liquid Service
ASTM C581
Standard Test Method for Rate of Burning and/or Extent and Time of
Burning of Plastics in a Horizontal Position
ASTM D635
Standard Practice for Xenon-Arc Exposure of Plastics Intended for
Outdoor Applications
ASTM D2565
Standard Test Method for Surface Burning Characteristics of
Building Materials
ASTM E84 REV A
Electric Equipment for use in Hazardous (Classified) Locations
General Requirements
FM 3600
Intrinsically Safe Apparatus and Associated Apparatus for Use in
Class I, II, and III, Division 1, Hazardous (Classified) Locations
FM 3610
Explosion-proof electrical equipment - General Requirements
FM 3615
Purged and Pressurized Electrical Equipment for Hazardous
(Classified) Locations
FM 3620
Issued by: FM Approvals
Guide for Safety in AC Substation Grounding
IEEE 80
Recommended Practices and Requirements for Harmonic Control in
Electrical Power Systems
IEEE 519
Issued by: Institute of Electrical and Electronic Engineers Inc.
Standard for the Installation of Stationary Pumps for Fire Protection
NFPA 20
Standard for Purged and Pressurized Enclosures for Electrical
Equipment
NFPA 496
UL Standard for Safety Industrial Control Panels relating to
Hazardous (Classified) Locations
UL 698A
UL Standard for Safety Outlet Boxes and Fittings for Use in
Hazardous (Classified) Locations
UL 886
UL Standard for Safety Electrical Apparatus for Explosive Gas
Atmospheres
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 89
Part 1: Equipment Protection by Flameproof Enclosures "d"
UL 60079-1
Part 5: Equipment Protection by Powder Filling "q"
UL 60079-5
Part 6: Equipment Protection by Oil-Immersion "o"
UL 60079-6
Part 7: Equipment Protection by Increased Safety "e"
UL 60079-7
Part 11: Equipment Protection by Intrinsic Safety "i"
UL 60079-11
Part 15: Equipment Protection by Type of Protection "n"
UL 60079-15
Part 18: Equipment Protection by encapsulation “m”
UL 60079-18
Issued by: Underwriters Laboratories Inc.
BRITISH STANDARDS
Wood poles for overhead power and telecommunications lines
Part 1 - Specification for softwood poles
BS 1990-1
Lead-acid stationary cells and batteries,
Part 4 - Specification for lead-acid valve regulated sealed type
BS 6290-4
Elastomer insulated cables for fixed wiring in ships and on mobile
and fixed offshore units
BS 6883
IP Model Code of Safe Practice
Part 15: Area classification code for petroleum installations
IP 15
Issued by: The Energy Institute
International safety guide for oil tankers and terminals
ISGOTT
Issued by: Oil Companies International Marine Forum
Current Rating Standards 69-0030 Part IX.
Sustained Current Ratings for Thermosetting Insulated Cables up to
70mm Squared to BS 7211:1989 in Mixed Groups in Painted Steel
Trunking to BS 4678 Part 1: 1971
ERA Report 69-0030
Issued by: ERA Technology Ltd,
Procedure to meet IEC 60909 Electricity Network Association
UK Engineering Recommendation
ER G 7/4
Specification for underground armoured cable Protected against
solvent penetration and corrosive attack
EEMUA PUB No 133
NETHERLANDS STANDARDS
Veiligheidsbepalingen voor laagspanningsinstallaties
NEN 1010
Issued by: NEN
EUROPEAN STANDARDS
Safety rules for the construction and installation of lifts
EN 81
Precast concrete products, masts and poles
CEN EN 12843
Cable glands for electrical installations
CENELEC EN 50262
Electrical apparatus for explosive gas atmospheres
CENELEC EN 60079
Part 1 - Construction and verification test of flameproof enclosures of
electrical apparatus
CENELEC EN 60079-1
Part 2 - Electrical apparatus type of protection 'p’
CENELEC EN 60079-2
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 90
Part 5 - Sand-filled apparatus
CENELEC EN 60079-5
Part 6 - Oil-immersed apparatus
CENELEC EN 60079-6
Part 7 - Increased safety 'e'
CENELEC EN 60079-7
Part 11 - Construction and test of intrinsically safe and associated
apparatus
CENELEC EN 60079-11
Part 15 - Electrical apparatus with type of protection 'n'
CENELEC EN 60079-15
Part 18 - Electrical apparatus with type of protection 'm'
CENELEC EN 60079-18
Part 25 - Intrinsically safe systems
CENELEC EN 60079-25
Issued by: CENELEC - European Committee for Electrotechnical Standardization
Directive 94/9/EC on the approximation of the laws of the Member
States concerning equipment and protective systems intended for
use in potentially explosive atmospheres
ATEX Directive
Issued by:
The European Commission
Website: http://europa.eu.int/comm/enterprise/atex/
INTERNATIONAL STANDARDS
Annex 14 to the Convention on International Civil Aviation
Aerodromes
ICAO
Issued by: (ICAO) International Civil Aviation Organisation
Rotating electrical machines - Part 1 - Rating and performance
IEC 60034-1
IEC standard voltages
IEC 60038
International electrotechnical vocabulary
IEC 60050
High-voltage alternating-current circuit-breakers
IEC 60056
Insulation co-ordination
IEC 60071
Power transformers
IEC 60076
Part 5 -Ability to withstand short circuit
IEC 60076-5
Electrical apparatus for explosive gas atmospheres
IEC 60079
Part 1 - Construction and verification test of flameproof enclosures of
electrical apparatus
IEC 60079-1
Part 2 - Electrical apparatus type of protection 'p
IEC 60079-2
Part 5 - Sand-filled apparatus
IEC 60079-5
Part 6 - Oil-immersed apparatus
IEC 60079-6
Part 7 - Increased safety 'e'
IEC 60079-7
Explosive atmospheres – Part 10-2: Classification of areas –
Combustible dust atmospheres
IEC 60079-10-2
Part 11 - Construction and test of intrinsically safe and associated
apparatus
IEC 60079-11
Part 13 - Construction and use of rooms or buildings protected by
pressurisation
IEC 60079-13
Part 14 - Electrical installations design, selection and erection
IEC 60079-14
Part 15 - Electrical apparatus with type of protection 'n'
IEC 60079-15
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 91
Part 17 - Inspection and maintenance of electrical installations
IEC 60079-17
Part 18 - Electrical apparatus with type of protection 'm'
IEC 60079-18
Part 25 - Intrinsically safe systems
IEC 60079-25
Surge arresters
Part 1 - Non-linear resistor type arrester for AC systems
IEC 60099-1
Diagrams, charts, tables
IEC 60113
Dimensions of ball and socket couplings of string insulator units
IEC 60120
Polyvinyl chloride insulated cables of rated voltages up to including
450/750 V
IEC 60227
Electric Cables - Calculation of the Current Rating - Part 3-1:
Sections on Operating Conditions - Reference Operating Conditions
and Selection of Cable Type
IEC 60287-3-1
Plugs, socket-outlets and couplers for industrial purposes
IEC 60309
Tests for electric cables under fire conditions – Circuit integrity
IEC 60331
Tests on electric cables under fire conditions
IEC 60332
Tests on electric cables under fire conditions Part 3 - Tests on
bunched wires or cables
IEC 60332-3
Electrical installations of buildings
IEC 60364
Electrical installations of buildings Part 3 - Assessment of general
characteristics
IEC 60364-3
Tests on insulators of ceramic material or glass for overhead lines
with a nominal voltage greater than 1000 V
IEC 60383
Insulators for Overhead Lines with a Nominal Voltage Above 1 000 V
- Ceramic Insulators for AC Systems Characteristics of string
insulator units of the long rod type
IEC 60433
Power Cables with Extruded Insulation and Their Accessories for
Rated Voltages from 1 kV (Um = 1,2 kV) up to 30 kV (Um = 36 kV) Part 2: Cables for Rated Voltages from 6 kV (Um = 7,2 kV) and up to
30 kV (Um = 36 kV)
IEC 60502-2
Degrees of protection provided by enclosures (IP Code)
IEC 60529
High-voltage fuses for the external protection of shunt power
capacitors
IEC 60549
Graphical symbols for diagrams
IEC 60617 DATABASE
Test on gases evolved during combustion of materials from cables –
Part 1: Determination of the halogen acid gas content
IEC 60754-1
Test on gases evolved during combustion of materials from cables –
Part 2: Determination of acidity (by pH measurement) and
conductivity
IEC 60754-2
Guide for the selection of insulators in respect of polluted conditions
IEC 60815
Selection and dimensioning of high-voltage insulators intended for
use in polluted conditions – Part 1: Definitions, information and
general principles
IEC TS 60815-1
Selection and dimensioning of high-voltage insulators intended for
use in polluted conditions – Part 2: Ceramic and glass insulators for
AC systems
IEC TS 60815-2
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 92
Shunt power capacitors of the self-heating type for AC systems
having a rated voltage up to and including 1 kV
IEC 60831
Shunt capacitors for AC power systems having a rated voltage
above 1 kV
IEC 60871
Shunt capacitors for AC power systems having a rated voltage
above 1000 V – Part 4: Internal fuses
IEC 60871-4
Short-circuit currents in three-phase AC systems – Part 0:
Calculation of currents
IEC 60909-0
Short-Circuit Currents in Three-Phase AC Systems - Part 1: Factors
for the Calculation of Short-Circuit Currents according to
IEC 60909-0
IEC 60909-1
Short-circuit currents in three-phase AC systems – Part 2: Data of
electrical equipment for short-circuit current calculations
IEC 60909-2
Short-circuit currents in three-phase AC systems – Part 3: Currents
during two separate simultaneous line-to-earth short circuits and
partial short-circuit currents flowing through earth
IEC 60909-3 CORR 1
Short-Circuit Currents in Three-Phase AC Systems - Part 4:
Examples for the Calculation of Short-Circuit Currents
IEC 60909-4
Shunt power capacitors of the non-self-healing type for AC systems
having a rated voltage up to and including 1000 V – Part 3: Internal
fuses
IEC 60931-3
Low voltage switchgear and controlgear Part 2 - Circuit-breakers
IEC 60947-2
Electromagnetic compatibility (EMC)
Part 3 - Assessment of emission limits for distorting loads in MV, HV
and EHV power systems
IEC TR 61000-3-6
Measurement of smoke density of cables burning under defined
conditions – Part 2: Test procedure and requirements
IEC 61034-2
Round wire concentric lay overhead electrical stranded conductors
IEC 61089
Protection against electric shock – Common aspects for installation
and equipment
IEC 61140
Electrostatics - Part 2-1: Measurement Methods - Ability of Materials
and Products to Dissipate Static Electric Charge
IEC 61340-2-1
Low-voltage switchgear and controlgear assemblies (all parts)
IEC 61439
Low-voltage switchgear and controlgear assemblies – Part 4:
Particular requirements for assemblies for construction sites (ACS) -
IEC 61439-4
Use and handling of Sulphur Hexafluoride (SF6) in High-voltage
switchgear and controlgear
IEC 61634
Safety of power transformers, power supplies, reactors and similar
products
IEC 61558
Mobile and fixed offshore units – Electrical installations
IEC 61892 (all parts)
Mobile and fixed offshore units – Electrical installations –
Part 4: Cables
IEC 61892-4
Power installations exceeding 1 kV AC Part 1: Common rules
IEC 61936-1
High-voltage switchgear and controlgear – Part 100: Alternatingcurrent circuit-breakers IEC 62271-100
IEC 62271-100
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 93
High-voltage switchgear and controlgear Part 200: AC metalenclosed switchgear and controlgear for rated voltages above 1 kV
and up to and including 52 kV
IEC 62271-200
Protection against lightning – Part 2: Risk management
IEC 62305-2
Hot dip galvanized coatings on fabricated iron and steel articles Specifications and test methods
ISO 1461
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 94
APPENDIX 1
A1.1
SELECTION OF ELECTRICAL APPARATUS FOR EXPLOSIVE GAS
ATMOSPHERES
SUITABILITY OF ELECTRICAL APPARATUS
1.
In order to select the appropriate electrical apparatus for hazardous areas, the process
engineer classifies the hazardous area and specifies the ignition temperature(s) and
the apparatus group(s) relating to the substances being processed, handled or stored.
NOTE:
2.
3.
A1.2
For further information on the classification of hazardous areas, and the properties of
flammable liquids, vapours and gases, refer to IEC 60079 series of publications.
Electrical apparatus with the following types of protection may be installed in the zones
indicated below:
Zone 0
ia ; ma ; s
Zone 1
d ; e ; px ; py ; ma ; mb ; o ; q ; ia ; ib ; s
Zone 2
n ; pz ; + equipment suitable for Zones 0 and 1
The requirements as laid down in (2.3) shall be taken into account.
CONSTRUCTION STANDARDS FOR ELECTRICAL APPARATUS
1.
Electrical apparatus of the different types of protection complies with the relevant
standards tabulated below.
2.
Construction standards for electrical apparatus for explosive gas atmospheres are
given in following table:
Type of protection
Ex
code
IEC
CENELEC
NEC (USA)
Flameproof enclosure
d
IEC 60079-1
EN 60079-1
UL 60079-1
FM 3600
Increased safety
e
IEC 60079-7
EN 60079-7
UL 60079-7
FM 3600
Pressurised apparatus
p
IEC 60079-2
EN 60079-2
NFPA 496
FM 3620
Encapsulation
m
IEC 60079-18
EN 60079-18
UL 60079-18
FM 3600
Oil immersion
o
IEC 60079-6
EN 60079-6
UL 60079-6
FM 3600
Powder filling
q
IEC 60079-5
EN 60079-5
UL 60079-5
FM 3600
Intrinsic safety
i
IEC 60079-11
IEC 60079-25
EN 60079-11
EN 60079-25
UL 60079-11
FM 3610
Non sparking
n
IEC 60079-15
EN 60079-15
UL 60079-15
FM 3600
Special protection
s
see Note 3
Explosion proof
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
UL 698
UL 886
FM 3615
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 95
NOTES:
1) The above table does not necessarily imply that the standards are identical.
2) Equipment to be installed in the EU need additional markings in accordance with the ATEX
directives.
3) Ex ‘s’ certification by a Notified Body in a particular country is not covered by an IEC or CENELEC
standard.
4) There are many Notified Bodies (previously called Authorised Certification Bodies).
Some examples are:
Baseefa in UK
PTB in Germany
LCIE in France
CSI in Italy
UL and FM in USA
CSA in Canada
A1.3
NORTH AMERICAN PRACTICE
The classification of hazardous (classified) areas is covered by DEP 80.00.10.13-Gen.,
which is based on API standards:
•
API RP 500 for division classification (traditional recommended practice)
•
API RP 505 for zone classification (more recent recommended practice that follows
same principle as IEC and CENELEC).
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 96
APPENDIX 2
1.
SYSTEM NEUTRAL EARTHING DIAGRAMS
The connection of the public utility will be subject to agreement with the public supply
authority. The above scheme (3) should be considered as indicative only.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 97
APPENDIX 3
A3.1
CONTROLS, INSTRUMENTS, INDICATIONS AND ALARMS
GENERAL
1.
This Appendix states the typical requirements for controls, instruments and meters,
status indications and alarms to be provided both locally and remotely for the various
types of electrical plant and equipment.
2.
The inclusion of any items identified as optional, and the need for any additional items,
shall be determined by the Principal. Protection devices are shown on the relevant
Standard Drawing S 67.
3.
The requirements at each location in the following tables are identified as follows:
4.
5.
A
= mandatory, if applicable;
C
= common (grouped) alarms, etc.;
I
= individual alarms, etc;
O
= optional, at the discretion of the Principal;
T
= close circuit breaker in test position only;
X
= mandatory;
(n)
= number of signals, e.g. (3) = three ammeters (one per phase).
The locations are as follows:
CCR
= central control room;
CP
= control panel;
FAR
= field auxiliary room;
LOC
= local, e.g. FAR, S/S or on generator skid;
SER
= system event recorder;
S/S
= substation.
Other abbreviations are as follows:
BC
= bus coupler;
BS
= bus section;
CB
= circuit breaker;
G/T
= generator transformer;
OLTC = on-load tap changer.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 98
A3.2
MAIN GENERATING SETS
Description
CCR
Location
S/S
HV swbd
LOC
Gen. CP
LOC
Driver CP
Controls:
Generating set - normal start
X
Generating set - auto start
X
X
Generating set - fast loading
A
A
Generating set - normal stop
X
X
Generating set - emergency stop
X
X
Generating set –
local/remote control selector switch
X
Isochronous/droop control
selector switch
A
Generating set - base/peak load
selector switch
A
Governor setpoint control
X
Generator CB control
X
XT
X
G/T OLTC - tap raise/lower
A
Field switch - on/off
X
Voltage regulator - auto/manual
selector switch
X
Description
CCR
Location
S/S
HV swbd
X
LOC
Gen. CP
Voltage regulator - voltage/p.f.
selector switch
A
Voltage setpoint control - auto
X
Voltage setpoint control - manual
X
P.F. setpoint control
A
Synchronising selector switch
X
LOC
Driver CP
Indications (status):
Generating set - local/remote control
X
X
Generating set - base/peak load
operation
A
A
Isochronous/droop operation
Generator CB - open/closed
A
X
Field switch - open/closed
Voltage regulator - voltage/p.f.
X
X
X
O
A
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 99
Instruments and meters:
Generator voltage
X
X(3)
X(3)
Generator frequency
X
X
X
Generator current
X
X(3)
X(3)
Generator real power
X
A
X
Generator reactive power
X
X
Generator power factor
X
X
Generator real energy summated
X
Generator reactive energy summated
X
X
Synchronising instruments
X
Field voltage
X
Field current
X
Stator temperature
X
Alarms:
Master trip relay(s)
X
X
X
Protection watchdog alarm
C
Stator temperature high alarm
X
X
O
Coolant temperature high alarm
X
X
O
G/T temperature high alarm
A
A
O
G/T Buchholz gas alarm
A
A
O
Excitation system alarm
X
X
O
Rotor earth fault
A
A
O
Auxiliary systems
X
X
O
I
O
All protection relays (trip)
X
Mechanical non-trip alarms
O
C
I
Mechanical trip alarms
O
C
I
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 100
A3.3
GRID INTAKE, POWER PLANT AND DISTRIBUTION SUBSTATIONS
Location
Description
CCR
S/S
HV swbd
LOC CP
CB control
O
X
X
sync relay and selector switch
O
X
tap raise/lower
O
A
AVR setpoint control
O
A
Controls:
Incoming feeder CB -
Incoming transformer OLTC -
auto/manual selector switch
A
Generator circuit controls
Refer to (A6.2)
BS/BC CB CB control
O
sync relay and selector switch
O
X
X
A
Outgoing feeder CB CB control
O
X
X
O
X
X
voltage
O
X
X
frequency
O
X
X
voltage
O
X(3)
X(3)
current
O
X(3)
X(3)
real power
O
X
reactive power
O
X
power factor
O
X
real power summated
O
X
reactive power summated
O
A
transformer tap position
O
A
Indications (status):
All CBs - open/closed
Instruments and meters:
Busbars (per section) -
Incoming feeder -
Generator circuit
BC current
Refer to (A6.2)
O
O
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
A
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 101
Outgoing feeder current (Note 1)
O
X
real power
O
O
reactive power
O
O
real energy (Note 2)
O
O
Location
Description
CCR
S/S
HV swbd
LOC
Annunciator
SER
All circuits - master trip relay(s)
O
I
I
I
Protection watchdog alarm
C
I
X
I
I
Alarms:
Switchgear tripping and closing
supplies battery/charger (each)
Description
CCR
O
Location
S/S
HV swbd
LOC Gen.
CP
LOC
Driver
CP
I
I
C
Trip circuit supervision
(per busbar section)
Loadshedding (per stage)
A
I
Annunciator repeat alarms
C
Annunciator fault
C
I
HVAC failure
A
I
A
I
Substation temperature
too high/too low
NOTES:
1. A thermal maximum demand ammeter may optionally be provided on the switchboard.
2. The real energy integrating meters may optionally be fitted with a maximum demand indicator.
4.
Where incoming supplies are metered by a Public Utility, check metering shall be
installed on the Principal's switchboard.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 102
A3.4
PLANT SUBSTATIONS (HV SWITCHBOARDS)
Location
Description
CCR
S/S
HV swbd
LOC
Annunciator
SER
Controls:
Incoming feeder CB control
X
BS CB control
X
Distribution feeder CB control
X
Motor control
XT
Indications (status):
Incoming feeder and BS CBs open/closed
X
IO
Distribution feeders - open/closed
X
IO
Motor feeders - open/closed
IO
Motor feeders - operations counter
X
X
Instruments and meters:
Busbar voltage (per section)
O
Incoming feeder voltage
X
X
Incoming feeder current
O
X
BS current
O
X
Distribution feeder current
O
X
Motor current
O
X
Motor hour run meter
X
Alarms:
All non-motor circuits master trip relay
C
I
I
C
I
X
Motor circuits - protection operated
I
I
Switchgear tripping and closing
supplies battery/charger (each)
I
I
Protection Watchdog alarm
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
C
O
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 103
Description
CCR
Location
S/S
HV swbd
LOC
Gen. CP
LOC
Driver
CP
I
I
C
Trip circuit supervision (per busbar section)
Annunciator repeat alarms
C
Annunciator fault
C
I
HVAC failure
A
I
A
I
Substation temperature
too high/too low
A3.5
VSDS (HV)
Location
Description
CCR
S/S
HV swbd
VSDS
Converter
Controls:
Normal start
X
X
Normal stop
X
X
Emergency stop
X
X
Local/remote selector switch
X
Supply switch control
Setpoint control
X
X
X
X
Drive stopped
X
X
Drive running
X
X
Supply switch - open/closed
X
X
Supply current
O
X
Speed
X
X
Process variables
A
A
Output voltage
O
X
Output current
O
X
Output power
X
X
Indications (status):
Instruments and meters:
Alarms:
Master trip relay
X
X
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 104
Protection Watchdog alarms
C
I
Protective devices on converter
I
Protection relays on switchgear
A3.6
I
Electrical non-trip alarms
I
I
Mechanical non-trip alarms
I
C
Mechanical trip alarms
I
C
SYNCHRONOUS MOTORS (HV)
Location
Description
CCR
S/S
HV swbd
LOC
CP
Controls:
Normal start
X
X
Normal stop
X
X
Emergency stop
X
X
Local/remote selector switch
X
CB control
X
Excitation setpoint control
X
X
X
X
Drive stopped
X
X
Drive running
X
X
CB -open/closed
X
X
Stator current
X
X
Real power
X
X
Reactive power
X
X
Power Factor
X
X
Indications (status):
Instrument and meters:
X
Field voltage
X
Field current
X
Stator temperature
X
Hour run meter
X
Alarms:
Master trip relay
X
X
Protection Watchdog alarm
C
I
Stator temperature high alarm
X
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
X
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 105
Coolant temperature high alarm
X
X
Excitation system alarm
X
X
Protection relays on switchgear
A3.7
I
Electrical non-trip alarms
I
I
Mechanical non-trip alarms
I
C
Mechanical trip alarms
I
C
ASYNCHRONOUS (INDUCTION) MOTORS (HV) > 500 kW
Description
CCR
S/S
HV swbd
Controls:
Normal start
X
Normal stop
X
Emergency stop
X
X
Indications (status):
Motor stopped
X
Motor running
X
Instrument and meters:
Stator current
X
X
Master trip relay
X
X
Protection Watchdog alarm
C
I
Stator temperature high alarm
X
Bearing temperature high alarm
X
Coolant temperature high alarm
X
Alarms:
Protection relays on switchgear
I
Electrical non-trip alarms
I
Mechanical non-trip alarms
I
Mechanical trip alarms
I
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 106
APPENDIX 4
ILLUMINATION LEVELS
1.
The required illumination levels, measured at the working plane or 1 m above the floor
level in a horizontal plane, are shown in the table below.
2.
These values are mean values and the uniformity ratio (Emin/Emean) is ¼ for normal
installations.
3.
These values shall be used as a basis for the design of new installations unless higher
illumination levels are required by national or local regulations in the country of
installation. The tabulated illumination levels apply when the luminaires are dirty, i.e.,
after taking account of the following fouling factors:
Location
fouling factor
Plant areas (both indoor and outdoor):
0.80
Non-plant areas (outdoor):
0.80
Non-plant areas (indoor):
0.85
REQUIRED ILLUMINATION LEVELS
Emean
(Lux)
Location
Notes
CONTROL ROOMS
General, including front of panel
300/500
Rear of panels
1, 7
150
Auxiliary rooms
150/300
Outside, near entrances
2
150
PLANT AREAS
Operating areas requiring regular
operator intervention
pumps, compressors,
generators, drivers,
valves, manifolds,
loading arms, etc.
150
Local control and monitoring
points
indicating instruments,
gauges and control
devices
75
Level gauges (see-through) to be lit from behind by single
tube fluorescent luminaries
Access ways:
walkways, platforms,
stairways, ladders,
module roofs
(offshore)
Plant and jetty approaches and road intersections
25
5
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
3
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 107
Emean
(Lux)
Location
Non-operational areas with limited attendance, e.g. tank
farms without equipment requiring regular operator
intervention.
Loading gantries:
Notes
0.5
top loading, walkways
and top of tankers
150
bottom loading
(coupling handling
area)
150
Road tanker parking area
25
Emean (Lux)
Location
Notes
NON-PLANT AREAS
Switchrooms, including relay and auxiliary rooms
200
Workshops and garages
indoor general
250
3
local on workbenches
and machine tools
400
4
outdoor storage and
handling areas
50
indoor between
storage racks
150
bulk storage
50
outdoor storage areas
5
Warehouses and stores
Laboratories and analyser rooms
Street lighting and fence lighting
400
lit by twin 40 W
fluorescent or single
70 W HP sodium
(SON) luminaires on
standard 8 m poles at,
typically, 50 m spacing
5, 6
NON-INDUSTRIAL AREAS
Canteens (dining areas)
Car parks
100
1
Catering areas (food preparation and serving)
300
Communications rooms
400
Computer rooms
400
Conference rooms
400
Corridors and stairways
100
Drawing offices
400
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
7
7
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 108
First aid rooms
400
Libraries and reading rooms
400
Lifts
100
Offices
400
Plant rooms
150
Print rooms
250
Reception areas
150-400
Recreation rooms and lounges
300
Store rooms
150
Toilets and locker rooms
100
NOTES:
1. 300 lux applies at night and 500 lux during the daytime. Control of the illumination level down to
100 lux should be possible either by switching off rows/groups of luminaires, or by use of
electronic dimmers, or both.
2. 150 lux applies for normal access and 300 lux for maintenance activities. The illumination level
should be controlled by switching each lamp in a twin fitting from separately controlled circuits or
by switching alternative fittings.
3. Where overhead travelling cranes are installed, floodlights should be fitted under the crane beam
to provide an illumination level of 400 lux for better illumination during maintenance.
4. In areas where very fine work is carried out, local lighting with higher illumination levels may be
required, e.g. 750 – 1000 lux on an instrument workshop bench.
5. Higher illumination levels apply where security fence lighting is required, e.g. for use with video
camera surveillance. These should be specified to be compatible with the video system utilised.
6. At the security barrier and checkpoint in front of site entrance gatehouses, higher illumination
levels may be required.
7. In rooms where VDUs are permanently installed, the lighting shall be designed to avoid reflections
and glare from the screens.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 109
APPENDIX 5
EQUIPMENT AND CABLE NUMBERING
A5.1
EQUIPMENT NUMBERING
A5.1.1
General
1.
Electrical machines shall be identified as stated in DEP 31.10.03.10-Gen.
2.
Electrical distribution and control equipment shall be identified by a number, thus:
WWxxxYz, where
•
WW is the two letter equipment reference as stated in (A5.1.2);
•
xxx is the three digit substation number as determined by the Principal;
•
Y is the one letter voltage identification as stated in (A5.1.3), or two letters for
transformers, one for each winding voltage;
•
NOTES:
z is the one or two digit sequence identification.
1.
For greenfield sites the substation number should be as follows:
The sources of power, i.e., Main Electrical Intake Station and/or Power Station Switchboard:
Alphabetic characters with if applicable an additional sequence number, e.g. MIS, PSS1,
PSS2;
HV substations fed directly from these substations: A three digit number with a prefix "SS",
e.g. SS-100, SS-200 etc. The first digit is a sequence number;
HV substations fed from another HV substation: A sequence number of the second digit,
e.g. SS-110, SS-210 etc.;
LV substations fed from an HV substation: A sequence number of the third digit, e.g.
SS-111, SS-201 etc.).
2. The sequence identification may be numbers and/or letters. Letters, e.g. A, B should be used
as the final character in the identification of several identical items of plant.
A5.1.2
Equipment references
The following references shall be used to identify the function of the equipment:
AP
=
Alarm panel;
CA
=
Capacitor bank;
CP
=
Control panel;
IR
=
Interposing relay box;
JB
=
Junction box;
RR
=
Resistor (earthing);
RX
=
Reactor;
SB
=
Switchboard;
TR
=
Transformer;
UP
=
UPS unit;
VS
=
VSDS
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 110
A5.1.3
Voltage identification
The following references shall be used to identify the nominal voltage level(s) of the
equipment:
A5.1.4
A5.2
A
=
60 kV and above;
B
=
20 kV – 33 kV;
C
=
10 kV and 11 kV;
D
=
3 kV - 6.6 kV;
E
=
LV (interruptible, maintained);
F
=
LV (DC) N = LV (essential and non-essential);
V
=
LV (uninterruptible, maintained);
X
=
LV (controls, alarms and indications, AC or DC).
Examples
1.
The first 6.6 kV switchboard in substation 110 is SB110D1.
2.
The third 400 V (AC) switchboard in substation 112 is SB112E3.
3.
The second 33/6.9 kV transformer located at distribution substation 300 is TR300BD2.
The tap change control panel associated with this transformer would be identified as
CP300X2.
CABLE NUMBERING
1.
Cable numbers shall be listed in the project cable schedule, DEP 05.00.54.84-Gen.
sheet 4, stating all the information specified. The destinations shall be specific, stating
the switchboard and panel numbers, etc.
2.
If cables having different voltages or differing functions have to be distinguished, the
sequence identification numbers should be sub-divided into blocks, e.g. 1000-1999 for
HV cables, 2000-2999 for LV cables, 3000-3999 for control cables, etc.
3.
A block of cable numbers should be allocated for site use, e.g. 1900-1999, 2900-2999,
etc.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 111
APPENDIX 6
DECISION PROCEDURE FOR ABOVE-GROUND OR UNDERGROUND CABLE
ROUTING
The following flowchart presents a method for evaluating whether to route cables aboveground (A/G) or underground (U/G), for on-plot areas of process plants.
Start
(Typically 20% into SELECT phase)
Gather following key inputs from
Project Team to populate high level
model for cabling evaluation.
Responsibility: Electrical Engineer
1)
HSSE
2)
Capex and Design
3)
Constructability / Schedule
4)
Operability / Maintainability
Refer to checklist
Workshop
Evaluate cabling option using the
populated high level model.
Chaired by: Project Manager
Facilitator: Electrical Engineer
Other participants: Process,
Mechanical
Is there a clear
driver to decide
cabling option?
NO
Adopt default as defined in (4.8.1).
YES
Prepare decision note for the
selected cabling policy
Responsibility: Electrical Engineer
Approved by: Project Manager
Output
Project Decision Note
Incorporate design option in Project
Execu ion Strategy
Responsibility: Project Manager
Output
PES incorporating strategy/
decision from model /
workshop
Optimise design layout, cable
routes, etc. and include in relevant
DEFINE documents.
Responsibility: Project Team
BDEP incorporation
design option
DECISION IMPLICATIONS
ASSESSED AT
CONSTRUCTABIITY WORKSHOPS
Review the following aspects with
respect to cabling:
1)
Layout optimisation
2)
Risk analysis and mitigation
3)
Effects on Procurement, logistics
and storage infrastructure
4)
Execution strategy
5)
Inclusion of relevant costs as per
strategy in the cost estimate
6)
Effect on overall completion
Output
POTENTIAL RISKS
IDENTIFIED AND
RECORDED FOR
MITIGATION IN FED 3
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 112
1.
The evaluation of underground and above-ground cable routing policy shall be made
by first identifying any key overriding drivers for the specific project using the check
lists below as a guide. These checklists are not exhaustive; other factors may also
need to be considered.
2.
In the absence of any clear overriding driver and/or to check the impact on capex, use
the spreadsheet model given in item B below to determine relative cost impact.
NOTE:
3.
This model is not for cost estimating. It is a simplified comparison of relative costs for above-ground
and underground cabling policy.
The main categories to consider are as follows:
A
HSSE
B
CAPEX AND DESIGN
C
CONSTRUCTABILTY AND SCHEDULE
D
OPERABILITY
A) MAIN HSSE RISK DRIVERS (Check list)
Close proximity to operational plant
•
Obstruction to operations due to heavy excavation machinery, Crane movements etc
•
Ignition source from construction activity
•
Impact on construction activity due to process upsets
•
Working near Live cables (underground or over head lines)
•
Contamination of ground by potentially Hazardous chemicals
Severe weather conditions
•
Heavy rain or snow, Risk of flooding etc
•
High winds. Cyclone/Typhoon risk area
•
High or low temperatures
Installation hazards
•
Many lifts around route resulting in risk of disruption due to clearing of area under lift.
•
Many truck movements near excavated trenching (loose soil)
•
Caving in of trenches due to Loose soil
•
Potential risk of falling objects due to other nearby work (concurrent working)
•
Pulling of heavy cables on above-ground trays
B) CAPEX AND DESIGN DRIVERS
Evaluate the relative capex costs for above-ground and underground cabling policy using
the spreadsheet model form in DEP 33.64.10.80-Gen.
The input data is in two sections
a) Project specific parameters
b) “Firm” data that has been pre-set in model (this data may only be changed with the
approval of the Principal).
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 113
Generally, (for greenfield sites) the cable material and installing costs are approximately
four to six times the cost for trenching or tray/structure. Hence, the parameter that has the
most impact is the labour rate and associated productivity and the higher number of
manhours per unit length to install cable on trays versus underground.
C) MAIN CONSTRUCTABILITY DRIVERS
Factor
Project specific condition
Comments
Local regulations
Regulation specifies
underground
Check for local regulations on constructability
and safety to decide the cabling option
Impact of schedule
delay
Schedule constrained
Very tight schedule with limited float in
combination with high impact of delay in start
up.
Level of congestion
within plant area
Congested layout may not
allow parallel working
Assess the layout to check the levels of
congestion:
Does the layout allow parallel working?
Is sequencing of activities a must considering
the congestion levels?
Is there a risk of disturbing / damaging cables
if laid U/G?
A layout that allows parallel working has a
neutral effect on cabling option, sequencing
requirements act as driver towards A/G
cabling to avoid delays
Other underground
services within the
plant area
High
1)
2)
High - drives towards A/G cabling
Moderate / Low - as a driver is
neutral
Ground water table
High
1)
High water table - drives towards
A/G cabling
Moderate / Low - is a driver that is
neutral
2)
Soil condition
Hard rock
1)
2)
3)
Cables supply
chain
Local or imported. Remote
site location.
Lead covered cables
specified
1)
2)
3)
Hard rock - Drives towards A/G
cabling
Soft rock - Check capex for decision
Other types - as a driver is neutral
Locally available - as a driver is
neutral
Import cable (Long lead) - drives
towards A/G cabling
Availability of lead covered cable for
contaminated ground.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 114
D) MAIN OPERABILITY DRIVERS
Operability drivers try to capture the “life cycle” factors, particularly potential lost production
issues associated with the decision of above-ground versus underground.
These are captured in three elements and should be assessed in conjunction with plant
operations specialists.
•
Risk of “flash” fires.
Consider the probability of flash fire, based on operational experience of similar plants and
consequential cost in lost production to repair cables and restore power. If this is
considered high then driver is for underground cable routing.
•
Future expansion (de-bottlenecking)
If regular changes (e.g. every 3-5 years) are expected due to the nature of the process then
consider the risk of disruption to production. If this probability is considered high, then this
would be a driver for above-ground cable routing.
•
Other factors, e.g.
o
Above-ground
1) Impact on maintenance access during a major plant shutdown.
2) Regular Inspection and potential partial replacement of tray/supports due to
corrosion.
o
Underground
1) Impact of future site clearance requirements to comply with National Environment
Regulations.
2) Soil settlement causing stress points resulting in failures.
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 115
APPENDIX 7
1.
DELIVERABLE DOCUMENTS
The table below should be used to
a. Produce the Discipline Delivery Plan as required by DCAF (Discipline Controls &
Assurance Framework) standard.
b. Define the documents to be produced by a design Contractor (e.g., EPC).
2.
TA1, TA2 and TA3 are technical authority levels currently defined in the Shell DCAF
system.
Project documents
SELECT
DEFINE
EXECUTE
Detailed Design
(TA Approval)
(TA Approval)
Deviation from choice of standards for
hazardous area classification and
equipment selection, installation and
inspection
X TA1
X TA1
X TA1
System Description including Power
Generation & Distribution Philosophy
X TA2
X TA2
X TA2
System Operation Philosophy
X TA2
X TA2
X TA2
Contractor
preparation
(TA Approval)
DESCRIPTIVE SECTIONS:
System Commissioning Philosophy
X TA2
X
X TA2
Control, Monitoring and Protection
X TA3
X TA3
X TA2
Emergency and Vital Supplies
X TA2
X TA3
X TA2
Electrical Load list
X TA3
X TA3
X TA3
X TA1
X TA1
Shell Documents:
Derogations from DEPs
Deviations/Amendments/Supplements
to DEPs
X TA2
List of Recommended Vendors
X TA2
OPCO Requirements
X TA3
X
X TA1
X TA2
X
X TA2
STUDIES:
Cable sizing calculations
X
X(s)TA3
X
X(m) TA2
Harmonic analysis
(X)
X TA3
Illumination levels
X
X TA3
(X)
X TA3
X
X TA3
X
X TA2
Equipment sizing calculation
X(m) TA2
Motor re-start and reacceleration after
voltage dip
Substations (quantity and location)
X TA3
X TA3
Power factor correction (if required)
Protection philosophy
X(m) TA2
Protection scheme & relay setting
schedules
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 116
Project documents
SELECT
DEFINE
EXECUTE
Detailed Design
(TA Approval)
(TA Approval)
Contractor
preparation
(TA Approval)
Short circuit & load flow
X(p) TA2
X TA2
X
X TA2
System dynamic stability and load
shedding
X(v)TA2
(X) TA2
(X)
X TA2
Motor starting
X(p) TA3
X TA3
X
X TA3
VSDS economics
(X) TA3
(X) TA3
SAFOP
(X) TA1
X TA1
X
X TA1
(X)
X TA2
X
X TA3
X
X TA3
X TA1
X
X TA2
X TA2
X
X TA2
HV switchboard single line diagrams
X
X TA3
Connection diagrams
X
X TA3
Control system block diagram
X
X(s) TA3
Schematic diagrams
X
EMC Review
Vital Supply Recovery Study
X(p) TA3
Arc Flash energy calculations
DRAWINGS:
X TA1
Key line diagram
Emergency and vital systems
S.L. diagrams
Protection and metering key diagrams
X(p) TA2
Protection setting document
X
X TA2
X
X TA3
X(w) (TA3)
Area classification layouts and sections
X(w) (TA2)
X
Cable routing layouts
X(m) TA2
X
X(m) TA3
Earthing layouts
X
X(m) TA3
Lighting and LV power layouts
(including buildings)
X
X(m)TA3
Power layout (motors, etc.)
X
X(m) TA3
X
X TA3
Trace heating system layouts
X
X TA3
Cable trench details
X
X TA3
Construction details
X
X TA3
X TA3
X
X TA3
Control, alarm and monitoring table
X TA3
X
X TA3
HV switchgear
X TA3
X
X(s) TA3
LV switchgear
X TA3
X
X(s) TA3
Substation layouts
Temporary installation(s) (construction
power supplies).
X(t) TA3
X TA3
SCHEDULES:
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 117
Project documents
SELECT
DEFINE
(TA Approval)
(TA Approval)
EXECUTE
Detailed Design
Contractor
preparation
(TA Approval)
X
X(s)TA2
Protection relay settings including
individual set point lists for all relay
protection parameters whether utilised
or not
Summary of Electrical Engineering
(electrical equipment summary sheets)
X TA3
X
X TA3
Utility data (electrical)
X TA3
X
X TA3
X TA2
X
X TA2
REQUISITIONS:
Generators
Luminaires
X
Motors (HV)
X(t) TA3
X
Motors (LV)
X(t) TA3
X
Remote control units (RCUs)
Switchgear (HV)
Switchgear (LV - MCC)
X(s) TA3
X
X TA3
X
X(s) TA2
X(t) TA3
X
X(s) TA3
Switchgear (LV - misc.)
X
Transformers
X(t) TA3
X
X(s) TA3
UPS units (AC)
X(t) TA3
X
X(s) TA3
UPS units (DC)
X(t) TA3
X
X(s) TA3
X TA2
X
X(s) TA2
VSDS
SPECIFICATIONS (as applicable):
X
Bulk materials
X
Cables
X(t) TA3
X
X(s) TA3
Motor operated valves (MOVs)
X TA3
X
X(s) TA3
Neutral earthing device
X TA3
X
X(s) TA3
Power factor correction
X TA3
X
X(s) TA3
Package units
X TA3
X
X(s) TA3
Process heaters
X TA3
X
X(s) TA3
X(t) TA3
X
X(s) TA3
Construction specification
X
X TA3
Design manual
X
X(s) TA3
X
X(s) TA3
X
X TA3
Trace heating
MISCELLANEOUS:
Equipment Bid Evaluation (Report)
X TA3
Equipment Bid Tabulations (Tech.)
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)
lOMoARcPSD|28844136
DEP 33.64.10.10-Gen.
February 2014
Page 118
Project documents
SELECT
DEFINE
(TA Approval)
(TA Approval)
EXECUTE
Detailed Design
Contractor
preparation
(TA Approval)
Operating manuals
X
X(s) TA3
Spare parts list (and SPIR)
X
X(s) TA3
Ex equipment register (in suitable
format for import into the computerised
maintenance management system)
X
X(s) TA2
Temporary installation (including
construction power supplies)
specification
X
X TA3
Test record forms (site)
X
X TA3
Testing procedures (site)
X
X(s) TA3
Vendor drawings
X
X(s) TA3
Vendor equipment certificates
X
X(s) TA3
Legend for Appendix 7:
(X)
=
If requested by Principal
(m)
=
Main
(p)
=
Preliminary
(s)
=
Selected
(t)
=
Typical
(v)
=
See (3.5.3 Note 5)
(w)
=
Deliverable is from Technical Safety – no approval by Electrical TA
(P1 and
P2)
=
Parts 1 and 2 only of the Summary of Electrical Engineering (electrical
equipment summary sheets).
This document has been supplied under license by Shell to:
Tebodin & Partners LLC kramesh@tebodin.co.om 30/03/2016 07:26:23
Downloaded by sotoj sotojm (sotoj73773@royalka.com)