p1268™/d7 draft standard for guide for safety in the...

P1268 /D7, January 2015 Draft Standard for Guide for Safety in the Installation of Mobile Substation Equipment

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This is an unapproved IEEE Standards Draft, subject to change.

P1268™/D7 1

Draft Standard for Guide for Safety in 2

the Installation of Mobile Substation 3

Equipment 4

Sponsor 5 6 Substations Committee 7 of the 8 IEEE Power & Energy Society 9 10 11 Approved <Date Approved> 12 13 IEEE-SA Standards Board 14 15 Copyright © 2014 by The Institute of Electrical and Electronics Engineers, Inc. 16 Three Park Avenue 17 New York, New York 10016-5997, USA 18

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vi

Participants 1

At the time this draft<opt_trial-use><gde./rec. prac./std.> was completed, the <Working Group Name> 2 Working Group had the following membership: 3

<Chair Name>, Chair 4 <Vice-chair Name>, Vice Chair 5

6 Participant1 7 Participant2 8 Participant3 9

Participant4 10 Participant5 11 Participant6 12

Participant7 13 Participant8 14 Participant9 15

16

The following members of the <individual/entity> balloting committee voted on this<opt_trial-17 use><gde./rec. prac./std.>. Balloters may have voted for approval, disapproval, or abstention. 18

[To be supplied by IEEE] 19

Balloter1 20 Balloter2 21 Balloter3 22



29

When the IEEE-SA Standards Board approved this<opt_trial-use><gde./rec. prac./std.> on <Date 30 Approved>, it had the following membership: 31

[To be supplied by IEEE] 32

<Name>, Chair 33 <Name>, Vice Chair 34 <Name>, Past Chair 35

Konstantinos Karachalios, Secretary 36

SBMember1 37 SBMember2 38 SBMember3 39



*Member Emeritus 46 47

Also included are the following nonvoting IEEE-SA Standards Board liaisons: 48

<Name>, DOE Representative 49 <Name>, NIST Representative 50

51 <Name> 52 IEEE-SA 53 <Name> 54 IEEE-SA 55

56 57

58




vii

Introduction 1

This introduction is not part of P<designation>/D<draft_number>, Draft<opt_Trial-Use><Gde./Rec. Prac./Std.> for 2 <Complete Title Matching PAR>. 3

<Select this text and type or paste introduction text> 4

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viii

Contents 1

TableofContents2

1. Overview .................................................................................................................................................... 1 3 1.1 Scope ................................................................................................................................................... 1 4 1.2 Purpose ................................................................................................................................................ 1 5

2. Normative references .................................................................................................................................. 2 6

3. Definitions .................................................................................................................................................. 2 7

4. Electrical clearances ................................................................................................................................... 3 8

5. Grounding ................................................................................................................................................... 3 9 5.1 General ................................................................................................................................................ 3 10 5.2 Safety criteria ....................................................................................................................................... 4 11 5.4 Methods of grounding ......................................................................................................................... 6 12 5.5 Connection to the existing grid ............................................................................................................ 7 13

6. Installation Procedures ............................................................................................................................... 8 14 6.1 Planning ............................................................................................................................................... 8 15 6.2 Surface/site preparation ....................................................................................................................... 9 16 6.3 Preparing the mobile substation for transport ...................................................................................... 9 17 6.4 Placing the mobile substation in service ............................................................................................ 10 18 6.5 Removing the mobile substation from service ................................................................................... 12 19

7. Enclosure practices ................................................................................................................................... 13 20 7.1 General .............................................................................................................................................. 13 21 7.2 Fence safety clearances ...................................................................................................................... 13 22 7.3 Warning signs .................................................................................................................................... 13 23

8. Protection of transformer .......................................................................................................................... 13 24 8.1 General .............................................................................................................................................. 13 25 8.2 Types of transformer failures ............................................................................................................. 14 26 8.3 Electrical detection of faults .............................................................................................................. 14 27 8.4 Mechanical detection of faults ........................................................................................................... 16 28 8.5 Fault clearing ..................................................................................................................................... 16 29

9. Work Practices ......................................................................................................................................... 17 30

10. Lighting .................................................................................................................................................. 17 31 10.1 Area lighting .................................................................................................................................... 17 32 10.2 Operational external light ................................................................................................................ 18 33 10.3 Alarm external light ......................................................................................................................... 18 34

11. Direct lightning stroke protection ........................................................................................................... 18 35

12. Surge protection...................................................................................................................................... 19 36

13. Arc flash ................................................................................................................................................. 19 37




ix

Annex A (informative) Bibliography ........................................................................................................... 20 1

Annex B (informative) Summary of relevant parts of Canadian and U.S. work practice related documents 21 2 B.1 Relevant codes and practices ............................................................................................................ 21 3

4 5




1

Draft Standard for Guide for Safety in 1

the Installation of Mobile Substation 2

Equipment3

IMPORTANT NOTICE: IEEE Standards documents are not intended to ensure safety, security, health, 4 or environmental protection, or ensure against interference with or from other devices or networks. 5 Implementers of IEEE Standards documents are responsible for determining and complying with all 6 appropriate safety, security, environmental, health, and interference protection practices and all 7 applicable laws and regulations. 8

This IEEE document is made available for use subject to important notices and legal disclaimers. 9 These notices and disclaimers appear in all publications containing this document and may 10 be found under the heading “Important Notice” or “Important Notices and Disclaimers 11 Concerning IEEE Documents.” They can also be obtained on request from IEEE or viewed at 12 http://standards.ieee.org/IPR/disclaimers.html. 13

1. Overview 14

1.1 Scope 15

This guide contains information on general topics and items pertaining to the installation of mobile 16 substation equipment. The guide recognizes that mobile substations vary widely regarding the particular 17 devices and equipment used. It is beyond the scope of this guide to provide a specific step-by-step set of 18 instructions for individual units. This guide covers installation of mobile substation equipment up to 245 19 kV. 20

1.2 Purpose 21

The purpose of this guide is to establish general transport, setup, and installation guidelines for the safe use 22 of mobile substation equipment. This guide has been developed with the intent to identify specific areas of 23 concern and offer design assistance in those areas. 24




2

2. Normative references 1

The following referenced documents are indispensable for the application of this document. For dated 2 references, only the edition cited applies. For undated references, the latest edition of the referenced 3 document (including any amendments or corrigenda) applies. 4

IEEE Std 80™, IEEE Guide for Safety in AC Substation Grounding. 5

IEEE Std 81™, IEEE. Guide for Measuring Earth Resistivity, Ground Impedance, and Earth Surface 6 Potentials of a Grounding System 7

IEEE Std 525™, IEEE Guide for the Design and Installation of Cable Systems in Substations. 8

IEEE Std 998™ , IEEE Guide for Direct Lightning Stroke Shielding of Substations. 9

IEEE Std 1427 Guide for Recommended Electrical Clearances and Insulation Levels in Air-Insulated 10 Electrical Power Substations 11

3. Definitions 12

For the purposes of this document, the following terms and definitions apply. The IEEE Standards 13 Dictionary Online should be consulted for terms not defined in this clause. 1 14

clearances: The separation between two conductors, between conductors and supports or other objects, or 15 between conductors and ground. 16

electric-supply equipment: Equipment that produces, modifies, regulates, controls, or safeguards a supply 17 of electric energy. 18

electric-supply station: Any building, room, or separate space within which electric-supply equipment is 19 located and the interior of which is accessible, as a rule, only to properly qualified persons. This includes 20 generating stations and substations, including their associated generator, storage battery, transformer, and 21 switchgear rooms. 22

exposed: Not isolated or guarded. 23

ground potential rise: The maximum electrical potential that a substation grounding grid might attain 24 relative to a distant grounding point assumed to be at the potential of remote earth. 25

live parts: Those parts that are designed to operate at voltage different from that of the earth. 26

metal-to-metal touch voltage: The voltage between metallic objects or structures within the substation site 27 that might be bridged by direct hand-to-hand or hand-to-feet contact. 28

mobile substation equipment: Substation equipment mounted and readily movable as a system of 29 transportable devices. 30

step voltage: The difference in surface potential experienced by a person not in contact with any grounded 31 object and whose feet are spaced 1 m apart. 32

1IEEE Standards Dictionary Online subscription is available at: http://www.ieee.org/portal/innovate/products/standard/standards_dictionary.html.




3

touch voltage: The potential difference between the ground potential rise and the surface potential at the 1 point where a person is standing while at the same time having one hand in contact with a grounded 2 structure. 3

transferred voltage: A special case of the touch voltage where a voltage is transferred into or out of the 4 substation from or to a remote point external to the substation site. 5

4. Electrical clearances 6

Guarding and clearances to energized parts are given in Rule 124 of the National Electrical Safety Code 7 (NESC). Clearances to energized parts for safety of personnel are given in Table 124-1 “Clearances from 8 Live Parts” of the 2012NESC unless adequate insulation or suitable barriers are provided. Rule 124A.3 of 9 the 2012NESC states a minimum of 2.6 m between any ungrounded part or parts of indeterminate potential 10 and any permanent supporting surface where workers might stand. Temporary structures might be required 11 to maintain proper clearances. 12

Phase-to-ground and phase-to-phase clearances will not be tested and therefore should follow the 13 requirements of IEEE Std 1427 or any other jurisdictional codes. Tested devices such as the mobile 14 substation (if tested) with its permanently installed equipment may have clearances that are less than those 15 of the temporary connections required to place the mobile in service. 16

5. Grounding 17

5.1 General 18

IEEE Std 80 provides general and specific guidelines for grounding substations and can be applied to 19 mobile substation equipment. IEEE Std 81 provides guidelines for the testing of grounding systems. This 20 clause is intended to discuss specific items that need special emphasis or special treatment. 21

Mobile substations or transformer trailers might be installed in many locations. The trailers might be 22 installed on utility property or non-utility property. On utility property, the mobile substation might be 23 installed inside or outside the permanent substation fence. The mobile substation located outside the 24 permanent substation fence might be located next to the substation, a distance away from the substation, on 25 the transmission line right-of-way, or on non-utility property. When the mobile substation is located outside 26 the substation fence or on non-utility property, special attention needs to be given to the touch and step 27 voltages at the mobile substation fence because it is the most likely point of contact by non-utility 28 personnel. Transferred potential rise between the mobile (and its fencing, if applicable) and the substation 29 needs to be managed. 30

31




4

1

5.2 Safety criteria 2

The basic shock situations for mobile substations are the same as for permanent substations, as indicated in 3 IEEE Std 80 and as shown in Figure 1 below. 4

5

6

7

8

9

10

11

12

13

14

15

16

Figure 1 —Basic shock situations 17

The purpose of the grounding system is as follows: 18

a) To provide a means to conduct electric current into the earth under normal and fault conditions 19

without exceeding any operating and equipment limits or adversely affecting continuity of service 20

b) To ensure that a person in the vicinity of grounded facilities is not exposed to the danger of 21

electrical shock greater than allowable by IEEE Std 80 22

Transferred voltage needs to be considered when a mobile substation is located outside a permanent 23 substation ground grid. If a minimal grounding system is installed around the mobile substation, this 24 transferred voltage might make it very difficult to satisfy tolerable touch and step voltage limits without 25 additional measures. Persons within the mobile substation fence can be protected with appropriate personal 26 protective equipment. 27

WARNING 28

The user is warned to protect the public outside the fence from high transferred touch and step voltages. 29

30




5

The grounding system is intended to limit the touch, step, and metal-to-metal touch voltages to acceptable 1 levels for personnel safety and safe equipment operation. If acceptable shock voltages are not achieved, 2 insulating gloves and/or boots can be worn by personnel working around the mobile substation. 3 Appropriate signs or barriers can be placed around the mobile substation. For a mobile substation located 4 outside the permanent substation fence, the touch voltage around the mobile substation fence might still be 5 a problem (see 5.4). 6

5.3 Items to ground 7

5.3.1 Fence 8

WARNING 9

The fence might be either connected to or isolated from the mobile substation grid. 10 Dangerous voltages can exist during a fault for either case and are described in the following list. 11

a) A dangerous voltage might exist if an isolated conducting (metallic) fence and the trailer 12

can be bridged by a person standing between them. Connecting the fence and trailer 13

together will lower the voltage between them. 14

b) If an ungrounded conductive temporary fence is installed adjacent to a grounded 15

substation fence, an isolation section might be necessary to prevent a transfer voltage on 16

the temporary fence. 17

c) If an isolated conductive temporary fence is installed, it will still attain a fraction of the 18

mobile substation ground potential rise (GPR) due to conduction through the earth, and 19

might pose a danger to persons touching the fence. 20

d) The use of non-conductive perimeter fences may be used to mitigate touch voltages. 21

5.3.2 Gate 22

A conductive gate can be bonded to a conductive fence and a bonding conductor can be installed across the 23 gate opening. If the gate swings outward, a loop conductor can be installed to control the touch voltages 24 when opening the gate. If the gate opens inward, no special grounding might be needed unless the fence is 25 isolated from the mobile substation’s ground grid. A jumper can be installed across the gate opening to 26 provide continuity to the perimeter conductor. 27

5.3.3 Trailer Frame 28

The trailer frame and/or trailer ground bus can be connected to the mobile substation grid with a conductor 29 of a size adequate to carry the available fault current. If the trailer has no ground bus for the equipment 30 connections, all equipment and the trailer can be connected to the mobile substation ground grid using 31 separate, properly sized conductors for each piece of equipment. Multiple trailers (e.g., a switch and fuse 32 trailer used with a mobile transformer trailer) can be connected via the mobile substation grid or a direct 33 cable tie to prevent voltages between them. 34

35




6

WARNING 1

Take caution while any maintenance is performed on the trailer 2 (e.g., changing or removing tires and adjusting jacks) while the unit is in service. 3

Movable (e.g., slide-out switch bases) or removable conducting parts (e.g., steps, dollies) can be connected 4 to the trailer ground bus or the ground grid, or both, to minimize voltages between them. 5

5.3.4 Cable shield grounding 6

Cable shields can be grounded. If the cable shield is to be grounded at both ends, the shield can be sized to 7 conduct fault current or a separate parallel conductor can be installed to prevent excessive current flowing 8 in the shield. Refer to IEEE Std 525 for further guidance. 9

5.3.5 Operator platforms, plates, or insulating mats 10

In the absence of a properly designed ground grid, or to supplement a properly designed ground grid, 11 operator platforms, plates, and/or special mats can be installed and connected to the grid at all switches and 12 handles that are accessible from the ground. The special mats can be conductive, insulating, or a 13 combination conductive mesh covered by insulating material. 14

5.3.6 Neutral grounding 15

Neutral conductors of adequate fault-current capacity can be installed from the mobile transformer to the 16 grid. Feeder neutrals can be connected to the provided attachment point (neutral bushing) or directly to the 17 grid. Transmission line shield wires can be connected to the grid to lower the complete grounding system 18 resistance. Due to the higher resistance of a separate mobile substation grid not connected to the permanent 19 substation grid, a high percentage of the fault current will flow on the neutral and transmission line shield 20 wires. In some cases, the current limits of these wires might be exceeded by return currents. 21

When the mobile substation is located outside the permanent substation fence, the permanent and mobile 22 substation grids can be connected together to lower the GPR. Installation of two or more ground cables is 23 desirable to reduce the inductive reactance between the two ground mats and to lower the transient 24 overvoltages. Feeder neutrals and transmission line shield wires are most often left attached to their 25 terminations at the substation buses, with power cables connecting the mobile substation to these buses. 26 The connection of the mobile substation neutral to the permanent substation neutral bus or ground grid will 27 provide another ground connection between the two grids. 28

5.3.7 Temporary equipment 29

Any temporary equipment connected to the trailer or equipment on the trailer can be grounded to the grid 30 or trailer ground bus. 31

5.4 Methods of grounding 32

5.4.1 Mobile substation grounding 33

A mobile substation installed inside a substation fence might have the trailer or trailers connected to the 34 substation grid in a minimum of two locations. A mobile substation located outside and away from the 35




7

substation might require different considerations. If the GPR from the permanent substation grid transfers 1 to the often minimal mobile substation grid, it might be difficult to provide adequate safety for persons 2 inside and outside the mobile substation fence. In such cases, persons inside the fence can be protected 3 using appropriate personal protective equipment. For protection of persons outside the fence, see 5.4.2. A 4 low impedance ground path is required to allow operation of protective devices. This might be 5 accomplished by connection of the mobile substation to the permanent substation grounding, connection to 6 the system neutral, or by a separate mobile substation grounding system. 7

The length of service and the location of the mobile substation are factors in determining the design of the 8 mobile substation ground grid, including what grounding to install and what deviations from standard 9 practices are acceptable. The grid conductor might be placed on the soil surface and connected to driven 10 ground rods to help lower the touch voltage and hold the cable in place. A buried conductor and ground 11 rods would result in lower touch voltages during a fault. A counterpoise or portable ground mat installed on 12 the soil surface might be a solution to the touch voltage hazard when a minimal grounding system is 13 installed. This mat might be installed over all or part of the mobile substation area. A layer of high-14 resistivity material might be installed to help increase the acceptable levels of touch and step voltages. The 15 safe practice of wearing insulating gloves and/or boots might be considered for all personnel inside the 16 mobile substation fence when it is located away from the permanent substation fence. 17

5.4.2 Mobile substation fence grounding 18

The fence around the mobile substation is the most likely point of contact by non-utility personnel. The 19 fence is often constructed to a lower standard than a permanent fence because it is a temporary installation. 20 The protection of persons outside the fence from both touch and step voltages requires different 21 considerations that are dependent on the available short circuit current. For conductive fences, a buried 22 perimeter conductor, either attached to or isolated from the mobile substation grid, might be used. A non-23 conductive fence can be used as one alternative although other alternatives can be designed. For conducting 24 (metallic) fences, a buried perimeter conductor outside the fence can be installed and connected to the fence 25 to lower the touch voltage. A layer of rock or other high-resistivity material might be installed inside the 26 fence, 1 m outside the fence, or both. A rock layer will increase the contact resistance of a person’s foot and 27 will lower the body current. The fence fabric and barbed wire might be connected to the grid according to 28 local code requirements and accepted utility practices. See Error! Reference source not found. for gate 29 grounding methods. 30

WARNING 31

When the mobile substation is located outside the permanent substation and a common side is 32 shared with the utility or a customer, isolation sections or insulated fencing might be necessary 33

to prevent a dangerous transferred voltage from being conducted on the adjacent fence. 34

If the mobile substation is located outside and/or away from the permanent substation, take special care to 35 ensure that the touch and step voltages at the fence are acceptable. In the absence of a normally designed 36 and installed grounding system, it might be preferable to isolate the mobile substation fence from the grid. 37 In some cases, especially when the mobile substation is some distance away from the permanent substation, 38 a solution might be the use of non-conductive fence. 39

5.5 Connection to the existing grid 40

Above-grade connections might be installed between the permanent substation grid and the mobile grid. 41 When this method is used, consider the following: 42

a) Tripping hazard 43




8

b) Exposure to high current during fault conditions 1

c) Exposure to cable movements under electromechanical forces during fault conditions 2

An above-grade connection is accessible not only to utility personnel but also to non-utility personnel and 3 animals. A fence or other barriers can avoid this accessibility. 4

A below-grade connection eliminates these above-grade hazards, but involves additional time and cost to 5 install. If the connection is from utility property to non-utility property, a removal cost of the connecting 6 conductor might be incurred when the mobile substation is removed from service. 7

6. Installation Procedures 8

6.1 Planning 9

Successful utilization of a mobile substation is dependent on detailed planning of the installation. Mobile 10 substation sites can be selected for suitability prior to emergency situations to facilitate proper installation 11 in a timely manner. 12

A site within an existing substation can be selected based on a review of the existing substation drawings 13 and a field inspection of the location. Sites outside an existing permanent substation can be selected to keep 14 the need for grading to a minimum. The proximity to required facilities, such as transmission and 15 distribution lines, and an adequate space to satisfy the mobile substation physical size, electrical clearances, 16 and access requirements need to be considered. This includes related equipment, such as oil tankers and 17 service or test equipment. 18

If the mobile substation is to be installed at an existing facility the following aspects could be considered: 19

a) Space for the installation and transportation of mobile equipment 20

b) Access space to remove failed equipment or for construction to expand substation 21

c) Installation of high voltage and / or low voltage switches to avoid outages to install mobile 22

equipment 23

d) Installation of devices capable of interrupting transformer parallel current when removing mobile 24

equipment 25

e) Installation of foundation to provide level location for mobile equipment 26

f) Means to connect mobile equipment to ground grid. 27

The proposed mobile substation travel route can be reviewed to ensure that all physical clearance 28 requirements and weight restrictions including any specific local codes are satisfied. The need for any 29 special insurance or permits can be determined and they can be obtained from the appropriate departments 30 or agencies. 31

Oil spill containment can also be considered in the selection of the site, wherever feasible. It might be 32 possible to utilize the oil spill containment measures in the permanent substation, even when the mobile 33 substation is placed outside the permanent substation fence. In other cases, temporary oil spill containment 34 measures might be utilized, where required by national or local codes. 35




9

1

In addition to the details of planning for installation at specific sites, studies can be done to determine the 2 impact of the mobile substation on the performance and protection of the electric distribution system. 3 Standard protective relay settings might be applicable and can be determined prior to required use. 4

Safety analysis and grounding system design for specific sites can be predetermined prior to required use in 5 order to make appropriate plans and have required materials available for quick installation. 6

6.2 Surface/site preparation 7

6.2.1 Existing substation sites 8

The site is selected to allow connection to the various power and control systems in a safe and efficient 9 manner. Maintain working clearances for the mobile substation and permanent substation equipment. 10 Additional support material can be installed (matting, cribbing, etc.) as necessary in poor soil conditions 11 resulting from seasonal variations (rainy seasons, spring thaw conditions). Review substation drawings for 12 routing/location of temporary equipment (e.g., control cables, power cables, barrier materials). 13

6.2.2 New temporary locations 14

The site can be graded for drainage and equipment installation. Installation of the ground grid is based on 15 the guidance found in Clause Error! Reference source not found.. Install proper fencing to secure the 16 site. 17

6.2.3 All locations 18

Obtain operational clearance as required, and install any temporary structures required for primary or 19 secondary connections. Install any temporary bus and temporary high-voltage jumper connections as 20 required for the mobile substation. 21

6.3 Preparing the mobile substation for transport 22

Prepare the mobile substation for transportation to the site in accordance with the relevant jurisdictional 23 transportation authority and manufacturer’s instructions. This includes the transformer, switches, breakers, 24 control/relay systems, and all connections. Verify shipping dimensions, and inspect the trailers, tires, etc. 25

Include the following items in a general inspection of the mobile substation prior to transportation: 26

a) Check the oil level in all tanks, compartments, and bushings and perform dissolved gas in oil tests. 27

b) For units with a nitrogen blanket, verify that the gas supply is adequate and that the cylinder is in 28

the transport position. 29

c) Verify that arresters are secured in the transport position. 30

d) Check high-voltage power fuses, if equipped. 31

e) Close the bottom valves of the cooling system to decrease the possibility of oil leaks during transit. 32




10

f) Inspect high- and low-side disconnect switches and verify that blades are clamped in the closed 1

position. 2

g) Verify that a set of instruction manuals and control drawings are with the unit. 3

h) Lock and secure all cabinet doors for transit. 4

i) Verify that all shipping braces, rock guards, and protective covers are secured for transit. 5

j) Verify that bushing shorting jumpers are in place. 6

6.4 Placing the mobile substation in service 7

6.4.1 Positioning the mobile substation 8

Position the mobile substation so the route of the temporary high-voltage primary and secondary 9 conductors will not interfere with maintenance of existing substation equipment. 10

WARNING 11

Barricade power and ground cables placed on the ground between the permanent and mobile substations to 12 guard against personnel injury from the whipping action of those cables in the event of a fault. 13

If feasible, constrain these cables to minimize movement in the event of a fault. Verify electrical and 14 working clearances. Some mobile substations, due to low profile, might require barriers even if placed 15 inside the fenced substation. 16

6.4.2 Leveling the mobile substation 17

When leveling the mobile substation: 18

a) Block and level all mobile substation trailers. 19

b) Support the weight of the mobile substation on temporary cribbing. 20

c) Allow no more than 5° deviation from level in any direction (side to side, front to rear). 21

6.4.3 Grounding the mobile substation 22

Connect the mobile substation to the ground grid utilizing Clause Error! Reference source not found.. 23 When making connections between the mobile equipment and another grounding system, consider the 24 possibility of voltage hazards and take suitable precautions. See IEEE Std 80 2013 section 18.5 for details. 25 Avoid routing of temporary ground risers in vehicle traffic areas. Verify continuity of the mobile 26 substation’s ground bus and all connections to equipment. Connect the neutral bushing(s) of the 27 transformer to system neutral with an appropriately rated conductor. 28

6.4.4 Inspection of equipment after transport 29

Check equipment (transformer, bushings, arresters, breaker, insulators, switches, relays, etc.) for damage 30 and oil leaks after transport. Check the following for proper levels and functions: 31

a) Oil levels in transformer tank, compartments, and bushings 32




11

b) Transformer tank pressure 1 c) Pressure relief device 2

6.4.5 Testing 3

Refer to manufacturer’s instructions for recommended tests prior to energization. The following tests are 4 suggested: 5

a) Transformer 6

1) Transformer turns ratio 7

2) Insulation, oil dielectric, and dissolved gas in oil tests 8

b) Circuit-interrupting devices 9

1) High-potential dielectric tests on interrupting devices 10

2) Insulation and dielectric tests 11

c) Current transformer 12

1) Transformer turns ratio 13

3) Insulation tests 14

d) Relays 15

e) Operational test—primary and secondary current injection test 16

6.4.6 Equipment setup 17

Install the mobile substation in accordance with the manufacturer’s instructions. Install lightning protection 18 systems and verify all connections to the arresters and the ground grid. 19

6.4.7 Pre-energization check items 20

Prior to energization, verify the following: 21

a) Power cable connections 22

b) Control and data acquisition 23

c) Station service 24

d) System neutral 25

e) Cooling system, including fan and pump operation (proper rotation) and valve position 26

f) Transformer tap position 27

g) Operation of load tap changer 28




12

h) Transformer primary protective device 1

i) Coordination of relays/trip circuit checks/alarms 2

j) Battery and charging systems 3

k) System phasing 4

l) Mobile substation grounding, including fence, and all grounding connections 5

m) Electrical clearances 6

n) Barriers and warning signs 7

o) Electrical operation of protective devices 8

p) Operation and alignment of disconnect switches 9

q) Stress cone orientation 10

r) Oil containment considerations 11

s) Connections to local remote terminal unit (RTU) 12

t) Check pressure on gas-interrupting devices 13

u) Record any control wiring changes 14

6.4.8 Energizing the mobile substation 15

Energize and load the mobile substation in accordance with established operational practices. Periodically 16 record load, oil temperature, and winding temperatures. Also, consider obtaining periodic gas-in-oil 17 samples and analysis while the unit is in service. 18

6.5 Removing the mobile substation from service 19

De-energize the mobile substation in accordance with established operational practices and manufacturer’s 20 instructions. Obtain an oil sample for a dissolved gas-in-oil test. 21

Keep the mobile substation cooling system in operation until top oil temperature has dropped to an 22 acceptable level. 23

6.5.1 Preparing the mobile substation for transport to storage 24

Prepare the mobile substation for transportation to storage in accordance with Error! Reference source 25 not found.. 26

6.5.2 Preparing the mobile substation for storage 27

Store the mobile substation in accordance with the manufacturer’s instructions. This includes checking the 28 power for battery and cabinet heaters, the battery charger float voltage, and the grounding. General 29 inspection and testing, such as oil circulation, nitrogen pressure, oil testing, tire integrity, and other general 30 maintenance, are suggested to allow for any needed repairs prior to the next deployment. 31




13

7. Enclosure practices 1

7.1 General 2

Section 110 of the 2012 NESC requires all electric supply stations to include fences, screens, partitions, or 3 walls to form an enclosure to minimize the possibility of entrance of unauthorized persons or interference 4 by them with equipment inside. Jurisdictional codes or standards might allow waiver of certain rules for 5 emergency or temporary installations. It is the responsibility of the entity installing the mobile substation to 6 determine if the installation qualifies for such a waiver. 7

WARNING 8

In general, avoid such noncompliance to the extent possible, and correct any condition 9 that might endanger persons or property as soon as practical. 10

7.2 Fence safety clearances 11

Rule 110.A of the 2012 NESC provides guidance on locating fence with respect to live parts. In accordance 12 with the NESC, locate exposed live parts outside the safety clearance zone. 13

7.3 Warning signs 14

Display appropriate signs. Consideration might be given to locating signs on all sides of the mobile 15 substation enclosure. Refer to ANSI Z535.2 for further guidance in designing and locating the signs. 16

8. Protection of transformer 17

8.1 General 18

a) Protect the transformer for the following reasons: 19

b) To electrically isolate the faulted unit from the system so that the system can continue to function 20

c) To limit damage to the faulted unit 21

d) To minimize the possibility of a fire 22

e) To minimize hazards to personnel 23

Faults internal to the transformer quite often involve a low magnitude of fault current relative to the 24 available fault current at the terminals. For such conditions to be detected, a protection scheme with high 25 sensitivity and high speed, as found in a transformer differential scheme or sudden pressure relay scheme, 26 might be required. 27

The choice of interrupting device can be made considering the required interrupting capability, cost, 28 weight, size, and isolating switch requirement. Fuses have the advantage of low cost, weight, and size, and 29 they incorporate a visual open break. They do not protect well against some types of faults. Also, fuses are 30 not generally used to energize or de-energize the transformer and therefore might require a separate device 31




14

for this purpose. Circuit breakers or other types of interrupting devices, such as vacuum switches or circuit 1 switchers, cost more than fuses and usually weigh more and are larger. However, they permit more 2 sensitive relay protection and can be used to energize or de-energize the transformer. For detailed 3 information on transformer protection, refer to IEEE Std C37.91. 4

8.2 Types of transformer failures 5

When considering transformer protection, the ability of the scheme to detect and clear the following types 6 of failures might be considered: 7

a) Winding failures 8

b) Tap changer failures 9

c) Bushing failures 10

d) Terminal board failures 11

e) Core failures 12

f) Cooling system failures 13

g) Miscellaneous failures 14

8.3 Electrical detection of faults 15

8.3.1 Fuse protection 16

Fuses have the merits of being economical and requiring little maintenance. No dc battery supply or current 17 transformers are needed. Fuses can reliably protect some power transformers against primary and 18 secondary external faults. They will provide limited protection for internal faults. Generally, more sensitive 19 means for protection from internal faults are provided for transformers of 10 MVA (base rating) and higher. 20 Fuses have been used at higher transformer ratings depending on the available fuse ampere ratings and the 21 ability to coordinate with upstream protection devices. The operation of one fuse on a three-phase system 22 will not necessarily de-energize the fault. If the fault is not de-energized, the resulting single-phase service 23 might be detrimental to the connected polyphase and single-phase motors and other loads. If required, add 24 special protection for single-phasing conditions. 25

Base the selection of the fuse and proper ampere rating on the following factors: 26

a) Fuse fault-interrupting capability and available system fault current 27

b) Maximum anticipated peak load current, daily peak loads, emergency peak loads, maximum 28

permissible transformer load current, and the applicable transformer through-fault current 29

protection curve 30

c) Hot-load pickup (inrush current upon instantaneous reclosing of source-side circuit breaker) and 31

cold-load pickup (inrush current and undiversified load current after an extended outage) 32

d) Available primary system fault current and transformer impedance 33

e) Coordination with source-side protection equipment 34




15

f) Coordination with low-side protection equipment 1

g) Maximum allowable fault time on the low-side bus conductors 2

h) Transformer connections and grounding impedance as they affect the primary current for various 3

types of secondary faults 4

i) Maximum degree of sensitivity for detection of high-impedance faults 5

j) Transformer magnetizing inrush 6

Ampere rating selection is facilitated by data published by fuse manufacturers. Such data include time-7 current characteristic curves, preloading adjustment curves, ambient temperature data plus daily and 8 emergency peak-loading tables. 9

Mobile and portable transformers are frequently designed and constructed with a higher-than-standard 10 winding temperature rise to reduce their size and weight. Therefore, they have reduced overload capability. 11 Consider this also when selecting the fuse rating. 12

8.3.2 Differential protection 13

Current differential relaying is a common type of protection for transformers of approximately 10 MVA 14 (base rating) and above. The term differential relaying refers to a current transformer connection scheme in 15 which the net operating current to the relay is the difference between input and output currents to the zone 16 of protection. 17

18

The following three general classes of relays are typically used with this current differential scheme: 19

a) Time overcurrent relay, which might include an instantaneous trip unit having a high-current 20

setting. 21

b) Percentage differential relay, with restraint actuated by the input and output currents. 22

c) Percentage differential relay, with restraint actuated by one or more harmonics in addition to the 23

restraint actuated by the input and output currents. Most modern transformer differential relays are 24

this type. 25

Current transformer connections and ratios can be such that the net current in the relay operating coil for 26 any type or location of external fault is effectively zero, unless relay current matching taps are available. 27 Most modern relays have current matching taps. 28

8.3.3 Overcurrent relay protection 29

A fault external to a transformer can result in damage to the transformer. If the fault is not cleared 30 promptly, the resulting overload on the transformer can cause severe overheating and failure. Overcurrent 31 relays (or fuses, see 8.3.1) can be used to clear the transformer from the faulted bus or line before the 32 transformer is damaged. On some small transformers, overcurrent relays can also protect in the case of 33 internal transformer faults, and on larger transformers, overcurrent relays can be used to provide a backup 34 for differential or sudden pressure relays. 35




16

8.4 Mechanical detection of faults 1

8.4.1 Sudden gas-pressure relay 2

The sudden gas-pressure relay is applicable to all gas-cushioned oil-immersed transformers and is mounted 3 in the area of the gas space. It consists of a pressure-actuated switch, housed in a hermetically sealed case 4 and isolated from the transformer gas space except for a pressure-equalizing orifice. 5

The relay operates on the difference between the pressure in the gas space of the transformer and the 6 pressure inside the relay. An equalizing orifice tends to equalize these two pressures for slow changes in 7 pressure due to loading and ambient temperature change. However, a more rapid rise in pressure in the gas 8 space of the transformer due to a fault results in operation of the relay. High-energy arcs produce a large 9 quantity of gas, which operates the relay in a short time. The operating time is longer for low-energy arcs. 10

8.4.2 Sudden oil-pressure relay 11

The sudden oil-pressure relay is applicable to all oil-immersed transformers and is mounted on the 12 transformer tank wall below the minimum liquid level. If an internal fault develops, the rapid rise in oil 13 pressure or pressure pulse is transmitted by the transformer oil and operates a relay. Small rises in oil 14 pressure (e.g., due to changes in loading or ambient temperature) are also transmitted by the transformer 15 oil. However, the pressure is relieved by equalizer holes, and the relay and the switch do not operate. Relay 16 sensitivity and response to a fault are independent of transformer-operating pressure. 17

8.5 Fault clearing 18

A faulted transformer can be separated from its power source by fault-clearing devices such as circuit 19 breakers, remote tripping of circuit breakers via transfer trip, fault-initiating switches, circuit switchers, 20 vacuum switches, or fuses. In addition to separating the transformer from its power source, consider 21 tripping oil pumps and fans to reduce their possible adverse effects in sustaining or spreading an oil fire. 22

Determination of the type of fault-clearing devices to be used involve the following considerations: 23

a) Installation and maintenance cost 24

b) Fault-clearing time relative to fire hazard and repair or replacement costs of the transformer 25

c) System stability and reliability 26

d) System operating limitations 27

e) Device-interrupting capability 28

8.5.1 Circuit breakers 29

Circuit breakers directly actuated by a protective relay system are usually provided where it is desirable to 30 isolate a faulted transformer with minimum effect on other segments of the power system. They offer the 31 fastest fault-clearing time and highest interrupting capability. 32




17

8.5.2 Remote tripping of circuit breakers 1

In some situations it is difficult to justify the cost of local circuit breakers. Tripping of remote-source 2 circuit breakers by use of local relays and communication channels, or by use of fault-initiating switches 3 (high-speed ground switches) are alternatives. When remote tripping is used, a power-operated 4 disconnecting switch is usually connected on the source side of the transformer to isolate the transformer 5 from the system. The switch is arranged to open automatically and cancels the remote-transfer trip signal, 6 or isolates the ground switch from the system. In both cases, this permits the remote breakers to reclose. 7

8.5.3 Fault-initiating switch 8

Remote tripping of circuit breakers can be accomplished by operating a high-speed ground switch. This 9 applies a solid phase-to-ground fault on the source line so that remote line relays will detect it and trip the 10 remote circuit breakers. A disadvantage of this scheme is the additional time required for the ground switch 11 to close and the remote relays to detect the fault. Also, the ground switch phase and faulted phase(s) on the 12 transformer might be different, thus imposing a multiphase fault on the system. Other disadvantages 13 include the disturbance caused by placing a bolted fault on the system and an outage to other customers 14 connected to the source line(s). 15

8.5.4 Circuit switcher 16

A circuit switcher is a mechanical switching device with an integral interrupter, suitable for making, 17 carrying, and interrupting currents under normal circuit conditions. It is also suitable for interrupting 18 specified short-circuit current that is less than its close-and-latch, momentary, and short-time current 19 ratings. Note: This device might be suitable for transformer protection where the majority of faults are 20 limited by the transformer and system impedance. If possible, coordinate remote line relays to avoid remote 21 tripping for the lower magnitude faults. High-magnitude source-side faults on the transformer exceeding 22 the interrupting rating of the circuit switcher can be detected by remote line relays and cleared by the 23 remote breakers before the circuit switcher opens. The circuit switcher might be blocked from tripping 24 using an instantaneous overcurrent relay, or it might be allowed to attempt interruption depending on user 25 preference. 26

9. Work Practices 27

The references listed in Clause 2, the Canadian Occupational Health and Safety Regulations [B4], or the 28 Regulations and Procedures of the Occupational Safety and Health Administration (OSHA) [B10] have 29 sections that cover general work practices for electrical equipment. Follow the applicable sections to ensure 30 safe work practices for installation of the mobile substation. Annex B lists relevant sections for these 31 references. Users of this guide outside the U.S. and Canada might refer to equivalent documents in their 32 countries. If no such documents exist, it is suggested that the listed documents be considered. 33

10. Lighting 34

10.1 Area lighting 35

General illumination for security of the mobile substation area can often be part of the initial substation 36 design process. When allocating space for the mobile substation within the permanent substation fenced 37




18

area, consider permanent or temporary lighting-fixture locations and aiming of floodlight-type fixtures to 1 accommodate the mobile substation. 2

If it is necessary to position the mobile substation outside the station fence, then it might be practical to 3 install temporary lighting fixtures. The permanent station fence posts, especially the corner posts, can 4 provide a place for locating temporary lighting masts by attaching the lighting masts to the fence posts with 5 U-bolts or other suitable hardware. 6

In addition to fixed lighting units (either permanent or temporary), a wide variety of portable lights exist. 7 These portable units can be as small as hand-held extension-type lights or considerably larger devices on 8 tripods. When determining the size and quantity of receptacles to be provided with the mobile substation, 9 consider the particular type of plug-in lighting units used by substation repair crews. 10

10.2 Operational external light 11

Lights can be mounted on the mobile substation trailer to indicate when the mobile substation is energized. 12 Position the lights to be clearly visible from the front, sides, and rear. 13

10.3 Alarm external light 14

A blinking alarm light can be mounted in a readily visible location on the mobile substation and connected 15 such that it will be energized by an alarm relay that is activated by selected alarm conditions. 16

11. Direct lightning stroke protection 17

The risk of direct lightning strokes to mobile substations is typically less than for permanent substations for 18 the following reasons: 19

a) Mobile substations are usually installed for relatively short periods of time. The time of exposure, 20

therefore, is low compared to permanent substations, and this leads to a lower probability that a 21

direct stroke will occur. 22

b) The area occupied by the installation is small compared to large switchyards or long transmission 23

lines. For a given ground flash density, therefore, the probability of a stroke to the area will usually 24

be quite low. 25

c) Mobile substations are low in profile to comply with maximum height restrictions for highway 26

travel. As a result, they are less susceptible to attracting direct strokes and might be partially 27

shielded by adjacent structures or transmission lines. 28

29

Nevertheless, for installations in areas of high lightning activity, installations of long duration, or for 30 installations on flat, open areas, it is prudent to provide direct stroke shielding for the installation. Refer to 31 IEEE Std 998 for guidance. 32




19

Before installing special shielding, the engineer can check the proposed site for existing shielding. If 1 existing substation structures, overhead shield wires, or phase conductors provide adequate shielding for 2 the mobile substation, no further shielding is necessary. 3

12. Surge protection 4

The shielding from direct strokes as discussed in Clause 11 does not, of course, provide any protection 5 from surges coming in on the line conductors or from nearby direct strokes. The mobile transformer can be 6 fitted with surge arresters located near its terminals to provide this protection. Connect the arresters to the 7 protected equipment and ground grid or equipment frame with leads as short and straight as possible. 8

Low weight and the ability to be installed quickly are critical factors in mobile substation design. Selecting 9 arresters with polymer housing can reduce arrester weight by about 70%. Mobile transformers often 10 provide multiple voltage taps. Because of their wide protective margins, it is sometimes possible to select a 11 metal-oxide arrester that will cover more than one voltage level. This arrangement speeds installation since 12 arrester shunts do not have to be reconnected. It also reduces weight and height. See IEEE Std C62.22 for 13 guidance in the application of metal-oxide surge arresters. 14

13. Arc flash 15

As in permanent substations, arc flash is a safety concern in mobile substations. Follow the same safety 16 program in mobile substations as in permanent substations. 17

18




20

Annex A 1

(informative) 2

Bibliography 3

[B1] Accredited Standards Committee C2, National Electrical Safety Code® (NESC®). 4

[B2] ANSI C37.32™-2002, American National Standard for Switchgear—High Voltage Air Switches, 5 Bus Supports, and Switch Accessories—Schedules of Preferred Ratings, Manufacturing Specifications, and 6 Application Guide. 7

[B3] ANSI Z535.2, Environmental and Facility Safety Signs. 8

[B4] Canadian Electrical Code, Part I, 22nd Edition (C22.1-12), Safety Standard for Electrical 9 Installations. 10

[B5] Canadian Occupational Health and Safety Regulations ( SOR/86 -304 ), Department of Justice, 11 CANADA 12

[B6] IEEE 100™, The Authoritataive Dictionary of IEEE Standards Terms, Seventh Edition. 13

[B7] IEEE Std C37.91™, IEEE Guide for Protective Relay Applications to Power Transformers. 14

[B8] IEEE Std C62.22™, IEEE Guide for Application of Metal-Oxide Surge Arresters for Alternating-15 Current Systems. 16

[B9] NFPA 70, 2005 Edition, National Electrical Code® (NEC®) 17

[B10] Occupational Safety and Health Administration’s Regulations and Procedures, Volume I—General 18 Industry Safety Standards, Part 1910, and General Construction Standard, Part 1926. 19

20




21

Annex B (informative) 1

Summary of relevant parts of Canadian and U.S. work practice related documents 2

B.1 Relevant codes and practices 3

Jurisdictional authorities might have their own approved codes and practices, and can be referenced in lieu 4 of the publications listed in this annex. 5

B.1.1 Canada 6

Canadian Occupational Health and Safety Regulations ( SOR/86 -304 ) [B4],addresses safety regulations. 7

B.1.2 OSHA’s Regulations and Procedures – U.S. 8

OSHA Regulations and Procedures [B10] contains two subparts (R and S) in Volume I of the General 9 Industry Standards and Interpretations that are applicable to electrical work. 10

Subpart R covers special industries and is applicable to the operation and maintenance of electric power 11 generation, control, and transformation, along with distribution and transmission lines and electrical 12 equipment, and includes electrical utilities. 13

Subpart S addresses electrical safety requirements for the practical safeguarding of employees in their 14 workplace. However, this subpart is not applicable to indoor or outdoor installations under the exclusive 15 control of electrical utilities for the purpose of communications or metering, or the generation, control, 16 transformation, transmission, and distribution of electrical energy. Because its purpose is the practical 17 safeguarding of personnel from hazards arising from the use of electricity, parts of it have been included as 18 reference material. 19

Appendix A, associated with Subpart R and Subpart S of this document, contains two flowcharts that are 20 useful in helping the user decide which subpart of this document governs the electrical work being 21 undertaken. Table 1, included in Appendix A, identifies the relevant sections of Subpart R that are in 22 compliance with the requirements of Subpart S, and which other sections in Subpart R still apply regardless 23 of compliance with Subpart S. 24

B.1.3 NEC—U.S. 25

Although the NEC is purely advisory in nature and does not have jurisdiction over electrical utilities, it has 26 been included as a reference because its purpose is the practical safeguarding of persons and property from 27 hazards arising from the use of electricity. 28

B.1.4 NESC—U.S. 29

The NESC covers the work practices that are necessary for the safeguarding of employees and the public 30 from possible hazards arising from electrical lines and equipment. 31




22

B.1.5 Canadian Electrical Code, Part I—Canada 1

Although Part I of the Canadian Electrical Code (CEC) [B1] does not have jurisdiction over electrical 2 utilities, it has been included as a reference because it contains practical information covering electrical 3 work and electrical equipment. 4