2014 Testing, Inspection & Maintenance Plan

2014 Testing, Inspection &

Maintenance Plan Annual Planning Report

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

2

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

3

2014 Testing, Inspection & Maintenance Plan Annual Planning Report

Executive Summary Hydro Ottawa’s testing, inspection and maintenance (TIM) programs are crucial to ensuring a reliable and

sustainable distribution system. Information from the testing, inspection and maintenance programs feed

back into the Asset Management Plan to allow for effective life-cycle planning of assets. Currently, there are

many different types of testing, inspection and maintenance activities that are used to gain asset

information, health information required for the determination of replacement and/or maintenance

prioritization in order to increase asset reliability and longevity.

The TIM Annual Planning Report was developed to serve as a summary and guide of the current activities,

data collection methodologies as well as to identify the gaps in the existing practices.

In 2013, most of Hydro Ottawa Distribution TIM programs met inspection targets within budget. The

programs that did not meet inspection targets include critical switch inspection and pole inspection. These

programs have no outside services budget and rely on availability of Hydro Ottawa resources to complete the

scope of work.

In 2013, most of Hydro Ottawa Station TIM programs did not meet target number of inspections and were

under budget. The Station’s maintenance information is transitioning to new software called PowerDB that

has limited reporting function. Hydro Ottawa is working with the PowerDB software to create effective

inspection reports to summarize Station TIM program performance numbers. This will allow for proper

evaluation of Station TIM program data. Stations TIM programs often do not meet targets as Station

resources are heavily focused on capital projects.

Through the examination of the various maintenance programs, a common theme was seen: a lack of a long

term plan, finances and available resources. This document will outline the current and future requirements

in order to identify the activities that need more or less attention and resources.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

4

Contents Executive Summary .................................................................................................................................. 3

1 Background ...................................................................................................................................... 5

1.1 Purpose of the Testing, Inspection, and Maintenance Plan ................................................................ 5

2 Distribution Testing, Inspection and Maintenance ............................................................................. 6

2.1 Infrared (IR) and Visual Inspection ....................................................................................................... 7

2.2 Padmount Switchgear CO2 Wash ....................................................................................................... 12

2.3 Civil Structure Inspections .................................................................................................................. 14

2.4 Vegetation Management ................................................................................................................... 16

2.5 Insulator Washing .............................................................................................................................. 18

2.6 Cable Inspection ................................................................................................................................. 20

2.7 Critical Switch Inspections.................................................................................................................. 22

2.8 Pole Inspections ................................................................................................................................. 24

2.9 Graffiti Abatement ............................................................................................................................. 26

2.10 Vault Maintenance ............................................................................................................................. 28

3 Station Testing, Inspection, and Maintenance .................................................................................. 30

3.1 Battery Maintenance ......................................................................................................................... 31

3.2 Relay Maintenance ............................................................................................................................. 33

3.3 Transformer Maintenance ................................................................................................................. 34

3.4 Transformer Oil Analysis Testing ........................................................................................................ 36

3.5 Transformer Doble Testing ................................................................................................................ 37

3.6 Station Visual Inspections .................................................................................................................. 38

3.7 Tap Changer Maintenance ................................................................................................................. 40

3.8 Stations Infrared (IR) Inspection ........................................................................................................ 43

3.9 Switchgear Maintenance ................................................................................................................... 44

4 SCADA Maintenance - Stations and Distribution .............................................................................. 51

4.1 Program Details .................................................................................................................................. 51

4.2 Program Schedule .............................................................................................................................. 51

4.3 Program Performance Indicators ....................................................................................................... 51

4.4 Data Governance ................................................................................................................................ 51

4.5 Reactive Maintenance ........................................................................................................................ 51

4.6 Gap Analysis ....................................................................................................................................... 51

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

5

1 Background

1.1 Purpose of the Testing, Inspection, and Maintenance Plan The intention of the Testing, Inspection and Maintenance (TIM) Plan is to document the asset TIM practices

used by Hydro Ottawa Limited (HOL) as part of the optimized lifecycle strategy for distribution and station

assets. The objective of the TIM plan is to outline the current and future requirements in order to identify the

activities that need more or less attention and resources to ensure a sustainable and reliable system.

The TIM Plan is a key component of the maintenance planning process which will identify the HOL

maintenance programs, the type of assets the maintenance is being performed on, the current maintenance

schedule, budgeting information, and identify any gaps in the current programs.

Ongoing TIM programs have been sustained by HOL with limited involvement from the Asset management

group in the past. In the interest of better leveraging the current activities, for the purposes of inclusive asset

management, a review has been undertaken of the current programs and practices. The TIM Plan serves as a

summary and guide of the current activities and data collection methodologies.

The purpose of the Hydro Ottawa TIM programs is to test, inspect and maintain the equipment to gather

equipment information for use in asset lifecycle planning. Testing of equipment involves using test/metering

devices to obtain equipment, material or component condition information either during equipment

operation or shutdown. Inspection of equipment usually refers to visual or infrared inspection through which

equipment nameplate information, physical equipment condition and operating temperature of equipment is

obtained. Maintenance activities refer to the physical work being performed on the equipment and can

include cleaning, torquing, greasing, operating the equipment, or replacing components.

Many of the TIM programs are evolving from utilizing paper forms for data capture, which are extremely

difficult to analyze, to new portable inspection tablets. These tablets allow for the electronic entry of

inspection information creating data sets that are easily queried and analyzed.

Hydro Ottawa’s TIM Plan is divided into three categories: Distribution, Stations, and SCADA. These sections

will define the current TIM programs, including scheduling, data governance, reactive maintenance and gap

analysis.

Further development of the TIM programs will continue to improve scheduling, analyses, and more efficient

use of inspection resources. All of these items will drive the optimization between asset maintenance versus

replacement.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

6

2 Distribution Testing, Inspection and Maintenance

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

7

2.1 Infrared (IR) and Visual Inspection Hydro Ottawa performs infrared (IR) and visual inspection

for many of its assets. The IR inspections allow crews and

contractors to examine equipment operating temperature

to detect defective components, poor connections, or

overloaded equipment which can indicate the potential for

failures. Visual inspections are important to monitor

cleanliness, ease of access, obtain updated nomenclature

and equipment information, and to assess damage and any

potential follow-up activities required.

In order to effectively use the IR scanning information, an

equipment health index was created

and is used for all IR scanned equipment

(see Table 2.1). The condition rating is

based on the temperature difference

between the reference temperature

and the equipment’s actual measured

temperature. Equipment that is within

the critical temperature range has an Outage Management System (OMS) ticket created to schedule

immediate repair. It is the responsibility of the area supervisor to schedule the work and close out the ticket

when the issue is verified to be resolved.

2.1.1 Padmount Switchgear

2.1.1.1 Program Details The padmount switchgear inspection consists of IR

scanning and a visual inspection of air-break

switchgear. The IR scan detects loose connections,

tracking, overloaded equipment, and other heat

related problems. Visual inspection includes recording equipment information as well as checking for

swollen elbows, exposed electrical hazards, operating hazards, rusting and graffiti.

2.1.1.2 Program Schedule Padmount switchgear is inspected on a three year cycle (see Table 2.2). Hydro Ottawa contracts out these

inspections to a qualified third party. The switchgear cycle transpired from historical cleaning records.

The Ontario Energy Board (OEB) minimum inspection for switchgear requires they are patrolled in urban

areas at a maximum interval of 3 years and in rural

areas at a maximum interval of 6 years.

2.1.1.3 Program Performance Indicators In 2013, Hydro Ottawa completed 82 out of 83

switchgear inspections (see Table 2.3).

The number of air brake switchgear and cost of the

program continues to decrease, as they are replaced

with newer SF6 switchgear.

TABLE 2.2 - SWITCHGEAR INSPECTION

Frequency 2013 Budget

Every 3 Years

(90 switchgear / year)

$14,000

TABLE 2.1 - INFRARED CONDITION RATING

Critical - (>75°C), immediate repair

Major Problem - (>36°C-75°C), repair as soon as possible

Intermediate - (>10°C- 36°C)

Minor - 10°C or less

TABLE 2.3 - 2013 INSPECTION ACTUALS

2013

Budget

Actuals

Switchgear

Inspection

Target

Switchgear

Inspection

Actuals

Cost of

Inspection

/ SG

$11,748 83 82 $143

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

8

2.1.1.4 Data Governance Inspection records are currently being stored in an Access database with the information found in Table 2.4.

The inspection records can be viewed in the Hydro Ottawa Portal via GIS asset attribute tab hyperlink.

TABLE 2.4 - SWITCHGEAR INSPECTION STORED INFORMATION

Manufacturer Comments Hinges OK

Model Type Contact Condition Base Pad Condition

Year of Manufacture Fault Indicators Vault Condition

Voltage Class (in kV) Follow Up Action Required Penta Bolt

No SW Fuse Ways Comments Lock

Fuse Sizes Exterior Condition Visible Gap Lid/Door

Insulation Lifting Bolts Removed Operation Type

SCADA Control Safety Labels IR Temp

Contact Condition Unit ID Label Hot Stick Operation

Fault Indicators Exterior SW Oper Label Oil Leak

Follow Up Action Required Access to Location Internal Labeling to Spec

2.1.1.5 Reactive Maintenance Equipment that is considered critical condition will have an OMS ticket created for immediate follow-up

action. It is the responsibility of the area supervisor to schedule the work and close out the ticket when the

issue is resolved.

Most of the switchgear hot spots can be mitigated by cleaning connections, replacing minor components or

tightening connections. If the switchgear is unable to be improved through minor maintenance it will be

prioritized for replacement.

Switchgear that pose a safety, environmental or operating concern and are deemed defective are scheduled

for immediate replacement.

2.1.1.6 Gap Analysis The data captured through the infrared inspection needs to be fed back into the maintenance and Physical

Asset Management Plan. Determination of the number of switchgear undergoing maintenance and

replacement due to the influence of IR is required. Maintenance cost versus the replacement needs to be

analyzed to be incorporated in long term planning.

Information collected from the inspections needs to be fed back into GIS to verify base data, equipment

information and nomenclature.

Currently, there is no TIM program for the SF6 switchgear. In accordance with the manufacturers

recommendations no mechanical maintenance is required for the SF6 switchgear. The manufacturer

recommends occasional inspection of the switchgear and exercising the load interrupter switches and fault

interrupters. In addition to the manufacturer’s recommendations an inspection program should verify gas

pressure, record overall equipment condition and complete an infrared inspection of elbow connections.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

9

2.1.2 Padmount and Kiosk Transformers

2.1.2.1 Program Details The padmount and kiosk transformer inspections consist of an infrared scan and a visual inspection. Infrared

scanning detects loose connections, tracking, equipment overload, and other heat related problems. Visual

inspection checks for swollen elbows, exposed electrical hazards, operating hazards and graffiti. Additional

patrol inspection is performed as a result of the Graffiti Abatement and Repainting program.

2.1.2.2 Program Schedule Padmount transformers and kiosk transformers are inspected on

a three year cycle (see Table 2.5).

The OEB minimum inspection requirements dictates that

padmount transformers are to be patrolled in urban areas at a

maximum interval of 3 years and in rural areas at a maximum

interval of 6 years.

2.1.2.3 Program Performance Indicators In 2013, Hydro Ottawa inspected 99.7% of the

targeted padmount or kiosk transformers (see Table

2.6). The target number of transformers for 2013 was

higher as some of the scope from 2012 carried over.

Transformer bulk inspection lowers cost per

inspection with comparison of the air break

switchgear.

2.1.2.4 Data Governance Hydro Ottawa contracts out the padmount transformer inspections to a qualified third party. Currently, the

inspections are being completed using HOL tablets and the records are being stored in an Access database

with the information found in Table 2.7.


XFMR

Inspection

Target

XFMR

Inspection

Actuals

2013

Budget

Actuals

Cost per

XFMR

Inspected

6,156 6,137 $220,086 $36.00

TABLE 2.5 - PADMOUNT INSPECTION

Frequency 2013

Budget

Every 3 Years

(5000 transformers /

year)

$300,000

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

10

TABLE 2.7 - TRANSFORMER INSPECTION STORED INFORMATION

Exterior Condition Spot Primary (degrees C) Elbow Manufacturer

Lifting Bolts Removed Spot Secondary (degrees C) Open Point

Safety Labels Spot Tank (degrees C) Open Point LA

Unit ID Label Spot Ambient (degrees C) Insulators

Access to Location Connected to phase XFRM ID Lbl Inside

Hinges OK Integ Sec Conn Asbestos

Base Pad Condition Elbow Condition Prim Lbl Per Spec

Vault Condition Tap Changer Sec Lbl Per Spec

Penta Bolt Curr Limt Fuse Manufacturer

Lock Fuse Type Year of Manufacture

Visible Gap Lid/Door Fault Ind Serial Number

Operation Type Fault Ind Correctly Installed Condition Rating

Hot Stick Operation Under Oil LBS Follow Up Action Required

Oil Leak Insert Vent Follow Up Action

Internal Labeling to Spec Elbow Posi Break Comments

2.1.2.5 Reactive Maintenance Equipment that is considered critical condition will have an OMS ticket created for immediate follow-up

action. It is the responsibility of the area supervisor to schedule the work and close out the ticket when the

issue is resolved.

Most of the transformer hot spots can be mitigated by cleaning connections, replacing minor components or

tightening connections. If the transformer is unable to be improved through minor maintenance it will be

prioritized for replacement.

Transformers that pose a safety, environmental or operating concern and are deemed defective are

scheduled for immediate replacement.

2.1.2.6 Gap Analysis Confirmation is required that the infrared inspection information is fed back into the maintenance and

replacement plan. The number of transformers undergoing maintenance and replacement due to the

influence of IR scans needs to be determined. The cost of maintenance versus the cost of replacement needs

to be analyzed for incorporation in future planning.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

11

2.1.3 Overhead Equipment

2.1.3.1 Program Details Overhead switches, transformers, lines, and associated

attachments are inspected through the IR Scanning Program.

The IR Scanning Program consists of performing infrared

inspections on overhead equipment from ground level.

Equipment that is over a temperature threshold is flagged as requiring further investigation.

2.1.3.2 Program Schedule All overhead power lines and associated apparatus, including switches and transformers, are scanned on a

three year cycle (see Table 2.8). Hydro Ottawa contracts out these inspections to a qualified third party.

The OEB minimum inspection requirement for overhead conductors and cables is to patrol urban areas at a

maximum interval of 3 years and rural areas at a maximum interval of 6 years.

2.1.3.3 Program Performance Indicators The target area for overhead insulator IR scan was completed and was under budget in 2013.

2.1.3.4 Data Governance Any problematic equipment in the critical equipment temperature range, as per Table 2.1, is included in a

report which is later given to Hydro Ottawa in paper and PDF format.

2.1.3.5 Reactive Maintenance Any equipment that is identified as a priority for maintenance will be further investigated for remediation of

any problems. The hot spots that are found usually indicate that connections need to be torqued and/or

cleaned, equipment needs to be replaced, or the equipment is being overloaded.

2.1.3.6 Gap Analysis The need for ultrasonic surveying should be investigated for the purpose of identifying equipment that is

tracking, but not yet overheating. Confirmation is required to determine if the contractor is trained and has

the proper equipment to conduct ultrasonic inspections while completing the infrared scanning.

The infrared inspection information must be fed back into the maintenance and replacement plan. The

number of overhead assets undergoing maintenance and replacement due to the influence of IR scans needs

to be determined. The cost of maintenance versus the cost of replacement needs to be analyzed for

incorporation into the development of long term plans.

Digital Image Thermal Image

TABLE 2.8 – OVERHEAD IR SCAN

Frequency 2013

Budget

2013

Actuals

1/3rd of the City

Every 3 Years

$15,000 $13,770

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

12

2.2 Padmount Switchgear CO2 Wash

2.2.1 Program Details Currently, all identified air-brake switchgear are being CO2

washed by contractors to remove contamination, such as road

salt or dirt, that contributes to tracking and flashover. To

eliminate the contamination’s impact on the IR results, the

switches are washed prior to performing IR scan. The carbon

dioxide is mixed with clean compressed air at the spraying

nozzle and safely removes surface contamination from both energized and de-energized internal equipment.

CO2 wash allows switchgear to be cleaned while energized, is environmentally friendly, safe, and will increase

system reliability by removing surface contamination that can lead to flashover.

C02 Wash: Before CO2 Wash: After

2.2.2 Program Schedule Currently, air-break switches are being washed on a 3 year cycle. The program schedule was developed based

on the switchgear cleaning prioritization that organized the switches based on their last CO2 wash.

The OEB minimum inspection requirements dictate that switchgear be patrolled in urban areas at a

maximum interval of 3 years, and in rural areas at a maximum interval of 6 years. CO2 wash is a

supplementary maintenance activity from the OEB’s minimum

inspection requirements.

2.2.3 Program Performance Indicators Hydro Ottawa had 79 out of 82 switchgear cleaned (see Table 2.10).

The remaining switchgear were inaccessible with the CO2 wash

equipment. These switchgear will continue to have visual and IR

inspections to ensure acceptable operating conditions. The number

of air brake switchgear and cost of the program continues to decrease, as they are replaced with SF6

switchgear.

TABLE 2.9 – SWITCHGEAR CO2 WASH

Frequency 2013 Budget 2013

Actuals

Every 3 Years

$100,000 $54,510


SG Wash

Target SG Washed

Cost per

Switch

82 79 $690

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

13

2.2.4 Data Governance The CO2 wash information is being stored in a dedicated directory. The information is contained in an

inspection sheet completed by the contractor as well as a photo of the gear taken before and after the

cleaning (see Table 2.11).

2.2.5 Reactive Maintenance Equipment that has noticeable damage or requires further attention is reported to HOL for further

investigation. An OMS ticket is then entered for scheduling of the work. It is the responsibility of the area

supervisor to schedule the work and close out the ticket when the issue is resolved.

2.2.6 Gap Analysis The switchgear CO2 wash period will be reviewed to determine if the switchgear is being over washed and if

the cycle should be adjusted to make the program more cost effective. A method to determine if the wash

cycle is too frequent is to perform an IR scan prior to and after cleaning to prove a temperature change.

Ultrasonic testing is another method that will be investigated for use to determine the intensity of tracking

prior to and after the CO2 wash.

Switchgear failure analysis should trend the time between CO2 washing and the equipment failure to

evaluate the current CO2 wash cycle and the effectiveness of the wash.

The program should integrate the use of the inspection tablets to easily capture the CO2 wash inspection

information.

TABLE 2.11 – CO2 WASH STORED INFORMATION

Support Insulators Connection Pad Foundation

Switch Insulators Fault Indicators Latch/Mech Bolt

Arc Supressors Excess Moisture Door Hinges

Cable Terminations Evidence of Overheating Paint Condition

Barrier Boards Evidence of Arcing Nomenclature

Grounding Infrared Inspection Pad Grade/Level

Fuse holder Metal Enclosure Graffiti

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

14

2.3 Civil Structure Inspections

2.3.1 Program Details The manhole inspection program targets 300

manholes annually as part of a 10 year inspection

cycle. Underground chambers are also inspected

through regular work activities when crews perform

scheduled work in manholes and handholes.

2.3.2 Program Schedule All of the manholes will have undergone inspection

by 2017. Once all manholes are completed,

inspection or new build information will be

available for every HOL manhole. This will allow for

accurate prioritization of refurbishment and/or

replacement.

The OEB minimum inspection requirement for civil

infrastructure dictates that all structures be inspected

as part of patrol or in the course of doing routine work,

for urban civil structures at a maximum interval of 3

years and for rural structures at a maximum interval of

6 years.

The inspection will continue to meet 300 manholes per year to ensure a 10 year inspection cycle is

maintained. The civil structures are being inspected to

meet the OEB requirements through routine utility work.

2.3.3 Program Performance Indicators In 2013, Hydro Ottawa surpassed its target and had 589

manholes inspections logged (see Table 2.13). This large

inspection surplus was due to Hydro Ottawa resources

completing inspection during routine work along with two

contracted inspectors.

2.3.4 Data Governance Planned inspection of manholes is completed by a third

party contractor using HOL tablets. Hydro Ottawa crews also complete inspections when the civil structure is

entered as part of regular work activities. Inspection records are currently being stored in an Access

database containing the information found in the Table 2.14.

TABLE 2.12 – REMAINING INSPECTION FOR BASELINE

Manholes Inspected or

installed since 1999

Remaining Manholes to

be Inspected for Baseline

1716 1437

TABLE 2.13 – MANHOLES INSPECTED IN 2013

Inspector Manholes

Inspected

Cost per

Manhole

Greely 312 $300

Pipetek 31 $100

HOL 277 $100

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

15

TABLE 2.14 – MANHOLE INSPECTION STORED INFORMATION

Cover Location Sewer Connections

Okay

Sensors Okay Flat Sleeve Floor Rating

Cover Size Pump Required Asbestos Present Leaking Cables Racks Rating

Cover Condition Cleaning Required Asbestos Damaged Collar Rating Inspector Name

Cover Requires

Maintenance

Water Glass

Required

Swollen Sleeve Roof Rating Follow up Action

Sewer Connection Sump Pump Okay Split Sleeve Wall Rating Remarks

2.3.5 Reactive Maintenance The manholes that are considered to have critically poor components are reported to Hydro Ottawa for

immediate attention. These manholes will be investigated by Hydro Ottawa and will have work prioritized for

refurbishment or replacement.

2.3.6 Gap Analysis A review must be conducted to determine if inspection of handholes, equipment pads and other civil

structures requires a formal inspection program. Risk of possible civil structure failure will be compared to

the cost and benefit of the inspections to determine the extent of the program.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

16

2.4 Vegetation Management

2.4.1 Program Details Vegetation that encroaches on the distribution lines on

any right-of-way is managed to ensure system reliability

and public safety. The Hydro Ottawa service territory is

currently divided into regions for vegetation

management: 12 suburb and 16 core areas (Figure 2.1)

Third party arborist contactors are hired to maintain

certain vegetation areas annually.

2.4.2 Program Schedule Hydro Ottawa has a vegetation management

program that removes vegetation on either a

two-year or three-year cycle, depending on

whether an area is considered core or suburbs.

Hydro Ottawa also completes off cycle work for

removals, quick tree growth, customer

requests, or storm work.

The OEB minimum inspection for vegetation requires

patrol in urban areas at a maximum interval of 3 years

and rural areas at a maximum interval of 6 years.

2.4.3 Program Performance Indicators The vegetation management program completed the

planned scope of work and was slightly over budget due

to increased planned tree trimming (see Table 2.15).

FIGURE 2.1 - VEGETATION MANAGEMENT AREAS

TABLE 2.15 – VEGETATION MANAGEMENT

Frequency 2013 Budget 2013 Actuals

Core: Every 2 Years

Suburb: Every 3 Years

$2,842,939 $3,074,426

TABLE 2.16 –BUDGET ACTUALS BY TRIM TYPE

Planned Tree

Trimming

Emergency

Trimming

Emerald Ash

Borer

$2,768,987 $101,100 $204,338

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

17

2.4.4 Data Governance A vegetation inspection program was started in 2012 to collect tree information for each HOL pole span. The

inspection program is used to track primary tree species, line overhang risk, vegetation growth, the

vegetation access type, clearance distance from the primary conductor and overall condition of vegetation

growth. The inspection records are stored in an Access database with the information found in Table 2.17

and can be analyzed using Intergraph GeoMedia software or Microsoft Excel. Customer calls are tracked in

OMS and can be used to provide insight into problem areas.

2.4.5 Reactive Maintenance In addition to a cyclical vegetation management program, overhead conductor is subject to regular patrol

inspection by crews through everyday work. Off cycle trimming is performed when vegetation is identified

by Hydro Ottawa staff, a customer, or a third party.

2.4.6 Gap Analysis The inspection information will be used to reevaluate the tree trimming program to make the program more

effective by creating new trim cycle areas and well defined standards. This reevaluation will be complete by

the end of May 2014 for input into the next tree trimming cycle.

TABLE 2.17 – VEGETATION INSPECTION STORED INFORMATION

Is the span clear? Ash Trees outside of 10', Hazard

Access Primary Species

Clearance from Primary (in feet) Species 2

Main Bole less than 10' from line Species 3

Trim Class Smart Removal

Overhang Class Smart Removal Comments

Ash Trees within 10', Hazard Minimum Trim Cycle Required

Ash Trees within 10', No Hazard Additional Remarks

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

18

2.5 Insulator Washing

2.5.1 Program Details Hydro Ottawa has adopted an extensive insulator washing program

with full washing of critical 44 kV, 27.6 kV and 13.2 kV circuits.

Washing is used to clean insulators with contamination build-up.

Contamination decreases the insulation strength and causes tracking

and flashover. This arcing causes electrical losses but can also lead to

pole fires, further equipment damage, and outages to the system.

Currently, only porcelain insulators are being washed as part of the

program.

The program was revisited in 2013 and the insulator routes were modified based on several criteria. The

main selection criteria were system voltage, type of traffic or

nearby industry, numbers of recorded pole fires and percentage of

porcelain insulators.

The insulator wash is a supplementary activity from those stated in

the OEB’s Minimum Inspection Requirement document.

2.5.2 Program Schedule Insulators are washed in early spring (around mid-February) and selectively washed in fall (around mid-

October) each year. The spring wash is more crucial to cover all areas due to the large amounts of

contamination caused by the winter roadway snow clearance and salt spray.

2.5.3 Program Performance Indicators The 2013 insulator wash scope of work was completed and was under budget. As part of the new insulator

wash program the new contractor must report the number of poles visited and the quantity of porcelain

insulators present (see Table 2.19). HOL will use the feedback to update and track washing routes and to

better monitor program costs. The scope of work and

budget for this program will decrease as porcelain

insulators are replaced with polymer as part of the ongoing

Insulator Replacement Program.

2.5.4 Data Governance The contractor provides records of the poles being washed

and the number of insulators present on the poles to allow

Hydro Ottawa to track the washing routes.

2.5.5 Reactive Maintenance The contractor reports any equipment that appears visually problematic for further assessment. An OMS

ticket is then entered for scheduling of the work. It is the responsibility of the area supervisor to schedule

work and close out the ticket when the issue is resolved.

TABLE 2.18 – INSULATOR WASHING

Frequency 2013

Budget

2013

Actuals

Spring & Fall

Annually

$130,000 $117,097

TABLE 2.19 – 2013 FALL POLE WASH

Poles Visited

Insulators Washed

Wash Cost Per Insulator

Average Replacement

Cost

1032 5682 $9.67 $1000

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

19

2.5.6 Gap Analysis The root cause of pole fires needs to be recorded so the information can be used to support the insulator

washing program. The information can be used to compare the proportion of pole fires where the insulators

have been washed to those that have not.

The 2013 changes to the program will need to be reviewed and analyzed to determine if they have

contributed positively to the reduction of pole fires. The program evaluation will be based on the number of

pole fires and insulator failures, compared with historical record.

FIGURE 2.2 - INSULATOR WASHING MAP

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

20

2.6 Cable Inspection

2.6.1 Program Details Underground cables are patrol inspected during

manhole inspections. Select condition testing of XLPE

cable is done annually in the winter through a cable

testing program with National Research Council of

Canada (NRC). Specific cable segments are tested using

a polarization / depolarization technique and the results

are compared to reference cables. Test locations are

determined based on fault history, age and future

planned replacement projects. Test results provide

input to Hydro Ottawa’s cable

replacement and cable injection

strategy.

2.6.2 Program Schedule The OEB minimum inspection for cable

requires patrol at a maximum interval of

3 years in urban areas and at a maximum

interval of 6 years in rural areas. The

number of cable segments inspected

annually is currently limited by the

NRC and Hydro Ottawa resources.

2.6.3 Program Performance Indicators

In 2013, HOL completed 119 out of

the 120 inspection sites. The program

exceeded budget due to the increase

in contractual costs (see Table 2.20).

The total cost of cable testing is a fraction of the cost of cable

replacement (see Table 2.21). Cable testing allows for major cost

savings through focused cable replacement and cable injection

projects. Although cable age is a main factor in cable condition,

there are many other variables that affect the cable condition

and cable testing is a necessary maintenance activity which

allows for appropriate prioritization of replacement or injection

projects (see Table 2.22).

2.6.4 Data Governance Following testing, Hydro Ottawa receives a report from the NRC

including: cable segment overall condition, length, age and

conductor type and size of the segments tested. The information

is then stored in Excel where it can be analyzed using Intergraph

GeoMedia software or Microsoft Excel (see Figure 2.3)

TABLE 2.20 – 2013 CABLE INSPECTION BUDGET

2013 Budget

for Outside

Services

Actual Costs

Outside

Services

Inside

Services

Total

$110,000 $120,500 $119,074 $239,574

TABLE 2.21 – 2013 CABLE INSPECTION ACTUALS

Cables

Inspected

Length of

Cable

tested

(m)

Total Cost per Meter

Testing Replacement

w/o duct

Replacement

with duct

Injection

119 22,141 $11 $300 $600 $60

TABLE 2.22 – 2013 CABLE INSPECTION RESULTS

Cable Condition

(ave. cable age

1982)

Percentage of

Cable Tested

Like New 6.7%

Good 52.1%

Fair 32.8%

Bad 5.0%

Critical 3.4%

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

21

2.6.5 Reactive Maintenance The cable inspection program will be used in 2014 to test cables that were injected during 2013. The results

from the cable inspection program will be used for comparison to determine the overall effectiveness of the

cable injection technique.

2.6.6 Gap Analysis The cable testing program budget should increase to reflect the increase in contract costs. The program relies

heavily on internal resources and this cost should also be considered for budgeting.

Future development of the cable inspection program to increase the scope of work to inspect more cable on

an annual basis should be evaluated.

Other cable testing methods should be investigated to establish if there is more information that can be

obtained about cable and associated attachments that could aid in improving system reliability.

FIGURE 2.3 – SAMPLE OF CABLE INSPECTION RESULTS

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

22

2.7 Critical Switch Inspections

2.7.1 Program Details Hydro Ottawa currently has a critical switch program with the purpose of maintaining and inspecting

switches that are deemed a higher priority. These switches are selected based on the requirements to

interrupt higher loads, supply many customers, or critical customers such as hospitals. The cyclic inspection

program will ensure all areas (urban, rural and difficult access), will be visited, and problems detected before

they lead to system failures that may:

Impair the safety of Hydro Ottawa employees or the public at large;

Impair system reliability and reduce the quality of service to our customer;

Seriously reduce the life expectancy of the equipment and increase costs; and/or

Adversely affect the environment.

Currently, the critical switch maintenance includes a visual and mechanical inspection, electrical tests, and

comparison of resistance tests with similar connections. The mechanical and visual inspection includes a

visual check of the physical appearance of the mechanical and electrical connections, cleaning of the switch,

and mechanical operator test. The electrical test includes connection resistance checks, equipment torquing,

and Megger checks on each pole and/or control

wiring.

2.7.2 Program Schedule Currently, the program inspects switches on a 3

year cycle, with the intention of identifying system

problems such as deterioration or defective

equipment, abnormal condition, safety hazards,

etc.

The OEB minimum inspection requirements for switches dictates that they be patrolled in urban areas at a

maximum interval of 3 years and in rural areas at a

maximum interval of 6 years.

2.7.3 Program Performance Indicators In 2013, HOL inspected 13 out of 30 switches (see Table

2.24). The switches that were not inspected in 2013 will

be carried over to the 2014 scope of work. No outside

service budget was spent as internal resources were used

for TIM activities.

2.7.4 Data Governance Currently, the inspections are being completed using HOL tablets and the records are being stored in an

Access database with the information found in Table 2.25. The records can be viewed using Intergraph

GeoMedia software or Microsoft Excel.

TABLE 2.23 – CRITICAL SWITCH INSPECTION

Frequency 2013 Budget Outside Service

Budgeted Actuals

Every 3 years

$15,000 0

TABLE 2.24 – CRITICAL SWITCH INSPECTION

ACTUALS

Target number of

Switch Inspections

Switches Inspected

30 13

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

23

2.7.5 Reactive Maintenance The inspection program will report any major issues with the switches and will feed into capital replacement

projects. If any problems are located that can be immediately resolved, HOL will be notified for further

follow-up. An OMS ticket is then entered for scheduling of the work. It is the responsibility of the area

supervisor to schedule the work and close out the ticket when the issue is resolved.

2.7.6 Gap Analysis The critical switch list should be re-evaluated periodically to include any new switches that are deemed as

critical as the distribution system expands and evolves. Other possible switch maintenance activities should

be investigated that could increase the inspection effectiveness and switch reliability.

TABLE 2.25 – CRITICAL SWITCH INSPECTION STORED INFORMATION

Access to Location Hazards Mechanical Operation

Air Break Insulation Cleanliness Motorized SCADA

Blade Movements and Contact Insulation Condition Mounting

Condition Rating Insulation Type Nomenclature

Current Rating (Amps) Insulators Normally Open Point

Electrical Connections kV Rating Remarks (Explain Deficiencies Here)

Follow Up Action Needed Lead Connections Security

Gang Operated "Live" Component Condition Serial Number

Ground Operated Load Break Switch and Component Anchorage

Grounding intact Manufacturer Year of Manufacture

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

24

TABLE 2.26 – POLE INSPECTION

Frequency 2013 Budget

4500 per year

(Every 10 years)

$0

TABLE 2.27 – POLE INSPECTION ACTUALS

Poles

Inspected in

2013

2013

Actuals

2013 Cost

per pole

Historical

Cost

(Contractor)

Historical

Cost

(HOL)

360 (8% of

Target) $18,890 $58 $22 $33

2.8 Pole Inspections

2.8.1 Program Details One of Hydro Ottawa’s largest asset classes is distribution poles and attached hardware. These assets are

used to support overhead to support distribution and sub-transmission conductors throughout the city.

Maintaining these assets is essential for a reliable and safe system.

Hydro Ottawa currently performs visual inspection and drill testing on poles. Visual inspections record

detailed information about the pole, the attached hardware and any other relevant information. This

information is used in conjunction with the drill test to prioritize pole replacement, hardware replacement or

to create new designs that will integrate with the present configuration. Drill assessment is a nondestructive

testing method using an International Distribution Network (IML) Resistograph drill which measures the

density or resistivity of the wood against the drill bit. The drill test provides an overall indication of rot, void,

and solid wood thickness that can be used to calculate the

remaining strength of the pole.

2.8.2 Program Schedule The planned inspection schedule calls for the inspection of 4,500

poles annually, creating a 10 year inspection cycle (see Table 2.26).

The OEB minimum inspection for poles requires that they be

inspected in urban areas at a maximum interval of 3 years and in rural areas at a maximum interval of 6

years. In addition to the pole inspection program HOL poles are being inspected during IR scans, insulator

washing, and normal patrol to meet the OEB requirements.

2.8.3 Program Performance Indicators In 2013, HOL only reached 8% of its target amount (see Table 2.27) and the cost per pole was almost double

historical costs due to the lack of dedicated pole inspectors.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

25

2.8.4 Data Governance Currently, the inspections are being completed using HOL tablets and the records are being stored in an

Access database with the information found in the Table 2.28. The records can be viewed using Intergraph

GeoMedia software or Microsoft Excel.

TABLE 2.28 – POLE INSPECTION STORED INFORMATION

Pole Material Broken or Loose Guying Max Pole Circumference

Pole Age Ground Wire Missing or not Intact Min Pole Circumference

Preservative Pole Leaning or Twisting External Damage Hole Width

Crossarm Condition Signs of Fire/Lighting/Arcing External Damage Hole Depth

Transformer Standard Comments Insect Infestation Drill Orientation

Porcelain Insulator Vegetation Growth Max External Decay Width

Pole Top Condition Debris or Bird's Nesting Max Internal Decay Width

Shell Condition Cut-out Switch Minimum Remaining Shell Width

Wood Pecker Damage Sound Test Interpretation of Test Result

Inline Switch Overall Visual and Sound Remarks

2.8.5 Reactive Maintenance If an emergent issue is identified, System Office will be notified to submit a work request for crews. The

regional crews will prioritize the work to be completed in an acceptable period. The non-emergent issues and

inspection information is reviewed by Assets for future work planning.

2.8.6 Gap Analysis The program fails to meet the target goal of 4,500 poles annually since it mainly relies on light duty resources

and is approached as a low priority task, often being scheduled in the slow season of winter. Since the

program was developed in 2009, the number of poles inspected per year has been inconstant and below

targets.

The pole inspection program needs a budget to ensure dedicated resources can return target inspection

numbers. Currently, HOL does not have the internal resources to complete inspections without affecting

focus on capital projects.

Using non-dedicated resources affects the quality of the inspection returned. The information is inconsistent

and does not return reliable pole quality calculations. It is recommended that HOL hire a qualified third party

to perform the annual inspection as it will ensure scheduled completion and has historically proven to be the

most cost effective method.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

26

2.9 Graffiti Abatement

2.9.1 Program Details The objective of the Graffiti Abatement program is for painting rusted equipment, graffiti removal,

refurbishment and removal of eyesores and extending equipment life when necessary. Currently, equipment

requiring attention is identified through regular patrol by a contractor. The Graffiti Abatement program was

developed in response to the City of Ottawa Graffiti By-Law to ensure HOL keeps its property free of graffiti.

It also allows HOL to work cooperatively with the City of Ottawa By-Law department to address criminal acts

of graffiti to deter future acts of vandalism.

Before After

2.9.2 Program Schedule The graffiti abatement program does not have a

periodic inspection cycle. The contractor performs

regular inspections of the HOL region to identify

equipment requiring attention. The frequency of

inspections is based on the area’s historical

requirement for follow-up action.

The OEB Minimum Inspection Requirement states that transformer and switching kiosks are patrolled to

locate degraded paint and enclosure corrosion or damage. The graffiti abatement program supports Hydro

Ottawa in meeting these requirements.

2.9.3 Program Performance Indicators The graffiti abatement program has no predetermined

target. Equipment is routinely inspected and attended to

by a 3rd party. There were 1169 sites needing graffiti

removal or restoration (see Table 2.30) in 2013.

2.9.4 Data Governance The contractor provides Hydro Ottawa with paper records and before and after photos of the work that is

completed.

TABLE 2.29 – GRAFFITI ABATEMENT

Frequency 2013

Budget

2013

Actuals

Variable $102,000 $100,931

TABLE 2.30 –NUMBERS BY VISIT TYPE

Rust

Restoration

Tag

Removal

Total

Visits

Average

Cost

205 964 1169 $86

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

27

2.9.5 Reactive Maintenance If attention is required beyond the scope of the contractor, HOL will be contacted to further assess the

equipment condition. An OMS ticket is then entered for scheduling of the work. It is the responsibility of the

area supervisor to schedule the work and close out the ticket when the issue is resolved.

2.9.6 Gap Analysis Public awareness of the maintenance costs for this program could deter vandalism and deliberate damage to

HOL equipment. The program should integrate the use of the inspection tablets to easily capture the Graffiti

Abatement inspection information and potentially capture other equipment information.

Before After

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

28

2.10 Vault Maintenance

2.10.1 Program Details Hydro Ottawa has approximately 1500 vaults in its system, most of which are customer owned. Hydro

Ottawa is in the process of creating a vault maintenance program. Customer owned vaults are the customers’

responsibility to maintain along with the containing equipment. If no current maintenance is being

performed on customer owned vaults, Hydro Ottawa will recommend that maintenance is performed by the

customer. In the rare case that a customer does not complete maintenance on their vaults and there are

obvious issues, the vault could be reported to the Electrical Safety Authority (ESA) for follow-up.

Vault maintenance being performed is at the discretion of the customer or the contractor completing the

work. Most often vault maintenance includes visual inspection of the civil structure, ventilation fans, and all

electrical equipment, cleaning of the switchgear, transformer(s), breakers, the vault floors and any other

required equipment, IR scanning of the electrical equipment, torquing connections, inspecting grounding and

lighting and any other supplementary maintenance.

2.10.2 Program Schedule Currently, Hydro Ottawa is recommending 3 year inspection periods for vaults containing air break switches

and 6 years for vacuum, SF6 filled and oil filled switchgear. It is the customer’s responsibility to maintain their

vault.

Most often, inspection by Hydro Ottawa crews happens indirectly with the act of entering the vault to

perform field switching. This allows HOL crews to observe the equipment and the vault condition to ensure

that it is acceptable. HOL also performs inspections for smoke and heat detectors on a regular basis allowing

for spot checks of the vault condition.

2.10.3 Program Performance Indicators Currently, there are no performance indicators for this program. Performance indicators will be created once

inspections are completed using the tablets.

2.10.4 Data Governance Customer owned vaults that have contractors’ perform maintenance work often use paper forms for

maintenance records. It is at the discretion of the customer if they want to send a copy of the report to HOL

for its records. HOL indirectly keeps records of the vault maintenance in the System logs. When a customer is

performing vault maintenance HOL is required to isolate the vault. A request is submitted to HOL for the

switching isolations and a system log is created that can be used as a record of maintenance.

In past HOL inspection programs, such as PCB inspections, HOL has used paper format to record information

in the vault. The inspection fields that are completed by inspectors can be found in Table 2.31.

Currently, HOL keeps an Access database of the most current vault information including equipment details

and TIM records.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

29

TABLE 2.31 – VAULT INSPECTION STORED INFORMATION

Primary Voltage Floors Manager Company

Nomenclatures Sills Circuits1

Feed Type Grounding Signs

Asbestos (Y/N) Switchgear Type Prim. Cable Size

Heat Detectors(s) Incomers Fencing

Transformer Size Fourth Cable Hinges/Locks

Transformer Leaks/Noise Vault Pictures Ceiling

Ventilation Bucket Access Water Signs

Louvers 65F/16C Address Drains

Lighting Company Public Safety Concern

Door Condition Also Feeds Fuse Disconnects

Walls Sub Vaults Pole Pictures

2.10.5 Reactive Maintenance If problems are detected by HOL, the customer will be contacted to initiate maintenance activities for their

vault. If a customer does not initiate maintenance to rectify a problem that can impact HOL equipment and

reliability or affect public safety, the ESA can be contacted to initiate an inspection. If a problem is detected in

an HOL owned vault, underground crews are contacted immediately to attend to the equipment.

2.10.6 Gap Analysis Currently, there is no formal process of tracking customer vault maintenance. A periodic inspection program

of vaults containing HOL equipment needs to be implemented. HOL is in the process of incorporating the

tablets with the inspection program to improve data analysis and inspection tracking.

Communication to customers owning vaults needs to occur to properly educate customers on the

requirement for maintenance and ensuring it is clear the equipment for which they are responsible for

maintaining.

Through the amalgamation of the local distribution companies into HOL, some vault ownership and

demarcation points have become undecided by both parties. Vault ownership and demarcation points must

be determined in order to be able to consistently develop a path forward for maintenance activities.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

30

3 Station Testing, Inspection, and Maintenance

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

31

TABLE 3.1 – BATTERY MAINTENANCE

2013

Budget

2013

Actuals

$65,430 $42,930

TABLE 3.2 –BATTERY INSPECTION SCHEDULE

Maintenance Activity Frequency

Visual Inspection Monthly

IR Inspection Yearly

Electrical Test Yearly

TABLE 3.3 – BATTERY MAINTENANCE

Battery Visual

Inspection Target

Battery

Inspection

Actuals

1,008 443

TABLE 3.4 – BATTERY INSPECTION STORED

INFORMATION

General Appearance Access to Location

Battery Voltage Equalize Cycle

Battery Equalize Remarks

Battery Rack Bonding Follow-up Action

3.1 Battery Maintenance

3.1.1 Program Details Currently, the station battery and battery charger are inspected by completing voltage measurements and

visual inspection of the DC supply components. Included in the voltage measurements are recording

individual cell voltages, the battery charger normal charging voltage and the battery charger equalization

voltage. The voltage of the individual cells will ensure that they are holding their nominal level and will

confirm the cell is in good condition. The charging voltages are taken to ensure the battery charger is set up

to charge the battery at the manufacturer’s recommendations. Visual inspections are completed for the

bonding connections, the battery and battery charger as

well as all connecting equipment. The visual inspection

determines if there are low electrolyte levels and if

corrosion exists at the battery terminals.

3.1.2 Program Schedule Currently, the cells and DC supplies are visually inspected

as part of the monthly station visual inspections. The goal

for the battery maintenance schedule is to meet the

requirements set out in Table 3.2.

3.1.3 Program Performance Indicators In 2013, HOL performed 443 battery monthly visual

inspections and maintenance actuals were under budget

(see Table 3.1 and Table 3.3). The inspection performance

numbers do not include inspections completed using

PowerDB software. Hydro Ottawa is working with the

PowerDB software to create effective inspection reports

to summarize Station TIM program performance

numbers.

3.1.4 Data Governance Electrical testing is completed using Alber’s testing

equipment and results are uploaded to an HOL database.

The Alber’s test equipment measures individual cell

voltage, resistance, specific gravity, temperature and

provides an overall cell health rating. Other records are

completed in paper form and are stored in the stations

directory (see Table 3.4). As well as yearly inspection, the SCADA system continuously monitors the stations

battery voltage levels and in turn is monitored by system office.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

32

3.1.5 Reactive Maintenance If a deficiency is identified by the inspections, a maintenance activity is created in either Track-It or PowerDB

depending on the work complexity. This enables tracking of stations required maintenance activities. The

work is then scheduled to be performed by the

crews after any necessary planning and

procurement has been completed.

Common failure modes of cells in a battery are:

under voltage due to improper equalization charge,

low electrolyte levels, and loose strap connections

connecting the cells together. Cells with low voltage

should be replaced to ensure thermal runaway does

not happen and the battery’s integrity is

maintained. A thermal runaway can occur when

cells in a battery bank vary in voltage. The difference

in cell voltages cause internal currents to circulate in

the battery bank and can cause more heat to be

generated in a cell than can be dissipated on the

case. The heat then causes catastrophic damage to

the cell casing and can lead to thermal runaways in other cells.

If terminal connections are found to be corroded and or loose, the connections should be cleaned, an oxide

exhibitor should be used and the connections should be torqued to specifications.

3.1.6 Gap Analysis PowerDB must be developed to have the ability to show effective inspection reports. Hydro Ottawa is

currently working with the PowerDB software to create effective inspection reports to summarize Station

TIM programs.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

33

3.2 Relay Maintenance

3.2.1 Program Details Relays are currently undergoing complete inspections every 4 to

6 years. Visual inspections are part of the monthly stations

inspection and check for obvious equipment deficiencies.

Electrical, mechanical and operational inspections identify loose

connections, broken studs, burned insulation, dirty contacts,

setting configuration and proper operation. IR scans are

completed as part of the station annual IR scan and detects

equipment operating over the manufacturers temperature

specifications.

3.2.2 Program Schedule Visual inspections are part of the monthly stations inspection (see Table 3.6). IR scans are completed as part

of the station annual IR scan. Electrical, mechanical and operational test are completed every 4 to 6 years.

3.2.3 Program Performance Indicators In 2103, HOL did not meet monthly relay inspection targets (see

Table 3.7) and was under budget (see Table 3.5) due to lack of

available resources and capital projects taking precedence. Also,

the inspection performance numbers do not include inspections

completed using PowerDB software. Hydro Ottawa is working with

the PowerDB software to create effective inspection reports to

summarize Station TIM program performance numbers.

3.2.4 Data Governance Relay inspections have transitioned over to PowerDB software.

The inspection information is centralized in an Access database

and can be viewed using PowerDB (see Table 3.8).

3.2.5 Reactive Maintenance If a deficiency is identified by the inspections, a maintenance activity is

created in either Track-It or PowerDB depending on the work

complexity. This enables tracking of stations requiring maintenance

activities. The work is then scheduled to be performed by the crews

after any necessary planning and procurement has been

completed.

3.2.6 Gap Analysis The maintenance schedule needs to be developed to meet the

minimum periodic inspections listed in Table 3.6. Information

on failure modes should then be evaluated as part of the

Physical Asset Management Plan.

PowerDB must be developed to have the ability to show effective inspection reports. Hydro Ottawa is


TIM programs.

TABLE 3.5 –RELAY/BREAKER MAINTENANCE

Frequency 2013

Budget

2013

Budget

Actuals

4 - 6 Years

$573,333 $315,700

TABLE 3.6 –RELAY MAINTENANCE SCHEDULE




Operational Test 4 - 6 Years

Mechanical Test 4 - 6 Years

Electrical Test 4 - 6 Years

TABLE 3.8 –RELAY INSPECTION STORED

INFORMATION

As Found Settings Visual Condition

As Left Settings Electrical Test

Results

TABLE 3.7 –RELAY INSPECTIONS

Relay Visual

Inspections

Target

Inspections

300

1,008

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

34

3.3 Transformer Maintenance

3.3.1 Program Details Transformer maintenance currently includes: visual inspection,

electrical tests, mechanical tests and oil sampling. The visual

inspection involves current and voltage readings, temperature

readings, liquid level check, physical condition assessment and

pressure/vacuum gauge readings.

The visual inspections of current, voltage and temperature

readings ensure that the transformers are operating within the

acceptable limits. If the levels are measured outside of the

specifications, investigation will be required to determine the root cause

and remediation plans.

Liquid, pressure and vacuum level readings are checked to ensure that

the transformer is not leaking in any way. If the readings are out of the

acceptable range, the stations office is contacted to provide immediate

support or to create a Track-It entry to schedule follow-up action.

3.3.2 Program Schedule The power transformer maintenance uses Table 3.10 as a guide for scheduling.

3.3.3 Program Performance Indicators In 2013, Hydro Ottawa did not meet target inspection numbers

(see Table 3.11). The inspection report is created from inspections

completed on the tablet. TIM activities apart from the visual

inspection are not recorded by tablet and may account for the

program being over budget. Also, the inspection performance

numbers do not include inspections completed using PowerDB

software. Hydro Ottawa is working with the PowerDB software to

create effective inspection reports to summarize Station TIM

program performance numbers.

TABLE 3.9 –POWER TRANSFORMER

MAINTENANCE

2013

Budget

2013

Actuals

$18,000 $62,860

TABLE 3.10 - POWER TRANSFORMER

SCHEDULE




Mechanical Test 3 - 5 Years

Electrical Test 3 - 5 Years

Operational Test 3 – 5 Yearly

Oil Samples Yearly

TABLE 3.11 –POWER TRANSFORMER VISUAL

INSPECTION

2013 Visual

Inspections

2013 Target

Inspections

1,011 4,008

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

35

3.3.4 Data Governance Transformer inspections have transitioned over to PowerDB software. The inspection information is

centralized in an Access database and can be viewed using PowerDB (see Table 3.12).

TABLE 3.12 – TRANSFORMER INSPECTION STORED INFORMATION

General Appearance Explosion Vent Condition Recorded Tank Pressure

Oil Leaks Silica Gel Breather Condition Recorded Oil Temp Present

Bushings Condition Grounding Intact Recorded Oil Temp Maximum

Cooling Pump Condition Recorded Oil Level Bushings Gauge Recorded Wind Temp Present

Fans Condition Recorded Oil Level Bushings Sight

glass

Recorded Wind Temp

Maximum

Control Cabinet/Heaters

Condition

Recorded Oil Level Transformer

Gauge

Remarks

Gas Relay Condition Recorded Gas Pressure FollowUp Action Required


depending on the work complexity. This enables tracking of stations requiring maintenance activities. The

work is then scheduled to be performed by the crews after any necessary planning and procurement has

been completed.

3.3.6 Gap Analysis A well-defined periodic inspection schedule must be created for station transformers to allow for more

efficient future maintenance activities.

Transformer inspections need to be tracked more accurately to ensure the different maintenance, inspection

and testing activities are being completed.

The current TIM should be compared with industry best practice to ensure HOL is creating an effective TIM

Plan.



TIM programs.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

36

3.4 Transformer Oil Analysis Testing

3.4.1 Program Details Currently, transformers undergo dissolved gas analysis (DGA) and oil quality analysis annually. The DGA and

oil quality analyses are an important diagnostic tool used to monitor the condition of the unit. Emphasis is

placed on these tests for detecting insulation breakdown, water in the oil, stressing of the coils, localized

overheating and arcing that can lead to failure of the transformer. Currently, HOL sends oil samples to an oil

testing laboratory, uses DGA portable equipment and uses DGA online monitoring equipment. The oil testing

laboratory uses sophisticated lab equipment that creates a full analysis of the oil sample, compares the

results to any previous transformer oil samples, and specifies detailed recommendations for the transformer.

If the laboratory processing lead time is too lengthy, HOL will use portable DGA equipment for immediate

results. The online DGA equipment is used for continuous monitoring of transformer gas concentrations and

can be used to set alarms at specific gas concentration thresholds. DGA online monitoring systems are being

installed as part of HOL standards and are capable of sending DGA

data to the PI server data historian.

DGA and oil quality tests identify abnormalities within the transformer

and provide detailed information to allow for sound decision making

for future operation and maintenance of the transformer.

3.4.2 Program Schedule The target inspection schedule is to annually complete DGA testing

and oil quality analyses on all transformers, with

more frequent testing on units showing

abnormalities.

3.4.3 Program Performance Indicators In 2013, HOL met the testing targets (see Table

3.14). Transformers or tap changers showing

abnormal results may be tested more frequently as recommended by the consultant. The budget for outside

services needs to be reevaluated to be more consistent with actual spending.

3.4.4 Data Governance Currently, the DGA and oil quality analysis are performed by a qualified oil testing laboratory and provides

HOL with DGA summary reports that are stored in the HOL stations network directory. The portable oil

analyzer prints a paper copy of the DGA results that are analyzed immediately. The DGA online monitoring

results are fed back into the PI data server and can be accessed via PI software.


depending on the work complexity. This enables tracking of stations required maintenance activities. The


been completed.

3.4.6 Gap Analysis HOL should investigate performing its own oil analysis and implementing a central repository for all of the

historical data.

The budget for this program should be re-evaluated to better reflect the program’s actual budget.

TABLE 3.13 –TRANSFORMER OIL

SAMPLING

Frequency 2013

Budget

2013

Actuals

Annually

$198,000 $64,340

TABLE 3.14 –TRANSFORMER OIL TESTING RESULTS

XFMR

Target

Tap Changers

Target

XFMR Tests

Completed

Tap Changer

Tests Completed

151 41 163 45

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

37

3.5 Transformer Doble Testing

3.5.1 Program Details Doble testing equipment is being used to assess the overall power factor, turns ratio testing, leakage

reactance and exciting current of the transformer. These tests are used to detect moisture in the oil or

insulation, detect contamination in the transformer bushing, determine the electrical insulation quality, and

locate bad connections and winding movement. The Doble equipment provides test results and expected

values and thresholds to effectively translate the results. Doble testing, DGA testing and oil quality analysis

complement each other to provide clear

indication of the overall health of the

transformer.

3.5.2 Program Schedule Doble testing follows transformer maintenance

and is targeted every 3 to 5 years (see Table

3.15).

3.5.3 Program Performance Indicators In 2013, HOL did not meet inspection targets (see Table 3.15) due to lack of available resources and capital

projects taking precedence.

3.5.4 Data Governance The Doble testing results are stored in the stations network directory and can be viewed in Microsoft Internet

Explorer or using the Doble Software.

3.5.5 Reactive Maintenance The test results are used to plan future operation, maintenance, and replacement of the transformer.

3.5.6 Gap Analysis A periodic inspection cycle needs to be created for all station transformers. The Doble testing results need to

be analyzed closely to be able to better determine equipment health indexing and prioritization. Testing

results should be located in a central repository with all other transformer testing results.

TABLE 3.15 –TRANSFORMER DOBLE TESTING

Frequency 2013 Target

Testing

2013 Testing

Actuals

Every 3 to 5 years 33-55/year 24

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

38

3.6 Station Visual Inspections

3.6.1 Program Details The Station Visual Inspection program is used

to assess the condition of the station yard, the

station building exterior and interior, the

station security, and general equipment

condition.

3.6.2 Program Schedule The current inspection program visits stations

on a monthly basis. The stations are

categorized by voltage and location type (see

Table 3.17).

3.6.3 Program Performance Indicator In 2013, HOL did not meet its targets for station inspections due

to lack of available resources and capital projects taking

precedence. Station inspection targets are once a month for every

station (see Table 3.18). The inspection performance numbers do

not include inspections completed using PowerDB software.

Hydro Ottawa is working with the PowerDB software

to create effective inspection reports to summarize

Station TIM program performance numbers.

3.6.4 Data Governance Stations visual inspections have transitioned over to

PowerDB software. The inspection information is

centralized in an Access database and can be viewed

using PowerDB. Station visual inspection is completed

for all main components:

Yard

Building Exterior

Building Interior

Basement

DC System

Station RTU

Protection Relay Panels

Outdoor Structures

Station Service Transformers

Power Transformers

Circuit Breakers / Reclosers

Voltage Regulators

Switchgear Assemblies

Circuit Switches

Ground Grid

TABLE 3.16 –STATION INSPECTIONS

Frequency 2013

Budget

2013

Actuals

Monthly $295,616 $100,670

TABLE 3.18 –STATION INSPECTIONS

Inspection Type Quantity

(Target

1,008)

Building Exterior 380

Building Interior 380

Basement 287

Station Structure 161

Stations Yard 443

TABLE 3.17 –STATIONS BY TYPE

Station Type Quantity

Urban Outdoor Open TS 9

Urban Outdoor Open DS 13

Urban Outdoor Enclosed DS 13

Urban Indoor Enclosed DS 47

Rural Outdoor Open DS 2

Urban Outdoor Open TS 9

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

39

3.6.5 Reactive Maintenance If a deficiency is identified by the inspections, a

maintenance activity is created in either Track-It or

PowerDB depending on the work complexity. This

enables tracking of stations requiring maintenance

activities. The work is then scheduled to be

performed by the crews after any necessary

planning and procurement has been completed.

3.6.6 Gap Analysis Monthly station inspections need to be consistently

completed to meet the target schedule. If capital

work continues to dominate HOL resources, a

dedicated maintenance crew or a 3rd party may be required to complete the inspections.



TIM programs.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

40

3.7 Tap Changer Maintenance

3.7.1 Oil Filled (Filtered) Tap Changers

3.7.1.1 Program Details Oil filled tap changer TIM activities include

recording position of the tap changer, inspecting

the physical and mechanical condition, verifying

correct auxiliary device operation, verifying

correct liquid level in all tanks, performing tests

as recommended by the manufacturer, verifying

operation of heaters and verifying grounding.

An internal inspection is also conducted and

includes removing of the oil and cleaning carbon

residue and debris from compartment, inspecting the contacts

for wear and alignment, tightening all electrical and mechanical

connections to calibrated specifications, inspecting the tap

changer components for signs of moisture, cracks, electrical

tracking or excessive wear and then refilling the tank with

filtered oil.

3.7.1.2 Program Schedule The oil filled (filtered) tap changer inspections are completed

monthly and maintenance is performed every 3 to 5 years.

HOL completes oil analyses on select tap changers during

transformer oil analysis.

3.7.1.3 Program Performance Indicator In 2013, Hydro Ottawa did not meet the monthly inspection

targets (see Table 3.21) and budget actuals were greatly

exceeded (see Table 3.19). The increase in maintenance costs

were associated to exceeded labor and material costs. The

inspection report is created from inspections completed on

the tablet. TIM activities apart from the visual inspection are

not recorded by tablet and may account for the program being

over budget. Also, the inspection performance numbers do

not include inspections completed using PowerDB software. Hydro Ottawa is working with the PowerDB

software to create effective inspection reports to summarize Station TIM program performance numbers.

3.7.1.4 Data Governance Tap changer inspections have transitioned over to PowerDB software. The inspection information is

centralized in an Access database and can be viewed using PowerDB.

3.7.1.5 Reactive Maintenance If a deficiency is identified by the inspections, a maintenance activity is created in either Track-It or PowerDB



been completed.

TABLE 3.19 –TAP CHANGER BUDGET

2013

Budget

2013 Actuals

$36,324 $229,569

TABLE 3.20 –TAP CHANGER SCHEDULE

Visual

Inspection

Maintenance

Monthly Every 3-5 years

TABLE 3.21 –TAP CHANGER INSPECTIONS

Visual Inspection

Target

Inspection

Actuals

3406 305

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

41

3.7.1.6 Gap Analysis Tap changer inspections need to be consistently completed to meet the target schedule. If capital work

continues to dominate HOL resources, a dedicated maintenance crew or a 3rd party may be required to

complete the inspections.



TIM programs.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

42

3.7.2 Oil/Vacuum Filled Tap Changers

3.7.2.1 Program Details Oil/vacuum tap changer inspection includes: recording position of the tap changer, inspecting the physical

and mechanical condition, verifying correct auxiliary device operation, verifying vacuum level, performing

tests as recommended by the manufacturer, verifying operation of heaters, verifying grounding, and

inspecting the vacuum bottles for wear or erosion.

3.7.2.2 Program Schedule The oil filled/vacuum tap changer inspections are completed monthly and maintenance is performed every 3

to 5 years. HOL completes oil analyses on select tap changers during transformer oil analysis.

3.7.2.3 Program Performance Indicator In 2013, Hydro Ottawa did not meet the monthly inspection targets (see Table 3.21) and budget actuals were

exceeded (see Table 3.19). The increase in maintenance costs were associated to exceeded labor and

material costs. The inspection report is created from inspections completed on the tablet. TIM activities apart

from the visual inspection are not recorded by tablet and may account for the program being over budget.

Also, the inspection performance numbers do not include inspections completed using PowerDB software.

Hydro Ottawa is working with the PowerDB software to create effective inspection reports to summarize


3.7.2.4 Data Governance Tap changer inspections have transitioned over to PowerDB software. The inspection information is





been completed.

3.7.2.6 Gap Analysis Tap changer inspections need to be consistently completed to meet the target schedule. If capital work

continues to dominate HOL resources, a dedicated maintenance crew or a 3rd party may be required to

complete the inspections.



TIM programs.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

43

3.8 Stations Infrared (IR) Inspection

3.8.1 Program Details Infrared (IR) inspection on station equipment is

completed in conjunction with more specific equipment

inspection. The IR inspection checks equipment for hot

spots to indicated loose connections, defective

equipment, overloading, contamination, short circuits

and ground faults. HOL performs IR scanning, internally,

on station equipment.

3.8.2 Program Schedule The IR inspection is conducted in conjunction with other

station equipment inspections.

3.8.3 Program Performance Indicators In 2013, there were no charges to the stations IR scanning program

(see Table 3.22). The IR scanning was completed during station

inspection but was not formally documented.

3.8.4 Data Governance Currently, IR photos are stored in the stations network directory

with a record of IR scans kept in an Excel spreadsheet.

3.8.5 Reactive Maintenance Any hot spots identified by the inspection are monitored closely by station electricians. If the temperature

trends past a threshold, further maintenance is planned by creating an entry in Track-It or PowerDB. The

Station Office then schedules the work after any necessary planning and procurement has been completed.

3.8.6 Gap Analysis IR scans need to be documented using PowerDB. If a deficiency is found the IR image(s) should be attached

with the PowerDB work form for follow-up action.

TABLE 3.22 –STATION IR

INSPECTIONS

Frequency 2013

Budget

Actuals

Yearly $38,000 0

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

44

3.9 Switchgear Maintenance

3.9.1 Switchgear General Maintenance

3.9.1.1 Program Details Currently, switchgear undergoes inspections that check the switches,

over current relays, position indicator, heaters, breaker tools, and

breaker and racking mechanism operation (see Table 3.24).

3.9.2 Program Schedule Visual inspection follows the monthly station inspection. Thorough

switchgear maintenance and testing is completed every 4 – 6 years cycle.

3.9.3 Program Performance Indicators In 2013, HOL did not meet target inspection numbers (see Table 3.23). HOL

did not meet its targets for switchgear inspections due to lack of available

resources and capital projects taking precedence. Also,

the inspection performance numbers do not include

inspections completed using PowerDB software. Hydro

Ottawa is working with the PowerDB software to

create effective inspection reports to summarize


3.9.3.1 Data Governance Switchgear inspections have transitioned over to PowerDB software. The inspection information is





been completed.

3.9.3.3 Gap Analysis Switchgear testing, inspection, and maintenance needs to be consistently completed to meet the target

schedule. If capital work continues to dominate HOL resources, a dedicated maintenance crew or a 3rd party

may be required to complete the inspections.



TIM programs.

TABLE 3.24 –SWITCHGEAR INSPECTION

General Appearance Breaker Tools Condition

Heaters Condition Breakers Condition

Position Indicator

Position

Remarks

TABLE 3.23 –STATION

SWITCHGEAR INSPECTIONS

Target

Inspections

Actual

Inspections

1,008 288

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

45

3.9.4 Breaker Maintenance

3.9.4.1 Program Details The current TIM activities for circuit breakers

include: visual inspection and electrical,

mechanical, and operational tests (see Table 3.26).

Visual inspection ensures that the breakers are

clean, there are no signs of arcing or leaking oil,

and there is no damage to the breaker or arc

chute. Electrical testing includes performing insulation resistance and contact resistance testing. Mechanical

tests include: cleaning the bushing, checking for any leaks around the gaskets, cleaning, lubricating and

testing the operating mechanism, checking the contacts, and tightening all bolts, pins, and connections.

Operational testing of the breaker checks the operating mechanisms, and ensures the proper operation of

the breaker and the charging motor.

TABLE 3.26 –BREAKER MAINTENANCE

Equipment TIM Activity

Visual Electrical Mechanical Operational

Contacts

Arc Interrupters

Insulation

Trip Device Circuit

Operating Mechanism

3.9.4.2 Program Schedule The schedule for the different types of breakers varies depending on the recommended maintenance

requirements of the manufacturer. The tables below list the ideal maintenance schedule for the various

breaker types.

TABLE 3.27 –MINIMUM OIL CIRCUIT BREAKER SCHEDULE

Maintenance

Activity

Frequency



Mechanical Test 4 – 6 years

Electrical Test 4 – 6 years

Operational Test 4 – 6 years

TABLE 3.28 – HIGH VOLTAGE CIRCUIT BREAKER

SCHEDULE







TABLE 3.25 –RELAY/BREAKER MAINTENANCE

Frequency 2013

Budget

2013

Budget

Number

of

Breakers

4 - 6 Years

$573,333 $315,700 929

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

46

3.9.4.3 Program Performance Indicators In 2013, HOL did not meet its targets (see Table 3.31) and

was under budget (see Table 3.25). Recloser and breaker

inspections are completed using the same inspection class,

impeding recloser and breaker inspections numbers from

being evaluated independently. HOL did not meet its targets for breaker and recloser maintenance due to

lack of available resources and capital projects taking precedence. Also, the inspection performance numbers

do not include inspections completed using PowerDB software. Hydro Ottawa is working with the PowerDB

software to create effective inspection reports to summarize Station TIM program performance numbers.

3.9.4.4 Data Governance Breaker TIM activities have transitioned over to PowerDB software. PowerDB enables form customization to

have breaker specific TIM activities per the manufacturers’ recommendations. The inspection information

can be viewed using the PowerDB software.

TABLE 3.32 – BREAKER INSPECTION

Overall Cleanliness Structural Members Main Contacts

Insulating Members Cubicle Arcing Contacts

Mechanical Connections Auxiliary Devices Arcing Chutes

Contact Sequence Ground Connection Insulation Testing

Contact Resistance Temperature Puffer Operation

Racking Device Shutter Contact Fingers




been completed.

TABLE 3.29 –SF6 CIRCUIT BREAKER SCHEDULE







TABLE 3.30 – AIR MAGNETIC CIRCUIT BREAKER SCHEDULE







TABLE 3.31 – BREAKER & RECLOSER INSPECTIONS

Target Actuals

11,844 1,295

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

47

3.9.4.6 Gap Analysis A well-defined breaker inspection schedule needs to be created to ensure that the recommended

maintenance is being performed in an acceptable time period. Analysis of test results needs to be done by

Assets following setting clear direction on expected test results and thresholds.



TIM programs.

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

48

3.9.5 Stations Recloser Maintenance

3.9.5.1 Program Details Recloser maintenance includes: visual inspection, electrical testing, mechanical testing and dielectric

sampling. The visual inspection checks the bushings, contacts and liquid level and includes an IR scan of the

recloser and its components. The electrical, mechanical, and operational inspection includes checking

mechanical connections, testing insulation resistance and recloser function test to ensure proper operation.

3.9.5.2 Program Schedule The schedule for recloser maintenance is every 4-6 years (see Table

3.33).

3.9.5.3 Program Performance Indicators In 2013, HOL did not meet its targets for breaker and recloser

inspections (see Table 3.31). Recloser and breaker inspections are

completed using the same inspection class, impeding recloser and breaker inspections numbers from being

evaluated independently. HOL did not meet its targets for breaker and recloser maintenance due to lack of

available resources and capital projects taking precedence. Also, the inspection performance numbers do not

include inspections completed using PowerDB software. Hydro Ottawa is working with the PowerDB software

to create effective inspection reports to summarize Station TIM program performance numbers.

3.9.5.4 Data Governance Recloser TIM activities have transitioned over to PowerDB software. PowerDB enables form customization to

have recloser specific TIM activities per the manufacturers’ recommendations. The inspection information

can be viewed using the PowerDB software.




been completed.

3.9.5.6 Gap Analysis Recloser operating and electrical test should include time-travel analysis to ensure the recloser is operating

within the manufactures specification.



TIM programs.

TABLE 3.33 –RECLOSER MAINTENANCE

Frequency Number of

Reclosers

4 - 6 Years 58

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

49

3.9.6 Station Switch Maintenance

3.9.6.1 Program Details Switches are currently undergoing visual inspection on a

monthly basis. Visual inspection checks for issues with the arc

shoots, arc tips, broken insulators, burned insulators, and dirty

components. The visual inspection is completed to ensure that

the switch has no issues that could indicate a problem with day

to day operation.

3.9.6.2 Program Schedule Electrical and operational tests that verify the overall switch

integrity are completed every 4 to 6 years.

3.9.6.3 Program Performance Indicators In 2013, switch inspections did not meet target due to lack of

available resources and capital projects taking precedence (see

Table 3.36). The inspection performance numbers do not

include inspections completed using PowerDB software. Hydro

Ottawa is working with the PowerDB software to create

effective inspection reports to summarize Station TIM program

performance numbers.

3.9.6.4 Data Governance Switch inspections have transitioned over to PowerDB

software. The inspection information is centralized in an

Access database and can be viewed using PowerDB (see Table

3.37).

3.9.6.5 Reactive Maintenance If a deficiency is identified by the inspections, a maintenance

activity is created in either Track-It or PowerDB depending on

the work complexity. This enables tracking of stations requiring

maintenance activities. The work is then scheduled to be

performed by the crews after any necessary planning and

procurement has been completed.

3.9.6.6 Gap Analysis A well-defined switch maintenance schedule and budget needs to be created to ensure the recommended

maintenance is being performed in an acceptable time period.



TIM programs.

TABLE 3.34 – STATION SWITCH MAINTENANCE

BUDGET

Switch Budget Actuals

0 $3,722

TABLE 3.35 – STATION SWITCH MAINTENANCE

SCHEDULE



IR Scan Yearly




TABLE 3.36 – STATION SWITCH INSPECTION

Approximate

Switch Inspection

Target

Switches Inspected

2000 109

TABLE 3.37 – STATION SWITCH INSPECTION

STORED INFORMATION

General

Appearance

Components

Condition

Switches/Fuses

Condition

Remarks

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

50

3.9.7 High Voltage Fuse Maintenance

3.9.7.1 Program Details High voltage fuse inspection involves: IR scans, visual

inspection and cleaning and clip pressure inspection.

The visual inspection includes: inspecting the fuse

holders, insulators and fuse for breaks, cracks, burns,

pitting, and indication of flashover and sign s of

deterioration. The IR inspection checks the fuse

holder to ensure the components are under the

threshold temperature.

3.9.7.2 Program Schedule Fuse inspections and maintenance follows

switch inspections (see Table 3.38).

3.9.7.3 Program Performance Indicators In 2013, fuse inspections did not meet target

due to lack of available resources and capital

projects taking precedence (see Table 3.36). The

inspection performance numbers do not include

inspections completed using PowerDB software.

Hydro Ottawa is working with the PowerDB

software to create effective inspection reports

to summarize Station TIM program performance

numbers.

3.9.7.4 Data Governance Fuse inspections have transitioned over to PowerDB software. The inspection information is centralized in an

Access database and can be viewed using PowerDB.




been completed.

3.9.7.6 Gap Analysis A well-defined high voltage fuse schedule needs to be created to ensure the recommended maintenance is

being performed in an acceptable time period. A more centralized database of fuse inspection and

maintenance needs to be created. PowerDB software should be used to store high voltage fuse inspection

information.



TIM programs.

TABLE 3.38 – STATION HIGH VOLTAGE FUSE

MAINTENANCE



IR Scan Yearly

Other – Check clip contact

pressure & clean

4-6 year

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

51

4 SCADA Maintenance - Stations and Distribution

4.1 Program Details Supervisory Control and Data Acquisition (SCADA) is a control system that allows for the monitoring and

control of compatible electrical equipment in the Hydro Ottawa electrical system. The maintenance

performed on SCADA controlled equipment includes visual inspection, checking communication, cleaning,

torquing, function testing and ground inspection.

4.2 Program Schedule Currently, SCADA devices are being inspected on an annual basis and

the SCADA controlled equipment has an operational test every 3 years.

The program does not have a predetermined budget (see Table 4.1).

4.3 Program Performance Indicators In 2013, HOL did not meet the target numbers due to lack of

available resources (see Table 4.2).

4.4 Data Governance The inspection records are currently being stored in an Access

database containing the information found in Table 4.3 and can be viewed using Intergraph GeoMedia

software or Microsoft Excel.

TABLE 4.3 – SCADA INSPECTION STORED INFORMATION

Device Type Pole Resistance Drawings "As Built"

Cabinet Nomenclature Verified Radio / RTU Lights Cabinet Condition

Pole Nomenclature Verified Antenna Appearance Cabinet Comment

By-Pass Switch Nomenclature Lightning Arrestors Additional Cabinet Comment

Nomenclature Remarks RSSI Signal (in dB) Check SF6 Gas Alarm Indicator

RTU Type All Locks in Place Check Air Break Position Sensor

Firmware Versions Heater and Fan Verified Fault Indicators

Config Saved Thermostat set at 5°C Date of Inspection

Cabinets Properly Grounded Infrared on All Electronics Battery Voltage (V)

Pole Properly Grounded Drawings in Cabinet Battery Date Installed

4.5 Reactive Maintenance If during the inspection the equipment cannot be repaired immediately an OMS ticket is created for HOL

crews to perform follow-up action.

4.6 Gap Analysis A defined budget and inspection cycle should be created. The inspection data needs to be analyzed in greater

depth. IR inspections could be completed on the switches at the time of SCADA maintenance to check for

overheating.

TABLE 4.2 –SCADA INSPECTIONS

Inspection

Target

Inspections

Actuals

135 40

TABLE 4.1 –SCADA BUDGET

2013 Budget 2013 Budget

Actuals

0 $68,422

201

4 T

esti

ng,

Insp

ecti

on

& M

ain

ten

ance

Pla

n

52

2014 Testing, Inspection & Maintenance Plan

Documents

Transcript of 2014 Testing, Inspection & Maintenance Plan