UAC Member Survey 2014 - EsaSafe · PDF fileUAC Member Survey 2014 ... • Results to be...
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Presented by Farrah Bourre Presented to UAC October 2, 2014 UAC Member Survey 2014
Transcript of UAC Member Survey 2014 - EsaSafe · PDF fileUAC Member Survey 2014 ... • Results to be...
Presented by Farrah Bourre Presented to UAC October 2, 2014
UAC Member Survey 2014
UAC Member Survey 2014
63% Response Rate
• Results summarized to RAGC Sept. 2
• Results to be provided to David Collie in Annual Advisory Council Chair Report to CEO
UAC MEMBER SURVEY RESULTS • OCTOBER 2, 2014 2
Results
UAC MEMBER SURVEY RESULTS • OCTOBER 2, 2014 3
Agreement that…. 2013 2014 Council is an effective forum for stakeholders & ESA to engage (Page 2)
88% (1 person disagrees)
93% (33% strongly)
Council has increased contributions in providing insight to ESA on stakeholder perspectives (Page 5)
75% Some/major contribution
26% increase 73% same
Council has increased contributions on technical/policy items (Page 5)
75% some/major contribution
20% 1 person - decreased
Council is effective in carrying out its mandate (Page 11)
* 87%
Council is engaged at appropriate stage in ESA’s strategic planning process (Page 11)
63% agree 1 person disagrees
73% 1 person strongly disagrees
*new 2014 question
Results
Agreement that…. 2013 2014 Council membership has correct mix of skills and competencies to bring balanced perspective to issues (Page 13)
75% (25% strongly) 2 people disagree
93% (20% strongly)
Appropriate ESA personnel are provided for meetings (Page 18)
* 100% (27% strongly)
Meetings are constructive and allow critical questioning (Page 18)
* 87% (20% strongly)
UAC MEMBER SURVEY RESULTS • OCTOBER 2, 2014 4
*new 2014 question
Accomplishments – 2013/2014
UAC’s Greatest Accomplishments • Contributions to new Bulletins, Handbook for First
Responders • Providing feedback and acting as sounding board • Consultations on voltage drop, emergency response to storms • Advice on public and worker safety programs resulting in
downward trend in powerline incidents; improvement in 22/04
• Keeping utilities engaged in conversation around 22/04
UAC MEMBER SURVEY RESULTS • OCTOBER 2, 2014 5
Looking Forward
UAC’s Focus for 2014/2015 • More items re: safety brought forward by members for
debate • More collaboration/brainstorming • Discussion on best practices • Coordination b/n ESA LDCs to reach out to high risk groups
to educate them about electrical safety • Utility consolidation/merger issues • Ontario equipment failure database • Best practices around inspection and maintenance
UAC MEMBER SURVEY RESULTS • OCTOBER 2, 2014 6
Challenges and Opportunities
• Increase council’s contributions on technical and operational items
• Increase understanding and importance of council’s contributions to ESA
UAC MEMBER SURVEY RESULTS • OCTOBER 2, 2014 7
Vice Chair Criteria
No term limit on the Vice-Chair Position Vice-Chair Criteria: • Governance experience; • Experience leading teams through decision making
processes; • Council or Committee experience; • Proven commitment to positioning societal perspectives; • Experience applying Robert’s Rules; • Ability to manage and engage others; and • Time availability to support Council activities
VICE CHAIR TIMELINES • OCTOBER 2, 2014 1
Vice Chair Nomination Timelines
• Call for Nominations – Oct. 2 2014
• Nominations – Oct. 6 – Nov. 6 2014
• Nominations Accepted – Week of Nov 10
• Nominee Info Sent to UAC – Week of Nov 17
• Vice Chair Election – December 11
VICE CHAIR TIMELINES • OCTOBER 2, 2014 2
Presented to Utility Advisory Committee Presented by Patrick Falzon Presentation date October 2 2014
Serious Incidents
Agenda
•Roofer contact •Non-Utility worker fatality •Eavestrough worker fatality
UAC Oct 2 2014 2
Roofer Contact
•Worker installing a metal flashing on the roof of a commercial building contacted an 8kV overhead powerline
•Worker received shock and fell 24ft-not tied off
UAC Oct 2 2014 3
Roofer Contact
UAC Oct 2 2014 4
Non-Utility Worker fatality
•Non-Utility worker came into contact with the secondary bus of a LDC owned pad mounted transformer
•Was testing for stray voltage issues
UAC Oct 2 2014 5
Non-Utility Worker fatality
•Non-utility worker used a grinder to cut the pad lock-LDC not called
•Dairy filter was installed over 9 years prior
•Primary CN disconnected from ground bar on transformer
UAC Oct 2 2014 6
Eavestrough Worker
•Fatality of a worker installing eavestrough-15years ago
•Worker moving ladder came into contact with overhead powerline.
•Partner sustained burns from step potential contact
UAC Oct 2 2014 7
Eavestrough Worker
•Current day
•While cleaning the eavestrough, worker contacted the overhead powerlines in the process of moving the ladder
UAC Oct 2 2014 8
Eavestrough Worker
•Same location as 15 years ago-splice
UAC Oct 2 2014 9
Health & Safety – April 15, 2014 event
Ajay Garg Hydro One Networks Inc.
ESA Utility Advisory Council Meeting October 2014
April 15, 2014 incident
Due to system maintenance activity load at five of the TS was distributed to K11W and K12W.
At 20:10, line protections automatically removed circuit K11W and its
companion K12W by configuration, resulting in 412 MW load loss in the western Toronto area. represented approximately 170,648 THESL customers
At 21:52 All loads were restored
April 15, 2014 incident (Contd.)
A newly constructed 27.6 kV feeder, built about 5 feet higher
Not yet in service (new poles 50’ vs. 45’)
contacted the K11W red phase
Confirmed that feeder needs to be lowered by 12’.
On the following day, Hold offs were obtained and the new and existing
feeders were lowered by the LDC.
Importance of Clearances
Significant health and safety risk for utility workers and the public
Inadequate “Line Clearances” will/can result in serious flashover and injuries
Changes to loading on transmission lines can increase conductor sag very quickly and reduce clearances significantly
Major events, such as
2003 North American blackout tree contact /clearance
Line Clearance Standards
Figure below illustrates how the distance between an object and transmission conductor changes as conductor operating temperature increases
Table 1 - Hydro One minimum vertical design clearance requirements between transmission and distribution conductors
Recommendations
1. Keep an inventory of your under build distribution line(s) - including physical design parameters
2. Make sure your new or existing structures have been approved by Hydro One
3. If approval has not been obtained a. Contact Hydro One Real Estate Services
b. Tel: 1-888-231-6657 or E-mail: [email protected]
4. Notify Hydro One Real Estate Services, in advance of: a. Installing new equipment on transmission rights-of-way
b. Modifying/replacing existing equipment on transmission rights-of-way
c. Constructing any new facilities that will cross beneath transmission lines
QUESTIONS?
Regional Infrastructure Planning
Ajay Garg Hydro One Networks Inc.
ESA Utility Advisory Council Meeting October 2014
Presentation Outline
● Context for Regional Infrastructure Planning
● Description of Regional Planning process
● Key features of Regional Infrastructure Planning (RIP) Process
● Transition and Implementation
● Regional planning websites (OPA/Hydro One)
● Status update and considerations for NW Ontario
Context for Regional Infrastructure Planning
● OEB announces need for Renewed Regulatory Framework for Electricity – RRFE (Oct. 2010)
● Board’s RRFE Report (Oct.18, 2012) set out 3 main policies ● 3 Rate Setting Methods for LDCs ● Planning
– Distribution Network Planning – Regional Infrastructure Planning
● Defining & Measuring Performance
● 5 Working Groups established ● Distribution Investment Planning, Performance & Benchmarking, Smart Grid, Regional
Infrastructure Planning, Asset Redefinition
● May 2013: Process Planning Working Group (PPWG) Report endorsed by the OEB
● Today’s focus - Regional Infrastructure Planning
Objectives of RIP Process
● A more structured and transparent approach to Regional Infrastructure Planning
● Assessment and planning to support timely identification and implementation of solutions
● Coordinated regional planning to ensure cost effective and efficient wires expansion
● Coordinate with the IRRP process to account for integrated (i.e. non-wires) solutions
● Support LDC rate applications
● Support transmitter rate and LTC (s.92) applications
Background and Highlights for Planning
● Power system planning involves the assessment of electrical needs (near, mid & long term) and the development of resources (generation & CDM) and wires (to connect and deliver power from resources to loads) to meet those needs
● OPA has been the mid [5 - 10 years] & long term [10 - 20 years] system planner at the bulk and regional level, including planning for resources and wires
● Transmitter conducts wires planning in coordination with:
- OPA on Inter-area Network and Local Area facilities; and - more directly with customers on connection facilities
● LDCs conduct wires (and resource) planning at distribution level and coordinate with Transmitter and OPA for mainly transmission supply facilities
What is Regional Infrastructure Planning ?
● Regional Infrastructure Planning: ● Focuses on planning of wires (mainly Tx and some Dx) ● Where needs are driven by regional considerations, coordinates planning of
wire facilities at the bulk transmission and distribution levels ● Coordinates, where required, transmission supply facilities to LDCs and other
customers
● Regional Infrastructure Planning does NOT plan: ● Bulk transmission facilities except where such facilities are driven by regional
needs or provide an alternative solution ● Distribution facilities except where such facilities are driven by regional needs ● Resources (i.e. Generation and CDM) at bulk, regional and distribution level
Regional Infrastructure Planning Features (1)
● A structured and more formal approach with regular reporting: ● 21 electrically based regions will help study efficiency and manageability ● Planning reports for all regions will be done in 3-5 year cycles ● Planned solutions to meet regional supply needs ● Support LDC and Transmitter planning activities ● RIP annual status updates to the Board
● Increased transparency of plan scoping and development
● Recognizes need for coordination with OPA’s IRRP process
Regional Infrastructure Planning Features (2)
● With three possible outcomes, RIP provides for the appropriate level of planning coordination: ● No regional coordination needed ● Regional coordination of wires only ● Regional coordination of resources (CDM & generation) and wires
● Sufficiently flexible to accommodate varying levels of planning complexity,
diversity of issues, and timing of needs
● Planning at sub-regional level can be done independently where appropriate
● Seeks to streamline the planning process where possible
Transmitter Key Deliverables
Intermediate Products ● Initial steps in Regional Planning process ● Needs Screening /Assessment Report
- Determines if regional planning needed and, if so, LDCs to be active participants
Final Products ● Planning Status Update Letters ● Periodic RIP Status updates to the OEB ● Regional Infrastructure Plan
- Recommended ‘wires’ solutions - Implementation plan - Project timelines and monitoring
OPA Key Deliverables
Intermediate Product ● Scoping Process Outcome Report
● Includes preliminary Terms of Reference ● Identifies planning approach - IRRP or RIP only
Final Product ● Integrated Regional Resource Plan (IRRP)
● Stakeholdering where appropriate ● Hand-off letter to transmitters for “wires only” planning ● Resource implementation plan ● Project timelines and monitoring
RIP Transition
● Up to 4 years to complete first cycle
● 21 Regions are prioritized into 3 groups based on expected need, geographic and resource considerations
● Group 1 - (underway – 2014) ● Group 2 - (2014 – 2015) ● Group 3 - (2015 – 2016)
● Regions in Group 1 have planning activities underway for some or all parts of the region
● Board endorsed Standing Committee to be established ● Facilitated by OEB staff and comprised of LDCs, transmitters, OPA and other
interest groups ● Regular reviews of the process and regional makeup ● Recommends changes based on ‘lessons learned’ ● Advises industry of any process/region changes
21 Preliminary Regions
Group 1 Group 2 Group 3
Burlington to Nanticoke East Lake Superior Chatham/Lambton/Sarnia
Greater Ottawa GTA East Greater Bruce/Huron
GTA North London area Niagara
GTA West Peterborough to Kingston
North of Moosonee
KWCG South Georgian Bay/Muskoka
North/East of Sudbury
Metro Toronto Sudbury/Algoma Renfrew
Northwest Ontario St. Lawrence
Windsor-Essex
Websites to Support Regional Planning
● Hydro One RIP activities http://www.hydroone.com/RegionalPlanning
● OPA IRRP activities http://www.powerauthority.on.ca/power-planning/regional-planning
● Hydro One and OPA sites inter-linked with each other and with the OEB website
● Provides full planning picture for a Region
● During transition not all material may not be consistent or complete (work in progress)
Hydro One Website – Landing Page (1)
Hydro One Website – Landing Page (2)
Hydro One Website – Region Template (1)
Hydro One Website – Region Template (2)
OPA Website Screenshots
OPA Regional Planning Website – Main Page (1)
OPA Regional Planning Website – Main Page (2)
OPA Regional Planning Website – Region Page
Current Status
● Website up and running
● Planning Status letters to LDCs from H1
● NS for Group 1 regions led by H1
● IRRP for Group 1 transition led by the OPA
QUESTIONS AND FEEDBACK?
Jason Hrycyshyn, P.Eng October 2, 2014
Audit Guideline and New Auditor Update
Audit Guideline Overview
Section 3 – Auditor Qualifications
• Six criteria for acceptance have been established
• Independence
• Ethical Standards
• Auditing Competencies
• Subject Matter Competencies
• Training
• Education, Work Experience and Continuing Professional
Development
2 Audit Guideline
Audit Guideline Overview
3 Audit Guideline
Audit Guideline Overview
4 Audit Guideline
Auditing Experience (auditor
must be independent of the
organizational unit being
audited)
30 days minimum of
auditing experience
over past three years
or
successful completion
of 2 shadow audits*
and 2 witness**
audits of Regulation
22/04 and totaling a
minimum of 24 hours.
30 days minimum of
auditing experience
over past three years
or
successful completion
of 2 shadow audits*
and 2 witness** audits
of Regulation 22/04
and totaling a
minimum of 24 hours.
*
**
Shadow Audit – Following an existing Regulation 22/04 qualified Auditor.
Witness Audit – Performing an audit under the supervision of an existing Regulation 22/04 qualified Auditor.
Audit Guideline Overview
Declaration of Auditor Compliance
The Declaration of Compliance is submitted by name of approved Auditor.
I name of approved Auditor hereby state that name of Auditor has successfully completed the
required number of shadow and witness audits totaling the minimum number of required hours as
defined by ESA.
I shall provide ESA with this Declaration of Auditor Compliance to ESA.
I shall provide ESA with such additional information relating to the review and validation process as
is considered necessary by ESA to support this Declaration of Auditor Compliance.
Signature
Title or Professional Designation
Date
5 Audit Guideline
Distributor Bulletin
Electrical Distribution Safety
July 11, 2014 Bulletin DB-06/14
Provincial Office 155A Matheson Blvd. West, Suite 200, Mississauga, Ontario L5R 3L5 Fax 905-507-4572
Website: www.esasafe.com E-Mail: [email protected]
Updated Auditor Information
Ontario Regulation 22/04, Section 13 requires every distributor to engage an auditor to conduct an annual audit of the distributor’s compliance with sections 4,5,6,7 and 8 and to prepare an audit report. The distributor shall engage an audit organization that is accredited by the Standards Council of Canada to register quality management systems whose scope of accreditation includes engineering services, construction and electricity supply or an organization acceptable to the Electrical Safety Authority.
The Electrical Safety Authority has reviewed and approved the applications of the following auditors and has found them qualified to conduct audits under Ontario Regulation 22/04. Catherine Ethier, P. Eng. MSc Burman Energy Consultants Group Senior Consultant, Program Engineering 4309 Lloydtown - Aurora Rd. King, Ontario, L7B 0E6 Tel: (877) 662-5489, (905) 939-7676 ext 247 Fax: (905) 939-4606 Email: [email protected] Web: burmanenergy.ca
Kris Paszkowiak, P.Eng. Contact: Neil Sandford, P.Eng. Vice President, Distribution Utility Services AESI Acumen Engineered Solutions International Inc. 775 Main St. East, Suite 1B Milton, ON. L9T 3Z3 Tel. (905) 875 2075 Fax. (905) 875 2062 Email: [email protected] Leslie Stoch, P. Eng. Leslie Stoch and Associates Contact: Neil Sandford, P.Eng. Vice President, Distribution Utility Services AESI Acumen Engineered Solutions International Inc. 775 Main St. East, Suite 1B Milton, ON. L9T 3Z3 Tel. (905) 875 2075 Fax. (905) 875 2062 Email: [email protected]
Carol Whalen, P. Eng. QUASAR, Quality Systems Assessment Registrar Contact: Indy Jaswal Registrar & Manager, Quality Assurance 8260 Parkhill Dr Milton, Ontario, L9T 5V7 Tel: (800) 844-6790 Ext.246 E-mail: [email protected]
Simeon F. Go, CET, ASA, CUSA 5223 Brockworth Drive Mississauga, Ontario, L5V 2B5 Tel: (905) 819-8696 Email: [email protected] John Smiciklas, BASc MJRD Assessment Incorporated 2028 Gander Street Oakville, Ontario L6H 3X7 Tel: (416) 358-9680 E-Mail: [email protected]
Jason Hrycyshyn, P.Eng September 15, 2014
Temporary Overvoltage (TOV)
Temporary Overvoltage (TOV)
GOALS • Create a Working Group
• Develop a Best Practice to define safety concerning TOV events and detail the interaction between LDCs and ESA
• Reasonable steps to ensure life safety devices (ex. smoke detectors) are addressed if there is a reasonably foreseeable concern they were damaged as part of a safety concerning TOV event
• Satisfy the LDC’s and ESA’s desire to have a well documented process.
2 TOV
Temporary Overvoltage (TOV)
What safety concerning TOV are we talking about? • Magnitude of the overvoltage
• Duration of the overvoltage
• Frequency of the overvoltage (ex. 60Hz, lightning)
What Life Safety Devices are we talking about which may be impacted by a TOV? What type of interaction (LDC / ESA) are we talking about? 3 TOV
Copper Theft ESA Meeting of the Utility Advisory Council Lorianne Gardner, Security Specialist, Security Operations
1
Introduction
• Security Operations initiated a province wide project to upgrade security at Operations Centers and Transmission Stations with Facilities and Asset Management in 2010 to address the ever increasing incidents of copper theft. As a result…
• Operation Centers will receive enhanced perimeter/yard security and Access Control
• Select Transmission Stations will receive enhanced perimeter security upgrades
2
Operation Centers
• These facilities which are located across the province may be equipped with:
• Thermal Closed Circuit Television, (CCTV) systems
• PTZ CCTV within the yards
• Video Analytics (To Track Intruders)
• Electronic Access Control (Yard & Facility Access)
3
Transmission Stations
• These facilities will be selected for security upgrades based on criticality to the overall electrical system and
• The number of criminal incidents at each facility will be used to determine the priority of the site receiving upgrades
• Upgrades may include Fencing, Thermal & PTZ Cameras, Video Analytics and Access Controls
4
Station Security
• Overview of security improvements
– Electronic Access Control – Concierge Service
5
Station Security
• Overview of security improvements
– Perimeter Thermal Cameras
6
Station Security
• Overview of security improvements
– Strategically Placed PTZ Cameras in Yards – Video Analytics – Remote Monitoring
7
Fence Upgrades
• Razor Wire fence upgrades have been completed at 45 high risk facilities. This initiative has been completed.
• Expanded Metal Grating is being used to replace chain link fencing materials at identified facilities.
8
Copper Theft
• Hydro One Networks like other utilities, (telecommunications, railways) have experienced significant criminal incidents of copper and tool theft
• Incidents of copper theft are directly related to the price of copper and rise and fall accordingly
• Copper theft from energized stations can adversely impact the electrical distribution system with power outages resulting
9
Statistics
10
0
50
100
150
200
250
# of Incidents
2008 2009 2010 2011 2012 2013
Year
Metal Thefts by Year
# of Thefts
• Metal Theft at Hydro One
has declined since 2008
• In 2014, there has been a 15% increase in metal
thefts from the same time period in 2013
Mitigation Strategies
• Aluminum Fence Grounds
• Painting the Grounds to Reduce Scrap Value
• Encasing Transformer Neutrals in Conduit
• Wrapping Buried Grounding Around Fence Posts
• Use of Copper Weld Cable
• Use of Super Structures as Grounding
11
Partnerships
• Two Metal Theft Symposiums were held to discuss how metal theft has
impacted many of Ontario’s critical infrastructure sectors. Key partners from
Telecommunications, Rail, Utilities and Police Services were brought together to
find a solution to this escalating crime.
• As a result of the two meetings the OPP have designated a Metal Theft Crime
Analyst and many of the Critical Infrastructure Partners and Police Services
have created a working group that will provide 3 years of statistical data and real
time theft to analyze and determine criminal gangs that cross geographical and
victim boundaries. The OPP will use this data to assemble participants of the
working group to target these criminal organizations.
12
Partnerships
13
• Also select members of this working group had a chance to speak with
MP Wai Wong on April 11, 2014 to express the concerns related to
metal theft and critical infrastructure reliability
• Hydro One Security Operations has supported an initiative by the CEA
to write a Policy Paper on Copper Theft from Canada’s Electricity
Infrastructure: Dangerous, Expensive and a Threat to Reliability. The
Paper suggests that there be a national plan to combat copper theft in
Canada which includes a coalition of stakeholders, provincial and
federal legislation and amendments to the Criminal Code.
Partnerships
• Security Operations - Police Training Video on
Copper Theft
• Security Operations - YouTube (Public Service
Announcement Video)
• Hydro One Security Operations is working with Station Service
Superintendents to create Expert Witnesses that have the ability to
explain to the courts the safety and reliability concerns when a theft
occurs at one of our facilities
14
Partnerships
• Postcards will be created as part of the Metal Theft Affects Me
campaign that will be handed out to the public at events that Hydro One
has a booth
15
Partnerships
• What we would like industry partners to do?
– Report all metal thefts to the police.
– Seize any opportunity to discuss metal theft as a safety issue and not just
the money.
– Help lobby for new legislation to combat metal theft.
– Work together to combat metal theft. Learn from each other.
16
Questions
Ron Gentle CSO Security Operations Hydro One Networks Inc. 416-345-6090 Lori Gardner Security Specialist Asset Protection and Investigative Services Security Operations Hydro One Networks Inc. 47-224-5764
17
Jason Hrycyshyn, P.Eng October 2, 2014
In-Field Equipment Refurbishment
Equipment Refurbishment
Question for Regulator • How does ESA view cable injection programs, as it relates to
Section 6 (Equipment Approval) of Regulation 22/04?
2 POWERLINE SAFETY CAMPAIGN UPDATE
Equipment Refurbishment
3 POWERLINE SAFETY CAMPAIGN UPDATE
Examples of In-Field Equipment Refurbishment, including cable injection.
Equipment Refurbishment
Answer • ESA views work performed in the field no different than within a
repair facility. ESA refers to 2.7.5 and 2.7.6 of the Technical Guidelines and Bulletin DB-05/14 for direction.
• ESA views in-field refurbishment work such as filling significantly sized voids in poles (ex. woodpecker holes), pole strength restoration wraps, cable injection programs and similar work to be applicable to the direction outlined in 2.7.5 and 2.7.6 of the Technical Guidelines and Bulletin DB-05/14.
4 POWERLINE SAFETY CAMPAIGN UPDATE
Equipment Refurbishment
Clarification Note • ESA notes for clarity that other, similar work such as
general maintenance activities in substation and switch lubrication to not fall under the scope of Section 6 of Regulation 22/04. These activities are considered to be maintenance activities and not refurbishment.
POWERLINE SAFETY CAMPAIGN UPDATE 5
Equipment Refurbishment
2.7.5 and 2.7.6 of the Technical Guidelines • 2.7.5 Good Utility Practice for Non-Major Equipment • 2.7.6 Good Utility Practice for Major Equipment used for
Maintenance or Reuse
Bulletin DB-05-14
• Major Equipment Refurbishment
POWERLINE SAFETY CAMPAIGN UPDATE 6
