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Advanced Distribution AutomationDiscussion Topic

Webinars #2 and #3

Nashville, TN

June 25 and June 26, 2014

2014 Transmission & Distribution BenchmarkingData Review Conference

Agenda

June 25, 2014 •Introductions•Overview of Discussion Topic Webinars – Questions to be answered•Discussion Topic Deliverables•Background on Advanced DA Topic, including review of information collected this year through the main T&D survey questionnaire•Recap of Webinar #1 completed on June 18 – “Where Are We?” •Webinar #2: - “How Did We Get Here?” Input from all participating companies

June 26, 2014•Webinar #3: - “Where Are We Going?” Input from all participating companies •Next Steps

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Overview of Advanced DA Webinars – Questions to be answered

Webinar #1 Where are We?(Completed - June 18)

Webinar #2How Did We Get Here?June 25, 2014

Webinar #3Where are We Going?June 26, 2014

• Technologies now in place o Pilotso Widespread

• Customer impact and acceptance

• Integration levels• Time in service• Documented benefits

• Driving forces• Evaluation of progress• Biggest obstacles

encountered• System performance

issues• Organization and

staffing impacts

• Planned installations over next 5 years o Pilotso Widespread

• Expected costs• Business cases• Regulatory or legislative

mandates• Integration with other

asset management plans

Discussion Topic Deliverables

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◼ Recordings and summaries of all webinar discussions

◼ Presentation of key insights/practices and other “learning” gleaned from the webinars

◼ Presentations of practices and initiatives from one or more companies

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Background

◼ We conducted Research Topics on “Intelligent Grid” in 2008 and “Distribution Automation” in 2011.

◼ Information on what our panel companies have been doing in this area has been collected annually through the main T&D benchmarking survey

◼ On the surface, our panel companies do not seem to be progressing as quickly in implementing advanced distribution automation systems as was anticipated several years ago

◼ This year, we have made some modifications to the questionnaire and are also conducting three discussion topic webinars to better understand:

1. What our companies have accomplished to date through their DA initiatives 2. What obstacles and challenges our companies have encountered while

implementing these systems3. The specific goals, plans and business cases that will be driving activity in this

area over the next several years

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2014 Survey – Preliminary Results

This chart provides an overview of technology status as of 2014. More than 70% of the responding companies have installed the technologies shaded in dark blue and more than 40% have installed the technologies shaded in light blue (Source: question DP15)

* This table shows the percent of responding companies reporting each technology at each status level

(Responses from 7 companies)

2014 Company Technology Status* :Now Pilot

/LimitedNow

WidespreadPlanned

Pilot/LimitedPlanned

WidespreadAMI: Smart meters 29% 57% 0% 29%AMI: AMI DMS integration 14% 29% 14% 14% AMI: Summer Saver Air conditioning 14% 0% 0% 0%AMI: Net Metering program 0% 29% 0% 14% DA: Remote controllers of switches and breakers 43% 43% 14% 14%DA: DMS/OMS 29% 43% 0% 57% DA: Automated capacitor controllers 57% 14% 0% 29% DA: Voltage and VAR control 57% 14% 14% 14% DA: Fault location based on wave shape analysis 43% 0% 14% 0% DA: Demand Response 29% 14% 0% 0% DA: Other 0% 14% 0% 0% DG: Distributed Storage [battery] 43% 0% 0% 0% DG: Distributed Generation Integration 29% 43% 0% 0%DG: Plug-in Hybrid vehicles 29% 14% 0% 0%Other Technology 14% 0% 0% 14%

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2014 Survey -- Preliminary Results -- System Impact

The responses to date show wide ranges in the % of feeder devices that can be operated remotely

% of Substation BreakersRange: 5% to 100% % of Line Switches

Range: 0% to 70% % of Cap BanksRange: 0% to 100%

(Responses from 7-9 companies)

Source ST Report pages 21-23, question ST110

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2014 Survey -- Preliminary Results -- Customer Impact

The responses to date also show wide ranges in the % of customers that are on circuits with different types of remote or automatic switching

(Responses from 5-8 companies)% on circuits with remotely

operated substation breakersRange: 5% to 100%

% on circuits with remotely operated line switchesRange: 0% to 27% % on circuits with automatic

FLISR schemesRange: 0 to 2%

Source ST Report pages 24-26, question ST115

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2014 Survey -- Preliminary Results – Demand Response Impact

The few responses to date show a wide range in the % of customer load that companies can interrupt during peak demand hours (demand response programs)

(Responses from 4 companies)

% of C/I LoadRange: 0% to 70%

% of Residential LoadRange: 0% to 1.25%

Source DP Report pages 6 and 7, question DP25

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2014 Survey – Preliminary Results – Use of Advanced Distribution Management Systems (ADMS)

Total Respondents 5

Yes 40%

No 60%

Total Respondents 3

VoltVar Optimiization 66.67%

Fault Location Isolation and Service Restoration 33.33%

Network configuration 33.33%

Training simulator 0%

Other 66.67%

(Responses from 5 companies)

Source DP Report pages 80 and 81, questions DP290 and DP295

Some companies have implemented Advanced Distribution Management Systems to integrate core DA functions on a common platform

DP290: Do you have an ADMS?

DP295: If you have an ADMS, what modules do you use?

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Gaps in Our Understanding

The benchmarking survey provides a great deal of information, but leaves some gaps in our understanding of the DA topic. In particular, we want to know more about:

◼ Why companies have chosen to implement or not implement the various technologies

◼ The level of customer acceptance of the technologies◼ How well the installed technologies are performing◼ How/whether the technologies have been integrated◼ What benefits have been achieved and documented◼ What obstacles, if any, are hindering the implementation of these technologies◼ What impact the technologies have had or are expected to have on company

staffing and training requirements◼ What is each company’s overall business case for moving forward

The year’s webinars are designed to fill in the above gaps

Advanced DA Discussion Topic Scope

Functions:

1. Remote Monitoring & Control of Feeder Devices (Breakers, Switches, Sectionalizers, Reclosers)

2. Automated Fault Location & Fault Isolation between Feeder Devices

3. Automatic Restoration via Centralized or Field Localized Intelligence

4. Remote Monitoring & Control of Capacitors

5. Automatic Voltage & VAR Control at the Circuit Level

6. Automatic Protection Reconfiguration

7. Remote Monitoring & Control of Customer Load Shedding (Demand Response)

8. Distribution Transformer Monitoring

9. Remote Monitoring & Control of Distributed Generation

10. Integration of Distributed Storage (batteries)

11. Automatic Islanding and Resynchronization

12. Real‐Time Communications from the Utility to the Customer

Related Systems:

13. GIS

14. OMS

15. D-SCADA

16. DMS

17. AMI

18. Demand Response

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System Integration Model

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Recap of Webinar #1 – Where Are We?

Participating Companies: BC Hydro, CenterPoint, KCP&L, Northwestern Energy, Oncor, PECO, Tucson Electric and Westar

Current installed technologies: Companies reported differing levels of implementation for various types of DA technology. The responses can be summarized as follows:

Remote control of substation breakers - All companies on the webinar except Northwestern Energy now control most or all of their distribution substation breakers via SCADA. Northwestern Energy is currently extending its communications system to reach distribution substations that serve about 90% of its customer base by 2020.

Remote control of line devices (switches and reclosers), remote control of capacitors, automatic voltage/VAR optimization and fault location, isolation and restoration (FLISR) - These are core functions that are included in all of the companies’ active DA initiatives.

Distributed generation, distributed storage and automatic islanding/resynchronization (microgrids)– BC Hydro and Tucson Electric have implemented all three of these technologies. KCP&L has implemented the first two and Oncor has implemented a distributed storage pilot. The other four companies on the webinar have not implemented any of these technologies

Demand response and real time communications to customers – KCP&L, Northwestern Energy and Tucson Electric have implemented demand response systems and KCP&L and Northwestern Energy also provide real-time communication of energy usage and cost information to customers. The other five companies have not implemented either of these DA technologies although some did mention their Outage website as an example of real time communications to customers.

Distribution transformer monitoring (condition-based maintenance)– BC Hydro is the only company on the webinar that has implemented this technology

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Recap of Webinar #1 – Where Are We? (Continued)

Customer impact and acceptance : Companies reported relatively low customer impact percentages (<20%) for much of the

DA technology that they have implemented. The exceptions are remote control of distribution substation breakers and remote control of capacitors – installed functions which now typically impact much higher percentages of the customer base.

Companies reported that customers are generally not aware of the DA technology that is in place “before the meter”. Acceptance of DA technologies that directly impact and engage customers, such as demand response and real-time communications, varies across the customer base. More technically oriented customers like having the ability to interact with these systems but the majority seem to be indifferent and/or more happy with a “set it and forget it” solution.

Years in service: Companies reported that that SCADA control of distribution substation breakers has been

in service for decades. Oncor’s technology for remote control of switches, line reclosers and capacitors has also been in service for about 10 years. The other companies indicated that their current DA technology other than substation SCADA is relatively new --- in service for three years or less.

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Recap of Webinar #1 – Where Are We? (Continued)

Benefits achieved and documented: Several companies reported that they are tracking the customer minutes of interruption

(CMI) that were saved through remote switching and/or the operation of their automated switching schemes. A question that was asked but not answered during the webinar is whether companies can attach a dollar value to these CMI savings.

Northwestern Energy reported that they are currently developing a method to determine the dollar value of energy savings achieved through Voltage/VAR optimization on their current pilot system

In addition to savings in the above two areas, Oncor has documented O&M labor cost reductions attributable to their remote switching capabilities

Level of system integration: CenterPoint reported that they are currently engaged in a large scale effort to

convert/integrate their OMS and D-SCADA systems into a new Advanced DMS system. They plan to do a “flash cutover” in November of 2014.

Oncor reported that their OMS, DMS and D-SCADA are already fully integrated Other companies reported more modest levels of integration, typically focused on one or

both of the following areas:

1) Using extracts from GIS systems to create and update the network models used by OMS and DA-related systems

2) Feeding outage detection data from AMI or AMR systems into OMS and DMS systems

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Webinar #2: How Did We Get Here?

Please answer the following questions about your DA initiatives to date:

1. What have been the driving forces behind your DA initiatives? What factors influenced your scoping decisions for pilots and widespread installations?

2. Have your DA initiatives progressed as quickly as expected? Are you and your stakeholders satisfied with the progress that has been made to date?

3. What have been the biggest implementation obstacles and challenges that you have encountered?

4. Have all of the installed DA technologies performed as well as expected? If not, what performance issues have been encountered and how have you been addressing those issues?

5. How have you organized and staffed your DA work? Have you done all of the planning, design, installation and maintenance work in-house? Have you contracted or used outside service providers for any significant portions of your DA work?

Webinar #2 Conclusion: These expected benefits of Distribution Automation were the driving force of what has been done to date

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* DER = Distributed Energy Resources – this encompasses Distributed Generation, Distributed Storage and utility controllable Demand Response

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Webinar #3: Where Are We Going?

Please answer the following questions about your DA plans for the next five years:

1. What specific DA functions/systems (new, expanded or replacement) are you planning to implement:

On a pilot or limited basis? On a wide-scale basis?

What are the key milestones/target implementation dates for the above plans?

2. About how much money will you be investing in DA technology over the next five years?

3. What benefits are identified in your business case(s) for these DA plans? Measurable benefits Non-measurable benefits

4. Are your DA plans being driven by any specific regulatory or legislative mandates?

5. Are your DA plans being justified on a stand-alone basis or are they part of a broader “grid modernization” or “infrastructure improvement” initiative?

Next Steps

Task Details Due Date Who?

Document webinars #2 and #3 discussions

Post webinar recordings a summary of responses on website

July 14 1QC

Complete T&D Questionnaire

Provide/verify/fix responses to all questions related to Distribution Automation (ST110, ST115, DP5 through DP25, DP290 and DP295)

July 21 (3rd Draft)

August 4(Final)

All companies

Insights ConferencePresentations

1. 1QC summary of key insights, common practices and other “learning” derived from questionnaire and webinars

Insights Conf. August 19-22

1QC

2. One or more company presentations on their practices and initiatives

Insights Conf. August 19-22

?

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Insights Conference

Here are some possible topics for company presentations or roundtable discussions at the Insights Conference:

◼ Road map and building blocks – Moving beyond the pilot/learning stage, what is the “best” sequence of developmental activity to maximize the effectiveness of company DA initiatives?

◼ Large scale system integration – what are the key planning and preparatory activities that companies must complete to assure a smooth transition?

◼ Workforce impacts – how has the introduction of DA technology impacted company staffing and training requirements (both in the field and in the distribution control center)? What are companies doing to keep their operations personnel up to date on the technology that is being installed?

◼ Demand response – what approaches have been successful in recruiting and effectively engaging customers in these programs?

◼ Distributed generation – should/do companies proactively seek and support customer owned DG development on their distribution systems? What are the long range implications of customer-owned DG to the distribution utility business model?

◼ Others?

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Thank you for your Input and Participation!

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