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Home My WebLink About2017-06-15 RMLD Board of Commissioners MinutespyyN OF O' yc Town of Reading Meeting Minutes co Board - Committee - Commission - Council: RMLD Board of Commissioners Date: 2017-06-15 Building: Reading Municipal Light Building Address: 230 Ash Street Purpose: General Business Attendees: Members - Present: Time: 7:30 PM Location: Winfred Spurr Audio Visual Room Session: Open Session Version: Philip B. Pacino, Chairman -Secretary Pro Tem; David Hennessy, Vice Chairman; Thomas O'Rourke, Commissioner; David Talbot, Commissioner. Members - Not Present: John Stempeck, Commissioner Others Present: RMLD: Coleen O'Brien, General Manager, Hamid Jaffari, Director of Engineering and Operations, Jane Parenteau, Director of Integrated Resources, Wendy Markiewicz, Director of Business Finance, and Tracy Schultz, Executive Assistant CAB: Dennis Kelley, Secretary, Citizens' Advisory Board Guest: Mayhew Seavey, PLM Engineering Public: Tony D'Arezzo, Resident, 130 John Street, Reading, MA Minutes Respectfully Submitted By: Philip B. Pacino, Chairman, Secretary Pro Tem Topics of Discussion: Call Meeting to Order Chairman Pacino called the meeting to order and announced that the meeting is being videotaped at the RMLD office at 230 Ash Street, for distribution to the community television stations in Reading, North Reading, Lynnfield, and Wilmington. Chairman Pacino expressed his concern that he received a complaint from the North Reading Selectmen that North Reading Cable Access and Media (NORCAM), North Reading's public access station, hasn't been receiving DVDs of the meetings. Ms. Parenteau explained that RMLD makes copies of the meeting DVDs and she will make sure that they are being delivered. Opening Remarks Chairman Pacino read the RMLD Board of Commissioners' Code of Conduct and welcomed Mr. Kelley from the Citizens Advisory Board. Mr. Kelley commented that the recent solar tour was interesting. Chairman Pacino announced that Mr. Stempeck is away and would not be in attendance this evening. Public Comment There were no Board Liaisons present and there was no public comment. Page I I Report RMLD Board Member Attendance at Citizens' Advisory Board Meeting May 24, 2017 Chairman Pacino stated that the CAB meeting's primary focus was the rate adjustments that the Commission will examine this evening. The CAB voted to recommend that the Commission approve the new rates. Report of the'Chait,�_� Chairman Pacino stated that he wanted to comment publicly that he saw a sign on Ash Street that read "Hate has no home here" and that he totally endorses and agrees with that statement. The Wilmington solar ribbon cutting ceremony was held last Thursday and that project is now up and running. The Commission had a strategic session with discussion and many assignments for the group to come back with. Chairman Pacino asked Mr. Kelly whether the CAB has determined who will be its members on the Committee on Payment to the Town of Reading stands. Mr. Kelley replied that he will check with Mr. Hooper. General Manager's Report - Ms. O'Brien Ms. O'Brien announced that RMLD Customer Service will be closed on Monday, July 3rd and Tuesday, July 4th. RMLD held a ribbon cutting ceremony at the community solar project at 326 Ballardvale on Thursday. It was a great event. There is another ribbon cutting coming up for the peak generator, but that date remains to be determined. In terms of community engagement, an informational table on Shred the Peak will be set up at the Reading Lions Club Friends and Family Day on June 17th, and at the Wilmington farmers' market on June 25th. Info sessions will be held at local senior centers on various days in June. Ms. O' Brien will be meeting with the North Reading Board of Selectmen on Monday, June 19th. Mr. O'Rourke asked that event dates now be included in the Commission packets. Quarterly Updates: Organizational L Reliability Reports - Ms. O'Brien and Mr. Jaffari (Attachment 1) - Ms. O'Brien explained that she would be talking about the Organizational highlights. A report will be issued in the first quarter of next year on the progress of. the Strategic Plan. The Six-year plan was updated as part of the budget, and is ongoing every year. The electric system master plan has essentially been completed by Mr. Jaffari and his group. There will be a final report and presentation in September to show where we are with grid modernization and the entire technological road map. The workforce development plan is wrapping up -that means career development plans and rewritten job descriptions for all employees. We're in the final stages and it has been quite an undertaking. A part of that is succession planning. As we've been redoing the job descriptions we've been anticipating employees who may be retiring in 5 -years and making sure that skill sets have been broadened, so other employees in those groups have opportunities to move ahead. RMLD now has a new review process that was just finalized. All managers are sitting down with their employees and giving out goals. The process starts July 1, fiscal year 2018. Organizational culture and employee satisfaction will be assessed; we will get a lot of input once the review process begins. A year from now, everyone will be reviewed in the management union. The labor union doesn't have a formal review process. There is an increase in efforts to fill vacant positions. Engineering will now be composed of five system engineer positions. All five engineers will be cross trained and capable of running the system. Mr. O'Rourke suggested an employee survey. Ms. O'Brien stated that RMLD has a survey that is part of what Leidos said to do; now that the reorganization is nearing completion, feedback can Page 1 2 Quarterly Updates: Organizational & Reliability Reports - Ms. O'Brien and Mr. Jaffari (Attachment 1) be solicited. Ms. O' Brien continued: cross -divisional management training is occurring, as is leadership training. Project management training will be held onsite at RMLD. Policies are ongoing. A risk management plan, as far as power supply, is an ongoing process. Changes in financial business processes are moving along. Assigning a compliance manager has not been done yet -figuring out the best way to address that. Asset management plan putting in SpryPoint-an automated quasi -work order stock timesheet system, that will serve as an interim while work order systems are reviewed. There has never been a true work order system here. There's now a pilot program in place for the interim program. The current work place is being enhanced; once the office is painted and reorganized, Ms. O' Brien proposed a tour for the Commissioners in September. Vice Chairman Hennessy asked if the leadership development for the management team has already started. Ms. O'Brien replied that there are a couple of levels of leadership. For middle management, project management, supervisory skills, and conflict resolution have been put onto everyone's career development plans. Middle management knows what they must take. Leadership in unions will also be required to take courses. Training plans for direct reporting managers are being developed. Mr. Kelley asked, without a work order system, how have you been tracking labor and cost? Ms. O'Brien replied, by using a paper stock sheet system. We will implement a full Work Order system. It is being evaluated. Mr. Kelley asked how were you doing inventory management then? Ms. O'Brien answered that everything was being done manually. The stock sheet has now become automated, and it has also become integrated. It's on tablets and is being piloted with the troublemen and the Control Room. Once that pilot is done it will be rolled out to everyone else and we'll get rid of the paper stock sheets. Mr. Jaffari stated that RMLD is making good progress on the Booth reliability recommendations. Mr. Jaffari stated that he is glad to announce that the bus work at Station 5 is completed. That substation is old and is nearing the end of its useful life so we're looking for land in the Wilmington area to build a new substation. However, that will take 3 to 5 years to be completed. In the interim, RMLD has made upgrades and rejuvenated the switchgear and reinsulated the bus in the existing station. While doing so, asbestos was discovered, which has prolonged the project. The switchgear's life has been extended for another 5 to 10 years. GIS data collection is completed and the contractor's work is being checked. This is anticipated to be completed by September 1 and then the data will be put into the engineering model so analysis can be down with more accuracy. SCADA work is underway. This week, consultants are upgrading SCADA and programming substation 3 and substation 4 to send telemetry data and connect to Eversource and National Grid so RMLD can join the overall 115 kv network. All critical substation items that were identified by UPG, the contractor that was brought in to test substations, have been addressed and completed. Mr. Kelley asked if a recent Wilmington outage was due upgrades to Substation 5. Ms. O' Brien replied it was not. The drawing setting didn't match the relay setting. It wasn't a new setting. It wasn't part of an, upgrade. It was a mistake on how it had been labeled originally. Recent directed testing was performed to catch it. Page 1 3 Proposed Rate Adjustments (Attachment 3) RATE TARIFF No. Residential Schedule A MDPU #269 Residential Time -of -Use Schedule A2 MDPU #270 Commercial Schedule C MDPU #271 Industrial Time -of -Use Schedule I MDPU #272 School Schedule SCH MDPU #273 Residential Schedule RW MDPU #274 Backup and Standby Rate MDPU #275 Purchase Power, Capacity, and Transmission Charge MDPU #276 RATE TARIFF No. Electric Vehicle (EV) Charging Rate MDPU #277 Mr. Seavey from Powerline Models (P.LM) introduced himself, and explained that he is here to make final recommendations for fiscal year 18 rates. Mr. Seavey stated that the objectives that RMLD set out to accomplish with the rate design included adjusting, subsidies between and within classes of customers, ensuring that rates for large and high -load customers continue to attract and retain such customers, and ensuring that the rates reflect cost of providing service. RMLD wants to provide price signals to encourage customers to reduce demand during peak periods. Additionally, RMLD wants to protect distribution revenues from erosion due to customer -owned generation such as solar and battery storage. The phase-in for some of these changes will occur over time to give customers time to adjust. Instead of across-the-board increases, the new rates are meant to adjust for subsidies and move towards more uniform rates of return. The residential rate of return should increase up to zero over the next 5 -year period; right now, it's significantly negative. The commercial rate of return should be reduced from high double digits down to low double digits. The industrial rate of return will remain where it is; it's low and appropriate for customers of that size. If the increase was flat across the board to cover expenses and produce the targeted 8 percent rate of return, residential customers would have had a 5.5 percent increase; commercial would have had a 5.7 percent increase. Instead, the first year of the 5 -year phase-in is a residential increase of 6.6 percent. Commercial customers will have a 3.5 percent increase this year. There will be similar changes each year. However, each year the rates will be revisited. The rate percentage changes over 5 years are based on projections that we have today regarding increases in RMLD's operating and maintenance costs and increases in capacity, transmission, and purchase energy costs. Mr. Seavey explained the changes to commercial and industrial rates. While industrial and commercial customers will see an increase, the next few years should show a decrease as capacity costs change. Rates will be more uniform and fair, but still quite competitive and attractive, particularly for the commercial and large customers. Another recommendation that aims to get price signals correct is to phase in a purchase. power capacity transmission (PPCT) demand charge. In the past, all those costs have been recovered through an energy charge. That tends to result in a subsidization of poor load factor customers by high load factor customers. By charging the correct price signal for demand, we remedy that situation and provide rate relief to customers who use their demand a lot. Only one customer in the first year is going to see an increase of more than ten percent. With the decreases in the following years no demand customers will see an increase, even with the phase ins of the demand. This is as painless a way of doing a significant shift of revenue, from energy to demand charges, as you can accomplish. Page 1 4 Proposed Rate Adjustments (Attachment 3) The renewable generation rate has a subsidization, but it is relatively small. It is $15 or $20 thousand a year for the existing 80 customers. It is more reasonable to cap the total amount of the subsidy rather than putting a cap on the amount of solar that can be installed. The cap is significant: $100,000, but only represents a cost to customers of 11 cents a month. It will not penalize customers who have already made an investment in facilities. Immediately recommending back up and stand by rate to protect against customers installing larger amounts of generation, particularly non-renewable generation like back up and stand by generators or co-generation systems. Ms. O'Brien clarified that the charge is to protect RMLD and its customers and that she wants customers to understand what that means. It's to protect everyone because we still pay distribution charges, we still have to keep the system up and running. RMLD is not trying to penalize people for putting in solar. We must recover our production charges and we still have to maintain the electric system. Mr. Seavey stated that everyone who uses the distribution system supports it appropriately. When a customer installs generation behind their meter they're continuing to use the distribution system just as much. The idea is to continue to recover revenues to maintain, own, if you don't, rates will rise for everyone. That, or you don't earn enough money to cover your expenses and you don't maintain the system. Mr. Talbot asked if a customer would still be able to disconnect from RMLD. Ms. O'Brien answered yes, although it's risky and it's their responsibility. Mr. Talbot asked for the amount of the standby rate, and clarified that this is just a recommendation at this point. Mr. Seavey corrected him and explained that the rate is being filed. The charge is the present distribution rate times the amount of capacity the customer wants you to back up. They'll still avoid purchase power, capacity, and fuel charges. Mr. Talbot asked who would this rate effect right now? Mr. Seavey answered: nobody, but it should be on the books. Mr. Talbot then asked how many municipals have a back-up and stand by rate now? Mr. Seavey replied, about half. Ms. O'Brien explained that there is a strategy behind this rate; when she arrived at RMLD the first thing she did was unbundle the rates, because she knew this was coming. if large customers are producing all this power, we still must pay for the distribution system. Mr. Seavey stated that the residential time of use rate, proposed changes will not work with RMLD's billing system. Presently the time of use is in the distribution rate and there is no time varying component, in the distribution charge. It should be in the purchase, capacity, and transmission charge where you have the on and off peak component. This should be addressed at some point in future. For now, equal factors were added to on and off peak across the board. Mr. Talbot asked if that meant those customers won't have as high an increase. Mr. Seavey explained there is still a high increase because the current rate is too low. Mr. Seavey continued, stating In 2014 an electric vehicle rate was piloted for the three charging stations at Analog. Took a look at how that has been working and how the cost has changed. There is not enough usage data to be conclusive as to whether the existing rate is adequate. He is proposing a rate that is roughly equivalent to the pilot rate but that the use of the charging stations is monitored. There was discussion as to where the best location to place a charging station in Reading would be. Ms. O' Brien explained that there will be two at RMLD; one is from the grant and we're getting an electric vehicle. Ms. O' Brien explained RMLD is trying to encourage its employees to Page 1 5 Proposed Rate Adjustments (Attachment 3) purchase electric vehicles. Mr. Talbot expressed his reservations that any resident would want to charge their vehicle at RMLD. Ms. O'Brien mentioned that RMLD could get into the business of installing electric vehicle charging stations at people's homes. Braintree has an electric vehicle leasing program. They're really engaging the community to bring in electric vehicles and putting in charging stations. But, we're not going to build them and see if customers come. They need to come and we'll build them. Mr. Talbot asked what will happen when people are charging during peak times. Ms. Parenteau explained that the charging stations can be programmed to either shut off or reduce the amount of electricity being used. Chairman Pacino stated that he has a procedural question. Why did the Electric Vehicle rate not go before the CAB before being presented to the Board? Ms. Parenteau explained that it was an oversight. Rates are scheduled to be effective on July 1, contingent on being approved at the June 21st CAB meeting. Mr. O'Rourke asked Mr. Kelley if he had any guidance from a CAB member's perspective. Mr. Kelley replied that this was his first time seeing the rate; Mr. Talbot has been helpful in giving insight. However, he needs more detail to understand make an educated decision and thinks the rest of group will have questions. Mr. Talbot asked if the Commission can defer this rate tonight. There are no electrical vehicle stations up yet. Mr. O'Rourke asked if pulling this piece out of the proposed rates will impact operations. Ms. Parenteau answered no. Mr. Talbot stated, as a time of use customer, he pays 6 or 7 cents to charge his car overnight at his house. He would never use the electric vehicle rate at his job and pay 11 cents. Mr. Talbot asked how ChargePoint works. A discussion about how ChargePoint operates and makes its revenue ensued, with Ms. Parenteau explaining that they get ten percent of sale for processing the credit card payment. Mr. Talbot added, and we get to use their name and be on their app. Mr. O'Rourke made a motion, seconded by Vice Chairman Hennessy, that the RMLD Board of Commissioners approve the rates MDPU numbers #269, 270, 271, 272, 273, 274, 275, and 276, effective July 1, 2017 on the recommendation of the General Manager. Motion Carried: 4:0:0. Chairman Pacino stated that the Commission agreed to hold off on voting on the electric vehicle rate,motion, and will defer that to a future meeting. Mr. Kelley asked if Mr. Talbot could make it to the next CAB Meeting; he cannot. Chairman Pacino will attend. Power Supply Report - March and April 2017- Ms. Parenteau (Attachment 2) Ms. Parenteau stated that she will be reporting on the April and May Purchase Power, starting with kWh sales in the first quarter of 2016 versus 2017. In 2017, 216 million kWh were sold, compared to 210 million kWh in 2016. Sales were up about 2.88 percent in 2017. However, when you look at the full fiscal year, it's considerably flat. It's 0.6 percent higher in 2017 than 2016, and that includes May and June estimated. Page 1 6 Power Supply Report - March and April 2017- Ms. Parenteau (Attachment 2) The total revenue received in the first quarter from Purchase Power, Capacity, and Transmission (PPCT) totaled about $500,000 less in 2017 than 2016. There are two contributing factors related to this -in 2016 sales were down about 2.6 percent, so we had to recover more dollars over less kWh. In 2017 we're up about 1 percent. Additionally, in 2016 our revenue in the beginning of the year was less than our expenses. Over the year, we try to recover the full Purchase ,Power and Capacity costs. It was necessary to increase PPCT in the 3rd quarter because of that situation. In 2017, revenues were exceeding expenses so that allowed us to decrease PPCT in the third quarter. Overall, capacity and transmission expenses from 2016 to 2017 increased 5.6 percent or $1.7 million dollars. Now that our portfolio contains quite a bit of hydro projects, thought it would be interesting to look at precipitation and how that relates to the hydro projects. January and April of 2017 had considerably higher precipitation than in 2016; overall, for the quarter, the average was 3.5 inches compared to 2.6 inches. In 2017, productions were up in January -and April for the hydros that we have purchase power agreements with. Natural gas is the commodity that really dictates the spot market. However, the more hydro that we have, the less we have to buy on the spot market. These projects have been very beneficial to us within our portfolio. Financial Report - April 2017 - Ms. Markiewicz (Attachment 4) Ms. Markiewicz said that she would be reporting on the April 2017 financials, beginning with accounts receivable. RMLD is 82 percent current, 15 percent overdue by 30-90 days, and only 3 percent over 90 days is outstanding. In FY 16, 89 percent was current, 9 percent was overdue by 30-90 days, and 2 percent was over 90 days. We've improved greatly since FY 15, where we had 75 percent current, 20 percent overdue by 30-90 days, and 5 percent over 90 days past due. Moratorium ended in April with two big collection pushes, which we should see the effects of in May or June. Vice Chairman Hennessy asked if the percentages were for all customers. Ms. Markiewicz replied in the affirmative; this is for commercial, residential, and industrial. Vice Chairman Hennessy asked whether it was residential or commercial customers who typically owe more. Ms. Parenteau explained that RMLD can shut off commercials for non- payment. Residential customers have a moratorium protecting them from shut off from November to April, so it's usually residential who owe more. Ms. Markiewicz continued, stating that the base revenue as compared to our operating expenses in fiscal year 2017 year-to-date $21,660,000 in base revenue, compared to fiscal year 2016 of $19,702,000, which is about a 10 percent increase. The 2017 budget was $21,250,000, so we're slightly above budget; about 1.6 percent. The base revenue compared to our, operating expenses is on target, with a 10 percent increase as well. Fiscal year 2017 year -to -date -is right on target: $17,538,00; FY 2016 was $15,915,000. When you compare that to the budget, we're about 1.4 percent less than anticipated at $17,837,000. Overall, we're right on target'budget- wise. Purchase Power, Transmission, and Capacity revenue is $28.2 million, as compared to the expense of $26.8 million. Fuel revenue was $27.7 million, with a fuel expense of 27.4. The $1.7 million excess in revenue will bring our true net income to $4 million, as compared to last year's 3.6 million. The overall budget is looking at an 18 percent increase. It's important to remember that there are lots of adjustments on the books at year end. Auditors were in-house yesterday doing preliminary testing. They were supposed to be here again today, but didn't feel that it was necessary. Page 1 7 Engineering and Operations Report - March and April 2017 - Mr. Jaffari (Attachment 5) Mr. Jaffari stated he would be reporting on March and April 2017. Routine construction year to date spending is $1,606,613. For fiscal year 2017 $9.5 million has been budgeted for capital projects. To date, $5.8 million of the budgeted .amount has been spent and a balance of $3.7 million remains. We're going to catch up in June; there's a large payment being made on the DG project and that will bring expenditures to $9.5 million. Routine maintenance is on target. Good progress is being made, especially on pole inspections, transformer replacements, and substation maintenance. There were no hot spots either month. Double poles are a work in progress. The reliability indices, SAIDI CAIDI and SAIFI, are measures that show the health and wellbeing of the system. Our reliability is good. RMLD is well below the national and regional averages..for outages. Bench markers are set by APPA. We're doing very well. The main outage causes from 2012 to 2017 were equipment, trees, and wildlife. 2017 year-to-date, April had a couple of storms that brought trees down. Unfortunately, there's nothing that can be done about pine trees that come down and cause extensive damage to the lines. Equipment outages are shrinking. We're heading in the right direction. General Discussion The next RMLD Board of Commissioners Meeting will be on Thursday, July 20, 2017. The next CAB meeting is Wednesday, June 21, 2017. Chairman Pacino will attend. Chairman Pacino stated that since he is signing the AP Warrants for this month he is also Secretary. He expressed his concern that a lot of minutes need to be approved. Ms. Schultz agreed, and stated they were on the agenda for the next meeting. Executive Session At 9:06 pm, Mr. O'Rourke made a motion, seconded by Vice Chairman Hennessy that the Commission go. into Executive Session to conduct business in relation to other entities making, selling or distributing electric power, to consider the purchase of real property, and to discuss strategy with respect to collective bargaining and return to Regular Session for the sole purpose of adjournment. Chairman Pacino called for a Poll of the Vote: Vice Chairman Hennessy: Aye; Chairman Pacino: Aye; Mr. O'Rourke: Aye; Mr. Talbot: Aye. Motion Carried: 4:0:0 Adjournment Mr. O'Rourke made a motion, seconded by Vice Chair Hennessy, to adjourn the Regular Session. Chairman Pacino called for a Poll of the Vote: Vice Chairman Hennessy: Aye; Chairman Pacino: Aye; Mr. O'Rourke: Aye; Mr. Talbot: Aye. A t7/ro urby f the RMLD Board of Commissioners minutes as a majority of the Commission. ip B: Pacino, Secretary Pro Tem LD Board of Commissioners Page 1 8 READING MUNICIPAL LIGHT DEPARTMENT BOARD OF COMMISSIONERS REGULAR SESSION THURSDAY, JUNE 15, 2017 QUARTERLY UPDATE: ORGANIZATIONAL & RELIABILTY REPORTS ATTACHMENT 1 LEIDOS - 201S ORGANIZATIONAL STUDY Leidos Timeline Recommendation Not Accepted RMLD Proposed Timeline Recommendation Completed Print date: 6/7/2017 1. 1 of 3 orvisios - CONSULTANT RECOMMENDATION DATION • ' CY 2015' . &2616CY 2017 43 44. Q1 Q2 Q3 44 .Q1l :Q2 43' CY 2018 " RMLD WORKPLAN/COMMENTS Q4 1 ESTABLISH PLANNING CULTURE 1.1 GM Update 2008 Strategic Plan (New Strategic Plan) 1.2 GM Establish planning culture On-going 1.3 1 Update Integrated, Resources plan 1.4 1.5 GM EO Update six-year plan Develop electric system master plan Annually Long-term Planning, GIS, and Technology Roadmap 2 DEVELOP AN EFFECTIVE SUSTAINABLE WORKFORCE 2.1 Develop workforce development plan Leidos Support; CBA 2.2 Develop succession plans Leidos Support - CY16 Q2 and Q3; CBA 2.3 2.4 HR Update job descriptions Implement consistent performance review process Leidos Support - CY16 Q2 and Q3; CBA Leidos Support - CY16 Q2 and Q3; CBA, 2.5 Hire additional HR personnel on hold 2.6 Increase efforts to fill vacant positions On-going; evaluating 3 IMPROVE ORGANIZATIONAL EFFECTIVENESS 3.1 Reorganize to better align functions On-going 3.2 3.3 GM GM Create new.Finance and Administration division Align Customer Services under the Integrated Resources Division Completed Completed 3.4 3.5 EO Reorganize & Expand Engineering group (DeveloSystem Engineering Group) Formalize business process and performance measurement Tied to IBEW negotiations. Posted two systems engineer positions; CBA Assessing IT roadmap and staffing - near completion. 3.6 Develop and implement internal and external communication plans Review roadmap. 3.7 4 Assess organizational culture and employee satisfaction DEVELOP LEADERSHIP CAPABILITIES Leidos Support 4.1 GM Assess leadership Completed 4.2. Provide management and leadership' training. On-going 4.3 Provide cross -divisional management training. On-going Print date: 6/7/2017 1. 1 of 3 LEIDOS - 2015 ORGANIZATIONAL STUDY Leidos Timeline Recommendation Not Accepteo RMLD Proposed Timeline Recommendation Completed Print date: 6/7/2017 2 of 3 CONSULTANT RECOMMENDATION CY 2015 'CY 2016 .' CY 2017 CY 2018 orvistoro . ''42':. RMLD WORK-PLAN/COMMENTS Q3: Q4..'Ql ::Q2 Q3 '_44. .Q1': Q3 , Q4. 'Ql 5 ESTABLISH PROJECT MANAGEMENT CULTURE 5.1 Develop project management policies and procedures Competed 5.2, Establish, project management training plan SIX MIX HR to organize with Director of E&O; CBA 5.3 Add project management experience and certifications to job descriptions On-going - job description revisions; CBA \ 5.4 Establish project management performance expectations CBA 6 ENSURE COMPETITIVELY PRICED SERVICES 6.1 IR Continue regular cost of service and rate design review Performing COS 2017 6.2 IR Increase customer and engagement and education of alternate rates " TOU, DSM, Education, Solar Choice 7 IMPROVE FINANCIAL PLANNING AND RISK MANAGEMENT 7.1 B Review and update reserve policies S All policies - steady progress Integrated Resources 7.2 Establish a risk management committee and enterprise risk management plan. \ 7.3 B Develop a succession plan for the Manager of Accounting and Business Completed 7.4 B Formalize financial and accounting business processes In progress. 8 STRENGTHEN SAFETY CULTURE 8.1 GM Review Board Safety Policy All policies. Developed Safety Program. 8.2 Develop injury and illness prevention program Review of existing manual and OSHA requirements 9 DIVERSIFY RESOURCES 9.1 IR Develop distributed generation penetration study Complete ? DSM and max/feeder? 9.2 Review cost effectiveness and economic potential for end-use measures Tangent and DSM 10 ESTABLISH A CULTURE OF COMPLIANCE 10.1 Assign Compliance Manager and develop compliance plan and requirements. Leidos Support 11 IMPROVE CUSTOMER SERVICE 11.1 IR Conduct customer satisfaction surveys. Communication Plan Print date: 6/7/2017 2 of 3 LEIDOS - 2015 ORGANIZATIONAL STUDY Leidos Timeline Recommendation Not Accepted RMLD Proposed Timeline Recommendation Completed DIVISION CONSULTANT RECOMMENDATION' ' CY 2015 CY 2016 CY 2017-- �CY.2018, ' RMLD WORK-PLAN/COMMENTS Q3 44. :Ql QZ' Q3' 44 Q1,'Q2 Q4 Q1 QZ 11.2 IR Conduct post transaction surveys. log Communication Plan 11.3 IR Develop and implement customer engagement plan. Service Requirements Handbook completed. Issued new Terms and Conaitions. Constant Contact -17,000 emailaddresses 12 PLAN FOR FUTURE TECHNOLOGIES 12.1 1 Complete operating technology roadmap 13 FOCUS ON ASSET MANAGEMENT 13.1 Develop and implement an asset management plan Asset Management System - GIS/Cogsdale 13.2 Develop and implement asset management business processes 13.3 Implement asset management system 13.4 IR Develop customer service manual (Service Requirement Handbook) Completed 14 LEVERAGE GEOGRAPHIC INFORMATION SYSTEMS 14.1 EO Conduct robust GPS -based inventory of assets and Infrastructure CDM - on-going 14.2 Adapt and implement industry standard common.information model CDM - on-going 14.3 EO Develop and implement business processes for GIS management CDM- on-going 14.4 EO Provide GIS training for Engineering and Operations (Add Other Divisions) On-going 15 FORMALIZE AND ENHANCE WORK MANAGEMENT - 15.1 Develop work management business processes Integrated with asset management plan: SpryPoint 15.2 Implement modern work management system Completed 16 PLAN FOR RESILIENCY 16.1 Develop disaster recovery and business continuity plans Emergency OP Procedure - completed. 17 ENHANCE FACILITIES 17.1 Enhance current workspace On-going - carpet, gym, paint, reorganize office space Print date: 6/7/2017 3 of 3 BOOTH AND ASSOCIATES - 2015 RELIABILITY STUDY - RECOMMENDATIONS • - . RECOMMENDATION CONSULTANT RECOMMENDATION YEAR COST (Booth Estimate) -; urrnxetr RMLD,WORKPLAN _ " • , x SOLUTION =..STATUS' - _ .. - 1 BOOTH Replace cable trench covers at Sub 4 (should be expense, but most put large investments " in capital) 2015-16 $100,000 ✓' `completed - _ - 2.1 2 BOOTH Sub 5 bus duct from transformer to switchgear has reached the end of useful life and 2015-16 $400,000 V' Bus 0 ahtl`E semp • etions.to the transformers m .leted11/12/16 on .' Main Bus 0and E sections, should be replaced with the switchgear replacement ^ completed P to be reinsulatedstartingthe'week of2/27/2017, . _ -� 3 BOOTH Replace fence at Sub 4 and Rx grounding issues. 2015-16 .$100,000 , , , ✓ .� _ • completed - - 4 BOOTH Rebuild pole line along Lowell Street - -. 2015-16 $375,000 completed". ^. -,. • .'' - -' ' 5 BOOTH Complete AMI Upgrade and RF Mesh Network 2015-16 $350,000 ✓ in _'' Fve gateways mstalled:�Relays installed Additional•meters in stock. Working on ' - _ ,' - progress communicating issue:with 1'deployed•meter. -° 6 BOOTH Implement GIS Upgrade Program 2015-16 $350,000 - $750,000 - ✓ _in progress _ GIS asset survey is in-progresi 7 BOOTH Implement Arc Flash Study Analysis 2015-16. $30,000 _✓' completed, - - - 8 BOOTH Develop construction standards 2015-16 in-house ✓ in;progress. ' '9 BOOTH Update Joint -Use Agreement with Verizon 2015-16 in-house ✓ •'- '.:' in progress',-•�� _ _ 10 BOOTH Replace bushings on Sub 4 transformer. .: 20.15-16 - $150,000 ` .. ._ completed Cr wiring at Sub 3 should be fixed. The CT circuits_ should only be bonded on grounding in 11 BOOTH exactly one spot 2015-16 - ow ✓ completed,.", CT's are grounded in only one location.: 12 BOOTH Sub 3 has NO under -frequency trips. Relay is not programmed to trip. 2015-16 0&M. ✓ compiefed Station 3<fias 11F capability. RMLD is in comPllance,with ISO's OF requirement; - Fence grounding is not up to code@ Station 4. Fabric and barbed wire should be 13 BOOTH . grounded. 2015-16 0&M ', '✓ - completed I . .. ... _ .. , 14 BOOTH Earth/gravel around fence at Sub 5 - 2015-16 O&M r ✓ .' completed ' ' - -• - - - 15 BOOTH Interface CIS with GIS platform - 2015-16 in-house °, _✓ " " • in progress-,,' GIS Data collection ii in;progmss •• - - ' 16 BOOTH Create Milsoh Windmil' model 2015-16 in-house ' _' �. ✓ Being done ii coniuc(ionwith GIS mllecuon: As each feederis;mmpleted by,DRG±tis being in. progress ' sent to Milsoft'to create the model. 17 BOOTH Complete SCADA software and hardware upgrade 2015-17 $350,000 ✓ • in progress: - nbimensions,cyber'securiry software complete. - 18 BOOTH Upgrade main feeder of Circuit 5W9 to 795 to address voltage and conductor capacity ' ✓: The first 3000' has been -reconductored. This work can only be,done during the fall/winter, Issues (1.6 miles) 2015-17 $240,000 ... in progress months. May.have arhurdle.with,Verizon and pole. replacements. -" Can't -parallel up the feeder get a ways,at Station 4 and Station S, no spareconduits available. 19 (1) BOOTH - Upgrade UG circuit 3W5,3W13,4W9,3Wib,4W14,4W36,4W23,4W24,4W28,4W30, 2015-19 - $850,000.. ✓ 3 - Cant arallely [he feeder eta-awa sat Station=3; roomfor'.the second set of cablesih: P F - 6 no y. SW4 exits to parallel 750 Cu .. - - - the back of-the;switchgeaC Solution: Load reliehby feeder switching and/or new Wilmington'. I Substation. 20 BOOTH Replace breakers at Sub 4 due to age and condition 2015-20 $3,000,000 " ✓ completed' All 2&break_ers were;replaced�by'1/30/2016,.. Pole inspection and replacement program. RMLD currently Inspects 10% of RMLD-owned. .. ,. ,. ' • - 21 . BOOTH poles per year. Negotiate with Verizon to address Verizon -owned poles. Total 13,000 P 2015-24 $9,000,000✓•' -in:progress:, , _ 2014 /2035x/2016 ±nsp'ection completetl Pole replacement in- progress poles. , 22 BOOTH- Continued implementation of Grid Modernization Plan (GMP)- 2015-24 '• • Outage Management (OMS) • ' `in OMS installed waiting'forGIS overhaul. and AMI lntii ation" $100,000 .✓ progress - - Transformer Loading Management TLM 8 8 ( 1 $100,000 � ✓ - in. progress ' ' •' - - - - - ' • Demand Response (DR) $Soo,000 ✓ - ,: _ in, progress Demand Side management (DSM) $100,000 In _ ' Distributed Generation Program - $11,000,000 _ ✓' .: ,• inprogress' ,,- ,•- . - ` - 23 (1) BOOTH Upgrade UG circuit exit 4W7 to parallel 750 Cu 2016 $70,000 - Cant parallel. up the feeder get-a-way,at Station 4, no spare.condurts available.•Soiution:Load r - reliefby,feeder.switching:and/ornew Wilmington'Substation. . - Upgrade main feeder for Circuit SIAS to 795 to address voltage and conductor capacity ' :r_t' 24 BOOTH issues (2.5 miles) 2016-17 $375,000 , Chan a- constructi n yearo FY17" , FY18 and F"Y19: H'u' rde: Verizon poie re lacemeritaea ^' Print date: 6/7/2017 1 of4 Print date: 6/7/2017 2 of 4 RECOMMENDATION CONSULTANT RECOMMENDATION YEAR COST (Booth Estimate) RMLD WORK PLAN AITERNAIE AccEPiEO sclimAl o. STATUS 25 BOOTH New Wilmington Substation (land acquisition and design) 201617 $750,000 ✓ in progress Searching for land in Wilmington Upgrade mato feeder of Circuit 4W24 to 795 to address voltage and conductor capacity 26 BOOTH issues (1.5 miles) 2016.17 $225,000 .✓ Change construction years. to FY17, FY18'and FY19. Hurdle: Verizon pole, replacement area 27 BOOTH Complete comprehensive distribution system analysis upon GIS completion 2016-17 in-house ✓ 28 BOOTH Complete the 4 kV Conversion Program 2016-19 $1,500,000 ✓ in progress Change completion date to FY20. Multiple year project. 32+/. stepdown. areas in the service territory. Converted the Burrough's Road area October 22, 2035. Sub 3 does have SEL relays but they are all legacy models that don't provide the function 29 BOOTH (especially communication) of today's versions. If the plan is to have a fully -automated 2016-19 $200,000 ✓ in PLM design complete:. Materials received. Construction in progress: Approximately 70%' - system then: replace the SEL relays with the modern version. Should be able to replace in Ys P Y P progress. complete.: existing hole and wiring.. 30 BOOTH New Wilmington Substation (procurement, design, construction and commission) 2017-19 $4,250,000 ✓ in. progress Searching for land near 115 kV lines in Ballardvale/Upton. Rd area Sub 5 Switchgear is at the end of useful life. The relaying needs to be updated for the 31(1) BOOTH system automation project. The existing breakers are 2008 vintage but should not be 2017.19 $1,200,000 ,/ As part of the planning for the proposed substation. in Willmington the need for the reused. They can be sold on the open market. Wildwood Substation will be reviewed. Can't parallel up the feeder get -a -ways at Station 4: and. Station 5, no spare conduits available. 32 (1) BOOTH Upgrade UG circuit exits 3W7, 4W5, 5W5, 5W9 to parallel 750 Cu to increase circuit 2017-19 $280,000 ✓ Can't parallel up the feeder get-a-aways, at Station 3, no room for the second set cables in capacity the back of the switchgear: Solution: load relief by feeder switching and/or new Wilmington Substation. 33 BOOTH Feeder Automation - complete System Coordination Study in conjunction 2017-24 $4,000,000 ✓ in planning Upgrade main feeder of Circuit 4W28 to 1000 Cu to address voltage and conductor 4W28 is the dedicated circuit for Analog Devices. Any type of load relief for feeder4W28 will 34 BOOTH capacity issues (0.3 miles) 2018 $60,000 ✓ require the reconfiguration of ADI distribution system or an additional RMLD feeder to the site. 35 BOOTH Substation automation 2019 $112,000 - ✓ in progress Can't parallel up the feeder get-a-waysat Station 4 and Station 5, no spare conduits available. 36 (1) BOOTH Upgrade UG circuit exits 4W6, 5W8 to parallel 750 to increase circuit capacity. 2019 $120,000 V Can't parallel up the feeder get-a-aways at Station 3, no room for the second set of cables in. the back of theswitchgear. Solution: Load relief by feeder switching and/or new Wilmington Substation. Upgrade main feeder of Circuit 4W23 to 795 to address voltage and conductor capacity 37 BOOTH issues (1.1 miles) 2020 $165,000 ✓ Change construction years to'FY20, FV21 and FY 22. Hurdle: Verizon pole replacement area. Can't parallel up the feeder get-a-waysat Station 4 and Station 5, no spare conduits available. 38 (1) BOOTH Upgrade UG circuit exits 3W18, 4W4, 4W10, 4W18 to parallel 750 to increase circuit 2021.23 $370,000 Can't parallel up the feeder get-a•aways. at Station 3, no room for the second set ofcables in capacity. P tY, the back of the switchgear. Solution: . Load relief by feeder switching and/or new Wilmington Substation. Upgrade main feeder of Circuit 4W9 to 795 to address voltage and conductor capacity 39 BOOTH issues. 2021-23 $75,000 ✓ 40 BOOTH Review and upgrade electric. system comprehensive analysis 2024 $100,000 ✓ Transformer D and E replacement at both Sub 4 and Sub 5. They are approaching their 41 BOOTH end of useful life. 2024-25 $3,400,000 ✓ 42 BOOTH Install oil containment for Transformer D and E at Sub 4 2024.25 $100,000 ✓ completed Can't parallel up the feeder get-a-waysat Station 4, no spare conduits available. Can't parallel 43(l) BOOTH Upgrade UG circuit exits 3WB, 4W12 to parallel 750 Cu to increase circuit capacity. 2024.26 $180,000 ✓ up the feeder get-a-aways at Station 3, no room for the second set of cables in the back of the switchgear. Solution: Load relief by feeder switching and/or new Wilmington Substation. Print date: 6/7/2017 2 of 4 Print date: 6/7/2017 3 of ' RECOMMENDATIONAETEenAiE ' ` • -' ` CONSULTANT RECOMMENDATION YEAR COST (Booth Estimate( _ RMLD WORK PLAN "A(CEPTEO SOLUTION STATUS. 44 BOOTH ' Upgrade main feeder of Circuit 4W30 to 795 to address voltage and conductor capacity • issues. 2024-26 5165,000 '✓ , - .. - 45 BOOTH Replace control panels for Ring bus at Sub 4 2024-26 5200,000 ✓ 'completed - Design Complete: Material to arrive°by 10/24/16. Construction'100%completed. Completion In early March 2017.. - 46 UPG Station 3 Transformers: 113. Adjust timingdela on the winding temperature tri Y g P P• V - - in progress PLM designing upgrades: Materials out: to bid September 2016; award'pending. Construction to oegign mid March 2017. 47 UPG Station 3 Transformers: #4. Add a low oil trip to transformers so they trip before any ✓ PLMdesi nin a rades. Materials out'to.bid September 2016; award end n Construction 6 B P8 P P 8•. winding damage can occur. in progress p g t0 begin in mid March"2017. 48 UPG Station 3 Transformers: #5. Replace LTC main braking rollers with the new design that has - •. - .' .. a brass sleeve for the roller to ride on. ✓ completed Scheduled.forlate November 201,6 Rollers replaced on 12/2/2016 49 UPG Station 3 Transformers: 96. Repair LTC control displays for #TA and #TB ✓ completed• LTC controls repair and installed: 50 UPG Station 3 Transformers: 117. Replace or repair the Trans-TB Hydran unit. ,[ - 51 UPG Station 3 Transformers: #8. Repair the Trans TB temperature differential unit which is in failure mode. s/. - completed Unit replaced. 52 UPG Station 3 15 kV Breakers 112: the close spring assembly needs to be replaced. ✓ - -in progress - - 53 UPG Station 15 kV Breakers: #3. OC control power fuses for trip, close, motor should be in Will. be addressed during Station #3 upgra des'Ma[erials have'bee received. Construction to, separated. . s/ - •✓ progress begin in Mid March 201.7. - 54 UPG Station 3 15 kV Breakers: #4. Control handle trip should be separated from relay and - Will be. addressed during Station 03 upgrades Materials have bee received: Construction to should trip breaker directly. in progress• - begin in Mid•March 2017. - 55 UPG Station 3 Relays: #1. The DC negative feed to the differential relay for the digital inputs - ✓. in Will-be addressed during Station 03 upgrades Materials have'bee received. Construction,to, should be altered to tie a DC negative via a fuse. progress - begin.in.Mid March-2017. 56 UPG Station 3 Relays: 02. Review and alter the under voltage transfer scheme so that it Will'be addressed during Station #3'upgrades Materials have,bee received. Construction to" operates like the same schemes at the other stations. ih•progress begin In Mid March 2017. 57 UPG Station 4 115 kV Breakers: 01 (GCB1). Replace the breaker. ,/'- completed _ - - 58 UPG Station 4 Transformers: #1. Repair trans 4110D cooling contactor for stage #2. Will need to follow-up with UPG for`more information. 59 UPG Station 4 Transformers: 142. Replace the trans #110D main tank pressure relief device contact. �/ . ' n' completed ' - -. - 60 UPG Station 4 Transformers: 93. Replace the trans #110D main tank low oil gauge. ✓ - completed - - - 61 UPG Station 4 Transformers: 94. Repair the DC control power supply control cabling. - ✓ completed - - Station 4 Transformers: #5. Replace the trans 110E main tank low oil and pressure relief ,✓ 62 UPG device cables from the devices to the conduit bodies. completed .. " 63 UPG Station 4 Transformers: 46. Replace the trans 110E cooling fan mounted top left.✓" - •completed • _ - 64 UPG Station 4 Transformers: 07. Replace all four bushings of Trans #110E and #110D. ✓ 'completed , See,ltem #10 (Booth` Recommendation) Station 4 I5kV Breakers: 112. check circuit 4W11 on a normal basis to insure that the 65 UPG heaters remain on to keep the breakers above ambient temperature so that no moisture ✓ - completed - - condenses on the breaker insulation. 66 UPG Station 4 Breakers: 04. Replace the ground stab on 4W22. ✓ •completed . Station 5 Transformers: #1. Replace the trans #D main tank low oil and pressure relief 67 UPG divide output cable. Reconnect the LTC low oil level gauge wiring in the conduit body completed'- where the device cable terminates. 68 UPG Station 5 15kV Breakers: #1. Take bus out of service and check alignment and correct if - Bus D and E sectlonsto the transformers completed on 11/12/16. Main Bus D andsections' possible. • tom leted P _E to be reinsulated starting the week of 2/27/2017. , Print date: 6/7/2017 3 of '`7r+4*,l"0171",i ..414•'' )�-M�'d ..�i%4. �t�-d'-::, T 2 G• CONSULTANTRECOMMENDATION *tveaRe r r..: eosr(B ottfEstimaieL ". RECOMMENDATION ; . - Rf1ALD_ WORK PLAN: - 'A Pita .urtnunTe . .. .... STATUS xk.'"...lF• .sr't.A' v SOCUnON ' _ 69 UPG Station 5 15kV Breakers: q2. Remove breaker 5W9, inspect for corossions, and correct " .� - Bus D and E sections to'the transformers completed on 11/12/16: Main Bus D,and E sections' misalignment of the Breaker contact Rosette and cell stab during maintenance cycle. B g cY - completed_ , •. to be reinsulated starting the week of2/27/2017.. - 70 UPG Stations ISkV Breakers: p3. Take bus out of service and check alignment and correct if ' -'� Bus D and E sechonsto the. transformers,completed on 11/12%16. Main Bus D and E sections possible. P � - Completed tobe reinsulated starting the week of 2/27/2017.- 2017. - - 71 UPG UPG Station 5,15kV Breakers: p4. Take bus tie breaker out of service and check alignment and -. � �. Bus D and E sections to the transformers completed on 11/12/16. Main BusD"and E sec ions, correct if possible. P Completed„ . - - •: - - to be'reinsulateds[arting the week of Necommenaoons ano priorities are oasea on existing system conditions. Should conditions change, these priorities will likely require re- evaluation. (1) New Substation in Wilmington will address these recommendations: alternate solution provided in the meantime. Print date: 6/7/2017 4 of 4 POWER SUPPLY REPORT MARCH & APRIL 2017 ATTACHMENT 2 Integrated R.eso RMLD Board of Commi! Reporting Jane Parenteau Director of Integrated Resources kWh Sales 1st Quarter 2016 vs. 2017 AW -44W January _ February�� March April I Q1 Total j 48,836,336 54,279,229 52,417,738 55,283,094 210,816,397 ® 2017 17 56,812,248 1 57,075,866 52,281,239 50,728,215 216,897,568 ®2016 ■2017 Purchase Power, Capacity and Transmission (PPCT) ReVE 1 It Quarter 2016 vs 2017 --;_-_--- -- January. -----4- .-- . Februa_ry March April . Q1. Totals m2016 $2,075,758 $2,712,157 _ 4 -' — - -- _- � _ - $2,894,687_ - -$3,106,977 i-- $10,789,579 i ■2017, $2,846,098 - $2,740,693 __. $2,444,474 i $2,261,244 $10,292,509 Capacity, Transmission January -April 201 Precipitation by Inches Reading, MA 2016 vs. 2017 1St Quarter January February March j April P Averages —2016-2.71 2.59 3.36 2.07 2.68 20171 4.44 0.07 1.69 7.74 3.49 —2016 —2017 Hydro Pr( 1St Quartet 2016 vs. 21 7,000,000 6,000,000 5,000,000 r 3 4,000,000 Y 3,000,000 2,000,000 1,000,000 c Precipitation Levels and Their Effects on Energy Produc 1 St Quarter 2016 16,000,000 14,000,000 12,000,000 r 3 Y c 10,000,000 0 v �0 8,000,000 0 n`. o,n 6,000,000 c w 4,000,000 2,000,000 0 January February March April Hydro Spot Market -Precipitation j 10.0c 9.00 8.00 7.00 6.00 5.00 4.00 3.00 2.00 1.00 0.00 Precipitation Levels and Their Effects on Energy Produc 1 St Quarter 2017 16,000,000 14,000,000 12,000,000 s 0 10.000,000 V 0 8,000,000 CL 6,000,000 a, w 4,000,000 2,000,000 0 January February March April 9.00 8.00 7.00 ,,, m L 6.00 C 5.00 C 4.00 Y 3.00 'n v 2.00 a 1.00 0.00 Hydro Spot Market -Precipitation PROPOSED RATE ADJUSTMENTS ATTACHMENT 3 necutc. Kate:- uesig Recommendations Reading— Munjcipal Light Department P L M Electric Power Engineering Strategic Rate Design Objectives - - • Reduce -or eliminate subsidies betinreen. and within classes of customers • Ensure that rates for large, high load factor customers can attract and retain such. customers • Make rates more reflective of the cost of providing service Provide price signals that: encourage customers to reduce demand during peak periods and to increase usage during off- peak periods Phase-in changes over period of time to permit: customers -time to respond and. -adjust Protect distribution revenues from erosion due to customer - owned generation of electricity. June 15, 2017 PLM Electric Power Engineering 2 RECOMMENDATION. Phase 1 n: Scenario -.-3 .Ove.r-.5. - Years -Instead -of-i-ncreases --of between- 51/2 and 61/2 percent, average bills would change by the -following percentages In FY18: 3 Scenario 1 Scenario 3 Uniform Increase Move to Uniform ROR •- Residentia.l 5.6% -6.6% • Residential TOU 5.7% 7.6% • Schoo.1 6.5% 4.7% i • Commercial 5.7% 3:5% Industrial' ' 6.0% '6.1%0 3 Phase -In of Scenario 3 Rate Changes Average Customer Bri1.1 Impact 10.0% 8.0% 6.0% 2.0% — ----- --- 0.0% FY18 FY19, • MY120 MY2 FN -2.0% -4.0%--- -6.0%- N Residential M Commercial, ®_Industria!_______._____ June 15, 2017 PLM Electric Power Engineering 4 . r r:♦r. r-. r. t� ..rn.+we.:♦4'x.n �.r. .ru ... 1r <. fr �r, w0.r .• .. .r, Ak ir.a.r. '.r:a Fi .r,i n fn .. .4.ir n a.... Phase -In of Scenario 3 Rate. Changes Average, -Customer Bill I.m-pact Residential 750 kWh $140 ------------------------- .------------- ..___...-_-_-_....__.___.._-d.__-w___-,_ $120 $100 $60 $40 $20 FY17 June 15, 2017 FY18 FY19 FY20 FY21 FY22 PLM Electric Power Engineering ■ Purchased Power. fm Energy ■ Base.Rate 5 Phase -I n of Scenario 3 Rate Changes Average Customer Bill Impact $9,000 - $8,000 $7,000 $6,000 $5,000 $4,000 $3,000 $2,000 $1,000 Medium Commercial FY17 FY18 FY19 TY20 FY21 June 15, 2017 PLM Electric Power Engineering FY22 ■ Purchased Power Im Energy ■ Base Rate Phase-Iof Scenario 3 Rate -Changes Average Customer. Bill Impact Medium Industrial . $90,000--------------------------------------------------------------------------------------------------- $80,000 $70;000 $60;000 $50,000 .$40,000 $30,000 $20,000 $10,000 FY17 June 15, 2017 FY18 FY19, FY20 FY21 FY22 PLM Electric Power Engineering ■ Purchased Power IN Energy ■ Base Rate 7 RECOMMENDATION: Renewable,- Generation. Rate • Cap the total a -mount of Renewable Generation:: Subsidy, at - -- $100,.000.per year. • Represents approximately 300 additional residential solar. customers • 'Represents a subsidy cost to an average residential; customer of $0:41/month , . • When ,the cap is reached implement one of the three options identified previously, depending on the cost and availability of metering and billing: • Immediately put in place a Backup and: Standby rate to recover e , distribution revenue, requirements from any customer using energy storage to offset most of all kWh purchased from RMLD • Phase-in the elimination of -the- time -of -use Distribution energy charge and replace with flat rate energy charge Phase-in an on -peak and off-peak Purchased Capacity and Transmission charge to recover most allocated costs during on -peak hours only Phase in an annual increase in the Distribution - Charge over five- years to produce a zero rate of return- comparable to the -base Residential rate Phase- in the on -peak Purchased Capacityand Transmission charge over five years June 15, 2017 PLM Electric Power Engineering 10 RECOMMENDATION: __ - Electric- Vehicle Rate: ---.Replace' the existing Pilot 'rate created -in-, 2014with a tariff filed with the DPU. • Rate structure: Distribution Charge $0.1111 -Fuel Charge - - as billed - Purchased Power Charge as billed.- - Rate calculation makes assumptions regarding the level of usage and should be re-evaluated- after actual usage data is gathered • Price is equivalent to about $1.80/gallon' of gasoline June 15, 2017 PLM Electric Power Engineering 11 Town of Reading, Massachusetts Municipal Light Department Designation: Residential A Rate MDPU # 269 supersedes and cancels MDPU # 259 Residential Schedule A Rate Available in: Reading, Lynnfield Center, North Reading,, and Wilmington Applicable to: Individual residential customers far all domestic uses where service is taken through. one meter. incidental commercial use, not exceeding 20% of the total energy used on the same premises is permitted. Character of service: A.C. 60 cycles: single phase. Customer Charge: $4.81 per month Distribution Energy Charge: 5.06301 per Kilowatt-hour for all Kilowatt-hours usage Budget Billing: The customers under this rate will have available to theni a budget billing program under which the customer is required to pay a levelized amount to the Department each billing period during the calendar year. The specifics of this program are outlined in the Department's General Terms and Conditions. Low Income Discount The Customer Charge- under this rate will be waived upon verification ofa low-income customer's receipt of any means -tested public benefit, or verification of eligibility for the low-income honle energy assistance program, or its Successorprogratll, Ibr which eligibility does riot exceed 200 percent of the federal. poverty level based on a 110USellold's gross i.nconlc. In a program year in which maximum eligibility 11or LII IFAP exceeds 200 percent of the federal poverty level, a household that is income eligible under LIHEAP shall be eligible liar the low-income electric discount. It is the responsibility of the customer to annually certify, by lornls provided by the utility, the C011t►l]Ucd compliance with the foregoing qualifications. Rate Filed: June 19, 2017 Effective: On Billings on or After.luly 1, 2017 Filed By: Coleen M. O'Brien, General Manager Town of Reading, Massachusetts Municipal Light Department MDPU # 269 supersedes and cancels MDPU # 259 Residential Schedule A Rate (cont'd) Farm Discount: Customers who meet the eligibility retjuirements set forth by the Massachusetts Department of food and. Agriculture for being engaged in the business of agriculture or fanning, and upon certification to the RMC.I).by the ivlassachusetts Department of food and Agriculture; will be eligible for an additional 10% discount, prior to the RMLD prompt payment discount, on rates and charges applicable oil their monthly billing statement. Energy Conservation Charge: The bill for service hereunder may be increased or decreased as provided by the Energy Conservation Charge. Fuel Adjustment: The bill 1'cir service' hereunder may be increased or decreased as provided by the Standard Fuel Adjustment Clause. Purchase Power Capacity and Transmission Charge: The bill for service hereunder may be increased or decreased as provided by the Purchase Power -Capacity and Transmission Charge. Mcter Reading and Billing: Bills under this schedule will be rendered monthly. A prompt payment discount of 15% will be allowed on the CLIStolllet' Charge and Distribution Energy Charge, only ifthe entire bill is paid-iri-full by the discount due date. General Terms.and Conditions: Service hereunder is. subject to. the General Ternls and Conditions which are incorporated herein and are a part of this rate schedule. Rate Filed: June 19, 2017 Effective: On Billings on or After July 1, 2017 Filed By: Coleen M. O'Brien, General Manager Town of Reading, Massachusetts Municipal Light Department MDPU # 270 supersedes. and cancels.MDPU # 261 Residential Time -of Use Schedule A2 hate Designation: ResidentialTime-or-Use A2 Rate Available in: Reading, l..ynnlield Center, North heading,, and Wilmington Applicable to: Individual residential customers for all domestic uses where service is taken through one On -'Peak and Oft -Peak meter. Incidental commercial use, not exceeding 20% of the total energy used on the same premises is permitted.. Character of service: A.C. 60 cycles: single phase. Customer Charge:. $7.44 per month. Distribution Energy Charge: $.09450 per Kilowatt-hour for all Kilowatt-hours usage d U ri ng. t he- On -Peak hours. $,02188 per Kilowatt-hour for all Kilowatt-hours usage during the Off-peak hours. Definition of Periods: The On -Peak period is defined as the hours. between'] 2:00 Noon and 7:.00 P.M.. Monday through Friday except holidays as 'listed under the "Granted Holidays" paragraph listed below. The Off -Peak period is. (lei ined as the !yours between 7.:00 P.M. and 12:0.0 Noon Monday .through Friday and all hours Saturday, Sunday and granted holidays' as listed below. Contry)lled Water Heater Allowance: When.a customer regularly uses an electric water heater oi'a type approved by the Department, 333 kWh will be credited to usage during the Oft' -Peak period and will be billed at $.00300 per kWli. All kWh used Off=Peak above 33 3 kWli will be charged at the regular Off=Peak rate. If less than 333 kWh are. used 011' Peak then onl.y.that amount of kWh will be billed at $.00300 per kWh. Water heater with two elements shall be interlocked to prevent simultaneous operation. Service to the water heater will be controlled by a Department owned time.switch in an approved outdoor socket. Term: A customer electing to be billed under this rate must remain. on this rate for a minimtun of one year. At the end of one. year on this rate a customer may elect to remain on. this rate or be billed under the Residential A Rate. Rate Filed: .lune 19,2017 Effective: On Billings on or After Jul), 1, 2017 Filed By: Coleen M. O'Brien, General Manager Town of Reading, Massachusetts _Municipal Light Department MDPU # 270 -supersedes and cancels MDPU # 261 Residential Time-of=Use Schedule A2 Rate (cont'd) Budget Billing: The customers under this rate wilt have available to thele a budget billing program under which the customer is required to pay a ICVeli%Cil a111011nt to the Department each billing period during the calendar year. The specifies of this program are outlined in the Department's General Terms and Conditions. LoNv Income Discount The Customer Charge under this rate will be waived upon verification ol'a low-income customer's receipt of any means -tested public benefit, or verification of eligibility for the lout -income home energy assistance program, or its successor program, for which eligibility does not exceed 200 percent of the federal poverty level based on a household's gross income. In a program year in which maximum eligibility ibr L:IHEAP exceeds 200 percent ol'the federal poverty level, a household that is income eli"ible under LiHE:AI' shall be eligible for the low-income electric discount. It is the responsibility of the customer to annually certify, by forms provided by the utility, the- continued compliance with the foregoing qualifications. Farm Discount: Customers who meet the eligibility requirements. set forth by the Massachusetts Department of Food and Agriculture liar being engaged in the business of'agriculture or farming, and upon certification to the RMLD by the Massachusetts Department of Food and Agriculture, Will. be eligible ('or an additional ten percent discount, prior to the RMLD prompt payment discount, on. rates and charges applicable on their monthly billing statement. Energy Conservation Charge: The bill for service hereunder may be increased or decreased as provided by the Energy Conservation Charge. Fuel Adjustment: The bill for service hereunder may be increased or decreased as provided by the Siandard Fuel Adjustnlent. Clause. Purchase Power Capacity and Transmission Charge: The bill for service hereunder may be increased or decreased as provided by the Purchase Power Capacity and Transmission Charge, Meter Beading and Billing:. Bills under this schedule will be rendered monthly. A prompt payment.discount of 151A will be allowed on the Customer Charoe, Distribution Demand Charge -and Distribution Energy Charge, only if the entire bill is paid -in -fun I by the discount due. date. Rate Filed: June 19, 2017 Effective: On Billings on or After July 1, 2017 Filed By: Coleen M. O'Brien, General Manager 'Town of Reading, Massachusetts Municipal Light Department MDPU # 270 supersedes and cancels NIDPU # 261 Residential Time -of -Use Schedule A2 Rete (cont'd) Granted Holidays Under the Residential Time-of=Use Schedule A2 Rate the holidays granted for Off -Peak are: New Year's Day, President's Day, Memorial' Day, Independence Day, Labor Day, 'thanksgiving Day, Columbus Day, Veteran's Day and Christmas Day. General Terms and .Conditions: Service hereunder is subject to the General Terms and Conditions Nvhich are incorporated herein and .are a part of this rate schedule. Rate riled: June 19, 2017 Effective: On Billings on or After July 1, 2017 Filed By: Colecu NI. O'Brien, General Manager Town of Reading, Massachusetts MDPU # 271.supersedes Municipal Light Department and cancels MDPU # 262 Commercial Schedule C Rate Designation: Commercial C Rate Available in: Reading, Lynntield Center,'North Reading, and Wilmington Applicable to: Service tinder this rate is available to industrial or commercial customers who take all their requirements under this rate. All electricity (urnis}ted Wider this rate will be metzred through one service finless it is convenient for the Department to du otherwise. Character of service: AC 60 cycles: single phase or three phase. Customer Charge: $7.4.7 per month. Distribution Demand Charge: $7.82 per Kilowattfor all demand Usage. Distribution Energy Charge: �.01659 per Kilowatt-hour for all Kilowatt-hours usage. Budget Billing: The eftstomers under the C Rate may elect the BudgCt Billing program under which the Customer is required to pay the levelized amount to the Department each billing period during the calendar year. This rate is not available to C Rate Customers electing the Contract Demand Rate, or the Non -Firm Demand Rate. The specifics ol'thns program -are outlined in the Department's General Terms and Conditions. Energy Conservation Charge: The bill for service hereunder may be increased or decreased as provided by the Energy Conservation Charge. Fuel Adjustment: The bill Ior service hereunder may be increased or decreased as provided by the Standard Fuel Adjustment Clause. Purchase Power Capaeiq and Transmission Charge: The bill for service hereunder may be increased or decreased as provided by the. Purchase Power Capacity and Transmission Charge. Rate Filed: ,lune 19, 2017 Effective: On. Billings on or After July 1, 2017 Filed By: Coleen M. O'Brien, General Manager 'Town of Reading, Massachusetts Municipal Light Department MDPU # 271 supersedes and cancels YIDPU #262 Commercial Schedule C Rate (cont'd) Measurement of Billing Demand: The billing demand shall be the highest of the liftcen minute kilowatt demand established during the billing period, but not less than eighty percent of the maxiillUrn demand established during the preceding summer season or sixty percent of the maxinitml demand established during the winter season. Definitions of Seasons: The summer season is defined as the months of June thraugh September and the winter season is defined as the months of October tlu•otigll May. Farm Discount: Customers who meet the eligibility requirements set forth by the Massachusetts Department ol' Food and Agriculture for being engaged in the business of agriculture or farming, and upon certification to the RMLD by the Masslchusetts Department of Food and Agriculture, will be eligible for an additional ten percent discount, prior to [lie RML.D prompt payment discount, on rates and charges applicable oil their monthly billing statement. Customer Transformer Ownership: A customer requiring a minimal transformer capacity of over 2,000 kW will be required to furnish its own transforming and protective equipment, including slat, vault, primary and secondary cables, conduits, CtC., Which must comply with the specifications ofthe Department, The I61lowing diSCOUnts apply when the above is Complied with: $.12 per kilowatt ofdemand when the service is taken at 2,400/4,160 volts. $.25 per Kilowatt ofdemand when the service is taken it 13,800 volts. $.375 per Kilowatt ofdemand when the service is taken at 34,500 volts. Primary Metering Discount: The Department may, at its option. meter at the cusulnler's utilization voltage or oil the high side of the transformer through Which the service is furnished. in the latter case, or if the customer's utilization voltage requires no transformation, a discount of 1.8% will be applied to the bill's consumption charges but in no case will SUch diSCOUnt be allowed if the metering voltage is less than 2,400 voltage. Rate Filed: .lune 19, 2017 Effective: On Billings on or After July 1, 2017. Filed By: Coleen Ni. O'Brien, General Manager Town of Reeding, Massachusetts MDPU 4 271 supersedes Municipal light Department and cancels MDPU €f 262 Commercial Schedule C Rate (cont.'d) Meter Reading and Billing: Bills under this schedule will be rendered monthly. A prompt payment discount of 15% will be allowed on the Customer Charge, Distribution Demand Charge and Distribution Energy Charge, only, if the entire bill is paid -in -bill by the discount due date, General Terms: Service hereunder is subjCct 10 the General 'Perms and Conditions which are incorporated herein and are a part of this rate Schedule. Rate Filed: June 19, 2017 Effective: On Billings on or After July 1, 2017 Filed By: Coleen M. O'Brien, General Manager Town of Reading, Massachusetts ;Municipal Light Department MUPU # 272 supersedes and cancels iMDPU 9 263 Industrial Time -of -Use Schedule I Rate Designation: Industrial Time -of -Use I Rate Available in: Reading, I.ynnfield Center, North Reading, and Wilmington applicable to: Service under this rate is available to industrial or commercial customers who take all their requirements under this rate. All electricity furnished under this ripe will be metered using an electronic meter capable of metering On -Peak and 017=Peak energy as well as kW demand. Character of service: A.C. 60 cycles: single phase or three phase. Customer Charge: $37.49 per month. Distribution Demand Charge: $9.37 per Kilowatt for all demand usage. Definition of Periods: The On -Peak period is defined as the h6Urs between 12:00 Noon and 7:00 P:>V1., Monday through Friday except holidays -as listed below. The Off -Peak period is defined as the hours between 7:00 PAI. and 12:00 Noon, Monday through Friday and all hours Saturday, Sunday and granted holidays as listed below. Term: A customer erecting to be billed under this rate must remain on this rate for a minimum of one near. At the end of oneyear oh this rate a customer may elect to remain on this rate or be billed under the Commercial C Rate. Energy Conservation Charge: Tile bill for service hereunder may be increased or decreased as provided by the Energy Conservation Charge. Fuel Adjustment: The bill for service hereunder may be increased or decreased as provided by the Standard Fuel Adjustment Clause. Purchase Power Capacity and Transmission Charge: The bill for service liereunder may he increased or decreased as provided by the Purchase Power Capacity and 'Transmission Charge. Rate Filed: June 19, 2017 Effective: On Billings on or After July 1, 2017 Filed By: Coleen M. O'Brien, General Manager Town of Reading, Massachusetts Municipal Light Department i (DPU # 272 supersedes and cancels MDPU # 263 Industrial Time -of -Use Schedule I Rate (cont'd) Measurement of Billing Demand: The Billing demand shall be the highest of the litteen minute On Peak kilowatt demand established during the billing period, bUt not less than eighty percent of the ma\inlunl On Peak demand established during the preceding summer season or sixty percent of the maxinlum On Peak demand established during the winter season. The summer seftson is defined as the months of JUnC through September and the winter season is defined as the months of October through A'lay. Farm Discount: Customers who meet the eligibility requirements set fbrth by the Massachusetts Department of Food and Agriculture for being.engaged in the business of agrieulttUre or farming, and upon certification to the RMLD by the Massachusetts Department of Food and Agriculture, Nvill be eligible fin• an additional ten percent discount, prior to the. RNILD prompt payment discount, on rates and charges applicable on their monthly billing statement. Customer Transformer Ownership: A Customer requiring a minimal transformer capacity of over 2000 kW will be required to furnish its own transforming and.protective equipment, including mat, vault, primary and secondary cables, conduits. etc., which 111USt Comply with the specifications of the Department. The li61lowing discounts apply when the above is complied with: $.12 per Kilowatt of demand when the service is taken at 2,400!4,160 volts. $.25 per Kilowatt of demand when the service is taken at 13,800 volts. $.373 per Kilowatt of demand when the service is taken at 3=4,500 volts. Priman, Metering Discount: The Department may, at its option, meter at the customer's utili-ration voltage or on the high side ofthe transformer through which the service is furnished. In the latter case, or if the customer's utilization voltage requires no transformation, a discount 01'1.8% will be. applied to the bill's consumption charges but in no case will such.diseount be allowed it' the metering voltage is less than 2.100 voltage. Rate Filed: June 19, 2017 i:ffective: On Billings on or After,iuly 1, 2017 .Filed By: Coleen NI. O'Brien, C:eneral Manager Town of Reading, Massachusetts MDPU # 272 supersedes Municipal Light Department and cancels MDPU # 263 Industrial Time -of Use Schedule 1 Rate (cont'd) Meter Reading and Billing: Bills under this schedule will be rendered monthly. A prompt. payment discount of 15% will be allowed oil the Customer Charge, Distribution Demand Charge and. Distribution Energy Charge, only if the entire bill is pai&in-!till by the discount due date. Granted Holidays Under the Industrial Time-of=Use Schedule 1 Rate the holidays for O1't=Peak are; New Year's Day,'President's Day. Memorial Day, Independence Day, Labor Day, Thanksoiving Day, Columbus Day, Veteran's, Day and Christmas Day, General Terms and Conditions: Service hereunder is subject to the General Terns and Conditions which are incorporated herein and are a part of this rate schedule, I Rate Filed: June 19, 2017 Effective: On Billings on or After July 1, 2017 Filed By: Coleen M. O'Brien, General Manager Town of heading, Massachusetts MDPCI 0 273 supersedes Municipal Light Department anti cancels MDPU h 263 School Schedule SCH Rate Designation: School SCH Rate Available in: Reading, Lynnlield Center, North Reading, and Wilmington Applicable to: Applicable to public or private schools offering kindergarten, regular elementary, middle, and high school as approval by the Department, who take all their requirements under this rate. All electricity furnished under this rate will be metered through one service urilcss it is convenient for the Department to do otherwise. Character of service: AC 60 cycles: single phase or three phase. Customer Charge: $6.89 per month. Distribution Demand Charge: $720 per Kilowatt for all demand usage. Distribution Energy Charge: $.01136 per Kilowatt-hour for all KiIONVatt-hOLII"S LISage. Budget Billing: The customers tinder the School Rate may elect the Budget Billing program under which the customer is required to pay levelired amount to.the Department each billing period during the calendar year. Energy Conservation Charge: The bill for service hCreundCr may be increased or decreased as provided by the Energy Conservation Charge.. Fuel Adjustment: The bill for service hereunder may be increased or decreased as provided by the Standard Fuel Adjusuihent Clause. Purchase Power Capacity and Transmission Charge: The bill for service hereunder may be increased or decreased as provided by the Purchase Power Capacity and Transmission Charge. Rate Filed: June 19, 2017 Effective: On'Billings on or After July 1, 2017 Filed By: Coleen NJ. O'Brien, Central Manager Town of Reading, Massachusetts MDI'U # 273 supersedes Municipal Light Department and cancels MDI'L► 9 261 School Schedule SCH Rate (cont'd) Measurement of Billing Demand:: The billing demand shall be the highest of the lifteen minute Kilowatt demand established during the billing period, but not less than eighty percent ofthe maximum demand established during the preceding summer season or sixty percent of the maximum demand established during the winter season. Definitions of Seasons: The sutnmer season is defined as the months Of Aine through September and the winter season is defined as the months of October through May. Customer Transformer Ownership: A customer requiring a minimal transformer capacity of over 2000 kW will be required to furnish its own transforming and protective equipment, including mat, vault, primary and secondary cables, conduits, etc., which must comply with -the: specifications of the Department. The following discounts apply when the above is complied with: .$.12 per kilowatt of demand when the service is taken at 2,400%4,160 volts. S.25 per Kilowatt of demand when the service is taken at 13,800 volts. 5.375 per Kilowatt of demand when the service is taken at 34,500 volts. Metering: The Department may, at its option, meter at the custo ner's utilization voltage or on the high side of the transformers through which the serviceis furnished. In the latter case, or if the customer's utilization voltage requires no transformation, a discount of 1..8%o will be applied to the bill but, in no case will such a discount be allowed if the metering voltage is less than 2,400 volts. Meter Reading and Billing;: Bills under this schedule will be rendered monthly. A prompt payment discount ol' 15% will be allowed on the Customer -Charge, Distribution Demand Charge and Distribution - Energy Charge, only if the entire, bill is paid -in -full by the disc=ount due date. General Terms: Service hereunder is subject to the General "Perms and Conditions which are incorporated herein and are a part of this rate schedule. Rate Filed: June 19, 2017 Effective: On Billings on or After July 1, 2017 Filed By: Colcen M. O'Brien, General Manager Town of Reading,.Massachusetts Municipal Light Department Designation: Residential RW Rate MDPU # 27.1 supersedes and cancels MDPU # 260 Residential Schedule RW' Controlled Nater Heater Rate Available in: Reading, Lynnfield Center. North Reading, and Wilmington Applicable to: Individual residential customers tax• all domestic Lues where service is taken through one meter. Incidental commercial use, not exceeding 20% of the total energy Used oil the same premises is permitted. Character of service: A.C. 60 cycles: single phase. Terms of Use: When a customer regularly uses an electric water heater of a type approved by the Department, service to the water heater will be controlled by a Department owned timing device. Customer also needs a customer owned internet connection. Internal wiring will be the responsibility of the customer. Water heater with two elements shall be interlocked to prevent simultaneous operation, Customer Charge: $4.82. per month. Distribution Energy Charge: S.0=4832 per Kilowatt-hour for all Kilowatt-hours usage Budget Billing: The customers under this rate will have available to them a budget billing program Under which the customer is required to pay a Ievelized amount to the Department each billing period during the calendar year.. 'file specifics of this program are outlined in the Department's General 'terms and Conditions. Low Income Discount "I'he Customer Charge under this rate will be waived upon verification ora low-income customer's receipt of any means -tested public benefit, or verification of eligibility for the low -Income home energy assistance program, of its SUCCeSSor program, for which eligibility does not exceed 200 percent of the federal poverty level based on a household's gross income. In a program year ill which maximLim eligibility fir LIFIF-AP exceeds 200 percent of the flederal poverty level, a household that is income eligible under LII IEAP shall be eligible fur the luw-inconle electric- diSeOUrll. It is the responsibility of the- customer to annually certify, by forms provided by the utility, the continued compliance with the foregoing qualifications. Rate Filed: ,June 19, 2017 i?ffective: On Billings on or After ,July 1, 2017 Filed By: Coleen M. O'Brien, General Manager Town of Reading, Massachusetts Municipal Light Department PY NIDPU # 274 supersedes and cancels MDPU # 260 Residential Schedule R«< Controlled Water Heater Rate (cont'd) Farm Discount:. CLIStomers who Ineel the eligibility requirements set forth by the Massachusetts Department of rood and Agriculture for being engaged in the bLISlness ofagrlCllltlll'e of ]arming; and. upon certification to the RNILD -by the Massachusetts Department of Food and Agriculture, will be eligible for an additional 10% discount, prior to the RMLD prompt payment discount, on rates and charges applicable on their monthly billing statement. Energy Conservation Charge: The bill Por service hereunder may be increased.or decreased as provided by the Energy Conservation Charge. Fuel Adjustment: The bill for service hereunder may be increased or decreased as provided by the Standard Fuel Adjustment Clause. Purchase Power Capacity and Transmission Charge: The bill 1'6r service hereunder may be increased or decreased as provided by the Purchase Power Capacity and Transmission Charge Meter Reading and Billing: Bills under this schedule will be tendered monthly. A prompt payment diSCOLIIIt of 15% will be allowed on the Customer Charge and Distribution, Energy Charge, only ifthe entire bill is paid -h lull by the discount due date. General Terms and Conditions: Service hereunder is subject to the General 'Perms and Conditions which are incorporated herein and area part of this rate schedule. Rate Filed: June 19, 2017 Effective: On Billings on or After July 1, 2017 Filed By: Coleen. M. O'Brien, General Manager Town of Reading, Massachusetts N1DPU i# 275 Municipal Light Department Backup and Standby Rate Designation: Backup and Standby Rate Available in: Reading, L_ynntield Center, North Reading, and Wilmington Applicable to: This rate shall be applied to all partial requirements general service Customers tithe Customer). A partial requirements Customer is defined as one who normally generates all, or a portion of the Customer's electrical power and energy requiremerils. All electricity supplied shall be for the exclusive use of the Customer and shall not be resold. Service taken tinder this rate shall be electrically separated From the Customer's generating Facilities or provided with sufficient protective devices to prohibit such Facilities from causing disturbances on the RNiLD's system consistent with the. RMLD's Terns and Conditions. The RMLD reserves the right to refuse service to facilities where the RMLD reasonably detennines that the protection provided is inadequate. All electricity supplied to the Customer by the RNILD shall be measured through one meter, except that where the RNILD deems it impractical to deliver electricity through one service, or where the RMLD has installed more than one meter, then the. measurement of electricity may be by two or more meters: When the Customer's generating facilities are capable of operating in parallel with the RMLD's supply, the Customer shall furnish, at its expense, necessary facilities. for metering equipment including a dedicated voice grade telephone circuit for remote reading whereby the RMLD can meter the output of the Customer's generating facilities. Character of service: Finn Backup Service Finn Backup Service is intended to provide the. Customer with a finn supply of electric power and energy when the Customer's generating facilities are not in operation or are operating at Fess than full rated capability or when the Customer's load is greater than the capability of its generating facilities. To obtain service under this schedule, the Customer must specify in writing the maximum Finn back-up electric power demands (Finn Backup Contract Demand) that it plans to impose on the RMLD under this schedule. The amount of Finn Backup Contract Demand may be changed only by written notification to the RMLD at least six months prior to the effective date of such change. The RMLD reserves the right to refuse any increase in the Firm Backup Contract Demand if, in the sole judgment of the RMLD, such an increase would have an adverse impact on the reliability,or cost of the provision of firm service to any of: the RINILD's Finn service customers. Standbv Service Rate Filed: June 19, 2017 Effective: On Billings on or after July 1, 2017 Filed By: Coleen IM. O'Brien, General Manager Town of Reading, Massachusetts N,Iunicipal Light Department MDPU # 275 Standby Service is intended to reserve capacity on the RMLD's transmission and distribution system for the delivery of Firm Backup Service. Standby ServicewiII be taken and paid for regardless of whether Finn Backup Service is taken hi any month. Definitions Firm Backup Contract Demand: the maximum firm backup electric power demand which the Customer shall impose on the RMLD as specified by the Customer. Firm Backup Demand: the maximum. metered billing demand occurring in the billing period or the Finn Backup Contract Demand, whichever is less. Metered Energy: the Customer's actual electrical load without the application of the Customer's generation. Billing Energy: the electrical load imposed on the RMLD's system. Backup Energy: tile sum of the kWh of Billing Energy for the period. Metered Demand: the greatest actual ,etectrieal bird during any 15 minute period without the application of the Customer's generation. Billing Demand: the Greatest 15 minute electrical load imposed .on. the RMLD's system during thebilling period. Applicable General Service Rate: the rate under which the customer would be eligible to receive firm service from the RNILD if the. Customer did not generate any of its, own electric power and energy requirements. All demands refer to fifteen (15) minute kW demands. Monthly Rates Customer Charge: The customer charge in Applicable General Service Rate. Demand Rates: Standby Demand: The Distribution Demand Rate in the Applicable General Service Rate multiplied by the Finn Backup Contract Demand. Firm Backup Demand: The Distribution Demand rate in the Applicable General Service Rate=iltiplied by the Finn Backup Demand. Energy Rates: Backup Energy The energy rate, including the Energy Conservation Charge, Fuel Adjustment and Purchased Power Adjustment, in the Applicable General Service Rate per billing kWh. Rate. Filed: June 19, 2017 Effective: On Billings on or after July 1, 2017 Filed By: Coleen NI. O'Brien, General tllanagei Town of Reading, Massachusetts Municipal Light Department NiDPU # 275 Stranded Cost Charge The Distribution Energy Charge in the Applicable General Service Rate multiplied by the Metered Energy The monthly charge shall be the sum of the Customer Charge, the Standby Demand Charge, the Film Backup Demand Charge, the Backup Energy Charge and the Stranded Cost Charge, Term: Unless otherwise agreed in writing, service under this rate shall be for a period of not less than three years and thereafter may be discontinued only upon the RMLD's receipt of a 90 - day written notice. Service is also .subject to the provisions of the Rules and Regulations of the RMLD. Measurement of Billing Demand: The Billing demand shall be the highest ofthe fifteen minute kilowatt demand established during the billing period, but not less than eighty percent of the maximum demand established during the preceding summer season or sixty percent of the maximum demand established during the winter season. Farm Discount: Customers who meet the eligibility requirements set forth by the Massachusetts Department of Food and Agriculture for being engaged in the business of agriculture or farming, and upon certification to the RMLD by the Massachusetts Department of Food and Agriculture, will be eligible for an additional ten percent discount, prior to theRMLD prompt payment discount, on rates and charges applicable on their monthly billing statement. Customer Transformer Ownership: A customer requiring a minimal transformer capacity of'over 2000 kW will be required to fi►rlish its own transforming and protective equipment, including mat, vault, primary and secondary cables, conduits, etc., which must comply with the specifications of the Department. The following discounts apply when the above is complied with: S. 12 per Kilowatt of demand when the service is taken at 2,400/4,160 volts. S.25 per Kilowatt of demand when the service is taken at 13,800 volts. S.375 per Kilowatt of demand when the service is taken at 34,500 volts. Nletering: The Department may, at its option, meter at the customer's utilization voltage or on the high side of the transformer through which the service is furnished. In the latter case, or if the customer's utilization voltage requires no transformation, a discount of 1.8% will be applied to the bill but in no case will such discount be allowed if the metering voltage is less than 2,400 voltage. Nleter Reading and Billing: Rate Filed: June 19, 2017 Effective: On Billings on or after July 1, 2017 Filed By: Coleen Ni. O'Brien, General Manager Town of Reading,. Nlassachusetts Municipal Light Department NIDPU # 275 Bills under this schedule will be rendered monthly. A prompt payment discount of 15% will be allowed on the Customer Charge, Standby Demand Charge, Firm Backup Demand Charge, and Distribution Energy Charge, only if the entire bill is paid -in -full by the discount due date. General Terms and Conditions: Service hereunder is subject to the General Terms and Conditions which areincorporated herein and are a part of this rate schedule. Rate Filed: June 19, 2017 Effective: On Billings on. or after July 1,, 2017 Filed By: Colcen NI. O'Brien, General Manager Town of Reading, Massachusetts Municipal Light Department i1•IDPU # 276 supersedes and cancels. NIDPU # 236 Purchase Power Capacity and Transmission Charge Applicability: The Purchase Power Capacity aild Transmission Charge, or the annual average base power supply base costs, shall be applied to all customers receiving service under any rate schedule of the Department. Power Cost Amount: The Purchase Power Capacity and Transmission Charge amount shall be the total amount of all power and transmission charges incurred by the Department, exclusive of fuel, for electric service to all customers. Such cost shall be computed periodically on actual or estimated power billings and divided by the total kilowatt-hour sales to all customers for that month. The resultant cost shall be rounded to the nearest 5.00001/kilowatt-hour. For customers receiving service under the Department's Industrial Time -of -Use I Rate (N1DPU 4272) the power cost amount will be expressed as a demand charge in SMAI of demand. The demand charge will be calculated to recover the same revenue as the per - kilowatt -hour charge applied to all other customers. Calculation of the Purchase Power Capacity and Transmission Charge: The Purchase Power Capacity and Transmission Charge shall equal the power cost amount. The resultant charge shall be applied to all bills in tile following month. Other Charges and Credits: By order of the Reading Nlunicipal Light Board, die Purchase Power Capacity and Transmission Charge may reflect additional one-time or irregular credits resulting from power refunds, out of period adjustments or reduced power reserve needs. Rate Filed: June 19, 2017 Effective: On Billings on or After July 1, 2017 Filed By: Coleen M. O'Brien, General Manager Town of Reading, Massachusetts MDPU # 277 Municipal Light Department Electric Vehicle Supply Equipment Schedule EVSE Rate Designation: Electric Vehicle Charger (EVSE) Rate Available in: Reading, Lynnfield Center, North Reading, and Wilmington Applicable to: This rate is available to Customers who utilize Electric Vehicle Supply Equipment; installed and owned by RMLD. Character of service: AC 60 cycles: single phase or three phase. Distribution Energy Charge: $.1111 per Kilowatt-hour for all Kilowatt-hours usage Fuel Adjustment: The rate for service hereunder may be increased or decreased as provided by the Standard Fuel Adjustment Clause. Purchase Power Capacity and Transmission Charge: The rate for service hereunder may be increased or decreased as provided by the Purchase Power Capacity and Transmission Charge. Meter Reading and Billing: Service under this schedule will be rendered immediately. Payment due at point of sale. General Terms and Conditions: Service hereunder is subject to the General Terms and Conditions which are incorporated herein and are a part of this rate schedule. Rate Filed: June 19, 2017 Effective: On Billings on or After July 1, 2017 Filed By: Coleen M. O'Brien, General Manager FINANCIAL REPORT MARCH & APRIL 2017 ATTACHMENT 4 FINANCIAL REPORT IAPRIL 302017 s 0.95 0.9 F - z w 0.85 U w FF5 z 0.8 w U W a 0.75 0.7 JULY AUG = FY15 = FY16 = FY17 SEP OCT NOV DEC JAN FEB MAR APR MONTHS OF YEAR $25,000,000.00 $20,000,000.00 $1S,000,000.00 $10,000,000.00 $5,000,000.00 $0.00 Base Revenue & Operating Expenses Comparison July -April FY16 and FY17 10% increase Base Revenue Operating Expenses ■July -April FY16 (10 months) ■July -April FY17 (10 months) PPCT FUEL PPCT and Fuel Revenue and Expenses July 16 -April 17 FY17 (10 months) ® Revenue ® Expense Year to Date Operating and Maintenai Comparing FY16 FY17 and FY17 Budget July 2016 — April 2017 (10 moi $18,000,000.00 $16,000,000.00 $14,000,000.00 $12,000,000.00 $10,000,000.00 $8,000,000.00 $6,000,000.00 $4,000,000.00 $2,000,000.00 April ch � Year to Date Yearto Date j Year to Date July j FY16_ActuaI $1,315,415.23 FY17 Actual Budget $1,399,966.01 $1,783,203.00 IN Aug $2,918,703.69 $3,134,666.17 I $3,566,406.00 ® Sept ��.-- $4,461,345.01 $4,904,753.21 I $5,349,609.00 j ■ Oct $6,272,430.27 ! $6,493,213.21 I $7,132,812.00 ■ Nov $7,627,630.82 $8,309,938.88 $8,916,015.001 i Dec $9,441,533.29 $10,144,029.301_$10,699,218.00 .3 -----_ ■Jan ■ Feb $10,901,861.33 1 $12,563,605.41 $12,232,069.66 $12,482,421.001 ; $13,874,351.50 $14,265,624.00 1 ® March 1 $14,297,906.28 $15,643,132.30 $16,048,827.00 ISApril $15,915,181.84 $17,537,887.481 $17,832,030.00' April ch ENGINEERING & OPERATIONS REPORT MARCH & APRIL 2017 ATTACHMENT 5 READING MUNICIPAL LIGHT DEPARTMENT FOR PERIOD ENDING MARCH 2017 STATION UPGRADES: ALL 169,667 ACTUAL YTD ANNUAL REMAINING PROJ DESCRIPTION TOWN COST ADDITIONS BUDGET BALANCE CONSTRUCTION: 48,904 (64,305) 109 106 Underground Facilities Upgrades (URD's, Manholes, etc) ALL 31,801 296,716 149,965 (146,751) 107 13.8kV Upgrade (Step-down areas, etc.) ALL 1.646 6,555 105,748 99,193 SUB -TOTAL 33,447 303,271 256.713 (47,558) NEW CUSTOMER SERVICES: 141-146 New Service Installations (Commercial / Industrial) ALL 6,325 86,451 139,570 53,119 SUB -TOTAL 6,325 86,451 139,570 53,119 STATION UPGRADES: ALL 169,667 1,341,271 1,012,962 (328,309) 108 Station 4 (GAW) Relay Replacement Project R 113,209 48,904 (64,305) 109 Station 4 35kV Potential Transformer/Replacement R 57 - (57) 110 4W9 Getaway Replacement -Station 4 R 2,622,933 104,513 234,747 130,234 111 Substation Equipment Upgrade (all) ALL 192,232 - 74,590 74,590 113 Station 4 (GAW) Battery Bank Upgrade R - 24,000 17,037 (6,963) 120 Station 4 - Relay/SCADA Integration for Bus A&B R 26,964 51,225 70,308 19,083 130 Station 3 - Remote Terminal Unit (RTU) Replacement NR 24,850 24,850 39,330 14,480 133 Station 3 - Relay Upgrades and SCADA Integration NR 4,416 255,052 252,225 (2,827) 139 Station 5 - LTC Control Replacement W - 6,324 41,543 35,219 140 Substation Grounding Equipment Upgrade ALL - 125 20,671 20,671 70,440 SUB -TOTAL 360,000 56,230 579,231 799,355 220,124 NEW CUSTOMER SERVICES: 141-146 New Service Installations (Commercial / Industrial) ALL 6,325 86,451 139,570 53,119 SUB -TOTAL 6,325 86,451 139,570 53,119 TOTAL CAPITAL BUDGET $ 570,124.33 $ 4,564,999 $ 9,406,216 $ 4,841,217 ROUTINE CONSTRUCTION: ALL 169,667 1,341,271 1,012,962 (328,309) SPECIAL PROJECTS / CAPITAL PURCHASES: 100 Distributed Gas Generation (Pilot FY16-17) ALL 5,396 97,476 2,720,409 2,622,933 102 Padmounl Switchgear Upgrade at Industrial Parks W - 2,286 194,518 192,232 103 Grid Modernization and Opitmization ALL 9,885 232,024 284,000 51,976 105 New Wilmington Sub -Station W - - 250,000 250,000 112 AMI Mesh Network Expansion ALL 125,394 220,021 94,627 115 Fault Indicators ALL - 1,340 25,000 23,660 116 Transformers and Capacitors ALL 151,110 160,212 668,000 507,788 117 Meter Purchases ALL 2,145 30,381 80,000 49,619 125 GIS ALL 70,440 250,217 360,000 109,783 126 Communication Equipment (Fiber Optic) ALL - 7,064 69,173 62,109 131 LED Street Light Implementation ALL 40,644 525,770 804,070 278,300 134 Substation Test Equipment ALL - 14,270 30,000' 15,730 135 Analog Devices Cap Bank Upgrade W 548 54,188 53,640 136 Voltage Data Recorders ALL - - 25,000 25,000 SUB -TOTAL 279,619 1,446,981 5,784,379 4,337,398 OTHER CAPITAL PROJECTS: 96 Control Center Modifications ALL - - 100,000 100,000 97 HVAC Roof Units - Garage R 44,484 - (44,484) 98 Carpet Upgrade R 10,950 71,653 60,703 99 Electric Vehicle Supply Equipment ALL (1,303) - 10.000 10,000 104 RMLD Lighting (LED) Upgrade - 25,000 25,000 118 Rolling Stock Replacement ALL 53,083 310,000 256,917 119 Security Upgrades All Sites ALL - 34,684 5,000 (29,684) 121 HVAC System Upgrade - 230 Ash Street R 8,000 527,550 500,000 (27,550) 127 Hardware Upgrades ALL 9,389 75,668 112,065 36,397 128 Software and Licensing ALL 8,750 61,376 230,519 169,144 129 Master Facilities Site Pian R - 50,000 50,000 SUB -TOTAL 24,837 807,794 1,414,237 606,443 TOTAL CAPITAL BUDGET $ 570,124.33 $ 4,564,999 $ 9,406,216 $ 4,841,217 READING MUNICIPAL LIGHT DEPARTMENT CAPITAL VARIANCE REPORT FOR PERIOD ENDING APRIL 2017 NEW CUSTOMER SERVICES: 141-146 New Service Installations (Commercial / Industrial) ALL 7,513 93,964 139,570 45,606 SUBTOTAL 7,513 93,964 139,570 45,606 ROUTINE CONSTRUCTION: ALL ACTUAL YTD ANNUAL REMAINING PROJ DESCRIPTION TOWN COST • ADDITIONS BUDGET BALANCE CONSTRUCTION: 100 Distributed Gas Generation (Pilot FYI 6-17) ALL 690,997 106 Underground Facilities Upgrades (URD's, Manholes, etc) ALL 1,905 298,621 149,965 (148,656) 107 13.8kV Upgrade'(Step-down areas, etc.) ALL 3,258 9,813 105,748 95,935 258,865 SUB -TOTAL 25,135 5,163 308,434 255,713 (52,721) - STATION UPGRADES: 250,000 112 AMI Mesh Network Expansion ALL 108 Station 4 (GAW) Relay Replacement Project R - 113,209 48,904 (64,305) 109 Station 4 35kV Potential Transformer Replacement R 116 57 - (57) 110 4W9 Getaway Replacement -Station 4 R 117 104,513 234,747 130,234 111 Substation Equipment Upgrade (all) ALL 125 - 74,590 74,590 113 Station 4 (GAW) Battery Bank Upgrade R 126 24,000 17,037 (6,963) 120 Station 4 - Relay/SCADA Integration for Bus A&B R 131 51,225 70,308 19,083 130 Station 3 - Remote Terminal Unit (RTU) Replacement NR 134 24,850 39,330 14,480 133 Station 3 - Relay Upgrades and SCADA Integration NR 879 255,931 252,225 (3,706) 139 Station 5 - LTC Control Replacement ' W - 6,324 41,543 35,219 140 Substation Grounding Equipment Upgrade ALL - - 20,671 20,671 2,269,719 SUB -TOTAL 3,514,660 879 580,109 799,355 219,246 NEW CUSTOMER SERVICES: 141-146 New Service Installations (Commercial / Industrial) ALL 7,513 93,964 139,570 45,606 SUBTOTAL 7,513 93,964 139,570 45,606 TOTAL CAPITAL BUDGET $ 1,203,958 S 5,768,957 $ 9,406,216 S 3,637,259 ROUTINE CONSTRUCTION: ALL 265,341 1,606,613 1,012,962 (593,651) SPECIAL PROJECTS/ CAPITAL PURCHASES: ' 100 Distributed Gas Generation (Pilot FYI 6-17) ALL 690,997 788,473 2,720,409 1,931,936 102 Padmount Switchgear Upgrade at Industrial Parks W - 2,286 194,518 192,232 103 Grid Modernization and Opilmization ALL 26,841 258,865 284,000• 25,135 105 Now Wilmington Sub -Station W - 250,000 250,000 112 AMI Mesh Network Expansion ALL 125,394 220,021 94,827 115 Fault Indicators ALL - 1,340 25,000 23,660 116 Transformers and Capacitors ALL 19,794 180,006 668,000 487,994 117 Meter Purchases ALL 2,955 33,336 80,000 46,664 125 GIS ALL 41,366 291,583 360,000 68,417 126 Communication Equipment (Fiber Optic) ALL 410 7,474 69,173 61,699 131 LED Street Light Implementation ALL 28,518 554,289 804,070 249,781 134 Substation Test Equipment ALL 11,855 26,125 30,000 3,875 135 Analog Devices Cap Bank Upgrade W - 548 54,188 53.640 136 Voltage Data Recorders ALL - 25,000 25,000 SUBTOTAL 822,738 2,269,719 5,784,379 3,514,660 OTHER CAPITAL PROJECTS: 96 Control Center Modifications ALL 100,000 100,000 97 HVAC Roof Units - Garage R 44,484 (44,484) 98 Carpet Upgrade R 10,950 71,653 60,703 `99 Electric Vehicle Supply Equipment ALL - 10,000 10,000 104 RMLD Lighting (LED) Upgrade 25,000 25,000 118 Rolling Stock Replacement ALL 53,083 310,000 256,917 119 Security Upgrades All Sites ALL 34,684 5,000 (29,684) 121 HVAC System Upgrade - 230 Ash Street R 77,186 604,736 500,000 (104,736) 127 Hardware Upgrades ALL 9,298 84,966 112,065 27,099 128 Software and Licensing ALL 15,840 77,216 230,519 153,304 129 Master Facilities Site Plan R 50,000 50,000 SUBTOTAL 102,325 910,119 1,414,237 504,118 TOTAL CAPITAL BUDGET $ 1,203,958 S 5,768,957 $ 9,406,216 S 3,637,259 Igineering & Operations Aft RMLD Board of Commissioners Meeting June 15, 2017 March and April 2017 Reporting Period Hamid Jaffari, Director of Engineering & Operations 11111 '11 MO rFro i � � Distributed Gas Generator Pilot 20% $5,396 F' - -_ - _ - i $690,997.i $788,473; Underground Facilities Upgrades (URDs, Manholes, etc.) - -- - • Crestwood Road, North Reading On-going $31,801. $1,905 $298,621; Robin Road, North- Reading 13.8kV Upgrade (Step-down Areas, etc.) • Main Street, Lynnfield • Main Street Reading On-going ' $1,646 $3,258' $9,8131 Summit Tower,_ Reading_ Station 4: Relay/SCADA Integration for Bus A&B 100% $26,964 $51,225, Station 3: Remote Terminal Unit (RTU) Replacement 40% $24,850' $24,850!i Station 3: Relay Upgrades and SCADA Integration 70% $4,416 $879, 255,931; Service Installations - Residential and Commercial: , e This item includes new or upgraded overhead and On-going $6,325' $7,513; $93,964;' underground services. Grid Modernization and Optimization - — --y On-going $9,885 a $26,841 ; $258,865!; GIS 75% $70,440 $41,366 $291,583:. LED Street.Light Conversion. 65% $40,644.$28,5181 $554,289 Routine Construction Pole Setting/Transfers Overhead/Underground Projects Assigned as Required • Station - 1 15kV Reclosing Automation, R • Voltage Regulators, LC • Pumping Stations (West Street and Batchelder Road), R • 234 Ballardvale Street - Keolis, W _ •__ AT&T Appl W_1572 (Industrial/West), W_ Pole Damage/Knockdowns - Some Reimbursable • Work was done to repair or replace six (6) poles MAR APR $52,374; $29,720 $48,746 $15,348 $25,769 $174, $5,932 $4,13 ;Station Group $12,078, $6,247 Hazmat/Oil Spills $1,240 - • Concord Street, NR Porcelain Cutout Replacement Program - - Lighting (Street Light Connections) $4,341 $2,41, Storm Trouble $13,957 - Underground Subdivisions (new construction) $1 102 • Dogwood Lane, North Reading Animal Guard Installation $108 Miscellaneous Capital Costs $4,020 $32,99C TOTAL: YTD $332,50 $339,546 $354,111 $94,40 7il 67� $7,037 $26, 62 3 $45,812 $46,931 $1,162 1 $17 614 9 Routine Maintenance Transformer Replacement (through April 2017) Pad mount 26.17% Overhead 17.09% Pole Inspection (as of 5/26/17) 231 poles have been replaced 130 of 231 transfers have been completed Quarterly Inspection of Feeders (through May 25, 2017) Inspected Circuits (Jan -Mar): 3W5, 3W6, 3W7, 3W8, 3W 13, 3W 14, 3W 15, 3W 18, 4W4, 4W5, 4W6, 4W7, 4W9, 4W23, 4W24, 5W4, 5W5, 5W8, 5W9, 4P9, 4P2 Inspected Circuits (Apr -Jun): 4W 10, 4W 12, 4W 13 w Manhole Inspection (through April 2017) 961 of 1,237 manholes have been inspected. w Porcelain cutout Replacements (through April 2017) 91 % complete 253 remaining to be replaced w Tree Trimming March: 147 spans trimmed April: 144 spans trimmed YTD: w Substation Maintenance Infrared Scanning - March and April complete - no hot spots found 1,122 spans trimmed Double Poles nership: 16,000 (approximately) 50% RMLD 50% Verizon todial: Reading - split (see map) North Reading - RMLD Lynnfield - Verizon Wilmington - Verizon Town of Reading Pole Jurisdiction �S P it ✓ ' It�� NJ U NS "Next to Go" as of June 5, 2017 WILMINGTON Countor Ticket - _ "--'-- -- - - --"- -- - ---- ---- - ---- NTG Member and JobType I_i Number READING NORTH READING �n)avlCrmR 1, Count L NNFIELD Count of -' Ticket of NTG Member and JobType Irl Ticket of J TRANSFER r NTG Member and JobType Number ,)NGMA 1, SNP3PMA 7. Ticket rLTFMA 1 13 National Grid Non -participating 3 rd Party NTG MemberandJobType Number 0- ightowerFiberNetworks TRANSFER 1 A��ef- ��use t� LFLDFD 3' TRANSFER 7; TRANSFER 1 O- Lynnfield Fire Department BNP3PMA 1 SNPFAMA 4 TRANSFER 3=NP3PMA 9 Non -participating Fire NOn-participating 3rd Party _' Alarms - Massadhusetls Nan -participating 3rd Party Attacher r+ Attacher - Massachusetts TRANSFER 4 O- Massachusetts FIRMLD 3 TRANSFER 9 TRANSFER 1 32 i� +=iReadingMunicipal htDepariment =+ReadingMunicipal light Department TRANSFER 3 ORDNGFD $ 1NRDGFD 44 TRANSFER zaPULPOLE 4 1Reading Fire Department 3 North Ruing Rre Department TRANSFER g TRANSFER 44 �vzBMA a = VZNESA 1D 'Verizon Business 7 Verizon TRANSFER 1 TRANS R 5 JRMLD yZ JRMLD 120 S Reading Municipal Li ht De Department -� VZNEDR 79 PULL LE 5 H Reading Municipal Light Depariment g-1Verizon Jf nk) TRANSFER 34 TRANSFER 13 TRANSFER ss Grand Total 16 PULL POLE 58 PULL POLE 107 Puts PotE 13 WLMFIB 3 'JVZNESA 79 VZNEDR 24 "1Tow n or Wilmington , 9 Verizon '_]Verizon TRANSFER 3 TRANSFER 75 TRANSFER 16-,NrMGNFD 84 PULL POLE 4 PULL POLE 8 W huington Fire Department 'J(blank) 6(blank) TRANSFER 94 Grand Total 189 Grand Total 190 Grand Total 211 RMLD Reliability Indices SAIFI = Total Niiniberof Custonuei-Iiiierniptions Total Numberof Customers Served Note: Regional and -national averages have been updated for 2016. SAIDI 2012-2017 Minutes Minutes 60.00 120.00 56.77 50.00 T-------- - 111.83 2012 40.00 - 2013 30.00 94.96 2014 IEEE day threshold 27.65 2015 IEEE day threshold 20.00 2016 IEEE day threshold 10.00d!il -- - - 2017 YTD IEEE day threshold 60.00 —2016 Region Average (no ME) 0.00 64.22, X2015 2012-2013-2014-2015-2016- —2016 National Average (no ME) 2017 Average SAIDI { Total Durationof Customerinterruptions ? S DI (Minutes) = 0.00 Total Numberof CustomersSetved dr 2012-2013-2014-2015-2016-2017 Note: The major event (ME) threshold allows a utility to remove outages that exceed the IEEE 2.5 beta threshold for events. These events could be severe —2016 National Average weather, which can lead to unusually long outages in comparison to your Average CAIDI distribution system's typical outage. SAIFI = Total Niiniberof Custonuei-Iiiierniptions Total Numberof Customers Served Note: Regional and -national averages have been updated for 2016. 0.90 0.80 0.70 0.60 0.50 0.40 0.30 0.20 0.10 0.00 2012-2013-2014-2015-2016-2017 Average SAIFI CAIDI (Minutes) = Total Duration of Customer Interruptions Total Number of Customers Interruptions SAIR-2012-2017 ® 2012 2013 2014 2015 X2016 2017 YTD —2016 Region Average — 2016 National Average CAI DI 2012-2017 Minutes 120.00 111.83 100.00 ® 2012 94.96 X2013 80.00 X 2014 60.00 64.22, X2015 40.00 0 2016 20.00 2017 YTD 0.00 —2016 Region Average 2012-2013-2014-2015-2016-2017 —2016 National Average Average CAIDI 0.90 0.80 0.70 0.60 0.50 0.40 0.30 0.20 0.10 0.00 2012-2013-2014-2015-2016-2017 Average SAIFI CAIDI (Minutes) = Total Duration of Customer Interruptions Total Number of Customers Interruptions SAIR-2012-2017 ® 2012 2013 2014 2015 X2016 2017 YTD —2016 Region Average — 2016 National Average lOutages Causes YTD (from eReliability website) Weather i Utility Human j 0 Error 0% Unknown 0 O/ 0% Vehicle I Accident^ Natural 1 \ 0 0 ° ®M � 0% Tree 28 54% Outages Causes 2017 YTD April s ■ Equipment o Tree ■ Wildlife ■ Vehicle Accident ■ Weather Unknown ■ Utility Human Error ■ Natural Vehicl Unknown 6 Utility Human Error 3% � 2 1% Natural Annual Average 2012-2017; i i ■ Equipment u Tree ■ Wildlife ■ Vehicle Accident ® Weather Unknown ■ Utility Human Error ■ Natural ; i f r A90h BOARD MATERIAL AVAILABLE BUT NOT DISCUSSED TOWN OF READING MUNICIPAL LIGHT DEPARTMENT RATE COMPARISONS READING 8 SURROUNDING TOWNS May -17 PEABODY MUNICIPAL LIGHT PLANT TOTAL BILL $88.38 $172.43 $117.07 $952.31 $151.07 $4,709.23 $638,286.46 PER KWH CHARGE $0.11784 $0.11495 $0.11707 $0.13045 $0.13988 $0.13455 $0.09278 % DIFFERENCE -18.23% -6.63% -10.73% -2.63% -22.48% 3.74% -11.79% MIDDLETON MUNICIPAL LIGHT DEPT. TOTAL BILL $98.74 $201.66 $132.75 $959.51 $168.44 $4,762.93 $807,171.40 PER KWH CHARGE $0.13165 $0.13444 $0.13275 $0.13144 $0.15596 $0.13608 $0.11733 %DIFFERENCE -8.64% 9.20% 1.23% -1.89% -13.57% 4.92% 11.56% WAKEFIELD MUNICIPAL LIGHT DEPT. TOTAL BILL $115.49 $213.42 $144.38 $1,093.29 $175.48 $5,123.08 $852,765.30 PER KWH CHARGE $0.15398 $0.14228 $0.14438 $0.14977 $0.16249 $0.14637 $0.12396 % DIFFERENCE 6.85% 15.56% 10.10% 11.79% -9.96% 12.86% 17.86% INDUSTRIAL - TOU RESIDENTIAL RESIDENTIAL-TOU RES. HOT WATER COMMERCIAL SMALL COMMERCIAL SCHOOL RATE 109,600 kWh's 760 kWh's 1600 kWh's 1000 kWh's 7,300 kWh's 1,080 kWh's 36000 kWh's 260.000 kW Demand 76126 Split 26.000 kW Demand 10.000 kW Demand 130.6 kW Demand 80120 Split READING MUNICIPAL LIGHT DEPT. TOTAL BILL $108.08 $184.68 $131.14 $978.03 $194.89 $4,539.50 $723,561.98 PER KWH CHARGE $0.14410 $0.12312 $0.13114 $0.13398 $0.18045 $0.12970 $0.10518 NATIONAL GRID TOTAL BILL $151.90 $358.79 $188.23 $1,363.20 $210.20 $5,412.22 $1,603,701.44 PER KWH CHARGE $0.20253 $0.23919 $0.18823 $0.18674 $0.19463 $0.15463 $0.23311 %DIFFERENCE 40.55% 94.28% 43.53% 39.38% 7.86% 19.23% 121.64% EVERSOURCE(NSTAR) TOTAL BILL $143.50 $253.51 $189.19 $1,233.41 $203.03 $6,692.17 $936,202.98 PER KWH CHARGE $0.19133 $0.16901 $0.18919 $0.16896 $0.18799 $0.19120 $0.13608 %DIFFERENCE 32.77% 37.27% 44.27% 26.11% 4.18% 47.42% 29.39% PEABODY MUNICIPAL LIGHT PLANT TOTAL BILL $88.38 $172.43 $117.07 $952.31 $151.07 $4,709.23 $638,286.46 PER KWH CHARGE $0.11784 $0.11495 $0.11707 $0.13045 $0.13988 $0.13455 $0.09278 % DIFFERENCE -18.23% -6.63% -10.73% -2.63% -22.48% 3.74% -11.79% MIDDLETON MUNICIPAL LIGHT DEPT. TOTAL BILL $98.74 $201.66 $132.75 $959.51 $168.44 $4,762.93 $807,171.40 PER KWH CHARGE $0.13165 $0.13444 $0.13275 $0.13144 $0.15596 $0.13608 $0.11733 %DIFFERENCE -8.64% 9.20% 1.23% -1.89% -13.57% 4.92% 11.56% WAKEFIELD MUNICIPAL LIGHT DEPT. TOTAL BILL $115.49 $213.42 $144.38 $1,093.29 $175.48 $5,123.08 $852,765.30 PER KWH CHARGE $0.15398 $0.14228 $0.14438 $0.14977 $0.16249 $0.14637 $0.12396 % DIFFERENCE 6.85% 15.56% 10.10% 11.79% -9.96% 12.86% 17.86% TOWN OF READING MUNICIPAL LIGHT DEPARTMENT RATE COMPARISONS READING 8 SURROUNDING TOWNS June -17 PEABODY MUNICIPAL LIGHT PLANT TOTAL BILL $88.38 $172.43 $117.07 $952.31 $151.07 $4,709.23 $638,286.46 PER KWH CHARGE $0.11784 $0.11495 $0.11707 $0.13045 $0.13988 $0.13455 $0.09278 %DIFFERENCE -19.80% -8.72% -12.61% -4.01% -23.30% 2.22% -13.35% MIDDLETON MUNICIPAL LIGHT DEPT. TOTAL BILL $98.74 $201.66 $132.75 $959.51 $168.44 $4,762.93 $807,171.40 PER KWH CHARGE $0.13165 $0.13444 $0.13275 $0.13144 $0.15596 $0.13608 $0.11733 %DIFFERENCE -10.40% 6.75% -0.91% -3.29% -14.49% 3.38% 9.58% WAKEFIELD MUNICIPAL LIGHT DEPT. TOTAL BILL $115.49 $213.42 $144.38 $1,093.29 $175.48 $5,123.08 $852,765.30 PER KWH CHARGE $0.15398 $0.14228 $0.14438 $0.14977 $0.16249 $0.14637 $0.12396 %DIFFERENCE 4.80% 12.98% 7.78% 10.20% -10.91% 11.20% 15.77% INDUSTRIAL - TOU RESIDENTIAL RESIDENTIAL-TOU RES. HOT WATER COMMERCIAL SMALL COMMERCIAL SCHOOL RATE 109,600 kWh's 760 kWh's 1500 kWh's 1000 kWh's 7,300 kWh's 1,080 kWh's 36000 kWh's 260.000 kW Demand 75126 Split 26.000 kW Demand 10.000 kW Demand 130.6 kW Demand 80120 Split READING MUNICIPAL LIGHT DEPT. TOTAL BILL $110.19 $188.91 $133.96 $992.11 $196.97 $4,607.05 $736,600.61 PER KWH CHARGE $0.14692 $0.12594 $0.13396 $0.13591 $0.18238 $0.13163 $0.10707 NATIONAL GRID TOTAL BILL $151.90 $358.79 $188.23 $1,454.38 $223.69 $5,412.22 $975,136.26 PER KWH CHARGE $0.20253 $0.23919 $0.18823 $0.19923 $0.20712 $0.15463 $0.14174 %DIFFERENCE 37.85% 89.93% 40.51% 46.59% 13.56% 17.48% 32.38% EVERSOURCE(NSTAR) TOTAL BILL $143.50 $253.51 $189.19 $1,233.41 $203.03 $6,692.17 $1,037,846.34 PER KWH CHARGE $0.19133 $0.16901 $0.18919 $0.16896 $0.18799 $0.19120 $0.15086 %DIFFERENCE 30.23% 34.20% 41.23% 24.32% 3.08% 45.26% 40.90% PEABODY MUNICIPAL LIGHT PLANT TOTAL BILL $88.38 $172.43 $117.07 $952.31 $151.07 $4,709.23 $638,286.46 PER KWH CHARGE $0.11784 $0.11495 $0.11707 $0.13045 $0.13988 $0.13455 $0.09278 %DIFFERENCE -19.80% -8.72% -12.61% -4.01% -23.30% 2.22% -13.35% MIDDLETON MUNICIPAL LIGHT DEPT. TOTAL BILL $98.74 $201.66 $132.75 $959.51 $168.44 $4,762.93 $807,171.40 PER KWH CHARGE $0.13165 $0.13444 $0.13275 $0.13144 $0.15596 $0.13608 $0.11733 %DIFFERENCE -10.40% 6.75% -0.91% -3.29% -14.49% 3.38% 9.58% WAKEFIELD MUNICIPAL LIGHT DEPT. TOTAL BILL $115.49 $213.42 $144.38 $1,093.29 $175.48 $5,123.08 $852,765.30 PER KWH CHARGE $0.15398 $0.14228 $0.14438 $0.14977 $0.16249 $0.14637 $0.12396 %DIFFERENCE 4.80% 12.98% 7.78% 10.20% -10.91% 11.20% 15.77% From: Tracy Schultz To: RMLD Board Members Grouo Subject: AP Warrants and Payroll Date: Thursday, June 08, 2017 7:38:00 AM Good morning, There were no questions on the May 12, May 26, and June 2, 2017 AP Warrants. Mr. Hennessy had a question on the May 19 AP -the tree trimming contractor charges for labor and per span removed. There were no questions on the May 15 Payroll. Mr. O'Rourke had an inquiry about the May 29, 2017 Payroll: it was a tuition reimbursement payment to an employee. This message will be included in the packet for next Thursday's Board Meeting. Tracy Schultz Executive Assistant Reading Municipal Light Department 230 Ash Street. Reading. MA. 01867 Tel: 781.942.6489