BONNEVILLE POWER ADMINISTRATION

BPA Distributed Energy Resources Benchmarking Report

2018 To learn more visit: www.bpa.gov/goto/DER [email protected] 3 Letter from BPA 4 Dairyland 7 TVA 10 TVPPA + Seven States 13 HECO 17 NV Energy 21 NPPD 26 BGE 29 GRE 33 MVEC 36 WVPA DISTRIBUTED ENERGY RESOURCES BENCHMARKING PARTICIPANTS

Dairyland

GRE + MVEC

NPPD WVPA BGE NV Energy TVPPA + TVA

HECO

2 LETTER FROM BPA

The Bonneville Power Administration (BPA) has served the Pacific Northwest through the Federal Columbia River Power System (FCRPS) for over 80 years. We have been able to meet regional needs with the robust, flexible and low-cost capacity provided by the FCRPS and the electricity that is typically available in the Northwest’s wholesale power market. Currently, regional capacity needs that exceed supply appear on the horizon, in terms of aggregate system balance, as identified in the Northwest Power and Conservation Council’s Power Plan. These potential constraints have led BPA to look for ways to provide additional capacity beyond that of the FCRPS. Demand Response (DR) has been used as a long-term source of capacity elsewhere in the U.S. where utilities do not have access to the robust and ready supply of flexible capacity we have in the Pacific Northwest. Over the past several years, BPA has supported DR pilots and demonstrations in public utility service territories throughout the region. More recently, we have researched opportunities to use additional Distributed Energy Resources (DER) in both our Power and Transmission businesses to continue providing the necessary flexibility and reliability for BPA. To support this research objective, BPA staff met with 10 utilities throughout 2018 to better understand how they are using and enabling DER within their organizations and service territories. We learned the types of DER being used by public utilities, and how they are designing, implementing and developing strategies. This report provides summaries of what we learned during these discussions. As manager of the distributed energy resources team at BPA, I’d like to sincerely thank our many utility partners who generously contributed their valuable time and knowledge to participate in this benchmarking effort. We look forward to continuing these discussions in this important area of our business as new developments unfold. Sincerely, Lee Hall Manager, Power Services’ Distributed Energy Resources

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DAIRYLAND POWER

Dairyland Power Cooperative provides wholesale electric requirements and other services for its 24 member electric distribution cooperatives and 17 municipal utilities. These cooperatives deliver energy to more than a half million people, via nearly 3,200 miles of transmission lines over a HEADQUARTERS 44,500 square mile service area. Lacrosse, Wisconsin Dairyland’s DER systems encompass each of Dairyland’s FAST FACTS four areas of sustainability: ƒƒFounded in 1941 financial, environmental, social ƒƒ600,000 Customers and technological. Through evolving technology, strategic ƒƒServes 42 counties in four states DER deployments and investments, Dairyland is able PEAK DEMAND to make a difference in keeping ƒƒ1,171 MW power costs stable at times of high demand. Dairyland and its to align business decisions with cooperatives are able to delay or Dairyland’s “Preferred Plan” of DER PORTFOLIO defer traditional capital investment resource diversification. ƒƒResidential, Agricultural, and through DER as an alternative. Many community solar projects Commercial DR have been integrated alongside ƒƒ30 MW of Distributed Solar PV PPA facilities. Community solar through various PPAs and Coopera- Distributed Solar provides an opportunity for tive-sponsored community solar Dairyland and its member consumer members to receive cooperatives have collectively credit for solar generation without invested in approximately 30 the hassle of maintaining or siting MW of distributed solar PV their own array. It makes solar systems through various PPAs available to homeowners, renters and community solar projects. and anyone with a desire to invest These deployments are a shining in local, renewable energy. example of working collaboratively

4 Load Management Dairyland has a one-way direct DAIRYLAND MEMBERS load control program it has operated for more than 30 years. The load management programs at Dairyland help balance the demand for electricity with the availability of generation, while helping provide economical rate options. Dairyland estimates that the load management system can reduce demand by 80 MW in summer and 140 MW in winter. Incentive based Load Management programs are offered by Dairyland’s member cooperatives to their customers. Dairyland has a self-generated financial modeling tool that it uses to help member cooperatives evaluate program design options. Dairyland also provides marketing materials that can be rebranded for customers’ use.

Coordinated strategies for energy PROGRAM ATTRIBUTES storage using hot water heaters or backup heat systems allow How it Works most participants to experience a • Currently enabled by a radio frequency (RF) system seamless shift. • 130,000 receivers and 69 transmitter sites Major categories of service within • The system costs are managed by Dairyland Power as a the Load Management program shared service to its member cooperatives include: • Residential high-capacity • All 24 member cooperatives participate in the program water heaters, electric heating thermal storage, air conditioners, heat pumps, Rate-Driven How it Works in-floor hydronic heating and Dairyland’s wholesale rate is Dairyland is a member of the electric vehicle charging. designed to deliver price signals, Midcontinent Independent System which incent and reward the Operator (MISO). During periods • Agricultural irrigation pumps, member cooperatives’ participation of high electricity prices, peak grain drying systems and in Load Management. Member demand or constrained energy water heaters. cooperatives are subject to higher supply in the MISO wholesale • Commercial and Industrial demand charges and energy rates market, Dairyland issues load demand is managed with during peak time. They can avoid control events in which loads are stand-by generation and self- the charges if they participate in turned off, cycled or otherwise directed load reductions. the program. modulated. Control durations are time limited and full automation Dairyland’s member co-ops is used whenever possible to transfer their cost savings to provide a balance of comfort and consumers through incentives convenience for participants. or special rates that drive participation. 5 Dairyland is currently evaluating systems and vendors and working on a strategy to transition from a one- WHAT’S way DLC system to a system that accommodates data driven communications for enhanced capability and NEXT performance visibility. for Dairyland Demonstrating commitment to its Preferred Plan, Power? Dairyland has finalized a power purchase agreement with Ranger Power for a 149 MW solar PV project proposed in Jefferson County, WI. Pending permitting and approval, construction is anticipated to begin in 2020 with commercial operation commencing in 2022.

6 BPA Distributed Energy Resources Benchmarking Report

TENNESSEE VALLEY AUTHORITY

In 1933, the Tennessee Valley Authority (TVA) Act created a public corporation. The act enabled TVA to acquire real estate for the purpose of constructing dams, reservoirs, transmission lines, power houses and other structures, as well as navigation projects anywhere along the Tennessee River or its tributaries. TVA is the largest electric power HEADQUARTERS Knoxville, Tennessee producer in the country, typically producing 130 billion kilowatt-hours per year. FAST FACTS ƒƒFounded in 1933 TVA Business Model TVA customers consist of regional ƒƒTVA serves 10 million customers cooperatives and municipal TVA is a nonprofit organization, utilities. ƒƒTerritory spans seven states. All which partners with 154 local or parts of Tennessee, Mississippi, power companies and 59 end- TVA sells and distributes power to their customers, who in turn, Alabama, Georgia, North Carolina, use customers throughout the Virginia, Kentucky Tennessee Valley. TVA recovers sell and distribute it to their end almost all of its costs through users. TVA generates $10.9 billion PEAK DEMAND energy sales. in annual revenue. ƒƒ33,482 MW (2007 record)

DR PRODUCTS ƒƒDispatchable Voltage Regulation (DVR) ƒƒInterruptible Power ƒƒCommercial and Industrial

7 DR at TVA EnergyRight © Solutions (ERS) is the TVA portfolio of offerings that provide options for energy efficiency, electrification and DR. EnergyRight also seeks to position TVA and local power companies as trusted energy partners.

ERS Sized to Fit Needs TVA provides several options for its customers to choose from, depending on their needs. 1. Turnkey- TVA designs and delivers programs based on input from local power companies. Interruptible Power (1,400 MW) Dispatchable Voltage Regulation 2. Local power companies • This program enables TVA develop and deliver programs to suspend a portion of • Sixteen local power under contract(s) to TVA. participating customers‘ load, companies participate. 3. Programs developed and with five or 30 minutes notice, • One umbrella contract, supported by TVA, but during times of power system developed by TVA, that all 16 delivered by local power needs. participants separately sign. companies. • These programs are with Peak Power Partners 4. Programs developed and direct-serve customers as well (Aggregated) -Year round delivered by an aggregator, as local power companies under contract(s) to TVA. and the loads they serve. • TVA has partnered with DR aggregators offering • Participants in these programs both capacity and energy receive credits on their power payments during events. DR Delivers bills in exchange for reducing their electrical load to a DR at TVA provides 1,600 MW of previously determined level, capacity. Directly contracted DR either to meet a reliability or programs are managed by TVA. economic need. The programs are varied in size and type and include, but are not limited to, the following:

8 Batteries TVA is keeping close tabs on the efficacy and affordability of batteries as a source for demand WHAT’S reduction and rate optimization. TVA is actively working with research partners to understand the technology NEXT and current market value of energy storage devices (residential batteries to commercial scale application.) for Tennessee TVA sees energy storage as a means of smoothing Valley Authority? demand variations, increasing the flexibility of the grid, and enabling the use of renewable resources like wind, solar and other types of distributed generation.

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TENNESSEE VALLEY PUBLIC POWER ASSOCIATION AND SEVEN STATES POWER CORPORATION The Tennessee Valley Public Power Association mission: “Our mission is twofold: to serve as an effective advocate for our members’ interests with the public, in the political process and with TVA; and to be a successful independent provider of competitive utility business services.”

Seven States Power Corporation mission: “Serve HEADQUARTERS as an innovative platform for designing, developing Chattanooga, Tennessee and deploying distribution services, including energy and demand solutions, renewables and generation FAST FACTS ownership.” ƒƒOver 9 million customers served through their members TVPPA at a Glance Seven States at a ƒƒStates served: Alabama, Georgia, The Tennessee Valley Public Glance Tennessee, Mississippi, Kentucky, Power Association (TVPPA) is Seven States Power Corporation North Carolina and Virginia the nonprofit, regional service was incorporated in 2007 by the organization that represents the Tennessee Valley Public Power PEAK DEMAND interests of consumer-owned Association as a separate, ƒƒTypically in summer electric utilities operating within nonprofit membership corporation the Tennessee Valley Authority with the powers of a generation ƒƒCommunities closer to the mountains service area. TVPPA members and transmission cooperative to have a winter peak include both municipal utilities serve TVPPA’s 154 distributor and electric cooperatives. Their members. members serve more than 9 DER PORTFOLIO million customers in Alabama, The cooperative serves as a ƒƒResidential, Commercial and Industrial Georgia, Tennessee, Mississippi, platform for designing, developing DR via non-wires initiatives Kentucky, North Carolina and and deploying distribution services, Virginia. TVPPA is comprised of energy and demand solutions. 154 consumer-owned local power Current areas of focus include companies, governed by a board electric vehicles, renewables, of directors with representatives distribution management services across districts and from each of and generation ownership. Seven the seven states in the Tennessee States represents the community Valley. www.tvppa.com interest of local power companies. www.7spc.com 10 DERMS leveraged the buying power of DER through Seven the LPCs to negotiate affordable States In 2018, Seven States announced pricing for members that wish to The Seven States DR Aggregation a further step in its DR program utilize the service. with the selection of a Distributed Demonstration started in 2013. The intention of this decision is to TVA hired EnerNOC to develop Energy Resources Management System (DERMS). Seven States enable Seven States to aggregate a Commercial and Industrial utility load and DER assets, (C&I) DR aggregation program. leveraged the buying power of the LPCs to negotiate affordable create virtual power plants, and TVPPA members were able to drive aggregated programs that opt in or out. Several local power pricing for members that wish to utilize the service. provide economic and reliability companies opted out of the C&I benefits for its members. The DR Aggregation program. Of OATI, a software company, was solution also includes a NERC those that opted out, five agreed selected as the DERMS system CIP compliant hardware and to participate in the Seven States provider. The DERMS program software solution. The system proof of concept project with will be funded by the savings that uses advanced networking, one of the five being the Electric are accrued from the reduction in security and communication Power Board of Chattanooga. demand charges. The fully multi- technologies to give utilities Seven States joined forces with tenant OATI DERMS software complete observability and these five local power companies solution is intended to allow control of all their distributed to form a DR demonstration. utilities to optimally manage energy resources, load control The ADR program provided their distribution grids with a assets, generation assets and curtailment to TVA when they variety of interconnected DER electrical grid equipment. initiated curtailment events. programs including behind-the- These programs developed meter assets, commercial and by LPCs to manage their own industrial assets, and larger utility- demand charges are managed owned resources. Seven States under the TVA DERMS project. OATI DERMS APPROACH

11 Key Components of the Seven States Program: • Seven States prioritizes load management service solutions for use by utilities of varying sizes. • Seven States will finance the utilities’ upfront costs, if necessary, and recover those expenses through an affordable monthly fee. • Local control is a Seven States foundational principle.

TVPPA is conducting, on behalf of Seven States, extensive training for its cooperative and municipal WHAT’S members. That training will enable members to use load- NEXT control software on their systems in order to control their end-users’ devices, such as water heaters and for Seven States thermostats. and TVPPA?

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HAWAIIAN ELECTRIC COMPANY

For more than 100 years, Hawaiian Electric Company, or HECO, has provided the energy that has fueled the islands’ development from a Hawaiian kingdom to a modern state. Hawaiian Electric Company, and its subsidiaries, Maui Electric Company, and Hawaii Electric Light Company, HEADQUARTERS serve 95 percent of the state’s 1.4 million residents on the Honolulu, Hawaii islands of Oahu, Maui, Hawaii Island, Lanai and Molokai. FAST FACTS ƒƒFounded in 1891 DER at HECO A Rich History ƒƒHECO serves approximately 1.3 mil- Hawaiian Electric Company’s • 1881 - King David Kalakaua lion customers DR program rewards residential met Thomas Edison in New and business customers for York as part of a world tour. ƒƒTerritory- five Hawaiian islands. temporarily reducing their electric • 1886 - Electric light consumption during peak PEAK DEMAND demonstration organized energy periods. The program by Charles Otto Berger at ƒƒ1,100 MW (Oahu) helps Hawaii reduce imported the King’s residence Iolani oil consumption and stabilizes Palace. Shortly after, a steam DER PRODUCTS electricity demand. generator was installed to ƒƒResidential and Commercial DER light the palace grounds. ƒƒEnergy Storage (battery) • 1887 - Palace interior was wired, fitted with a generator and the interior was lit. • 1888 - Honolulu street lights energized by hydro turbines of Nuuanu plant. Water heaters and air conditioners are HECO • 1891 - Hawaii Electric was homes’ largest energy incorporated with William H. users. Hall as the first president and $17,000 in total assets. Water heaters alone can comprise up to 30 percent of a HECO customer’s electric bill. 13 DER at HECO HECO provides options for both commercial and residential customers to participate in DR programs.

Energy Scouttm for Business and Residential • For large commercial and industrial direct load control, HECO installs a free device that can temporarily curtail a customer’s energy load for typically no more than an hour per event. If a DR event is more than one hour, participants receive an additional energy reduction incentive. Program participants engage at two different levels: HECO PROMOTES INCREASED RENEWABLES 1. Dispatch- Customers have AND REDUCED RELIANCE ON OIL IMPORTS one hour to actively drop their THROUGH DR load. 2. Dispatch and Under Frequency- The installed device senses a drop in the system load frequency and Fast DR immediately curtails loads to This pilot program is available for commercial and industrial customers match demand. that can commit to a minimum 50 kW load reduction. The program targets non-essential equipment that can be automatically curtailed For its small business and at certain times. HECO provides a free preliminary assessment and residential direct load control technical audit to determine what equipment might be a good fit for fast program, HECO installs a free DR. Typical equipment and load reducing techniques are: device that can receive a signal to turn off water heaters or cycle air • Turning off or adjusting non-essential processes or other equipment. conditioners for one hour events. • Reducing HVAC usage. Daily peak is typically 5-9 p.m. During the events: • Shutting off non-essential indoor and outdoor lighting, signage or window displays. • Hot water stored in the tanks can still be used. • Shutting off fountains, saunas, and pool or hot tub heaters and pumps. • Air conditioners will continue to run, but for shorter periods. • Shutting off excess elevator banks or escalators as permitted. Small business participants If customers can designate the minimum load shed requirement of 50 receive a monthly check or bill kW, they receive a yearly credit of at least $3,000 ($5/kW-month) or credit for $5 per water heater and $6,000 ($10/kW-month) if a DR event was initiated. An additional $5 $5 for each ton of air conditioning or $10 per month incentive is issued for each kW available for load enrolled. shedding above the 50kW minimum.

14 CURRENT DER PORTFOLIO

CUSTOMER NAME SIZE PRIMARY USE INCENTIVE BASTE HECO installs a free device. EnergyScout™ Customers receive $3 every Residential Water Over 34,000 15 MW This system is used for month as a credit on their Heater Control Switch customers daily peak load reduction. electric bill, whether an event is triggered. HECO installs a free device. EnergyScout™ This system is used for Customers receive $5 every Residential Air Over 4,000 2.5 MW seasonal and daily peak month as a credit on their Conditioner customers load reduction. electric bill, whether or not an event is triggered. EnergyScout™ for Business, Large 14 HECO installs a free device Commercial and customers This system is used for that can temporarily curtail Industrial Direct Load (range from 18.2 MW daily peak load reduction. customer designated loads Control (CIDLC) – 50 kW to 5 for one-hour typical event Customer-controlled MW) duration. curtailment of load

HECO installs a free device. EnergyScout™ for Participants receive a check Business, Small or credit on their electric bill Business Direct Load 161 This system is used for each month of $5 for each Control Program customers 1 MW daily peak load reduction. water heater and $5 for each (SBDLC). Water heater ton of air conditioning enrolled, and air conditioner regardless if an event is triggered.

Coming Soon HECO has seven new renewable energy contracts in process, totaling 262 MW of solar, to be paired with 1,048 MWh of storage.

15 Grid Modernization Technologies WHAT’S HECO has initiated grid-modernization technology that enhances the capabilities of the electric grid.

NEXT Improving reliability: When outages take place, grid- for HECO? modernization technologies and advanced meters will communicate with each other and send an outage alert to the local utility. The problem is located and in some cases, problems can be fixed remotely, allowing for faster power restoration.

Integrating more renewable energy: Grid modernization will provide system operators and engineers with data and tools needed to help achieve Hawaii’s 100 percent renewable electricity goal. It will do this by improving the safe and reliable integration of greater amounts of renewable energy. Grid modernization creates flexibility to respond to changes in power flow produced by variable sources, such as wind and solar.

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NV ENERGY

NV Energy, has served customers in northern Nevada for more than 150 years, and southern Nevada since 1906. NV Energy was the first utility to be served by Hoover Dam. HEADQUARTERS Today, its service area covers nearly 46,000 square miles, Las Vegas, Nevada including the communities of Las Vegas, Reno-Sparks, FAST FACTS Henderson and Elko. ƒƒEnergy service provider for more than 150 years thermostats that allowed A History of DER customers to op-out of load ƒƒResidential: 1.2 million Development control events and performance based event incentives. Cool ƒƒCommercial and street lights: 155,995 NV Energy has been developing Share achieved 142 MW of ƒƒPublic authorities: 66 and operating a portfolio of demand reduction and had DR options since 2001. The 60,000 customers with 78,000 ƒƒElectric customers total: 1.3 million technology and incentive offerings devices. have evolved over time. They PEAK DEMAND have included: mPowered After deploying smart meter infrastructure and a DR ƒƒ 7,753 MW total load Cool Credit Beginning with the Management System (DRMS) in ƒƒ 230 MW emergency DR Cool Credit program, which used 2012, the Company launched one-way paging based switches next generation programs ƒƒ 160 MW economic DR and thermostats to control focused on Integrated Demand residential air conditioning, NV Side Management (IDSM). The DER PORTFOLIO Energy helped blaze the trail to mPowered program leveraged ƒƒEnergy Storage DR. The Cool Credit program ran smart meters, smart thermostats, from 2001-2006 and achieved and broadband communications ƒƒElectric Vehicles 20 MW of demand reduction. to help customers save energy ƒƒResidential DR There were 18,000 customers year round and more comfortably and 23,000 devices. Customers participate in DR events. Residential IDSM received a fixed incentive of $15 ƒƒ per summer month. ƒƒCommercial DR Cool Share In 2007, this ƒƒCommercial IDSM program introduced two-way paging web-programmable 17 Power Shift Smart Technology Under the portfolio brand name The system uses broadband PowerShift, NV Energy offers gateway and smart meter a wide range of DER program technology for event and data choices for customers. The communications. Thermostats marketing and program offerings can be integrated with home for demand response, energy energy management platforms. efficiency, storage, and electric A third party software partner vehicles are now shared. provides cloud-based analytics. By applying machine learning to equipment and temperature data, Residential IDSM the algorithms drive more energy and demand savings, and identify As mPowered transitioned to air conditioners that are in need of the PowerShift smart thermostat service or repair. program, the Company continued upgrading technology offerings Customers can log in to the and building out the IDSM platform to see real-time data and portfolio. This effort has added adjust system settings. another 92 MW of capacity so Smooth Temp Transitions far and continues to grow both in size and integration with other To create a smooth power and programs. The thermostats customer comfort transition, the provide year-round energy service automatically controls efficiency optimization as well as HVAC on DR-event days. The DR event optimization. system uses precooling, and also helps avoid peak “bounce back,” Automation & Pricing by controlling the ramp up of Because of the cloud-based demand after an event. optimization, the success of DR events are not dependent on high price signals. However, Event Optimization the system can be configured Events are typically two hours for to accommodate customers on each customer. Customer groups dynamic rates. are phased in over time to flatten Smart Meters out the system load shape. Customer specific rebates are paid per kilowatt hour reduction, and calculated using smart meter data.

Older technology is being phased out

18 Commercial IDSM The commercial programs also prioritize the integration of energy efficiency and DR, as well as automation

Large Commercial Programs Small & Medium (SME) Programs

High Networked Thermostats Technology • Customers receive no cost Control of rooftop HVAC units. Control • EE Measure “Technology” in the form of an options and analytics can identify and Assistance installed thermostat. An example drive additional energy savings. • Targeted of a “Targeted Enhancement” is Enhancement an economizer controls upgrade. OpenADR Client/Gateway Automated control of end use loads. Incentives in form of equipment, installation, or enhanced EE measure Level of EE rebates. Integration Demand Limiting Controls Coordinated control of rooftop HVAC units to reduce coincident facility demand. Supports customer operations. Message Based OpenADR Gateway Customer controls end use loads Automated control of customer Cash per based upon message from DRMS. selected end use loads. Performance kW Performance based incentive. based incentive.

Low Automation Level High

Portfolio Approach Event Control Customer Value In the framework pictured Except for a few customers Incentive options are varied. above, NV Energy prioritizes the that receive email notifications, Customers benefit from a higher development and deployment of NV Energy uses the OpenADR utility incentive and financial programs that offer a high degree protocol to manage DR events. savings if the DR infrastructure of automation and integration of For most SME programs, DRMS is leveraged to generate energy energy efficiency or other DER communicates with a vendor IoT savings. This can come in the types. Programs are developed cloud that supports OpenADR. form of no cost equipment and for customer segments by size, Otherwise, NV Energy installs installation, or a higher rebate end-use loads, and technology an OpenADR interface gateway, for an associated EE measure. capability. NV Energy works to or communicates directly with A standard performance based move customers from the bottom an OpenADR software client. $/kW incentive option is also left quadrant to the top right NV Energy has trials underway available. Customers can migrate quadrant. for managing customer owned from a standard approach to an energy storage devices using IDSM structure. OpenADR and IEEE2030.5.

19 DER Integration Increased adoption of new asset types such as electric and thermal energy storage devices, and electric vehicles into program designs as operational assets for grid management— WHAT’S at both the system level and distribution level—are the next phase of modernization for NV Energy DER programs. NV Energy NEXT continues to work to leverage artificial intelligence and machine learning to use smart meter and DR asset data to identify and for NV target customers for energy, demand, and cost saving measures. Energy Operating behind the meter assets to support renewable energy integration will be critical as the Company rapidly approaches 50% renewable energy generation.

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NEBRASKA PUBLIC POWER DISTRICT

Nebraska Public Power District is the state’s largest electric utility, whose chartered territory includes all or parts of 86 of the 93 counties in Nebraska. NPPD is governed by an 11-member board of directors, through popular vote within the chartered territory. The NPPD mission is to, “Safely generate and deliver reliable, low cost, sustainable energy and provide outstanding HEADQUARTERS customer service.” Columbus, Nebraska

NPPD uses certain facilities FAST FACTS NPPD Energy Mix such as Beatrice Power station, ƒƒNPPD is Nebraska’s largest electric NPPD is the sole wholesale power a combined oil- and gas-fueled provider for 25 public power turbine facility, to help reduce utility districts, 50 municipal customers peak demand costs and also ƒƒProvides electric service to more than (including 46 towns), along with provide emergency backup for 600,000 customers two partial requirements municipal other resources. This location customers. NPPD generates alone has a 250 MW capacity. ƒƒEstablished in 1970 the power and transmits it to the buyers. These wholesale ƒƒNebraska is the only fully public customers then distribute the powered state in the nation power to end-use customers. PEAK DEMAND NPPD also serves approximately 89,000 retail customers; however, ƒƒWinter-2,700 MW 70 percent of NPPD’s revenue ƒƒSummer-2,200 MW is derived from the wholesale business. DER PORTFOLIO NPPD uses a mix of generation ƒƒIrrigation Control supply to meet the customers’ demand needs. The diversity of ƒƒResidential DR energy types helps NPPD meet demand and keep energy rates low. Peak Demand Energy resource diversity helps NPPD manage peak demand.

21 Price Signals & DER NPPD has a Billable Demand Program. Through this program, wholesale customers manage DER IN NPPD IS MANAGED BY ITS their loads based on the price WHOLESALE CUSTOMERS signals NPPD sends at or near peak load levels. Here is how it works: NPPD customers are notified daily, via messaging from the NPPD control center, if peak demand hours will be “billable” or “nonbillable” for that day. NPPD looks at hourly load projections each day. If the load will not be near/at peak levels, NPPD may choose to waive demand charges for that day during typical on-peak hours. If the demand projects are near/at peak levels, NPPD will bill for demand. This charge motivates and triggers the customers to implement load control measures to reduce overall costs for the day. NPPD’s on-peak hours are 9 a.m.– 11 p.m. Monday through Sunday. The effectiveness of the load-reduction programs Irrigation DER have ultimately shifted the peak demand, which now occurs Irrigation makes up one third of the total demand in NPPD territory. around 11 p.m., when the Roughly 2.2 million horsepower is connected to the DER system. The controlled loads are released average irrigation service load is 58 horsepower. This makes up about back onto the grid. Typical peak 87 percent of the connected loads in irrigation. Connected irrigation without this load control effect is horsepower served by NPPD has grown from 300,554 horsepower in 6-8 p.m. during the week. Peak 1970 to 2,349,283 horsepower in 2017. That is a 4.47 percent annual demand also occurs on Sunday growth rate. Customers have the option of signing up for interruptible as a result of load control ending irrigation service rates through their electric service provider. on that day. In these cases, a device is installed, free of charge, on the customer’s irrigation electrical service. This device is a switch that can be controlled through a radio signal by the utility. The customers have the option to buy or lease a pager that informs them about the event start and stop times.

22 Approximately 87 percent of amount of time they are willing to of businesses and industries, the total irrigation load served let their load be controlled during such as steel manufacturing. by NPPD and its wholesale peak billing hours. This program pays customers a customers is enrolled in a load market price per megawatt-hour management program. for voluntary load curtailment during peak periods. Customers If an event is called, it will be on Energy Curtailment may also participate in ECP preassigned control days, with Program (ECP) by volunteering to run local the exception of an emergency In addition to Billable Demand, generation, as long as they situation. The majority of NPPD’s NPPD offers customers another are not in a capacity purchase DR is in rural areas through load management and cost agreement with NPPD. irrigation control. savings program called ECP. The savings the end-use While Billable Demand focuses customers get is based on the mainly on irrigation control, ECP focuses on a wider range

NPPD CUSTOMERS HAVE A RANGE OF COST-SAVINGS OPTIONS, DEPENDING ON THE TYPE OF PROGRAM IN WHICH THEY ARE ENROLLED.

23 SINCE 2008, NPPD HAS PARTNERED WITH THEIR CUSTOMERS AND DEVELOPED ENERGYWISE - A SERIES OF ENERGY EFFICIENCY AND DEMAND- SIDE MANAGEMENT OPTIONS.

EV charging stations Industrial demand management $200 one-time incentive towards a analysis ChargePoint 32 amp Wi-Fi enabled residential This includes a walk through of facilities to vehicle charging station. Wi-Fi will be used identify demand-management opportunities initially to collect data that will help toward and provide recommendations.The analysis future infrastructure control such as DR. helps estimate cost savings from shifting to the demand-reduction strategy.

24 NPPD is Looking Forward to More Vehicle WHAT’S Electrification In addition to the three hybrid vehicles in its fleet, which NEXT have saved over $10,000 in fuel costs and offset over 425 kilograms of carbon dioxide, NPPD has been testing a for NPPD? Chevy Volt. The Volt is a PEV (plug-in electric vehicle). As a transportation fuel, electricity costs about 75 cents per gallon equivalent. NPPD anticipates an uptick in electric vehicles and has installed three charging stations in its Norfolk Operations Center as well as stations in its Columbus, Nebraska headquarters. NPPD sees the possibility of DR programs through electric vehicle charging, once the popularity of the vehicles increases.

Carbon Reduction NPPD is working hard to reduce carbon emissions and has set a goal of creating 10 percent new renewable energy by 2020. As part of NPPD’s environmental efforts, it is converting the Sheldon Coal Station to hydrogen. SHELDON HYDROGEN GENERATION PLANT- CONVERTED FROM COAL

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BALTIMORE GAS AND ELECTRIC

Baltimore Gas & Electric (BGE) has been in business for over 200 years and is the largest natural gas and electric utility in Maryland. BGE is a subsidiary of Exelon, one of the largest energy suppliers in the U.S.

AC Program HEADQUARTERS PeakRewards = DR Baltimore, Maryland Through the PeakRewards ƒƒ325,000 customers program launched in 2008, BGE FAST FACTS ƒƒ400,000 devices offers options for customers to ƒƒ1.25+ million electric customers take part in DR. This program has ƒƒ240 MW of controllable load produced more than 500 MW of ƒƒ650,000+ natural gas customers peak load control capacity. Hot Water Heater Program ƒƒ2,300 square mile service area Strong Customer Base ƒƒ22,000 customers ƒƒ3,200 employees Enrollment in the DR programs ƒƒ23,000 devices has been very strong since the PEAK DEMAND program launch in 2008. ƒƒ6 MW of controllable load ƒƒ4,800 MW

DR PORTFOLIO ƒƒResidential Air Conditioning and Water BGE PEAKREWARDS TIMELINE Heaters

26 PEAKREWARDS RESIDENTIAL PROGRAMS

Air Conditioning CUSTOMER UP TO 50% UP TO 75% UP TO 100% Air Conditioning is the largest PARTICIPATION DEVICE DEVICE DEVICE DR program with approximately LEVEL OPTIONS CYCLING CYCLING CYCLING Annual 325,000 enrolled participants. Annual bill Incentives by Smart thermostats and load- credit per $50 $75 $100 Participation control switches are the backbone device Type of the air-conditioning program One-time (customers choose between the enrollment $50 $75 $100 two.) There are about 400,000 of incentive these units deployed. Incentives paid June through September Air conditioning control targets summer peak demand which typically occurs between 1 and 7 p.m. Monthly Bill Credit or Monthly $6.25-$12.50 Credit plus Bonus Electric Water Heaters Annual Bill Credit $25 Electric Water Heaters are an One-time Enrollment Bill Credit $25 additional DR program within BGE. The Electric Water Heater control Incentives are paid November through February program, although dwarfed by the AC program, is large and impactful with 22,000 enrolled participants Water heaters are only cycled and 23,000 installed units. during a PJM emergency, not for an The water heater control program targets summer as well as winter economic (BGE) event peak demand which typically occurs weekdays from 6-9 a.m. and 6-9 p.m.

CUSTOMER ANNUAL BILL PeakRewards SUMMER (RESIDENT) CREDIT PER FIRST YEAR MONTHLY BILL Multifamily Technology PARTICIPATION DEVICE-FIRST TOTAL CREDITS PeakRewards Multifamily is LEVEL OPTIONS YEAR BONUS an opportunity for multi-tenant Up to 50 percent property owners and the residents $12.50 $12.50 $100 in those buildings to benefit from device cycling DR programs and cost savings. Similar to other residential Up to 100 percent $18.75 $18.75 $150 programs, participation in this device cycling program has no out-of-pocket fees for participants. Landlords get the choice between a smart Up to 100 percent $25 $25 $200 thermostat or a switch that controls device cycling air conditioner cycling, installed directly to the air-conditioning unit. Landlords and residents also get the benefit of old mercury thermostat recycling, a welcome marketing kit and uninstallation should the participants choose to 27 disengage with the program. PeakRewards Trade Ally PROGRAM COMPONENT INCENTIVE This unique program brings in eligible HVAC contractors who help maintain connected Notification of device found removed or disconnected $10 program devices, identify and remove disconnected devices and potentially participate in training to Notification of system upgrade thermostat need $10 install new air-conditioning switches.

Participating trade ally contractors Removing or disconnecting PeakRewards device, based $10 receive incentives for referring new on non-participation or opt-out from customer customers, removing unwanted or unused devices or reconnecting a Re-installing PeakRewards device on newly installed switch. $50 HVAC equipment Contractors must apply to take part in the trade ally program, ensuring customers are provided a qualified Referral resulting in new PeakRewards customer $25 and trained service team. AMI BGE began deployment of Advanced Metering Infrastructure (AMI) in their territory in 2012. These smart meters are now standard. Although customers may opt out of using smart-meters, they need to fill out a request for the opt-out process. BGE uses smart meters to give customers time-of-use rebates during periods called Energy Savings Days. BGE informs customers which days they should conserve energy and then uses the smart-meter data to inform the customer of the rebates they earned during these periods, along with the amount of energy and money they saved.

Smart Grid BGE sees smart grid technologies as the future of energy reliability and technology advancement. WHAT’S Smart grid technologies will allow for improved energy delivery and smoother transitions between traditional NEXT energy sources and renewable energy sources. BGE for BGE? continues to invest in tools that will help grow the capabilities of its smart grid.

28 BPA Distributed Energy Resources Benchmarking Report

GREAT RIVER ENERGY

Great River Energy is a non-profit generation and transmission cooperative with 28 members who collectively own GRE and its services. HEADQUARTERS GRE and its co-op members Maple Grove, Minnesota DER at Great River have tools to help customers Great River Energy uses DR visualize and understand what FAST FACTS as a strategy to avoid building their usage looks like on a daily additional power plants and ƒƒSecond largest electric power basis, including individual home provider in Minnesota purchasing supplemental energy monitoring and system-wide from the wholesale market. This energy load graphics. These tools ƒƒServes 695,000 customers strategy also helps members pay not only show customers the less for energy during the peak current status of the system, they ƒƒOne of the largest generation and demand and peak pricing times also help guide energy reduction transmission co-ops in the U.S. of day. Customers are able to during critical periods. sign up for a wide range of DER DER PORTFOLIO options and may opt out at any time. ƒƒIrrigation DR ƒƒResidential AC & Water Heating DR The Load Management page on the GRE website shows ƒƒElectric Thermal Storage (ETS) customers the current demand. As levels reach elevated, peak or critical, the website offers suggestions on how customers can ƒƒETS Space Heating reduce their electricity usage and what times of day are best to ƒƒDuel Fuel System do so. ƒƒCommercial and Industrial DR ƒƒElectric Vehicles

29 Residential DER Programs at GRE

capabilities of the system. Air Conditioning ETS Water Heating Although there are many types Air conditioning control is available Electric thermal storage (ETS) of ETS heating systems, the to customers with either central AC water heating is a larger, most common are water and or hard-wired room units that are more extended version of the ceramic. ETS systems can also able to be connected to a load- interruptible water heating offering. be embedded in a building’s control device. The cycling strategy The system must have the foundation slab. also is applicable to air source heat capacity to supply hot water to the pumps. During the DR event, the user for an extended period without air conditioner is cycled on and power and must have the ability to Dual Fuel off to enable a partial diversified be connected to an interruptible Dual-fuel systems combine demand reduction. With the typical control switch. The device must conventional electric heating with program, GRE may interrupt AC have the ability to recharge the backup sources from oil, gas, liquid loads for up to six hours per day system over the nighttime hours of propane or even wood. While for a total of 200 hours between 11 p.m. to 7 a.m., in increments allowed, the use of wood is not May and September (the cooling (or continuously.) To qualify for encouraged by GRE, because the season). GRE may also extend the participation, customers must system requires manual operation. typical DR period due to extreme have a minimum required 80 gallon To qualify, the secondary system or emergency conditions. storage capacity hot water tank. must have the ability to heat the entire home for several hours. With this program, GRE may interrupt Interruptible Water ETS Space Heating loads for up to 12 hours per day Heating ETS space heating systems and a total of 400 hours between Water heating systems often have is another component of the the months of September and May. the capacity to supply hot water for portfolio of offerings for DR an extended period of time when load management at GRE. To electricity is interrupted. participate, the customer’s ETS heating system must be capable Qualifying units must have the of providing 100 percent of the ability to connect a load control home’s heating needs through device that allows either four or thermal storage during the eight hours of service interruption recharge hours of 11 p.m. to 7 during any month. GRE a.m. A professional heat loss recommends units with a minimum analysis is required to assess storage capacity of 50 gallons. the proper size and discharge

30 Interruptible Irrigation This program is available for systems that can be connected to an approved load-control device. Participants may have electricity to the assigned devices curtailed for up to four hours per day during the May to September cooling season. Although GRE attempts to regulate the controlled periods, it may happen during any time of day that presents the demand-control need.

ChargeWise This program is available to residential customers who charge plug-in electric vehicles. To qualify, the customer must have a ChargeWise outlet installed and a meter that records energy used at the ChargeWise outlet. For participants, a load-control device is installed at the outlet that limits charging on certain days to the nighttime hours of 11 p.m. to 7 a.m. Commercial and Industrial Interruptible Metered Interruptible with Electric Vehicle Energy Load GenSet Storage For customers in this program, Along the same program This program is for owners of GRE controls all or part of their guidelines as the Interruptible commercial electric fleet vehicles electrical load for up to 300 hours Metered Load program, the including cars, golf carts, forklifts per calendar year. Customers Interruptible Load With GensSet and other electric vehicles. To have the option to receive an alert program has an option for a participate, the customer must 30 minutes in advance of a DR 30-minute advance alert and is have a dedicated circuit and event. There are two options with controllable for up to 300 hours separate meter for electric this program type: per calendar year. There are also vehicle(s) charging, along with two options with the GenSet an approved load-control device. 1. Fully interruptible load- the program: The device generally limits customer‘s load is curtailed charging to between the hours for up to six hours per DR 1. Full interruptible load with of 11 p.m. and 7 a.m. However, event. generator backup- the GRE may allow two hours of customer agrees to transfer 2. Partial interruptible load- additional recharge during their load fully to their own the customer reduces their midmorning or afternoon hours, generator backup for up to 10 load for up to six hours to a depending on control strategy hours per event. predetermined level. need. 2. Partial interruptible load with Generator Backup- the customer reduces their load for up to 10 hours per event at a predetermined level.

31 DER SCHEDULING AT GRE Great River Energy has one of the most expansive portfolios of DER programs in the industry. It also has one of the best customer-facing portals and set of tools for customers to use to manage their electricity use. To inform their customers of upcoming DR events, GRE posts a daily schedule showing the potential DR program event, occurrence likelihood and timing.

GREAT RIVER ENERGY CUSTOMER PORTAL

Load Management Schedule Wed Jan 23 15:14:41 CST 2019

Today Program Type Probability Expected Time

Residential Dual Fuel Unlikely Undetermined

Interruptible Water Residential Heating Unlikely Undetermined

Next Day Program Type Probability Expected Time

Residential Dual Fuel Likely Undetermined

Interruptible Water Residential Heating Likely Undetermined

GRE is focusing many efforts to provide clean energy and improve grid technologies. GRE is constantly updating and WHAT’S improving existing technologies such as smart meters and its energy management/demand management system. NEXT GRE is also piloting new technologies such as grid- interactive water heaters, battery-powered electric school for GRE? buses and a member and community solar initiative.

32 BPA Distributed Energy Resources Benchmarking Report

MINNESOTA VALLEY ELECTRIC CO-OP (GRE COOPERATIVE MEMBER)

Minnesota Valley Electric Cooperative (MVEC) is one of the leading cooperative members of Great River Energy group. Founded in 1937, MVEC began with a three-county service area and later expanded to the nine counties it serves today. HEADQUARTERS DER at MVEC Jordan, Minnesota MVEC operates multiple load control programs with 44% member FAST FACTS participation. Through these programs MVEC seeks to increase member satisfaction and monetize DR. ƒƒOne of GRE’s 28 distribution co-ops, 2nd largest in Minnesota ƒƒServes 45,000+ members and nine Air Conditioning Control counties ƒƒ968 square-mile service area INCENTIVE CONTROL DETAILS EVENT FREQUENCY ƒƒ90+ employees $50 bill credit after Four degree installation and 10 Five to seven times DER PORTFOLIO percent discount on adjustment, up to per month during kWh from June to four hours per event. summer ƒƒCycled Air Conditioning September (Two degree pre-cool) ƒƒResidential Heating ƒƒWater Heating

33 BEAT THE PEAK

For six years, MVEC held a summer energy saving contest. Over $120,000 in cash prizes was awarded to individuals and community groups. This unique and innovative Peak Load Management program was free to members served by MVEC. The voluntary program offered cash prizes through an interactive game format.

How it Works MVEC members are notified by their choice of email, text message or phone call. Messages are sent to participating members the day before and the day of a targeted event. MVEC also uses Twitter and Facebook to inform members and generate enthusiasm for the program and its benefits. Members choose how they want to reduce energy use during the event times called out by MVEC. The typical event timeframe is 5 to 9 p.m. and runs June- August.

PROGRAM RULES Individual Participation Team Participation • Residential members may participate individually • Teams must have at least five members. or as part of a team. • Each team must have a captain. • Rewards are based on full summer performance. • Teams may consist of commercial and residential members. PRIZES

INDIVIDUALS TEAMS 1st $500 Size 1st Place 2nd Place 3rd Place 2nd $250 5-10 $1,000 $500 $250 3rd $100 11-25 $2,500 $1,000 $500

Total awarded: $2,550 Over 25 $7,500 $3,000 $1,500 Total awarded: $17,750

34 Residential Heating Peak Shave Water Heat Commercial/Industrial Qualified electric heat from Electricity is interrupted over Generator Programs baseboards, fan-forced heaters, peak energy usage times for 4-8 Standby generators are connected in-floor heating, electric thermal hours. Residential members see a to radio receivers, which engage storage, plenum heaters, and heat substantial savings over propane the generator and disconnect the pumps are eligible for discount water heat. Because of the nature commercial service from the utility. electricity. Backup heat sources of this program, larger water heater Once the peak demand period is are required, since electric heat will capacities are recommended. over, the electric service is returned be interrupted during peak electric to normal. The business receives usage times. Members realize a the benefit of reduced energy substantial savings over propane costs, a backup emergency energy and other heat sources. source, and a quicker return on investment with the generator. WHAT’S Electric Vehicle Charging Programs MVEC gives you the choice to charge when it’s best for you NEXT EV-8 EV-24 for MVEC? traditional storage time of use program program

This rate offers members our low With this program you can charge off-peak electric rate for charging your vehicle whenever needed. an electric vehicle (EV). You will install a special meter on EV charging is available for eight your home to keep track of fluctu- hours a night and only during ating rate periods based on the off-peak hours of 11 p.m. - 7 a.m. time of day you charge your EV:

Power is not available outside of MVEC has two voluntary options Summer Rates (June-Sept): off-peak hours, and the charger for charging your EV at home. The • EV-Wise (Yellow) 6.9¢/kWh must be hardwired into your storage program offers a static, • EV-General (Green) 12.5¢/kWh circuit panel, if wired to its own but low price, while the time-of- • EV-Critical(Red) 39.7¢/kWh dedicated meter. No other outlet use program provides the most is allowed. flexibility. Rest of the Year Rates: EV-Wise (Yellow) 5.2¢/kWh All-Year Rate: 5.2¢/kWh • Additional outlets for your EV • EV-General (Green) 11.7¢/kWh that are not off-peak outlets are • EV-Critical(Red) 39.7¢/kWh prohibited when participating in either program. Charging EV-General 9 p.m. - 11 p.m EV-Wise available - Receive a $150 Rebate 11.7¢ 11 p.m. - 7 a.m. 11 p.m. - 7 a.m. rebate toward the installa- 5.2¢ tion of your EV charger . Charging when you sign up for either program. Avilable for each EV-Critical not available charger you enroll in either 3- 9 p.m. 7 a.m. - 11 p.m. EV-General program. 39.7¢ 7 a.m. - 3 p.m. 11.7¢ Find rebate form and further details at www.mvec.net/

residential/efficiency-rebates/ EV Wise rate includes weekends and the holidays of New Years Day, Memorial Day, Independence Day, Labor Day, Thanksgiving and Christmas Day.

Have questions? Talk to one of our energy specialists Michael Hinde 952.492.8292 | [email protected] Mike Orvick 952.492.8277 | [email protected] 35 BPA Distributed Energy Resources Benchmarking Report

WABASH VALLEY POWER

Wabash Valley Power is a non-profit generation and transmission electric cooperative, serving its 23 distribution co-op members.

Wabash Provides Power reduce supply and financial risk against a fluctuating market. As a co-op for co-ops, Wabash HEADQUARTERS In addition to the supply Valley Power provides power to Indianapolis, Indiana its member co-ops, who then resourcing strategy, WVPA uses load management through DR sell power on a retail basis to FAST FACTS management systems to keep homeowners, farms, businesses ƒƒSeventeenth largest generation and and schools. rates lower and as a response to the Midcontinent Independent transmission co-op in the U.S. By using a variety of electricity System Operator, or MISO, ƒƒServes customers in Indiana, Illinois fuel sources, WVPA is able to requirements. and Missouri WVPA supplies power to its members through a variety of sources. ƒƒProvides electric service to over 311,000 members

DER PORTFOLIO ƒƒIrrigation pump control ƒƒHVAC ƒƒHot Water Heaters

36 DER at WVPA Nineteen of the 23 co-op members within Wabash Valley Power Association participate in DER programs. MISO prescribes the capacity size for WVPA each year. The previous year one-hour peak sets the capacity for the following year. WVPA receives a capacity credit from MISO for DR actions and then passes the credits to its co- ops. As a response to MISO capacity requirements, WVPA uses DR programs and controls to: • Help customers lower their electricity bill • Avoid construction of new power plants through capacity provided by power supply alternatives • Respond to emergency needs for capacity WVPA offers many programs and incentives to its members for energy efficiency and DR. The overall program for both is called PowerMoves®. In this context, DR is called PowerShift®. Since 2010, PowerMoves® has awarded $5 million of incentives to its members. DR events at WVPA are triggered by price signals from MISO. WVPA has a DR committee, comprised of co-op members. To meet capacity and to maintain costs, this committee evaluates options of DR against market- based resources. AMI meters are used for data collection and verification for incentive payout.

POWERSHIFT® Under the heading of PowerShift®, WVPA partners with its members to offer their customers choices to save energy and lower their bills during peak demand times. Some examples of successful programs are:

Smart Thermostat Incentive Details

Thermostat paid by Wabash + $50 Customers must have approved rebate (for installation), $25 bill thermostat, Wi-Fi and central air credit at end of summer conditioning

Other Programs Item Entire Irrigation Water Pool Air Home Pump Heater Pump Conditioning Switch Control switch Control Switch Participants 2,000 1,000 14,000 20 6,517

37 Renewable Energy Growth Wabash Valley WHAT’S Power is a long-time leader in increasing renewable energy on the grid. With a wide variety of projects in NEXT place such as landfill gas generation, solar and wind, for Wabash Valley WVPA plans to continue to increase its renewable energy production. Power Association?

Solar WVPA has experienced success with its innovative community solar program, Co-Op Solar. This triggered the WVPA Board to increase the 1.7 MW program to 7 MW. Wabash has also entered into an agreement with a third party to develop three solar arrays that will produce 397 MW of clean solar energy. This project is expected to be in service by 2021 with installations in Illinois, Indiana and Missouri. Wind In 2019, WVPA will increase its wind portfolio to 139 MW, by adding a 75 MW system to its current 64 MW size. Then again in 2020, WVPA plans to increase the wind program to 218 MW total. DRMS WVPA has recently upgraded its distributed energy management system. For Wabash, this system offers an opportunity to continue to balance its load without developing new power stations and continue to increase the innovative use of renewable energy on the grid.

38 Acknowledgement and Disclaimer

This report was prepared as an account of work sponsored by an agency of the United States government. Neither the United States government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus, product, or process disclosed, or represents that its use would not infringe privately owned rights. Reference herein to any specific commercial product, process, or service by trade name, trademark, manufacturer, or otherwise does not necessarily constitute or imply its endorsement, recommendation, or favoring by the United States government or any agency thereof. The views and opinions of authors expressed herein do not necessarily state or reflect those of the United States government or any agency thereof.

www.bpa.gov

DOE/BP-4775 • 2018