1. Standby Generators & Demand Response What is Demand Response Why Demand Response Works PJM‘s DR Programs Financial Benefits Participation Requirements Emissions Regulations

2. Demand Response FERC & Electric Utility Support “Demand Response creates a more efficient grid and allows consumers to lower their bills. When you combine those two things together you’ve got a powerful engine that can start and maintain the smart grid”. –FERC Chairman, Jon Wellinghoff, 2010 SmartGrid Today. “Demand response and energy efficiency really have the highest potential to transform the way we consume electricity”. –Quote from Brett Perlman, former member of the Texas Public Utilities Commission, at the 2012 National Electricity Conference in Washington, DC. Page 2 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved

3. Demand Response Definitions Demand Response is the voluntary and temporary reduction of electricity usage in response to electrical power system stress or economic signals from retail rates. Reductions in electricity usage can be achieved by turning off building loads (lights, air conditioning, fans…) or by transferring building load to standby generators. Financial incentives exist across the US to encourage Demand Response participation which is needed to help lower peak demands. Page 3 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved

4. Page 4 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved NYISO 2011 Demand Peak Utilizing DR for Peak Management

5. Demand Response Demand Side Management DR provides electrical utilities and grid operators a tool to more efficiently balance electrical supply and demand. –Quickly reduces critical peak load demands. –Minimizes transmission congestion / constraints. Electricity demand continues to grow while supply side solutions are becoming increasingly limited due to: –High construction costs, –Environmental concerns, –Transmission capacity constraints. Traditional pricing structure also presents a challenge. –Most consumers pay a fixed price, while producers are paid based on a variable clearing price creating inelastic demand. Page 5 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved

6. Page 6 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved The Electricity Marketplace Price Determined by Load All resources are paid the clearing price. 0 50 100 150 200 250 0102030405060708090100110120130140150160170180 $/MWh GWs Supply Resources Hydro, Nuclear Coal Gas CC Peakers

7. Page 7 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved The Electricity Marketplace Inelastic Demand Curve

8. Page 8 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved PJM Demand Response Programs Operational Time Requirements Time of DayResponse TimeDurationFrequency Total Hours / Year Capacity (DR) ~ 2 - 6pm ½ - 3 Hours2 – 6 Hours 1 – 10 Times / Year 2 – 40 Hours Ancillary / Synch Reserves Anytime 24 / 7 10 Minutes 10 Minutes – 1 Hour 2 – 3 Times / Month 12 – 20 Hours Economic / Price Voluntary Day-Ahead or Day-Of Voluntary 10 to 40 Hours Peak~ 2 – 6pm1 – 2 Hours 10 – 15 Times / Year 10 – 20 Hours

9. Page 9 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved CAISO $48,000 - $62,000 PJM $6,000 - $62,000 Ontario $70,000 - $160,000 ISONE $60,000 NYISO ROS $24,000 NYC (Zone J) $60,000 - $150,000 2012 ISO Payments: $ per MW-yr (Typical DR Aggregator Take ~25%). ERCOT EILS - $60,000 LaaR - $90,000 Demand Response Programs Capacity Revenue Opportunity Duke/PE & SCG&E $30,000 - $42,000

10. Page 10 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved Demand Response Programs PJM Synch Reserve Revenue Synch payments in Eastern PJM ~$50,000 / MWyr.

11. Page 11 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved Economic demand response – load reduction performed when energy market price is higher than cost of generation. Simple run analysis based on the spread between local energy prices and operational (fuel) costs. – When energy price > fuel cost, run and keep the spread. – When energy price < fuel cost, don’t run. FERC Order 745 requires RTOs to pay demand resources the full LMP for load reductions. –Order 745 lowers run costs by up to 50% Economic DR revenue potential with Order 745 ranges between $5,000 and $25,000 / MW-year. Demand Response Programs Economic

12. Page 12 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved Demand Response Programs Economic Opportunity: Avg cents/kWh

13. Page 13 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved Understand your air permit. If you don’t have an air permit, you’ll need to get one. Standby generator air permits vary considerably by state and by application. Commonly categorized as: –Emergency – only operated during loss of utility power and during system operational testing events. –Non-emergency – Anything other than emergency, typically limited by annual allowable operating hours. Air permitting requirements: –Federal: RICE NESHAP, NSPS, Tier 4, Tier 2… –State Requirements – always trump Fed, most often more stringent Customer’s can only market their curtailable load. Demand Response Participation Using Standby Generators

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15. Page 15 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved DEMAND RESPONSE PARTICIPATION REQUIREMENTS Definition of Emergency: Emergency – when power is unavailable due to failure/loss of utility power beyond reasonable control of facility; not including storm avoidance. Federal Definitions – vary by regulation. Subpart IIII – strictly emergency operation. Subpart JJJJ & ZZZZ – allows for 50 hours per year for non-emergency operations (testing), but no peak shaving; allows for 15 hours per year for emergency DR participation. Definitions vary by state. DC, PA, NJ and DE – strictly for emergency, maintenance and testing; after- treatment required for emergency demand response and any other DR. MD and VA – Allow operation in emergency demand response; anything else requires after-treatment.

16. Page 16 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved EPA Statement regarding emergency generators: “Engine cannot be used for peak shaving or as part of financial arrangement with another entity, except 15 of the 50 non- emergency hours / year can be used for demand response in emergency situations (e.g., imminent blackout)” EPA / DR aggregator case pending which may increase emergency exception hours to 60 per year. States still have jurisdiction over whether or not they allow emergency generator to participate in any Demand Response program. New Jersey – does not allow customers with emergency generators to participate in any PJM Demand Response program. Demand Response Participation Emergency Permitted Generators

17. Page 17 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved Proven emissions after-treatment technology to meet state specific emissions requirements. Complete system monitoring. Closed transition load transfer capabilities allow for easier and safer DR participation with automated record keeping. Multi-year maintenance and warranty contracts minimize owning and operating risk. Emissions compliance testing and air permitting assistance provided when needed. Financing packages and lease to own options. New Generator Set Purchase Considerations DR Ready Packages

18. Standby Generation More Than Just Emergency Power A valuable revenue stream from otherwise dormant standby power generation equipment. Simple system requirements necessary for participation. Improved data analytics with remote monitoring, smart metering and web-based reporting. Proactive emergency preparation with advanced notice of grid stress. Corporate social responsibility and public recognition; helps “keep the lights on” and the grid more efficient and operational for everyone. Page 18 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved

19. Page 19 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved Electrical utility and Federal programs demonstrate the need for increased demand side management. Distributed generation will continue to be an integral part of lowering peak demands. A good energy management strategy can improve the bottom line of a company and the broader community. MTU Onsite Energy Energy Management Initiative

20. Page 20 / MTU Onsite Energy / 9/15/2015 © MTU Onsite Energy GmbH / All rights reserved Demand Response: Maximizing value from standby generation.