AEP Ohio. Combined Heat and Power (CHP) May 24 th, 2017 Steve Giles Vice President Alternative Energy Hull & Associates, Inc.

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1 AEP Ohio Combined Heat and Power (CHP) May 24 th, 2017 Steve Giles Vice President Alternative Energy Hull & Associates, Inc.

2 OUR MARKET AREAS Shale Oil & Gas Waste Management PROJECT DEVELOPMENT AND ASSET MANAGEMENT Brownfields Environmental Alternative Energy

3 Hull Alternative Energy Hull is one of the most diversified alternative energy developers in Ohio and has developed: 3 solar energy facilities 1 landfill-gas-to energy project 1 combined heat and power project Hull has also provided consulting services on several solar, wind and waste-toenergy projects in Ohio. operation

4 Combined Heat and Power Definitions CHP is the simultaneous production and use of power and heat from the same fuel source CHP = Cogeneration Island Mode - Island mode operation relates to CHP unit that can operate in isolation from the local electricity distribution network. operation

5 Combined Heat and Power Definitions CHP differs from waste heat recovery. In WHR, the waste heat is the fuel source to produce incremental power through a steam turbine or an Organic Rankine Cycle engine In Ohio, waste heat recovery systems are eligible technologies for renewable energy credits; CHP is not (with two exceptions)

6 CHP - Developing a Business Case CHP projects are just like any other projects; cost savings is the number one driver. Generating your own electricity and thermal energy can also provide a hedge against rising prices. CHP is very efficient and can contribute to sustainability initiatives and reduces greenhouse gas emission. The primary risk of CHP projects are: Operating risk, will the system perform as forecasted? Operating risk can be mitigated by using third-party financing structures and vendor maintenance agreements. Fuel risk, what if natural gas prices rise? Fuel risk can be mitigated by effective hedging strategies. 6

7 CHP - Key Regulatory Considerations Does CHP qualify for electric net metering? In Ohio net metering is driven by technology, not application. Microturbines qualify for net metering but reciprocating engines do not. Does the electric utility charge stand-by charges? Stand-by charges are charges by a utility to reserve capacity in case your self-generation project has an outage and they need to provide the capacity. There is a monthly charge whether you need the capacity or not. AEP Monthly Charges for Standby Service The customer shall contract for capacity sufficient to meet maximum requirements under the applicable General Service Schedule. All characteristics of service, including pricing, shall be governed by the General Service Schedule. Monthly charges computed for standby service shall be adjusted in accordance with the Commission-approved riders on Sheet No applicable to the General Service Schedule, including, but not limited to, the Generation Energy and Generation Capacity Riders. 7

8 CHP - Key Regulatory Considerations Understand your electric tariff and the demand component of your bill. Monthly Billing Demand Energy supplied hereunder will be delivered through not more than 1 singlephase or 1 polyphase meter. Billing demand in KW shall be taken each month as the single highest 30- minute integrated peak in KW as registered during the month by a 30-minute integrating demand meter or indicator, or at the Company's option, as the highest registration of a thermal-type demand meter. For accounts over 100 KW, monthly billing demand established hereunder shall not be less than 60% of the greater of (a) the customer's contract capacity in excess of 100 KW, or (b) the customer's highest previously established monthly billing demand during the past 11 months in excess of 100 KW. In no event shall the monthly billing demand be less than (a) the minimum billing demand, if any, specified in the service contract, or (b) 5 KW for any account. Per KW AEP GS 3 Rate KW 60% over 100KW $ 4.72 Contract Annual Peak Current Month Reading 500 $ 2, Amount Billed 540 $ 2, Excess over Actual $ Post 250 KW CHP installation Annual Peak 650 Current Month 250 $ 1, Amount Billed 540 $ 2, Excess over Actual $ 1,

9 CHP - How to make the economics work To maximize economic returns, energy projects must run at full load for as many hours during the year as possible. For CHP, this means fully utilizing both the electric and thermal energy outputs of the CHP system. It is essential to build electric and thermal energy (natural gas consumption) load profiles. Profiles must reflect minimum requirements, as well as peak demands, and take into consideration daily and seasonal volatility. The thermal energy profile should only be for facility equipment that will be offset by the CHP system and their operating efficiencies need to be accounted for to properly reflect natural gas consumption. Ideally you should create an hourly profile for a 12 month period. Very rarely does a CHP systems output match both the thermal and electric load profiles, therefore system sizing is critical. The CHP system needs to operate so that both the electric and thermal energy generated is being consumed at the facility. 9

10 CHP - How to make the economics work Are there capital offsets? E.g. boiler replacement What are the key construction issues impacting capital costs; Is there space inside the facility, if not a container will need to be purchased. What are the distances to the thermal and electric interconnection points. Is noise level a concern? Is there a value to being able to operate in island mode? Are there any utility rebates? AEP has an incentive program offering $0.035 to $0.05 per kwh for net generation of the first 12 months of operation. Are there any federal tax credits? The 10% Federal ITC for eligible systems has expired. Are there any state or local incentives? The Ohio CHP coalition has proposed legislation to provide a 20% state tax credit. 10

11 Dublin CHP Installed in noise-reducing enclosure to minimize sound to visitors 11

12 CHP Basic Economics Before CHP Natural Gas MMBTU 19,600 $ 4.24 $ 83, Electric kwh 3,861,000 $ 0.08 $ 308, Total Energy Costs $ 391, Less: 250 KWH Output Natural Gas MMBTU 10,620 $ 4.24 $ 45, Electric, net kwh 1,971,000 $ 0.08 $ 157, Total Energy Costs $ 202, Gross Savings $ 189, CHP Fuel MMBTU 20,300 $ 4.24 $ 86, O & M $0.018 per kwh $ 35, Net Savings $ 67, Simple Payback System Installed Costs w/o Incentive $ 500, Payback - Years 7.38 AEP Incentive $ 0.05 kwh $ 98, Net Investment $ 401, Payback - Years

13 Value Creation For Dublin Immediate cost savings Eliminates need for a boiler replacement, saving nearly $50,000 CHP system installed at no cost to the City Protection against rising energy costs Long-term lease agreement provides price stability for 15 years. Projected to save DCRC over $630,000 in utility bills over 15 years Emergency Power System provides backup power during grid outage saving $150,000 versus installing a similar sized backup generator Green energy solution Aligns with City s vision for the future: It s Greener in Dublin Annual CO 2 Savings: 187 cars taken off the road 900 tons of CO 2 removed 13

14 Project Financing The DCRC entered into a 15-year CHP Energy Sales Agreement DCRC purchases all of the electricity and thermal energy generated by the CHP system. It is invoiced monthly from the CHP owner. The system is owned by a separate entity, which is responsible for all O&M of the system. The first 5 years of the contract have a fixed rate, then rates escalate 3% annually until the end of the 15-year term. At the end of the initial term the DCRC will have the options to: Purchase the system Extend the contract Request equipment to be removed at owner s expense. 14

15 248 KW MTU Onsite CHP Unit 15

16 248 KW MTU Onsite CHP Unit 16

17 248 KW MTU Onsite CHP Unit 17

18 248 KW MTU Onsite CHP Unit 18

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