BPA Demand Response Program Agenda Introductions Demand Response - - PowerPoint PPT Presentation

BPA Demand Response Program

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Agenda

• Introductions
• Demand Response
• Program details
• Program update
• Program benefits
• EnerNOC experience

Proprietary & Confidential

Demand Response

Proprietary & Confidential

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Meeting demand in the peak hours each year requires excess supply. Facilities that can occasionally lower demand reduce the need for supply side resources, and are paid for the service.

Demand Response for a Stronger, Cleaner, and More Cost Effective Grid

Winter Spring Summer Fall

90% 50% 75% 25% 100%

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Typical dispatch

BPA anticipates need for demand- side resources and dispatches EnerNOC Dispatch signal relayed to facilities and personnel also notified by phone, email, and/or SMS Automated customers have the

• pportunity to opt out during the

notification period, if needed Manual and automated load control strategies are initiated, either by customer or by NOC. Load reduction is delivered to the grid at precisely the time it is needed Customer receives payment for demand reduction

Customer Real-Time Load Profile

Notify Respond Restore

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Real-Time Visibility with Energy Monitoring Software

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Customer view of event performance

Baseline: Estimate of site's anticipated demand that is calculated according to program rules. Current Demand: Represents current demand base on 5-minute interval data. Reduction Target Area: The green area represents the target reduction, or where a provider’s current demand should be during the dispatch. Dispatch Window: The white area between the gray areas represents the time period of the dispatch. Proprietary & Confidential

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Customer enablement workflow

EnerNOC’s implementation process is designed to be fast, cost-effective and scalable with an emphasis on customer satisfaction and support.

Qualification Visit Energy Reduction Plan Installation Acceptance Test Ready to Respond

12-20 weeks

EnerNOC Site Server (ESS)

• Customer

consultation to assess energy reduction ability and installation requirements

• Schedule and install

Current Transducers

• r Serving Utility

installs pulse outputs

• Design automated

energy reduction sequence

• Contractor installs

EnerNOC Site Server (ESS)

• Control systems

integration and programming

• Verify contact info

for 3+ site contacts

• Run “Demand

Reduction Test” (simulated dispatch)

• Enablement

complete: customer is now on call and “Ready to Respond”

Proprietary & Confidential

Program Details

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Winter Peak Management

Season December 1 – April 30 Eligible Customers

• All C&I customers in BPA balancing area (57 utilities)
• No behind-the-meter fossil fuel generation

Target Capacity 13-25MW Program Hours 7am – 10am; 5pm – 8pm PT Response Time 60 minute advance notification Event Duration / Limitations 1-3 hour events; 2 events per day; 6 hours between events; 60 hours per season Customer Payments Capacity payment: $5,000/MW month winter + Event payment: $125 MW/hr ($225 MW/hr above 20 hours) Payments made directly to customer Metering 1 Minute Interval Metering Provided to all participants

Program parameters

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How Payments Work

Explaining Payments to Our Customers:

• Earnings Potential: $36.5k/MW each winter season and $73k for both winter seasons
• Depending on how many events are called and how consistently you deliver
• Capacity payments are based on average performance in each event hour over a month
• Payment rates are $5,000/MW-month in the winter (Dec – Apr)
• Customers must deliver at least 70% of their nomination, otherwise performance for that hour will be 0
• Customers may receive credit for up to 120% of performance for a given hour
• Energy payments are based on performance in each event hour
• Payments are capped at 120% of a customer’s nomination
• Payments are earned even if a customer fails to reach 70% of his/her nomination
• Payment rates are $125/MW-hr for the first 20 hours of participation and $225/MW-hr for subsequent

hours in a period

Customers in the BPA Demand Response Program earn both energy and capacity payments

Proprietary & Confidential

Program Update

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Demand Response – Winter Dispatches Portfolio Size : 21MW (25MW cap) Number of DR events in 2016 winter season : 21 events Total DR event dispatched hours : 55 hours Average event duration : 2.5 hours

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Program Benefits

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Benefits of Demand Response Demand Response

Increase Sustainability Earn Payments Strengthen the Grid Increase Visibility into Energy Use

EnerNOC Overview and Experience

Proprietary & Confidential

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About EnerNOC

Proven Customer Track Record

• Thousands of enterprise

customers across nearly 80,000 sites

• Over $1B in customer savings

delivered to date

• Market leader in demand

response

To learn more, visit http://www.enernoc.com

Strong Financial Profile

• 2014 Revenues: $472M
• 2014 Adjusted EBITDA: $76M
• $143M in cash/cash equivalents on

balance sheet

• Publicly traded on the NASDAQ)

(ENOC)

• Over 1,300 employees and growing

fast; multiple “top places to work” awards

Full Value and Technology Offering

• Energy intelligence software = ~$5B

market in U.S. alone

• Energy intelligence application

platform addresses demand and supply-side, connects energy usage to currency

• Combines technology, managed

services, and market access

• ~$200M invested to date in

technology

Updated 8.2015

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Global demand response footprint

EnerNOC Demand Response EnerNOC Office

North America Australia and New Zealand Japan UK, Ireland, Germany

Proprietary & Confidential

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Regional experience in the Western US

EnerNOC works with C&I customers in utility DR and EE programs across the West, including significant experience with demand response in the Northwest

Demand Response

• Bonneville Power – C&I DR pilots (including City of Forest Grove,

Consumers Power, Utility, EWEB, Richland Energy Services)

• Idaho Power – 300 MW irrigation DR; 35 MW C&I DR
• PacifiCorp – 185 MW irrigation DR
• PG&E – 120 MW C&I DR
• Portland General Electric – 25 MW C&I DR
• Public Service Company of New Mexico– 30 MW C&I DR
• Puget Sound Energy – C&I DR pilot
• San Diego Gas & Electric – 25 MW C&I DR
• Southern California Edison – 125 MW C&I DR
• Salt River Project – 50 MW C&I DR
• Tucson Electric Power – 40 MW C&I DR
• Xcel Energy (Colorado) – 44 MW C&I DR

Energy Efficiency

• Energy Trust –Technical Service Provider on EE Projects
• NEEA – Montana SEM Cohorts
• PacifiCorp – EE Engineering Services
• PG&E – Industrial EE Programs
• Southern California Edison – Industrial EE Programs

Utility Program EnerNOC Office

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Proprietary & Confidential

Eric Bakken Business Development Manager eric.bakken@enernoc.com 503-314-8995