Automated Demand Response (ADR) Customer Update. August 29, 2013

Transcription

1 Automated Demand Response (ADR) Customer Update August 29, Today s Agenda Demand response (what, when, why, how) DR strategies (automated DR, enhanced automation) About PG&E s DR programs [Lunch break and exercise] Overview of PG&E s ADR program Getting started DR Automation Server (DRAS) connection, M&V test Wrap up 2 PGE ADR Customer Training Deck 1

2 Objectives After today s session, you should be able to: Describe the features of PG&E's Automated Demand Response (ADR) program Convey benefits of PG&E s Peak Day Pricing Discuss DR load shed strategies Apply ADR program protocols and procedures 3 Today s Presenters David Wylie, P.E., ASW Engineering Kitty Wang, Senior Project Manager, Energy Solutions 4 PGE ADR Customer Training Deck 2

3 Questions? Comments? Ask any time 5 WECC Transmission Grid 6 PGE ADR Customer Training Deck 3

4 What is Demand Response? 7 Characteristics of Demand Response Actions taken only when requested Involves temporary, uncommon activities Programs are voluntary Typically pays incentives 8 PGE ADR Customer Training Deck 4

5 When Demand Meets Supply 50,000 45,000 Megawatts 40,000 35,000 30,000 25, Hour Beginning Supply Demand Forecast Demand Revised Forecast With DR 9 The relationship between weather conditions, demand, and price of electricity Demand on a mild day Demand on a hot day Price of electricity Price on a mild day Price on a hot day Supply Demand for electricity 10 PGE ADR Customer Training Deck 5

6 Lights Keeping Out: the the Price Lights Reasonable: On: Price Demand Price After After Exceeds Additional Demand Supply Demand Response Response Demand Demand after after additional is greater demand than demand supply response = outage Price of electricity after demand response Price of electricity Price of electricity after additional demand response Supply Price of electricity on a mild day Demand for electricity 11 The Cost of Meeting the Peak 12 PGE ADR Customer Training Deck 6

7 Major Factors Affecting Supply Economy Demography Weather Demand Response Interruptibles Major Factors Affecting Supply Demand Target reserve margin Supply adequacy Supply Operating reserve margin Resource additions and retirements Local generation Generator outage Line outage Fuel availability Net import 13 Efficiency and Demand Energy Efficiency A reduction in kwh throughout the year 8,760 hours Daily Load Shift Actions taken to reduce or shift load during summer on-peak hours (kwh and kw) up to 900 hours during the summer Demand Response Reduce load (kw) when requested during unusual events Occasional, called by the utility; 12 to 60 hours 14 PGE ADR Customer Training Deck 7

8 Integrating EE and DR 15 Integrated Demand Side Management (IDSM) IDSM is identified in the CPUC Strategic Plan as an overarching strategy to promote customer-side energy management and achievement of zero net energy goals Can be: Energy efficiency (EE) Demand response (DR) Distributed generation (DG) 16 PGE ADR Customer Training Deck 8

9 Benefits of DR to Utility Companies Helps system reliability Frees up thousands of MW of power at critical times Promotes smart energy, smart grid Benefits of DR to Environment & Society Reduces use of fuels for generation Reduces power plant emissions; improves air quality Reduces greenhouse gases; less global warming PGE ADR Customer Training Deck 9

10 Benefits of DR to Businesses Reduce peak demand energy costs Lower operating costs increased property value Prepare businesses for dynamic pricing Promote a strong California economy Two Sources of Funds for DR DR load shedding participation revenue stream Technology Incentives (TI) funds help pay for hardware and software that enable ADR DR Programs Technology Incentives 20 PGE ADR Customer Training Deck 10

11 Check Your Understanding Think about the term demand response. It means responding to a utility company request to quickly reduce demand for electricity 21 Check Your Understanding Which of the following is a benefit of demand response programs? Helps ensure grid system reliability Earn financial incentives Help reduce the need for building new power plants All of the above 22 PGE ADR Customer Training Deck 11

12 Check Your Understanding How often does the utility company request that a business reduce load for demand response? On hot days Occasionally Hardly ever Once a week 23 Check Your Understanding In your own words, describe the difference between energy efficiency measures and demand response measures. 24 PGE ADR Customer Training Deck 12

13 2013 Operating Reserve Margins Operating Reserve Margin (%) 25% 20% 15% 10% 5% ISO, SP25, and NP26 Operating Reserve Margins (%) for Summer % 23.3% 21.1% 10.4% 6.2% 7.1% ISO SP26 NP26 3% firm load shedding 0% Normal Scenario Extreme Scenario 25 Summer 2013 Outlook 26 PGE ADR Customer Training Deck 13

14 Worst Case Scenario 27 Summer 2013 DR Programs 28 PGE ADR Customer Training Deck 14

15 2013 CA Generation Fuel Resources Renewables mix NDC = Net Dependable Capacity resources RPS = Renewables Portfolio Standard resources 29 Wind and Solar Power and Demand Response Wind and solar are intermittent and stability is more challenging When renewable resources are down, DR can serve as backup In 2012 California installed 1,656 MW of new wind-power capacity, for a total over 5,540 MW California can generate about 7% of its electricity from wind PGE ADR Customer Training Deck 15

16 DR Strategies Control Methods for Achieving DR Manual A person turns off selected equipment Semi-automated A person initiates a control strategy preprogrammed into the Energy Management System (EMS) Automated (ADR) The EMS initiates the control strategy No human intervention EMS receives a signal from PG&E s Demand Response server 32 PGE ADR Customer Training Deck 16

17 Who the Businesses Are the Big Picture People Buildings Process Facilities 33 Potential Demand Response Loads for People Buildings Cooling tower Air-handling units and ductwork Boiler Pumps Chiller 34 PGE ADR Customer Training Deck 17

18 The Top 10 List 1. Dim lights 2. Global Temperature Adjustment (GTA) 3. Limit chiller 4. Reconfigure chillers 5. Cycle package units 6. Reset static pressure 7. Elevators off 8. Fan VFD speed reduction 9. Pre-cool facility 10. Curtail machinery Lighting Strategies EMS Dim some lighting Turn off 1/4 or 1/3 of the lights Dim or shut off perimeter lighting Lighting Room by room notification Locations Private offices Hallways and corridors Lobby Central plant Mechanical rooms Lighting circuits Loading docks Elevator lobbies Bullpens 36 PGE ADR Customer Training Deck 18

19 Office Building HVAC Strategies Air Conditioning Strategies Package Units Cycle package units [Package unit kw] Global temperature adjustment (GTA) [Package unit kw] Central Plant Type of Air System CAV AHU VAV AHU Chiller Global temperature adjustment (GTA) [Chiller kw] Cycle fans [Fan kw + chiller] Reset leaving air temperature (relax humidity control) [Chiller kw] Global temperature adjustment (GTA) [Fan kw + chiller] Limit fan pressure or speed [Fan kw + chiller] Chiller lineup [Chiller kw] Limit speed if VFD is on the chiller [Chiller kw] Limit amps if inlet guide vanes (IGV) are on the chiller [Chiller kw] Where the kw reduction occurs [ in brackets ] 37 Other Machinery Vertical transportation Elevators Escalators Misc. Motors and other loads Manual EMS Pumps Fountains Swimming pools Spas Domestic hot water Fans General exhaust Elevator room Garage exhaust Misc. Machinery Vending machines Laundry room Drinking fountains 38 PGE ADR Customer Training Deck 19

20 DR Strategies: Office Buildings 39 DR Strategies: Hotels and Motels 40 PGE ADR Customer Training Deck 20

21 DR Strategies: Hospitals and Medical Office Buildings 41 DR Strategies: Retail Industry 42 PGE ADR Customer Training Deck 21

22 DR Strategies: Grocery Stores and Supermarkets 43 DR Strategies: Schools 44 PGE ADR Customer Training Deck 22

23 DR Strategies: Manufacturing & Process Facilities 45 DR Strategies: Injection Molding 46 PGE ADR Customer Training Deck 23

24 DR Strategies: Cold Storage & Food Processing 47 DR Strategies: Agricultural & Muni Water Pumping 48 PGE ADR Customer Training Deck 24

25 Focus on Automated Demand Response (ADR) Manual A person turns off selected equipment Semi-automated A person initiates a control strategy preprogrammed into the Energy Management System (EMS) Automated (ADR) The EMS initiates the control strategy No human intervention EMS receives a signal from PG&E s Demand Response server 49 How Does ADR Work? Grid Operator Utility Co. DR Automation Server Communication Pathway or Internet Gateway Business EMS HVAC Lighting Machines ADR enables demand response strategies automatically, without the need for human intervention. 50 PGE ADR Customer Training Deck 25

26 Enhanced Automation Monitoring Weather forecast Dynamic energy/ demand prices Meter information Demand response communication Lighting Occupancy levels HVAC Lighting levels HVAC CO2 Air/water temperature Air/water flow Thermostat setpoints Enhanced Automation EIS EMS Energy Information Systems and Energy Management Systems Controls Lighting Dimmable ballasts Bi-level lighting HVAC Lighting VSDs Ventilation HVAC Thermostat reset Other Chilled water temp. Other Demand limiting Thermal storage Demand response 51 Benefits of Auto-DR Efficiency: Smart, strategic management of energy use helps maximize savings Flexibility: Customers set and always control their own level of Auto-DR participation Ease: Auto-DR makes reducing energy usage automatic PGE ADR Customer Training Deck 26

27 Calculating Load Reductions Calculating Load Reduction What is the DR strategy? What are we calculating? What data? What formulas? 54 PGE ADR Customer Training Deck 27

28 The Nature of Baselines Estimate building load on non-dr days Used to calculate load reduction One baseline methodology does not fit all Baselines are important for: Settlement Resource planning Cost-effectiveness evaluation 55 Important Baselines Customer Specific Summer Baseline (CSSB) Customer Specific Energy Baseline (CSEB) (10-Day Baseline) Day-of Adjustments (calibration) Calibrates the 10-day to the test day 56 PGE ADR Customer Training Deck 28

29 CSSB Example Data Table A: Summer Monthly Average Daily Maximum Demand Month HE 1:00 p.m. HE 2:00 p.m. HE 3:00 p.m. HE 4:00 p.m. HE 5:00 p.m. HE 6:00 p.m. June July August September AVERAGE Example of CSEB Using 10-Day Baseline Methodology Assumes customer agrees to curtail 500 kw per hour from noon - 8:00 p.m. on Friday, August 19 Date Day of Week Day No. Calculation of the 10-day rolling average. HE 1:00 pm HE 2:00 pm HE 3:00 pm HE 4:00 pm HE 5:00 pm HE 6:00 pm HE 7:00 pm HE 8:00 pm Total 8/3 Wed Day 1 1,500 1,300 1,200 1, ,550 8/4 Thur Day 2 1,600 1,400 1, ,700 8/5 Fri Day 3 1,800 1,500 1,100 1, ,200 1,200 1,200 10,300 8/8 Mon Day 4 1,700 1,600 1,200 1, ,520 1,520 1,520 10,910 8/9 Tue Interruption N/A N/A N/A N/A N/A N/A N/A N/A 0 8/10 Wed Day 5 1,300 1,750 1,300 1, ,450 1,450 1,450 10,825 8/11 Thur Day 6 1,400 1,350 1,400 1,500 1,650 1,600 1,600 1,600 12,100 8/12 Fri Interruption N/A N/A N/A N/A N/A N/A N/A N/A 0 8/15 Mon Day 7 1,300 1,150 1,600 1,600 1,800 1,800 1,800 1,800 12,850 8/16 Tue Day 8 1,400 1,200 1,750 1,700 2,000 1,200 1,200 1,200 11,650 8/17 Wed Day 9 1,600 1,500 1,900 1, ,850 1,850 1,850 13,150 8/18 Thur Day 10 1,800 1,600 1,100 1, ,800 1,800 1,800 12,550 Total 15,400 14,350 13,550 14,750 10,675 13,620 13,620 13, day average 1,540 1,435 1,355 1,475 1,068 1,362 1,362 1,362 HE = Hour Ending 58 PGE ADR Customer Training Deck 29

30 10-Day Baseline with Day-of Adjustment 10-Day Baseline 10-Day Baseline Adjusted 59 Calculating Load Reduction Involves: Identifying feasible measures for DR Establishing an energy-use baseline for each DR measure Calculating the potential load reduction based on accepted engineering analysis 60 PGE ADR Customer Training Deck 30

31 Estimate of Demand Reduction When suggesting DR measures, they must adhere to all statutes, regulations, and standards (OSHA, EPA, etc.) Safety first! Consider health, comfort, productivity Use common sense, and be pragmatic! Needs to be sustainable for the facility 61 Check Your Understanding Name some of the most popular DR strategies for lighting Dim some lighting Turn off 1/4 or 1/3 of the lights Dim or shut off perimeter lighting 62 PGE ADR Customer Training Deck 31

32 Check Your Understanding Name some of the most popular DRstrategies for air conditioning Increase space temperature (such as GTA) Make chiller plant adjustments (e.g., reset CHW temperature, limit cooling valve, limit chiller demand) Cycle package units Pre-cool the building 63 Check Your Understanding Name and discuss a couple of DR strategies for constant air volume (CAV) systems Cycle fans Ventilation control (outside air flow) Increase supply air temperature (use with caution) 64 PGE ADR Customer Training Deck 32

33 Check Your Understanding Name and discuss a couple of DR strategies for variable air volume (VAV) systems Reset duct static pressure on fans in VAV HVAC systems Limit fan speed (set CFM /RPM limits) Ventilation control 65 Check Your Understanding Is installing dimming ballasts considered demand response? Maybe. By itself, installing dimming ballasts is not demand response. However, if the dimming ballasts are used to reduce lighting during a called event then it could be demand response. 66 PGE ADR Customer Training Deck 33

34 PG&E s DR Programs Two Sources of Funds for DR DR load shedding participation revenue stream Technology Incentives (TI) funds help pay for hardware and software that enable ADR DR Programs Technology Incentives 68 PGE ADR Customer Training Deck 34

35 DR Load-Shedding Programs Capacity Bidding Program (CBP) Demand Bidding Program (DBP) Aggregator Managed Portfolio (AMP) Peak Day Pricing (PDP) These are the qualifying programs for Technology Incentives 69 Capacity Bidding Program (CBP) May to October, event-based program 11 am 7 pm Monday thru Friday (non-holiday) Bid is placed prior to the beginning of the month Events can be scheduled day-ahead or day-of Two incentive options based on day-ahead or day-of Must enroll with or as third-party aggregator 70 PGE ADR Customer Training Deck 35

36 Demand Bidding Program (DBP) Low-risk, day-ahead DR program Voluntary year-round Internet-based bidding program Can submit load reduction bids on an hourly basis for any event Minimum load reduction 10 kw for two consecutive hours Must have 15-minute interval meter or SmartMeter Eligible for bill credits for reductions from 50% to 150% of bid amount 71 Aggregator Managed Portfolio (AMP) Customers enroll directly with selected DR service providers (aggregators) Individual contracts meet customer s needs See PG&E DR webpage for participating aggregators 72 PGE ADR Customer Training Deck 36

37 Peak Day Pricing (PDP) Smaller accounts receive a discount on all part and on-peak usage on all non-event days of the year Larger accounts get Summer demand (kw) credit Higher usage (kwh) charge during event hours 2 pm 6 pm Monday thru Friday (non-holiday) 12 pm to 6 pm Monday thru Friday for some accounts (see tariff) May 1 thru October 31 9 to 15 events annually 73 Peak Day Pricing (PDP) PGE ADR Customer Training Deck 37

38 Peak Day Pricing Advantages Bill protection lets customers participate risk-free for the first year Maximum potential cost savings Credit if PDP exceeds time-of-use pricing PDP Capacity Reservation Level PGE ADR Customer Training Deck 38

39 InterAct What-If Analysis of Peak Day Pricing (PDP) Participation An average big box store with a peak demand of 238 kw and an average demand of 120 kw during 2012 Energy costs of approximately $142,000 per year 250 Two Weeks of Summer Demand Demand (kw) Two Weeks 77 PDP Participation and Incentive 20% load shed ~ 43 kw for this user ADR incentive would be $8,600 at $200 per kw % Load Shed on Event Day Energy Use (kwh) Midnight to Midnight 78 PGE ADR Customer Training Deck 39

40 Impacts of Switching to PDP Rate Impacts on the utility bill by switching from E-19S rate to E-19S PDP rate Rate Option and Scenario Total Annual Energy Charges Difference from E-19S % Savings for the year Current Rate E-19S $ 142,677 $0 0% Enroll in PDP E-19S PDP $ 142,728 $51 more - 0.1% Participate in 12 DR events E-19S PDP with 20% Load Shed $ 140,605 $2,072* 1.5% Estimated total savings from participating between 9 and 15 PDP events per year 9 Events = $2, Events = $2,072* 15 Events = $1,698 *Assumes Capacity Reservation Level is optimized at 54% of peak. CRL for E-19S current rate and E-19S rate with PDP were also adjusted to increase savings. 79 Lunchtime Exercise PGE ADR Customer Training Deck 40

41 Office - Hourly Demand During Peak Summer Day 81 Office Average On Peak Demand Frequency Distribution 82 PGE ADR Customer Training Deck 41

42 Office - Customer Specific Summer Baseline (CSSB) 83 PG&E s ADR Program PGE ADR Customer Training Deck 42

43 Two Sources of Funds for DR DR load shedding participation revenue stream Technology Incentives (TI) funds help pay for hardware and software that enable ADR DR Programs Technology Incentives 85 Technology Incentives (TI) Funds Auto-DR enables DR programs by reducing electricity usage during period of peak demand without manual intervention Technology incentives (TI) are available for purchasing and installing qualifying DR-enabling equipment, such as EMS or other automated control systems PGE ADR Customer Training Deck 43

44 Introduction to PG&E s ADR Program Objective enable customers to reduce energy usage during times of peak demand with demand response $15.5 million in incentives Program MW goals: 72 MW 7 MW reserved for Advanced Technologies Program runs from September 2012 through December 2014 Provides incentives and technical assistance for medium to large nonresidential customers to install program equipment 87 Intro to PG&E s ADR Program (continued) Program implementers: Energy Solutions ASW Engineering Demand Response Research Center (DRRC) at Lawrence Berkeley National Laboratory (LBNL) Akuacom 88 PGE ADR Customer Training Deck 44

45 PG&E s ADR Program Website A resource for: Program load reduction MW goal and achievement to date Incentive funds available Announcements, and more 89 Program Status The total incentive funding is $15.5 million Currently, the program has $6.08 million available not yet reserved to projects. Of the remaining approximate $6 million, $4.4 million is budgeted for ADR projects for the PDP program. There is approximately $1.1 million allocated for advanced technology ADR projects, and $225,000 for conventional ADR projects in the other eligible DR programs 90 PGE ADR Customer Training Deck 45

46 DR Program Incentive Budget Demand Response Program Incentive Cap* Peak Day Pricing $4,865,000 Aggregator Managed Portfolio (AMP) $3,023,000 Capacity Bidding Program (CBP) $1,511,640 Demand Bidding Program (DBP) $2,000,000 *Updated on 7/10/13 and based on projects under review 91 ADR Program Incentive Availability by Technology Classification Demand Response Program Standard ADR Funding Available* Advanced Tech ADR Funding Available* ADR Funding Available* Peak Day Pricing $3,525,463 $896,716 $4,422,179 Aggregator Managed Portfolio (AMP) $0 $384,856 $384,856 Capacity Bidding Program (CBP) $203,160 $0 $203,160 ADR + Energy Efficiency Projects $1,070,345 Same Cap $1,070,345 Demand Bidding Program (DBP) $24,200 $0 $24,200 * As of 7/10/13 Current values found at: 92 PGE ADR Customer Training Deck 46

47 Program Timeline Program ends December 2014, but projects need to be installed by October 31, 2014 in order to receive incentives. To meet this timeline send in your applications, project proposals, and audit reports by January /31/2014 8/29/2013 (TODAY) Recruit & enroll 1/31/2014 Applications received 5/30/2014 Applications approved Projects installed by this date to be eligible for ADR incentives About 4.5 months 93 Why Consider ADR Incentives Now? It available Use it to add or upgrade facility controls, which benefits both customer and utility Incentives could decrease or disappear as the norm changes: Title 24 standards requirements Smart grid and advanced metering infrastructure Time varying rates (e.g., Peak Day Pricing) 94 PGE ADR Customer Training Deck 47

48 ADR Incentives are Win-Win for customers and the utilities Technology Incentives funds can be used for a variety of enabling technologies Thermostats Lighting control panels Monitoring energy use Title 24 Code Requirements for DR Lighting DR controls for buildings larger than 10,000 square feet, must be capable of lowering lighting by at least 15% HVAC DR controls requires Occupant Controlled Smart Thermostats (OCST); capable of remotely using EMS to increase cooling temperature by 4 degrees or more As DR capable lighting and HVAC controls become baseline requirements in code, they become ineligible for incentives 96 PGE ADR Customer Training Deck 48

49 ADR Eligibility Requirements Requirements to be eligible for ADR program incentives: Non residential customer Electric services from PG&E Interval meter installed Existing account with 24 months billing and usage data Enrolled or eligible to enroll in PG&E DR programs Project is new equipment that provides incremental kw and kwh reductions New equipment or systems not already installed Eligible customers can apply for technology incentives for semi-adr or ADR. 97 Items Not Covered by ADR Incentives Measures that are not covered by ADR incentives include: Metering Distributed generation Permanent load shifting technologies Cameras Solar Software licenses Ongoing maintenance Cloud-based controls Thermal energy storage 98 PGE ADR Customer Training Deck 49

50 ADR Program Incentive Limits Incentive Limits by Demand Response Program Incentive Limits by Technology Category Demand Response Program* ADR Funding Available DBP $2,000,000 CBP $1,511,640 PDP $4,865,000 AMP $3,023,000 PDP Peak Day Pricing AMP Aggregator Managed Portfolio CBP Capacity Bidding Program DBP Demand Bidding Program Technology Category Percent of Incentive Budget Lighting No Cap Non-Advanced HVAC 40% Other Non-Advanced 63% Process 50% Pumping 40% Electric Vehicles and Electric 30% Charging ADR Program Uses Tiered Incentive Structure to Promote Advanced Technologies Technology Category Incentive Rate ($/dispatchable kw) Semi Automated Demand Response $125 Automated Demand Response $200 Advanced Technology HVAC $350 Advanced Technology Lighting $400 Incentive calculation based on dispatchable kw according to the committed load reduction strategy Incentives capped at 100 percent of total project cost: Equipment and installation Construction/project management Sales tax PGE ADR Customer Training Deck 50

51 Additional ADR Program Information Remain on initial DR program for 1 year Remain on any DR program for 3 years Target date for applications before Jan 31, 2014 Projects completed by Oct,31, 2014 Open ADR 2.0b certification Semi-ADR customers must also implement an EE measure 101 Incentives Are Paid In Two Installments 1st installment: 60% after verification of equipment installation and testing of DR strategies 2nd installment: 40% is paid after verification of participant performance PGE ADR Customer Training Deck 51

52 About OpenADR Open Automated Demand Response (OpenADR) An open and standardized protocol Used by electricity providers and system operators to communicate DR signals The standard used by all major CA utilities, including PG&E A common language used over any existing IP-based communications network, such as the Internet The OpenADR Alliance fosters the development, adoption, and compliance of the OpenADR Smart Grid standard 103 What is Advanced Technology? Meets standard ADR eligibility and considered case-by-case Inclusion in a California Emerging Technologies Coordination Council (CA ETCC) DR evaluation Inclusion other recent advanced technology evaluation Wireless or real-time two-way communication within the facility Granularity of control to fixture, zone, or thermostat level Granularity of data reporting and sensing Technologies in early stages of adoption are preferred 104 PGE ADR Customer Training Deck 52

53 Approved Vendors for Advanced Technologies HVAC/R Cypress Envirosystems wireless pneumatic thermostat REGEN Energy wireless devices Lighting Daintree Networks networked, wireless control platform for smart buildings, wireless lighting controls Enlighted, Inc. energy solutions for lighting, HVAC, and data analytics 105 Integrated Demand Side Management (IDSM) IDSM funds: $1.07 million incentives remaining Eligible EE measure is any measure that qualifies for a PG&E EE program incentive Open to new DR customers (not in a DR program for past 12 months) PDP, CBP, DBP only (DBP can be currently enrolled but not participated in last 12 months) Installed at the same site as the ADR measure 106 PGE ADR Customer Training Deck 53

54 Getting Started with PG&E s ADR Program Fill out the 2013 ADR Application 107 CISR Form Customer Information Standard Request (CISR) form Gives a utility account owner s permission to the utility company to release confidential energy usage data to a third party 108 PGE ADR Customer Training Deck 54

55 ADR Project Lifecycle Engineering audit and project application Audit and application review Project installation Installation review and testing First installment payment for 60% of total incentive DR season performance Performance period evaluation Second installment payment up to 40% of total incentive 109 DRAS Connectivity PGE ADR Customer Training Deck 55

56 What is the DRAS? Demand Response Automation Server (DRAS) Automates the interactions between the utilities and their customers for DR programs 111 Customers with Aggregators Utility 112 PGE ADR Customer Training Deck 56

57 Why a DRAS Client Technician (DCT)? ADR may be challenging to implement ADR needs a project facilitator The DCT knows all aspects of the project DCT is project champion and facilitates installation 113 DCT Roles and Responsibilities The DCT: Acts as liaison between facilities and vendors Enables participation in ADR program Provides site support during the entire process Serves as a technical resource coordinates the technical activities required to automate DR load shed at facility sites 114 PGE ADR Customer Training Deck 57

58 Flow Chart: DCT Role / Responsibility Technical Audit (TA) completed; ADR Requested Utility approves potential ADR measures Customer proceeds by reserving Technology Incentive (TI) funds DCT facilitates the project: 1) Reviews steps to enable ADR at customer s site 2) Meets with customer on-site 3) Helps select contractors (if applicable) 4) Prepares scope of work for the site 5) Sets up site on Utility s DRAS 6) Coordinates and manages site work 7) Tests installed ADR system 8) Trains customer on ADR and DRAS 9) Completes DCT verification documents 10) Coordinates formal Utility Verification Test 11) Provides any necessary technical support Utility performs final verification test Customer receives initial 60% payment Utility monitors participation in first DR season Customer receives remaining 40% payment 115 Getting Started in the DRAS If a customer needs to opt-out of a single event they should: Log into the DRAS Click the Events tab Click the Opt-out button This will only be visible if there is an event initiated. Once the Opt-out button has been utilized the event will disappear from the customer interface. 116 PGE ADR Customer Training Deck 58

59 M&V Testing Measure & Verification Test The M&V Test validates the incentive payment M&V test signals are initiated through the DRAS The DRAS client must be online 48 hours prior to the test 118 PGE ADR Customer Training Deck 59

60 Verification Test Scheduling Test Day Schedule a test with site (or vendor) and DCT Site can select date and time Program staff can recommend a time for testing Starts at the site minutes before initiation Verifies installed equipment Witnesses initiation of ADR measures 119 Utility Verification Example #1 Office Building 120 PGE ADR Customer Training Deck 60

61 Utility Verification Example #1 Office Building (continued) Honeywell Jace Client KYZ Pulses for building load 121 Utility Verification Example #1 Office Building (continued) Communications Links EMS Connections 122 PGE ADR Customer Training Deck 61

62 Utility Verification Example #1 Office Building (continued) 123 Utility Verification Example #1 Office Building (continued) 124 PGE ADR Customer Training Deck 62

63 Utility Verification Example #1 Office Building (continued) Pre-Event System Status 125 Utility Verification Example #1 Office Building (continued) Event System Status 126 PGE ADR Customer Training Deck 63

64 Utility Verification Example #1 Office Building (continued) 127 Utility Verification Example #1 Office Building (continued) Pre-Event Fan Status Event Fan Status (ramping down) 128 PGE ADR Customer Training Deck 64

65 Utility Verification Example #1 Office Building (continued) 129 Utility Verification Example #1 Office Building (continued) Pre-Event Status Event Status An apparent 120 kw reduction from the building power readout 130 PGE ADR Customer Training Deck 65

66 Utility Verification Example #1 Office Building (continued) Elevator Curtailment Measure Pre-Event Status Event Status 131 Utility Verification Example #1 Office Building (continued) Corridor Lighting Curtailment Measure Pre-Event Status Event Status 132 PGE ADR Customer Training Deck 66

67 Results Office Building CSSB vs RTE Load Shed = kw kw :00 PM 2:00 PM 3:00 PM 4:00 PM 5:00 PM 6:00 PM Time (Hour Ending) CSSB RTE 600 Adjusted 10 in 10 vs RTE Load Shed = kw kw L :00 AM 8:00 AM 9:00 AM 10:00 AM 11:00 AM 12:00 PM Time (Hour Ending) 1:00 PM2:00 PM3:00 PM4:00 PM5:00 PM6:00 PM7:00 PM8:00 PM Adjusted 10 in 10 RTE 133 Resources Incentives, contact Energy Solutions pge-adr@energy-solution.com Phone: (510) PG&E ADR Website: OpenADR Alliance: Certified devices: PGE ADR Customer Training Deck 67

68 Questions and Comments What questions do you have about Automated Demand Response? What questions do you have about PG&E s PDP program? How do you think you can implement DR at your facility? What ideas do you have for making this work? 135 PGE ADR Customer Training Deck 68