New York City Solar Installer Workshop

Transcription

1 New York City Solar Installer Workshop March 12, 2018 Con Edison Cliff Baratta, Sr Specialist Kevin Bishop, Sr Specialist Beatrice Troiano, Specialist Distributed Generation Group 1

2 Agenda 2017 Overview Con Edison Grid 101 and Implications for PV Con Edison Interconnection Process Rates & Billing Uniform Business Practices for Distributed Energy Resource Suppliers (UBP DERS) Resources 2

3 2017 Overview 3

4 2017 Interconnections Customer Adoption Added 5,176 new DG installations Solar accounted for 98% of installs 32 new Remote Net Metering facilities 1 new Community DG facility Customer Segment Commercial Public Buildings Residential DG Installations (as of 12/31/17) Con Ed Territory NYC Only Units: # of installs Total 2017 only Total 2017 only Battery Storage Fuel Cells CHP Solar 17,779 5,098 13,188 4,297 TOTAL 18,114 5,176 13,484 4,368 4

5 2017 Interconnections Borough DG Capacity Additions 42 Added 66 MW new capacity Solar accounted for 65% of capacity Solar capacity is coming in on forecast 2018 projected to 221 MW capacity Brooklyn Bronx Manhattan Queens Staten Island Westchester DG Capacity Installed (as of 12/31/17) Con Ed Territory NYC Only Units: MW Total 2017 only Total 2017 only Battery Storage Fuel Cells CHP Solar TOTAL

6 Con Edison Grid 101 6

7 Electric Operations Overview Distribution The distribution system supplies power to low voltage Network customers and Radial customers from area substations at the primary service voltage levels. Majority of customers receive low voltage service directly at the distribution system secondary voltage levels A small percentage of high voltage customers receive power at primary service voltage Area Substation Feeders 64 Network Systems Supply 87% of System Demand Transformers Radial System Supplies 13% of System Demand 7

8 A Tale of 3 Warehouses Radial Network Spot/Isolated 8

9 Typical Con Edison Radial Grid Overhead Transformer Area Substation A Substation Breakers Closed Overhead Switch Open Overhead Switch PV Customer B C Radial Feeder (13/4 kv) Standard Customer D 120/208 Volt or 120/240 Volt Service E A Unit Substation B Unit Substation Primary Feeder (13/27/33 kv) 9

10 DG Implications: Radial Service Typically the easiest for export 2-way power flow Potential technical issues PV penetration on the feeder Size of PV vs service/transformer Switch or Re-closer issues Potential operational issues Higher rate of storm outages 10

11 Typical Network Grid Network Transformer Network Protector Area Substation Substation Breakers A PV Customer B Standard Customer C D 120/208 Volt Secondary Network Grid E Primary Feeder (13/27/33 kv) 11

12 DG Implications: Network Grid Service Export capability dependent upon multiple factors PV size vs service capacity Network loading Nearby transformer loading Upgrades to service may require street work Localized underground Increased customer cost & timeline 12

13 Spot or Isolated Network Network Transformer Network Protector Area Substation Substation Breakers A PV Customer B Standard Customer C D E 120/208 Volt Network Grid Primary Feeder (13/27/33 kv) Large Customer Spot or Isolated Network 13

14 DG Implications: Isolated/Spot Network Opening of network protector(s) would result in power loss to customer Cannot accept export without upgrades Solutions to enable export across network protector relays Additional interconnection costs to accept export 14

15 DG Export Solutions for Network System Anti-Pumping Protection (APP): Application: Network grid service Description: Modifications to nearby transformers relays Typical Cost: Up to $50K Communications Aided Tripping (CAT): Application: Isolated/Spot Network Description: Modifications to impacted transformers relays and communication to customer inverters. Typical Cost: $70-100K 15

16 Interconnection Process 16

17 Prior to First Interconnection Request Read the New York State Standard Interconnection Requirements (SIR) Application Process and Timelines Technical and Operating Requirements Required Contracts and Forms Read Rider R Net Metering and Value Stack Tariff Register with Power Clerk How you submit applications Contact us with any questions dgexpert@coned.com 17

18 What You Need to Submit Appendix F of NYS Standardized Interconnection Requirements: Covers all interconnection documents (customer authorization, site control forms, drawings, project information, specifications, verification test procedures, et cetera) Refer to our website for documentation checklist and Rate Forms: Completed Application Form G (net metering, remote net metering) or CDG Procedural Requirements Appendices A and B (Community DG) 18

19 Best Practices for Applications Have your Customer s Account Number and Meter Number Con Edison Meters have 7-digits Account Number we need is 14 digits (leave off 15 th digit) For Remote Net Metered/CDG cases, use Host Account For New Meter without Account Number assigned, all 9 s For New Service, enter MC number for Project Center Service case Select the appropriate type of metering, e.g. RNM or CDG Separate cases for multiple technologies at same premise 19

20 Who s Who in the Process Energy Services: Handles all paperwork. Your Customer Project Manager is your point of communication for your project. Distribution Engineering: Performs all engineering reviews, studies, and inspections. Distributed Generation: Provides guidance on rules, tariffs, general information. Customer Operations: Does all billing. This is who your customer calls with questions after PV goes in. 20

21 How You Submit: PowerClerk Register for Small DG and/or Large DG program(s) Projects up to 50 kw conedsmalldg.powerclerk.com Projects 50 kw to 5 MW conedlargedg.powerclerk.com 21

22 Beginning Your Application 22

23 Requirements for Your Application SIR determines the info and documents required Changes to the SIR will be reflected in PowerClerk * Indicates required field? Indicates help, e.g. a link to a blank form 23

24 Process for Energy Storage Projects Hybrid systems parallel with grid Technology Power Clerk Project Center Notes PV + Storage as Back-up (not grid parallel) Storage in Parallel with Grid New PV + New Storage New Storage + Existing PV New PV + Existing Storage Solar application ** Battery Energy Storage application 2 separate applications 1 for Solar ** 1 for Energy Storage Battery Energy Storage application Solar application Emergency Back-up generator application None None None None As of 03/01/2018 inverterbased energy storage systems can export and receive compensation under buy-back service (SC11) Refer to the other (MC#) in the Please Provide Project Overview field and also tell your project manager Note: ** Check Yes for Will this DG project include energy storage? Battery storage-specific fields will be implemented once the new SIR becomes effective 24

25 What Happens After You Submit Your Interconnection Application Customer and contractor receive acknowledgment letters and a case number: MC-xxxxxx Case is assigned to a Customer Project Manager (CPM) in Energy Services Up to 50kW solar projects will follow expedited process (no engineering review, self-certification) 50kW - 5MW solar projects will follow SIR process including preliminary screens and engineering reviews 25

26 Managing Your Application Back-and-forth process between the applicant and Con Edison Example process Application Submitted Pending Review Application Incomplete Revised Documentation Required Application Accepted Pending Preliminary Review Preliminary Screen Complete Pending Customer Action CESIR Requested Pending Payment KEY: Status Pending Con Ed Action Status Pending Customer Action 26

27 Under 50kW: Project Review Submit application via PowerClerk Con Ed reviews and approves design Fast Track: automatic approval for projects <25 kw for most developers Complete your construction Test inverter Submit self-certification form via PowerClerk Available on our website Signals to CPM that ready for final review and net meter order Con Ed issues formal letter of Final Acceptance 27

28 Available on website 28

29 50 kw to 5 MW: CESIR study Upon customer choice and payment for study Distribution Engineering Technical review of application Three-line in-depth review Review of PV output vs. load Historical Usage Transformer loading Meets/does not meet NYS SIR 60 business days (up to 2MW) 80 business days (2MW 5MW) 29

30 Post-CESIR Steps DE will present options to customer for interconnection with cost Customer chooses one option and pays for upgrades (if necessary) Con Edison issues Appendix A Project advances to Design Approved Pending Construction Developer receives Value Stack Summary document with all locked-in Value Stack eligibility and rates Construction 30

31 Verification Testing Before you request a verification test and inspection: Receive signoff from Con Edison on latest drawing version that matches system as-built Pass DOB inspection Pre-test your inverters Confirm attendance of necessary technicians and access to all equipment Con Edison has a verification test checklist up on our website Upon passing inspection, will receive Final Acceptance letter 31

32 Energy Services Contacts You can reach Energy Services from 7 a.m. to 3:30 p.m. Mon- Fri If no response from your CPM within 2 business days, contact their Manager: Employee Manager Phone Chris Mattina Shashi Ramjattan Kevin Dekeris Mike Brown Mike Tucci Seretse Henry Gerald Thompson Jack Chen Antoine Adams Peter Aufdemorte Rob Klopf klopfr@coned.com Richard Vitolo vitolor@coned.com Zhen Shao shaoz@coned.com Phyllis DelRe Tracy Downing downingt@coned.com For s, include the Job Number (MC-xxxxxx) in the subject and the project address, your CPM s name, and your contact information in the body Note: All this information is also available on our website If still no response within 2 business days, contact the Department Manager Directly: Tom McAndrews mcandrewst@coned.com

33 Rates & Billing 33

34 Common Service Classifications Mass Market Demand Billed SC 1: Residential/ Religious SC 2: General Small SC 8: Multiple Dwelling Redistribution SC 9: General Large Energy only (kwh) Energy and Fixed Demand Charge (kwh) Only for customers with demand < 10kW Energy and Demand Charges (kwh & kw) Highest 30 minutes of demand sets demand charge for entire month 34

35 Compensation for DERs: Outcome of Value of DER Order Mass Market* Demand Billed Systems in operation as of March 9, 2017 New residential & small commercial systems installed through sooner of January 1, 2020 or Phase 2 Order New Remote Net Metering (RNM) installations New Community DG (CDG) projects New large commercial and industrial installations Traditional NEM for life of system (no change) Can opt-in to Value Stack Phase One NEM for 20 years Value Stack without transition credit for 25 years Tranche 1-3: Value Stack for 25 years with transition credit (MTC) for mass market subscribers (declines by tranche) (Tranche 0: Phase One NEM for 20 years) Value Stack without transition credit for 25 years * SC 1 accounts cannot be RNM or CDG hosts 35

36 Compensation for DERs: Focus on NEM & Phase One NEM Mass Market* Demand Billed Systems in operation as of March 9, 2017 New residential & small commercial systems installed through sooner of January 1, 2020 or Phase 2 Order New Remote Net Metering (RNM) installations New Community DG (CDG) projects New large commercial and industrial installations Traditional NEM for life of system (no change) Can opt-in to Value Stack Phase One NEM for 20 years Value Stack without transition credit for 25 years Tranche 0: Phase One NEM for 20 years Tranche 1-3: Value Stack for 25 years with transition credit (MTC) for mass market subscribers (declines by tranche) Value Stack without transition credit for 25 years * SC 1 accounts cannot be RNM or CDG hosts 36

37 Grandfathered NEM and Phase One NEM: Residential energy-only (SC1) Rider R Section G When Export > Import for the month: Monthly energy (kwh) charges are zero. Customer pays Basic Service Charge only. Excess energy (kwh) is rolled over to the next month. Annual Reconciliation Grandfathered NEM only Customer can choose which month they want Unused energy credited kwh are converted to $ at a rate based on Con Edison s avoided cost. If < $100, credit is applied to the bill If $100, Con Edison will issue a check Phase One NEM has 20-year term from in-service date, then transition to the current structure in place at that time Customer will always get a bill 37

38 Grandfathered NEM and Phase One NEM: Small commercial energy-only (SC2) When Export > Import for the month: Monthly energy (kwh) charges are zero Customer pays Basic Service Charge only Excess energy (kwh) is rolled over to the next month No Annual Reconciliation for SC2 Excess energy (kwh) credits are applied to future usage Phase One NEM has 20-year term from in-service date, then transition to the current structure in place at that time SC2 accounts qualify for Remote Net Metering host sites Receive Value Stack credits if RNM 38

39 Compensation for DERs: Focus on Value Stack Mass Market* Demand Billed Systems in operation as of March 9, 2017 New residential & small commercial systems installed through sooner of January 1, 2020 or Phase 2 Order New Remote Net Metering (RNM) installations New Community DG (CDG) projects New large commercial and industrial installations Traditional NEM for life of system (no change) Can opt-in to Value Stack Phase One NEM for 20 years Value Stack without transition credit for 25 years Tranche 0: Phase One NEM for 20 years Tranche 1-3: Value Stack for 25 years with transition credit (MTC) for mass market subscribers (declines by tranche) Value Stack without transition credit for 25 years * SC 1 accounts cannot be RNM or CDG hosts 39

40 What is the VDER Value Stack? Combination of time- and location-specific credit components based on hourly net injections Component Description Eligibility Energy Value Volumetric credit based on Day Ahead Hourly LBMP All projects Installed Capacity Value Environmental Value Distribution Relief Value (DRV) Market Transition Credit (MTC) Locational System Relief Value (LSRV) Volumetric credit applied to production in all hours with option for higher credit in summer on-peak periods Volumetric credit valued at NYSERDA REC or cost of carbon Monetary credit for performance during 10 peak distribution hours of previous year valued at Marginal Cost of Service (MCOS) Volumetric credit for mass market accounts to bring compensation close to NEM Declines for new projects as tranches fill Additional incentive for DERs in high value areas Monetary credit determined same way as DRV All projects, solar get Alternative 1 Renewable technologies Applicable to customers not eligible for MTC (already built in to MTC) For mass market subscribers (SC1 & SC2) to CDG projects Customers in high value areas, until cap is reached 40

41 Value Stack: Demand Customers (SC8 & SC9) When solar is producing but not exporting to grid Reduce energy usage, reduce bill (at retail rate) Whenever solar energy is exporting to the grid Excess, grid exported kwh are valued at Value Stack rates Value Stack credits can offset entire Electric bill, not just energy charges If bill is completely offset, remaining credits carry over to the next month If eligible for DRV and/or LSRV, account receives the monthly credit regardless of kwh exported that month No Annual Reconciliation SC8 and SC9 accounts qualify for Remote Net Metering host sites Note: The installation of solar does not always reduce a customer s demand level. 41

42 VDER Value Stack Project Interconnection Milestones Application Accepted Initial Value Stack Summary communication sent to developer (coming soon) Design Approved Pending Construction * Final Value Stack Summary communication sent to developer; value stack rates and eligibility locked-in Start of first billing cycle following Final Acceptance Value Stack credits start accruing Application Submitted Application Accepted Preliminary Screen CESIR Study Pending Design Approval Design Approved Construction Complete Verification Test PTO Able to opt-out of Environmental Value Able to change Installed Capacity Value Alternative * Occurs once 25% of interconnection upgrade costs are paid or SIR contract is executed if no payment is required 42

43 Demand Customer Value Stack Bill Monthly Bill VDER Statement 43

44 Remote Net Metering: Conditions Host Account must be non-residential The Host Account and Satellite Account(s) shall be established in the exact same Customer name and located on property owned or leased by the Customer. Host and Satellite Accounts must be located in the same NYISO zone No minimum load required, but there will likely be upgrade costs to ensure service can accommodate export Use Form G, Section 4 for application Satellite Account can have more than one Host Account (limited to 2MW) Satellite Account can be a net metered customer-generator Satellite cannot be a Host Account 44

45 Community DG: Conditions Host Account must be non-residential Host and Satellite Accounts must be located in the same NYISO zone Minimum of ten satellite customers, unless all located on same property Each Satellite must have at least 1,000kWh annual usage Satellites above 25kW cannot take up more than 40% of allocation (exception for SC8 and SC12 accounts with multiple dwellings) No minimum load required, but there will likely be upgrade costs to ensure service can accommodate export Must meet Community DG Procedural Requirements for Value Stack Self-certification of creditworthiness, cyber security, NYISO load zone, and any other obligations as per PSC Community DG Order Uniform Business Practices (UBP) for DER Suppliers 45

46 Community DG: Process Read the Community DG Procedural Requirements for Value Stack before starting an application Follow the SIR process facilitated by PowerClerk Select Community DG If new account for export only, apply for New Service via Project Center Submit CDG Appendix A and B with interconnection application, instead of Form G Submit CDG Appendix C spreadsheet (Initial Allocation Request) via to cdgdevelopers@coned.com: At least 60 calendar days before commencing CDG program Include case number (MC-XXXXXX) in subject line 46

47 Uniform Business Practices for DER Suppliers (UBP DERS) 47

48 UBP DERS: Registration Requirements October 19, 2017: Order Establishing Oversight Framework and Uniform Business Practices for Distributed Energy Resource Suppliers (UBP DERS) link, see p. 160 CDG and on-site Mass Market DG providers must register with DPS If begin operating in NY after 12/1/2017, registration must be submitted and approved before they begin marketing to customers For developers already operating in NY before 12/1/2017, registration must be filed by April 2 Registration forms available on DPS website Note: This matter is still in progress. Con Ed is seeking clarification of the processes from DPS, e.g. how to collect registrations 48

49 UBP DERS: Customer Data Platforms For any third party to be authorized to access customer data: Satisfy all requirements indicated in UBP DERS (e.g., registration) Successfully complete Vendor Risk Assessment (VRA, Exhibit A of DSA) Sign Data Security Agreement (DSA) Complete any technical onboarding associated with customer data platform EDI, Electronic Data Interchange, allows for exchanging customer data with DERS link to EDI Green Button Connect My Data allows customers to exchange their data with DERS via an online platform contact filocomov@coned.com Green Button Download My Data provides customers easy access to their energy usage data via their online accounts can send to DERS, no DSA or VRA required These platforms replace all existing means for DERS to get customer data 49

50 Resources 50

51 Con Edison Solar Resources for Your Customer Con Ed DG website: Con Ed solar website: Con Ed Solar Photovoltaics Guide Billing questions Residential customers: or Large/commercial customers: Technical, process, or rate questions: 51

52 Questions? Thank you! 52

53 APPENDIX 53

54 Key Components of Three Line Drawing Equipment Locations Service Characteristic Drawing Details Include any existing DG on the site Con Edison has a System Diagram checklist for baseline requirements for the majority of cases. 54

55 Equipment Locations and Labeling Generator Disconnect Switch 89-L Include locations of: - 89L - Meter - Inverters 55

56 Title Block Include: - customer name and service address - account and meter number - revision number - date of last revision. 56

57 DG System Drawing Details Inverter Make/Model Include: - DG type clearly labeled - AC kw nameplate clearly labeled - 89L clearly labeled - Make/model of inverter clearly labeled 57

58 Service Characteristics Include: - Service type and configuration - Existing equipment - Label grounding - Show any existing DG 58

59 Utility/Customer Timelines Both utilities and applicant are responsible for meeting timelines Typical customer timeline is 30 days to respond on how to progress a case Responding to utility requests for additional information Choosing how to proceed after a screening analysis Payment for a study Payment for upgrades (60 days) 59

60 How Net Meters Work: import Utility provides power. Customer Utility Building Load Customer Supply Panel Customer pays retail rate for energy Net Meter Meter Readings going Up Import 60

61 How Net Meters Work: reduce load Utility and PV System share load requirement. Customer Utility Building Load Customer Supply Panel Customer pays retail rate for less energy Import Net Meter Meter Readings going Up Slowly 61

62 How Net Meters Work: export PV System provides power. Utility and PV System share load requirement. Customer Utility Building Load Customer Supply Panel Export Customer receives NEM or Value Stack credits for energy exported Net Meter Meter Readings going Backwards 62

63 SC-1 Net Metering Bills 63

64 SC-1 Net Metering Bills Customers will see actual meter readings 64

65 SC-1 Net Metering Bills Automated net metering summary page Where customers will see information on annual cash out 65

66 Historical per-kwh net metering rates ZONE J ZONE H & I SC1 SC2 SC8 SC9 SC12 SC1 SC2 SC8 SC9 SC12 Feb-18 $ $ $ $ $ $ $ $ $ $ Jan-18 $ $ $ $ $ $ $ $ $ $ Dec-17 $ $ $ $ $ $ $ $ $ $ Nov-17 $ $ $ $ $ $ $ $ $ $ Oct-17 $ $ $ $ $ $ $ $ $ $ Sep-17 $ $ $ $ $ $ $ $ $ $ Aug-17 $ $ $ $ $ $ $ $ $ $ July-17 $ $ $ $ $ $ $ $ $ $ June-17 $ $ $ $ $ $ $ $ $ $ May-17 $ $ $ $ $ $ $ $ $ $ Apr-17 $ $ $ $ $ $ $ $ $ $ Mar-17 $ $ $ $ $ $ $ $ $ $ Mo Avg $ $ $ $ $ $ $ $ $ $

67 Green Button Download My Data Customer tool to download energy use into a spreadsheet Link: 67

68 Important Things for Your Customer to Know Level billing: Customers should call to have themselves removed from level billing Time of Use: This is usually not a benefit for solar customers. Net meter v. solar production meters: Bill credits are not based on solar production, but net electricity export (for NEM) or total electricity export (for Value Stack). Demand customers: solar installations do not always reduce a customer s demand level. 68

69 VDER Resources PSC VDER Order Con Ed Private Generation Tariffs webpage: Components of Value Stack Timing of Value Stack Components Value Stack Calculations And more Con Edison VDER Statement: our current Value Stack rates NYSERDA VDER webpage, includes link to download VDER Calculator 69

70 Process for Energy Storage Projects Residential PV + Storage as a Back-up (not grid parallel) Select SOLAR (Photovoltaic) for Distributed Generation Type Check Yes for Will this DG project include energy storage? and Will you be installing an Automatic Transfer Switch? Separate application for battery in Project Center as back-up generator Energy Storage in Parallel with Grid Select BATTERY ENERGY STORAGE for Distributed Generation Type Depending upon charging level, upgrades may be required As of March 1, inverter-based energy storage systems can export to the grid and receive compensation under buy-back service (SC11) Note: Battery storage-specific fields will be implemented once the new SIR becomes effective 70

71 Process for Hybrid Energy Storage Projects (aka Paired Storage) Hybrid systems mix of technologies all parallel with grid 1. One installation of combined Solar PV + Battery Energy Storage Separate application for each technology Each application should refer to the other (MC# when available) in the Please Provide Project Overview field and also highlight to your project manager For Solar, check Yes for Will this DG project include energy storage? 2. Battery Energy Storage installation for customer with existing Solar PV One application only Application should refer to the other (MC#) in the Please Provide Project Overview field and also highlight to your project manager 3. Solar PV installation for customer with existing Battery Energy Storage: follow process from #2 except new PV application 71