Place your chosen image here. The four corners must just cover the arrow tips. For covers, the three pictures should be the same size and in a straight line. Renewable Energy at Closed Landfills Workshop Sponsored by EBC, DOER, and Mass DEP Tim Roughan Director of Energy and Environmental Policy July 26, 2012

2 What we’ll be covering today  Where are we with interconnection requests  Interconnection basics  Rules of Thumb  Q&A

3 DG Applications Submitted vs. Processed Each Year (Cumulative kW) through April 2012 AppliedAuthorized ,5102, ,74113, ,22934, ,71850,960

4 During 2011, the utilities had approximately 735 MWs of exp/standard applications, making the total amount of MWs close to 750 MWs. In contrast, in 2009, only approximately 66 MWs of exp/standard applications were received making the total amount close to 70 MWs.

5 Electric Transmission and Distribution System  The Electric Power System (EPS) is designed to safely and reliably move high quality power from source to load.  Distributed Generation (DG) can be interconnected to the transmission and distribution system  DG must be designed & interconnected so there is no adverse affect on:  Safety  Reliability  Power quality

6 Governing Regulations and Bodies  State jurisdiction vs. FERC jurisdiction  Will your system impact the bulk power system (transmission)?  Will you sell to the market or will you sell to the host utility as a QF or under net metering?  Are you the “first on” the distribution feeder?  ISO-NE Schedule 22 and Schedule 23: If you will be connecting to the transmission system, or if you will sell to the market on an existing “FERC jurisdictional” feeder.  Independent System Operator New England administers  Significant application fee and queueing  Distribution Level interconnection tariffs: Connection to a distribution feeder under “State Jurisdiction”  Local Distribution Company administers

7 7 Interconnection Contacts & Tariff Links National Grid Phone: Alex Kuriakose | NSTAR Joseph Feraci | Paul Kelley | Unitil Tim Noonis | resources/renewable-energy-generation resources/renewable-energy-generation WMECo Phone:

8 8 Other Information Resources  MA DG and Interconnection Website:  Net Metering Basics: t-metering-in-ma t-metering-in-ma  Interconnection Guide for Distributed Generation (Mass-CEC): nnectionGuidetoMA_Final%281%29.pdf nnectionGuidetoMA_Final%281%29.pdf 8

9 Where & How to connect to the Utility  Generators can connect at various voltage levels based on:  Aggregate rating of generation system  Type of distribution system located nearby and characteristics of the system  Interconnecting customer is responsible for costs of all studies and upgrades to the electric distribution system  Interconnection voltage levels:  Transmission – usually =>69 kV (bulk power)  Distribution – 13 kV, 23kV, 34 kV  Secondary voltages – 120/240 single phase, 120/208 three phase, 277/480 three phase  Early research can help determine the makeup of local transmission or distribution:  Three-phase power nearby?  Voltage level of local distribution? (e.g. 4 kV feeder can limit connection)  Any red flags from the local utility? (e.g. other DG already on line or tail end of feeder, etc.)

10 Overview of the Interconnection Standard  Introduction and definitions – Section 1  Basic Understandings – Section 2  Process Overview – Section 3  Interconnection Requirements – Section 4  Responsibility for Costs of Interconnecting a Facility – Section 5  Operating Requirements – Section 6  Disconnection – Section 7  Metering – Section 8  Dispute Resolution – Section 9  Confidentiality - Section 10  Insurance – Section 11  Exhibits

11 Section 2 - Basic Understandings If you don’t read any other portion of the standard – at least read this.  Interconnecting Customer and Company must enter into an agreement for interconnected generators.  Consult with the company before design to determine what utility facilities are present.  We’re here to help guide you through the process  The tariff was developed before the recent large solar farm projects were contemplated, so timelines in current tariff are for behind the meter applications, not large solar farms

12 Standard Process  After initial review and/or supplemental review, customer may need to enter Standard Process  Customer can request Standard Process up front  Appropriate study agreement sent to customer for signature and payment  Studies could include:  Impact Study: Determine the impact of the new generator on potentially affected systems, including EPS, other customers and other generators  Detailed Facility Study: Determine utility system modifications required and cost  After studies – interconnection agreement sent to customer for signature  As discussed, these timelines are not representative of the current work Review ProcessStandard Eligible FacilitiesAny DG Acknowledge Receipt of Application (3 days) Review Application for Completeness 10 days Complete Review of All Screens Complete Supplemental Review (if needed) Complete Standard Process Initial Review 20 days Send Follow-on Studies Cost/Agreement 5 days Complete Impact Study (if needed) 55 days Complete Detailed Study (if needed) 30 days Send Executable Agreement (Note 3) 15 days Total Maximum Days (Note 4) 125/150 days (note 6) Notice/ Witness TestBy mutual agreement

13 Example – Standard Process  Interconnecting Customer (IC) applies to install 1.5 MW wind turbine and has well designed relay protection system and proposed settings  Initial review determines that an Impact Study is required  IC signs Impact Study Agreement and pays for study  Impact Study is completed and required EPS modifications and costs are communicated to Interconnecting Customer along with any changes needed to protection system  Interconnection Agreement (IA) sent to Interconnecting Customer for signature  Interconnecting Customer pays for EPS modifications  Company builds system modifications, registers asset, etc.  Interconnecting Customer signs IA, builds facility, submits required insurance and relay test report.  Company conducts witness test and authorizes interconnection

14 Studies and agreements can involve many parties – on both sides  Application analyst – processes application and contracts  Lead Engineer for reviews/studies  Relay Engineering  Distribution Planning  Distribution Dispatch  Distribution Design Engineering  Meter operations  Meter Data Services  Relay Telecom Operations  Inspection team  Transmission and/or Substation Design  Energy Supply (asset registration)  Legal  Customer  Equipment vendor  Lead contractor  Electrician  Electrical Engineer (PE)  Relay Engineer  Relay testing firm  Legal UtilityInterconnecting Customer Many moving parts to coordinate

15 Behind the scenes at utility  Modifications to metering and billing (which way is the meter spinning?)  Modifications to protection systems as required (e.g. modify feeder breaker / recloser set-points, fusing, etc)  Larger generators (>5 MW) require review by NEPOOL reliability committee and registration with ISO-NE. They can review units > 1 MW  Adding generation asset to geographic information systems, maps, system one-lines, dispatch systems, etc.  Publish internal special operating guidelines for utility field personnel on larger generators.  Set up future testing for relay protection, meter calibration, etc.

16 Rules of Thumb  If aggregate generation on a feeder is over 7.5% of peak feeder load, there may be special reviews required.  The feeder voltage will impact the size of generator that can be safely interconnected at the distribution level. Currently, a maximum of 3 MWs is allowed on a 13 kV feeder.  If the generator will sell on the market and has to apply through ISO-NE, the process may take longer than the standard time frames.  Generators over 10 KW are most likely going to be three-phase. Make sure that the customer has three-phase service available. If a line extension is required, it is at the customer’s expense.  Some things of note on various things that must happen between the time an application is received and a system can go on line:  During initial analysis and various studies, there is usually an exchange of information which takes time. Customer and contractor’s quick response to any utility questions is vital.  System modifications can take some time, especially if specialty equipment must be ordered. Lead times for substation equipment can be 4-6 months and can only be ordered after detailed design is completed (design can also take a number of months).  ISO-NE Reliability Council review and asset registration for larger units which will export power.

17 Things to keep in mind  Budget time and money for various interconnection studies  Applying through ISO-NE Schedule 22 / 23 – you will be placed in a queue  Applying to local utility  Budget time and money for potential modifications needed for the utility’s Electric Power System  Require your equipment suppliers to provide accurate information about the generators to be installed  You will need a specialized engineer for relay and protection  Larger systems have more impact on the distribution system  Utilities need all the proper information and time to evaluate and ensure no adverse impact to the neighbors of the DG project

18 Summary  Contact utility in advance to verify service configuration in the area  Apply early  If needed, hire an engineer well schooled in protection issues  Apply early – each job is unique  The interconnection standard contains a wealth of information – get to know it.  Interconnection expenses should be budgeted into your project  Apply early – the pace of interconnection applications has picked up remarkably in the past two years