1. Collaborative Results Restructuring Roundtable March 28, 2003
Massachusetts DTE
DG Interconnection Collaborative
Collaborative Results
Restructuring Roundtable
March 28, 2003

2. What Is An Interconnect (Nomenclature)?
The interface between Distributed Generation (DG) equipment, (the Facility) and the grid (the area Electrical Power System or EPS)
Point of Common Coupling (PCC)
EPS
Radial
Customer Facility
EPS
Customer Site
(interconnecting facility)
Network
Customer
EPS
Load 1
Load 2
Load 3 DG
(generating facility)

3. Collaborative Effort Has Resulted in the Creation of Four Processes
Simplest process
Minimal or no costs expected
Shortest time
Still reasonably simple
Strict limits
Modest fees, longer time interval
Standardized process
Screens / Supplemental Review technical approach
Moderate fees , longer time interval
Similar to current process
Essentially based on actual costs
Potentially long time interval
Simplified - Radial
Simplified – Network
Expedited – Radial
Standard – Radial or Network

4. Simplified Radial Process
One sheet application and approval
Only three technical screens
Radial distribution systems only
Limited to 10kW or less
Inverter-based, UL1741 listed
Minimal or no costs expected
15 business days max
Customer Submits Application
Network or Radial EPS?
Complete Simplified Process
>7.5% of circuit peak load?
≤10kW Qualified Inverter?
Radial
Yes
To Network Process
To Supplemental Review No
To Expedited Screens

5. Simplified Network Process
One sheet application and approval
Additional technical limits
Spot network only
Tighter capacity limit
$100 or $300 fee
40 to 100 days max
Area or Grid Network 1
Substation Circuit 2 3
Secondary Bus
Loads
Primary Feeders
Transformer
Network Protector Breaker
Network Protector Fuse
Switch
Spot Network
Customer NP

6. Expedited Radial Process
Is Facility Certified?
Supplemental Review No
Yes
Pass Starting V Drop?
Standardized application
Five additional technical screens
If passed, only a review of possible EPS
modifications remains
If not passed, Supplemental Review
determines if application can remain in
Expedited or go to Standard process
Fee range from $300 to $3,750,
possible EPS upgrades
40 or 60 days max No
Yes
Pass Fault Contrib? No
Yes
Pass Config. Screen? No
Yes
Pass Trans. Stability? No
(If required)
Company makes EPS Modifications
Yes
Suppl. Review Determine Req.?
Company Sends Written Authorization
EPS Modification Check
Optional Witness Test
Yes
Customer Installs Facility No
To Standard Process

7. Basis For Screens Circuit impact
Fault handling, fuse desensitizing & nuisance trip
Short circuit handling
Proper connection
Single phase imbalance
Circuit size versus DG size
DG contribution to fault
Short circuit interrupting capability limit
Three-wire and four-wire circuit criteria
Nameplate limits

8. Standard Review Process
Standardized application
Initial review
Impact study if required
Facility study if required
Fee range from $300 to actual
costs (no limit)
125 or 150 days max
(If required)
Company makes EPS Modifications
initial review
optional scoping meeting
Impact Study if required
Facilities Study if required
Company Sends Written Authorization
Optional Witness Test
Customer Installs Facility

9. Process In Report
Customer submits complete application and application fee
1. Is the Point of Common Coupling on a Radial Distribution System? No
Go to Figure 2
Customer opts for Standard Process
Yes
2. Is the aggregate generating Facility capacity on the circuit less than 7.5% of circuit annual peak load? No
Perform
Supplemental
Review
Initiate Standard
Process initial review
Yes
3. Does the facility use a Qualified Inverter with a power rating of 10 kW or less? No
Yes
Does the facility pass all the following screens?
4. Is the Facility certified?
5. Is the Starting Voltage Drop Screen met?
6. Is the Fault Current Contribution Screen met?
7. Is the Service Configuration Screen met?
8. Is the Transient Stability Screen met? No
Does Supplemental Review determine requirements?
Yes
Yes No
System Modification Check
Company provides cost estimate and schedule for Interconnection Study(ies)
Customer accepts
Company performs Impact and Facility (if required) Study
Facility Processed for Simplified Interconnection Under DG Tariff
Facility Processed for Expedited Interconnection Under DG Tariff
Facility Processed for Standard Interconnection Under DG Tariff

10. Simplified Process For Networks
Is the Point of Common Coupling on a spot network? No
Initiate Standard process
Yes
Does the facility use a Qualified Inverter? (UL1741) No
Yes
Is the Facility 10kW or less? No
Yes
Is the aggregate generating Facility capacity less than
1/15 of Customer’s minimum load? No
Yes
System Modification Check
Yes
Facility Processed for Simplified Interconnection Under DG Tariff

11. Minimum Technical Requirements Set By
IEEE P1547 – “Draft Standard for Distributed Resources Interconnected with Electric Power Systems”.
Underwriters Laboratories Inc. Standard UL 1741, November 1, 2002 “Inverters, Converters and Charge Controllers for Use in Independent Power Systems
IEEE , “IEEE Recommended Practice for Utility Interface of Photovoltaic (PV) Systems.”

12. IEEE Std P1547 Key Clauses Voltage regulation
Integration with EPS grounding
Synchronization
Surge Withstand
Response to EPS abnormal conditions
Response to EPS faults
EPS reclosing coordination
Voltage detection and limits
Frequency detection and limits
Reconnection to EPS
Limitation of Flicker
Harmonics
Unintentional islanding
Design testing
Commissioning testing

13. Additional Technical Requirements
For Facilities qualified for Simplified Process
Must be “qualified” to UL 1741
Disconnect switch may be required
For Facilities >10kW:
Non-export functionality if not allowed to export
Disconnect switch or comparable device
Possible NPCC criteria
For Facilities with rotating generators
Interrupting Device (ID)
Synchronizing Device (could be part of ID)
Additional protection equipment requirements
For large Facilities
Transfer trip?
High speed protection
Communications channels
Reactive capability
(Note: Tariff also covers standby gensets that momentary parallel)

14. Simplified Spot Network
Fee Schedules
Qualified Inverter
≤ 10 kW
Qualified DG
Any DG
Simplified
Expedited
Standard
Simplified Spot Network
Application Fee (covers screens)
$3/kW,
minimum $300, maximum $2,500
≤ 3kW $100,
> 3kW $300
Supplemental Review or Additional Review (if applicable)
N/a
Up to 10 engineering hours at $125/hr ($1,250 maximum)
Standard Interconnection Initial Review
Included in application fee (if applicable)
Impact and Facility Study (if required)
Actual cost
Facility Upgrades
O and M
TBD
Witness Test
Actual cost, up to $300 + travel time

15. Simplified Spot Network
Maximum Time Lines
Qualified Inverter
≤ 10 kW
Qualified DG
Any DG
Simplified
Expedited
Standard
Simplified Spot Network
Acknowledge Receipt of Application
(3 days)
Review Application for Completeness
10 days
Complete Review of All Screens
25 days
N/a
Site review 30/90 days
Complete Supplemental Review (if needed)
20 days
Complete Standard Process Initial Review
Send Follow-on Studies Cost/Agreement
5 days
Complete Impact Study (if needed)
55 days
Complete Facility Study (if needed)
30 days
Send Executable Agreement
Done
15 days
Total Maximum Days
40/60 days
125/150 days
40/100 days
Notice/ Witness Test
<1 day with 10 day notice or by mutual agreement
1-2 days with 10 day notice or by mutual agreement
By mutual agreement
1 day with 10 day notice or by mutual agreement

16. Application Process Prior Notice One Point of Contact
Application submittal
Review
Load flow and Voltage constraints
Short Circuit and Protection review
System Modification Review
Agreement

17. Application Information
General (Single) or Specific Form?
Simplified process (Inverter)
Applicant contact information
Location of generator
Proof of UL1741
Others
Application contact information
Machine technical data
Proposed drawings

18. Massachusetts Company Contacts
Boston Edison, Cambridge Electric, Com Electric (NStar Electric)
Frank Gundal
Tel: (781)
Fitchburg Gas & Electric (Unitil)
John Bonazoli P.E.
Tel: (603)
Massachusetts Electric Co. (National Grid)
John J. Bzura, Ph.D., P.E., M.B.A.
Tel: (508)
Western Massachusetts Electric ( Northeast Utilities)
Doug Clarke
Tel:

19. Why is DG Different?

21. How Does DG Affect Distribution Companies?
Protection
Generator Protection
Coordination
Reliability Effects
Planning Procedures
Peak Load Planning
Firm Capacity

22. Interconnection Process Advantages
Standard Process
Easier planning for customer
More Efficient with time
Less time Consuming
Consistent Fees
Known Costs to customer
Known Process for customer

23. Challenges for Distribution Company
General Requirements
Interpretations
Analysis of compliance
Testing Requirements
New devices
Time Lines
Reports
Interconnection agreement

24. Future Efforts Quarterly Collaborative Meetings
Interconnection updates
Numbers of projects and applications
Annual Documentation sharing
Detailed process information
Process Adjustments as needed

25. Upcoming Tariff Document7 2 13 11 3 1
1.0 Introduction
2.0 Responsibility of the Parties
3.0 Process Overview
4.0 Interconnection Req.
5.0 General Operating Req.
6.0 Metering, Monitoring, and Communication
7.0 Responsibility For Costs of Interconnecting a Facility
8.0 Dispute Resolution Process
9.0 Confidentiality Statement
10.0 Insurance Req. 7 1 2 5 3
Exhibit A – Interconnection Service Agreement template
Exhibit B – Third Party Owner Agreement
Exhibit C – Simplified Application
Exhibit D – Expedited/Standard Application
Exhibit E – Supplemental Review Agreement
Exhibit F – Impact Study Agreement
Exhibit G – Facility Study Agreement
Exhibit H – Qualifying Facilities
Discussed already, from Collab. report, or new effort