1. IREC Interconnection Workshop Oct. 1, 2003 1 Interstate Renewable Energy Council Interstate Renewable Energy Council Kansas Interconnection Implementation Workshop Wichita Airport Hilton Christopher Cook, E3 Energy Svcs. October 1, 2003

2. IREC Interconnection Workshop Oct. 1, 2003 2 IREC Interconnection Model PDrawn from a variety of sources FERC ANOPR Consensus documents Mass. Collaborative Consensus tariff NARUC model IA Utility tariffs and applications PJM Small resource interconnection procedures

3. IREC Interconnection Workshop Oct. 1, 2003 3 IREC Interconnection Model Concept PStandardize the procedures for interconnection PCarve out a small category of generators that should be easy to interconnect and expedite these through the standard process

4. IREC Interconnection Workshop Oct. 1, 2003 4 IREC Interconnection Model - Overview P3 procedural paths PSimplified for 10kW and less inverter based only (from Mass.) PExpedited for up to 2MW provided equipment certified and meets screening criteria (from Mass. And FERC) PStandard for up to 20MW (used FERC limit)

5. IREC Interconnection Workshop Oct. 1, 2003 5 Interconnection Model -Simplified PInverter based equipment only Inverter must be certified to IEEE 929 and listed by UL or other NRTL to UL 1741 PListing by NRTL qualifies the inverter as certified for these procedures -- no type testing PMust pass limited number of screens

6. IREC Interconnection Workshop Oct. 1, 2003 6 Simplified Screens P<10% (15% for solar) of radial ckt. peak load (at the substation) Solar higher because of coincidence with load P20 kVA limit on single phase connections on shared secondary

7. IREC Interconnection Workshop Oct. 1, 2003 7 Simplified Screens -cont. PSingle phase on 240V center tap is no more that 20% imbalance of nameplate rating of transformer PNo transmission level interconnections POn spot networks, <5% of the spot network's maximum load PNo area networks

8. IREC Interconnection Workshop Oct. 1, 2003 8 Simplified -- Timing and Costs Recommended costs =$0 3 days to acknowledge receipt of application (reject if incomplete) 10 days to run screens 3 days to send IA if passes screens (where IA not required -email notice of approval) 15 days default approval

9. IREC Interconnection Workshop Oct. 1, 2003 9 Expedited Screens (2MW) P<10% (15% for solar) of radial circuit peak load (at the substation) Pgenerator cannot contribute more than l0% to the distribution circuit's maximum fault current on the high side Pgenerator cannot cause any protective devices or customer equipment to exceed 90 percent of the short circuit interrupting capability

10. IREC Interconnection Workshop Oct. 1, 2003 10 Expedited Procedure (2MW) Up to 2MW sized generators (Note: some suggest this is artificial limit -- see screen 10%) Generator and interconnection equipment package or interconnection equip. package must be certified (gen. type must be NRTL approved if equip. package only)

11. IREC Interconnection Workshop Oct. 1, 2003 11 Expedited Screens (cont.) PAggregate generation cannot exceed 10 MW in an area where there are known or posted transient stability limitations Pgenerator is interconnected as shown: Primary Distribution Line Configuration Interconnection to Primary Distribution Line Three-phase, three wire If a 3-phase or single phase generator, interconnection must be phase-to-phase Three-phase, four wire If a 3 phase (effectively grounded) or single- phase generator, interconnection must be line-to-neutral

12. IREC Interconnection Workshop Oct. 1, 2003 12 Expedited Screens (cont.) P20 kVA limit on single phase connections on shared secondary PSingle phase on 240V center tap is no more that 20% imbalance of nameplate rating of transformer PNo transmission level interconnections

13. IREC Interconnection Workshop Oct. 1, 2003 13 Networks - special screens PSpot networks: either <5% of the spot network's maximum load, or generator must utilize a protection to ensure its current flow will not affect the network protective devices (high speed reverse power). PArea Networks: export allowed for inverters only and limited to 10% of the minimum annual load on the network or 500 kW. (Solar measures min. during daylight). PArea networks: For all others (and inverters above limit) generator must utilize reverse power relays that ensure no export of power from the customer's site including inadvertent export that could adversely affect protective devices on the network circuit.

14. IREC Interconnection Workshop Oct. 1, 2003 14 Timing 3 days to acknowledge application receipt 10 days to tell applicant if complete (reject if incomplete w/ list of missing items) & to run screens under Initial Review 5 days to send an IA if passes screens 15 days total (3 weeks) More time for Additional Review

15. IREC Interconnection Workshop Oct. 1, 2003 15 Alternative Procedural Paths If fails screens but utility believes it can be interconnected safely and reliably, then can go forward (includes minor system modifications) If fails screens, can go to Additional Review. Utility sets out what it needs to study and provides cost estimate. Gen. can decide to proceed.

16. IREC Interconnection Workshop Oct. 1, 2003 16 Before Operation Local Code official sign off (not necessarily part of the IP) Utility can witness IEEE 1547 commissioning test

17. IREC Interconnection Workshop Oct. 1, 2003 17 Expedited IP --Fees Total cost = $50 plus $1 per kW Example: 500kW unit pays $550 to complete interconnection Minor system modifications and Additional review at cost -- paid by the generator

18. IREC Interconnection Workshop Oct. 1, 2003 18 Expedited Procedures -notes No external disconnect required (unless one of the NEC required disconnects is located outside) Reason: not a critical safety component; > seldom if ever used; > cost can be high.

19. IREC Interconnection Workshop Oct. 1, 2003 19 Standard Review For all generators not qualifying for expedited treatment Limited to 20MW (5MW KS) Idea is to set out procedural guidelines so that state/national standards can be developed

20. IREC Interconnection Workshop Oct. 1, 2003 20 Standard Review - procedure Scoping meeting/feasibility study Gives generator a quick overview of what can be expected based on the proposed point of interconnection Utility offers to conduct Impact Study and provides a good faith estimate of anticipated cost

21. IREC Interconnection Workshop Oct. 1, 2003 21 Standard Review - IP (cont.) If gen agrees, undertakes impact study including coordination with affected systems If scoping meeting/impact study identifies power flows onto transmission, additional transmission feasibility/impact studies may be required (>2MW)

22. IREC Interconnection Workshop Oct. 1, 2003 22 Impact Study elements -dist. Load Flow Study Short-Circuit Study Circuit Protection and Coordination Study Stability Study (and the conditions that would justify including this element in the Impact Study) Voltage Collapse Study (and the conditions that would justify including this element in the Impact Study).

23. IREC Interconnection Workshop Oct. 1, 2003 23 Transmission Study digression Can usually skip for < 2MW Like distribution standard review includes: Feasibility Impact Facilities Study (both trans. and dist.)

24. IREC Interconnection Workshop Oct. 1, 2003 24 Feasibility Study - transmission High level look for any criteria violations that would suggest Transmission Impact Study is required Expedited version of LGIP examine a limited contingency set Linear analysis tools used to evaluate compliance contingency criteria (SPP). Short circuit calculations

25. IREC Interconnection Workshop Oct. 1, 2003 25 Impact Study - trans. Often waived for generators <5MW If required, expedited version of LGIP Load deliverability only for areas where margins are known to be limited. Stability analysis is generally not performed Short circuit calculations Grounding review

26. IREC Interconnection Workshop Oct. 1, 2003 26 Facilities Study If (either) Impact Study shows facilities needed to address identified impacts, utility provides a Facilities Study agreement (and good faith estimate of cost ±25%) Facilities study identifies in detail the utility equipment needed to interconnect the generator (breakers, conductors, poles, xformers, etc.)

27. IREC Interconnection Workshop Oct. 1, 2003 27 Final steps - Standard IP Costs for facilities and time to construct incorporated into an interconnection agreement. Commissioning test required (IEEE 1547 governs test) Provided commissioning tests satisfactory, interconnected operation approved.

28. IREC Interconnection Workshop Oct. 1, 2003 28 Standard -fees Application fee of $100 plus $2 per kW Example: 2 MW generator pays application fee of $4100 Gen. also pays for costs of studies and facilities (study costs limited to $100/hr)

29. IREC Interconnection Workshop Oct. 1, 2003 29 Misc. Provisions -All IPs Generator must conduct an annual disconnect test where is verifies that it will not island. Manufacturer recommended testing must be followed Utility can inspect at reasonable hours and disconnect if not in compliance

30. IREC Interconnection Workshop Oct. 1, 2003 30 Dispute Resolution PUC may designate a technical master w/ binding arbitration powers Master may be a university, DOE laboratory or RTO

31. IREC Interconnection Workshop Oct. 1, 2003 31 Standard Form IAs Simplified - one page (application and IA on one form) Expedited and Standard -- Interconnection Agreement based on NARUC model with operating rules from Mass. Included

32. IREC Interconnection Workshop Oct. 1, 2003 32 IA details Mutual non-interference: Generator operations will not interfere with utility and utility will not hinder generator operations (voltage, harmonics, etc.) Gen. May disconnected if it is causing problems. Utility agrees to modify its system if its operations adversely affect generator operations.

33. IREC Interconnection Workshop Oct. 1, 2003 33 IA details (cont.) Right to access Right to review maintenance and testing logs (except simplified) Mutual liability and indemnification Insurance: no specific utility requirement

34. IREC Interconnection Workshop Oct. 1, 2003 34 IA details (cont.) Disconnection: Utility may disconnect for maintenance after 7 days notice. Customer may disconnect temporarily w/o notice or permanently after 60 days notice.

35. IREC Interconnection Workshop Oct. 1, 2003 35 Standard Form Application Based on SGC version of FERC Application Limited details required. For Standard review many of the details provided during the process. Specific gen. May not be known at time of interconnection request.

36. IREC Interconnection Workshop Oct. 1, 2003 The End Stay Up-To-Date www.irecusa.org