irec interconnection workshop oct. 1, 2003 1 interstate renewable energy council interstate...

IREC Interconnection WorkshopOct. 1, 2003

11

Interstate RenewableInterstate RenewableEnergy CouncilEnergy Council

Kansas Interconnection Implementation Workshop

Wichita Airport HiltonChristopher Cook, E3 Energy Svcs.

October 1, 2003


22

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


33

IREC Interconnection ModelConcept

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


44

IREC Interconnection Model - Overview

P3 procedural pathsPSimplified 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)


55

Interconnection Model -Simplified

PInverter based equipment only Inverter must be certified to IEEE 929 and

listed by UL or other NRTL to UL 1741PListing by NRTL qualifies the inverter

as certified for these procedures -- no type testing

PMust pass limited number of screens


66

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


77

Simplified Screens -cont.

PSingle phase on 240V center tap is no more that 20% imbalance of nameplate

rating of transformerPNo transmission level interconnections

POn spot networks, <5% of the spot network's maximum load

PNo area networks


88

Simplified -- Timing and CostsSimplified -- 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


99

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 sidePgenerator cannot cause any protective

devices or customer equipment to exceed 90 percent of the short circuit interrupting capability


1010

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)


1111

Expedited Screens (cont.)

PAggregate generation cannot exceed 10 MW in an area where there are known

or posted transient stability limitationsPgenerator is interconnected as shown:

Primary Distribution Line Configuration Interconnection to Primary Distribution Line

Three-phase, three wireIf 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


1212

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 transformerPNo transmission level interconnections


1313

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.


1414

TimingTiming

• 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


1515

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.


1616

Before Operation

• Local Code official sign off (not necessarily part of the IP)

• Utility can witness IEEE 1547 commissioning test


1717

Expedited IP --FeesExpedited 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


1818

Expedited Procedures -notesExpedited 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.


1919

Standard ReviewStandard 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


2020

Standard Review - procedureStandard 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


2121

Standard Review - IP (cont.)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)


2222

Impact Study elements -dist.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).


2323

Transmission Study digression

• Can usually skip for < 2MW

• Like distribution standard review includes:

• Feasibility

• Impact

• Facilities Study (both trans. and dist.)


2424

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


2525

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


2626

Facilities StudyFacilities 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.)


2727

Final steps - Standard IPFinal 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.


2828

Standard -feesStandard -fees

• Application fee of $100 plus $2 per kWExample: 2 MW generator

pays application fee of $4100

• Gen. also pays for costs of studies and facilities (study costs limited to $100/hr)


2929

Misc. Provisions -All IPsMisc. 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


3030

Dispute ResolutionDispute Resolution

• PUC may designate a technical master w/ binding arbitration powers

• Master may be a university, DOE laboratory or RTO


3131

Standard Form IAsStandard 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


3232

IA detailsIA 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 itssystem if its operations adversely

affect generator operations.


3333

IA details (cont.)IA details (cont.)

• Right to access

• Right to review maintenance and testing logs (except simplified) Mutual liability and indemnification

• Insurance: no specific utility requirement


3434

IA details (cont.)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.


3535

Standard Form ApplicationStandard 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.


The EndStay Up-To-Datewww.irecusa.org

irec interconnection workshop oct. 1, 2003 1 interstate renewable energy council interstate...

Documents

irec interconnection

interconnection pcarve

ferc limit slide

standard process slide

ferc pstandard

e3 energy svcs

simplified screens p

small category of generators