Transcript Ineterstate Renewable Energy Council Small Generator

Interstate Renewable
Energy Council
Kansas Interconnection
Implementation Workshop
Wichita Airport Hilton
Christopher Cook, E3 Energy Svcs.
October 1, 2003
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IREC Interconnection Model
P Drawn 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
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IREC Interconnection Model
Concept
P Standardize the procedures for
interconnection
P Carve out a small category of generators
that should be easy to interconnect and
expedite these through the standard
process
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IREC Interconnection Model Overview
P 3 procedural paths
P Simplified for 10kW and less inverter
based only (from Mass.)
P Expedited for up to 2MW provided
equipment certified and meets screening
criteria (from Mass. And FERC)
P Standard for up to 20MW (used FERC
limit)
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Interconnection Model -Simplified
P Inverter based equipment only
 Inverter must be certified to IEEE 929 and
listed by UL or other NRTL to UL 1741
P Listing by NRTL qualifies the inverter as
certified for these procedures -- no type
testing
P Must pass limited number of screens
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Simplified Screens
P <10% (15% for solar) of radial ckt. peak
load (at the substation)
 Solar higher because of coincidence with load
P 20 kVA limit on single phase connections
on shared secondary
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Simplified Screens -cont.
P Single phase on 240V center tap is no
more that 20% imbalance of nameplate
rating of transformer
P No transmission level interconnections
P On spot networks, <5% of the spot
network's maximum load
P No area networks
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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
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Expedited Screens (2MW)
P <10% (15% for solar) of radial circuit peak
load (at the substation)
P generator cannot contribute more than l0% to
the distribution circuit's maximum fault current
on the high side
P generator cannot cause any protective
devices or customer equipment to exceed 90
percent of the short circuit interrupting capability
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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)
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Expedited Screens (cont.)
P Aggregate generation cannot exceed 10
MW in an area where there are known or
posted transient stability limitations
P generator is interconnected as shown:
Primary Distribution
Line Configuration
Three-phase, three wire
Three-phase, four wire
Interconnection to Primary Distribution Line
If a 3-phase or single phase generator,
interconnection must be phase-to-phase
If a 3 phase (effectively grounded) or singlephase generator, interconnection must be
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line-to-neutral
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Expedited Screens (cont.)
P 20 kVA limit on single phase connections
on shared secondary
P Single phase on 240V center tap is no
more that 20% imbalance of nameplate
rating of transformer
P No transmission level interconnections
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Networks - special screens
P Spot 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).
P Area 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).
P Area 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
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network circuit.
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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
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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.
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Before Operation
• Local Code official sign off (not
necessarily part of the IP)
• Utility can witness IEEE 1547
commissioning test
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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
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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.
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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
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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
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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)
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Impact Study elements -dist.
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•
•
•
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).
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Transmission Study digression
•
•
•
•
•
Can usually skip for < 2MW
Like distribution standard review includes:
Feasibility
Impact
Facilities Study (both trans. and dist.)
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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
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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
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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.)
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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.
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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)
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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
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Dispute Resolution
• PUC may designate a technical master w/
binding arbitration powers
• Master may be a university, DOE
laboratory or RTO
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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
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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.
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IA details (cont.)
• Right to access
• Right to review maintenance and testing
logs (except simplified) Mutual liability
and indemnification
• Insurance: no specific utility requirement
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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.
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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.
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The End
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