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May 19, 2011

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RENEWABLES PORTFOLIO STANDARD 2011 SOLICITATION BIDDERS CONFERENCE May 19, 2011 Agenda Introduction Regulatory Landscape Solicitation Overview Offer Submittal ... – PowerPoint PPT presentation

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Title: May 19, 2011


1
RENEWABLES PORTFOLIO STANDARD
2011 SOLICITATION BIDDERS CONFERENCE
  • May 19, 2011

2
Agenda
  • Introduction
  • Regulatory Landscape
  • Solicitation Overview
  • Offer Submittal Process
  • Offer Form Highlights
  • Shortlisting Evaluation Methodology
  • Imperial Valley - Sunrise Powerlink
  • PPA Overview
  • Generation Interconnection Study Processes
  • Q A

3
Document Conflicts
  • This presentation is intended to be a summary
    level discussion of the information and
    requirements established in the RFO materials (it
    does not include all of the detailed information
    in the RFO Materials)
  • To the extent that there are any inconsistencies
    between the information provided in this
    presentation and the requirements in the RFO
    Materials, the RFO Materials shall govern

4
Not Part of RPS Solicitation
  • Feed-In Tariff
  • Up to 1.5 MW
  • Pricing based on Market Price Referent (MPR).
    Available without a solicitation.
  • http//www.pge.com/b2b/energysupply/wholesaleelect
    ricsuppliersolicitation/standardcontractsforpurcha
    se/
  • PV PPA Program RFO
  • 50 MW/yr over 5 years
  • First PV PPA RFO in progress next RFO in 2012
  • Renewable Auction Mechanism
  • CPUC decision issued December, 2010
  • Open to all new RPS-eligible resources 20 MW and
    less located in the service territories of any
    California investor owned utility
  • No schedule at this time for RFO issuance.
    Proposed protocol filed February 25, 2011 for
    CPUC approval. The schedule will depend on how
    long it takes for CPUC approval.
  • Combined Heat and Power RFO
  • Open to CHP Facilities greater than 5 MW
    interconnected to the CAISO
  • RFO issuance expected Q3/Q4 2011. Schedule is
    dependent on timing of all regulatory approvals
    of the CHP Program Settlement.

5
Regulatory Landscape
6
Regulatory Landscape Procurement targets remain
uncertain
  • SBX1 2 sets increasing targets over the next
    decade, with CPUC setting targets for
  • years between major milestones
  • For 2011-2013, average of 20 per year across
    compliance period
  • By end of 2016 25
  • By end of 2020 and each year thereafter 33
  • ? Actual procurement requirements for interim
    years (i.e., 2014, 2015, 2017, 2018, 2019) will
    depend on CPUC implementation of the interim
    milestones (OIR R.11-05-005), which are to be
    specified by the end of 2011. Interim targets
    should reflect reasonable progress to next
    target.

Unclear how much needs to be procured to achieve
33 RPS, but PGE expects to focus on the latter
part of the second (2014-2016) compliance period.
7
Regulatory Landscape Procurement Limitations
  • Limitations apply to post-June 1, 2010
    procurement
  • Bucket 1 Requires that by 2020, at least 75 of
    deliveries from contracts executed after June
    2010 must be from resources with
  • a) first point of interconnect with a California
    Balancing
  • authority
  • b) first point of interconnect with distribution
    facilities used
  • to serve end users within a California
    Balancing authority
  • c) scheduled into a California Balancing
    Authority
  • without substituting electricity from
    another source or
  • d) delivering energy that is dynamically
    scheduled into the state

8
Regulatory Landscape Procurement Limitations
(cont'd)
  • Limitations apply to post-June 1, 2010
    procurement
  • Bucket 2 By 2020, no more than 15-25
    deliveries from firming and shaping agreements
    with incremental energy delivered to state
  • Bucket 3 By 2020, no more than 10 from
    Unbundled RECs, firming and shaping agreements
    without incremental energy, any other product not
    meeting delivery requirements for Buckets 1 and 2

Legislation restricts PGEs long-term ability to
use firming and shaping and unbundled RECs for
RPS compliance. PGE willingness to pursue
out-of-state products will depend on how the CPUC
implements detailed rules on how these products
will fit into each bucket.
9
Solicitation Overview
10
RFO Schedule
See Section II of the Solicitation Protocol
11
Independent Evaluator (IE)
  • Primary role of the IE is to
  • Monitor RFO processes to ensure fair and equal
    treatment of all potential counterparties
  • Monitor evaluation processes to ensure PGE has
    implemented methodology as described and that
    bids are treated consistently
  • Ensure utility ownership and PPA offers are
    treated consistently
  • Report on proposed transactions to CPUC when
    filed for CPUC approval
  • The IE performs an independent review of all
    proposals
  • The IE may review all proposal data and monitor
    all negotiations
  • 2011 IE is Arroyo Seco Consulting (Lewis
    Hashimoto)

12
Eligible RPS offers
  • Eligible resources
  • All eligible renewable resources as determined by
    CEC
  • Biodiesel
  • Biomass
  • Conduit hydroelectric
  • Digester gas
  • Fuel cells using renewable fuels
  • Geothermal
  • Hydroelectric incremental generation from
    efficiency improvements
  • Landfill gas
  • Municipal solid waste
  • Ocean wave, ocean thermal, and tidal current
  • Photovoltaic
  • Small hydroelectric (30 MW less)
  • Solar thermal electric
  • Wind

13
Eligible RPS offers (contd)
  • Bundled In-State (Bucket 1)
  • Products
  • As-Available
  • Baseload
  • Dispatchable
  • Location
  • CAISO control area
  • Outside CAISO (e.g. LADWP, IID) Seller should
    specify how energy
  • will be delivered to CAISO
  • REC Firm Energy (Bucket 2)
  • Out-of-State
  • Offer price must include delivery to CAISO No
    busbar deliveries will be accepted
  • PGE has identified preferred delivery profile
  • REC-Only (Bucket 3)
  • In-State or Out-of-State

14
Eligible Offer Structures
  • Power Purchase Agreement (PPA)
  • PPA with Buyout Option
  • Buy-out must be at fair market value
  • Turnkey Ownership - Participants may propose to
    develop, permit, and construct a facility for
    purchase by PGE upon commercial operation
  • Proven technology, non-solar
  • In California
  • Site Offers
  • For development or expansion by PGE

See Section III and Attachments I and J of the
2011 Solicitation Protocol
15
Offer Variations
  • Up to five discrete Offers, with up to four (4)
    variations for each Offer. Offers may vary by
  • Offer Structure PPA vs. PSA
  • Size
  • Commercial Operation Date
  • Delivery Term
  • Seller may bid delivery term of one month up to
    20 years or more
  • Credit Terms
  • Pricing variations (e.g. fixed vs. escalating
    prices)

Participant may submit more than five (5)
Offers (maximum of 10 Offers) if the total MW
offered does not exceed 200 MW - See Section
VIII.C. of the Solicitation Protocol.
16
Offer Submittal Process
17
Offer Submittal
  • Offers must be received by PGE by Thursday, June
    15, 2011 at noon (PPT)
  • Both Electronic and Hard Copies
  • Electronic copies - two (2) flash drives
  • Hard copies - two (2) delivered to
  • RPS Solicitation
  • Renewable Energy Department
  • Pacific Gas Electric Company
  • 77 Beale Street, 25th floor, Mail Code B25J
  • San Francisco, CA 94105

18
Information due June 15
  • Fully Completed Offer Form (Attachment D1 or D2,
    as applicable)
  • FERC Order 717 Waiver (Attachment F)
  • Detailed term sheet (Attachment I or J)
  • Supplier Diversity Questionnaire (Attachment L)
  • CHP Facility Information (Attachment M), if
    applicable

See page 18 of 2011 Solicitation Protocol
19
Information due June 15 (contd)
  • Project Description (includes, but is not limited
    to)
  • Technology and equipment type
  • Environmental issues and permit status
  • Community development plans
  • Contribution to RPS goals
  • Site Control
  • Project Milestone Schedule
  • Transmission/Interconnection
  • Experience and Qualifications
  • Supplemental CEC Funding

See Section VIII.D. of the Solicitation Protocol
20
Additional forms if Shortlisted
  • By August 29th
  • Offer Deposit
  • Confidentiality Agreement (Attachment G)
  • Participant Credit-Related Information Form
    (Attachment E)
  • Request for Taxpayer ID Number (W-9) (Attachment
    N)

See Section XIV of the Solicitation Protocol
21
Offer Form Highlights
22
Offer Form Overview
  • File Version
  • MS Excel 2003 only
  • Other formats will be returned
  • If using newer version of Excel, please save as
    2003
  • Opening File
  • Be sure that you enable macros
  • Help
  • Instruction tab has overall process help on form
  • Specific instructions in the form of cell
    comments or in-cell validation
  • Two Different Offer Forms
  • Attachment D-1 In-State Bundled Resources
  • Attachment D-2 REC Firm Energy and REC Only
  • Currently posted forms are subject to revision by
    the CPUC

23
Changes to Forms
  • Information Requested
  • A few new data points, but
  • Largely unchanged
  • New Format
  • Help to get form right on first submission with
    the validation implemented
  • Goal is to eliminate forms that need to be
    returned for completion
  • Helps us by automating the data retrieval from
    the forms

24
Mandatory Inputs
  • Green Highlighted Cells
  • Every cell with a light green highlight must be
    filled out
  • Input cells without a light green highlight are
    additional information that would be very helpful
    in our evaluation, but not mandatory

25
Mandatory Inputs (contd)
  • Green Highlighted Cells
  • As you fill in information, the green highlight
    will go away

26
Mandatory Inputs (cont'd)
  • There is an indicator at the top of the form
    letting you know how many missing mandatory
    inputs there are at any point during data entry

Once you have filled out all mandatory inputs,
you will get a Complete indicator
27
Mandatory Inputs (cont'd)
  • Rejected File
  • If your form does not have this Complete
    indicator, your submission will be deemed invalid
    and the form will be returned to you.

We have an automated process that will look for
this code. If it is not there, the process will
automatically move your submission to an
incomplete list and your form will be returned to
you.
28
Hidden Cells
  • Blank Space
  • When you first go to the Product Description Tab,
    there appears to be random blank cells
  • These contain data points but are hidden from
    view
  • They will become visible based on selections in
    other data fields
  • Field Locking
  • Fields are locked when hidden and unlocked if
    they come into view
  • Prevents inadvertent data entry

29
New - Technology
  • When you first get to the Technology Section, you
    will see the following
  • These Eligible Renewable Resource (ERR) Type
    selections will require additional data points
    (which will become visible depending on the
    technology selected)
  • Biogas (Fuel Only)
  • Separate Biogas tab will be enabled
  • Solar Photovoltaic
  • Solar PV Technology and Solar Module Detail
  • Depending on the Solar Technology, you may also
    get the request for tracking and orientation
    information
  • Solar Thermal
  • Solar Thermal Technology, Solar Module, and
    Cooling Method (see previous slide for example)

30
New Transmission and Generation
  • When you first get to the Transmission Section,
    you will see the following
  • Interconnecting Utility
  • Four options
  • PGE, SDGE, SCE, and Other
  • If one of the three California IOUs, you will be
    asked for the applicable Transmission Ranking
    Cluster
  • If you select other, you will be asked to provide
    the name of the utility you are interconnecting
    with
  • If Interconnection App Filed
  • Application Status No Study
  • Provide Interconnecting Utility, Transmission
    Cluster, and Queue Number, if available
  • Upgrade Costs will be estimated based on your
    Transmission Cluster
  • Application Status Phase 1 or Phase 2
  • Provide Interconnecting Utility, Queue Number (if
    available), and your Upgrade Costs

31
New Electronic Signature
  • Be sure to electronically sign the form (located
    in the lower right hand corner). These three
    fields are requiredyour form will not validate
    if they are left unanswered.

32
New - Biogas Offers
  • ERR Type
  • Biogas (Fuel Only) as ERR Type
  • Enables Biogas Tab
  • Next tab to the right of the Product Description
    Tab
  • Functionality
  • This tab functions just like the Product
    Description tab
  • Light green highlight cells
  • Hidden cells dependent on other data inputs

33
Pricing and Gen Profile
  • Three Middle Sections Inputs Needed
  • Energy Pricing Tab
  • Contract Capacity Column L
  • Expected Annual Capacity Factor Column M
  • Guaranteed Annual Energy Production Column O
  • Contract Price Column P
  • Gen Profile Tab
  • 12 x 24 Generation Profile for each contract year
  • Follow instructions at the top of the tab
  • Dispatchable Tab
  • If you are offering a dispatchable product, this
    tab will become visible for you to fill out

34
Project Viability Worksheet
  • Three Sections
  • Company / Development Team
  • Project Development Experience
  • EPC Experience
  • Ownership / OM Experience
  • Technology
  • Technical Feasibility
  • Resource Quality
  • Manufacturing Supply Chain
  • Development Milestones
  • Site Control
  • Permitting Status
  • Project Financing Status
  • Interconnection Progress
  • Transmission Requirements
  • Reasonableness of COD

35
Project Viability Worksheet (contd)
  • Mandatory Inputs
  • Light Yellow Select score from list of
    available options
  • List of score options and description supporting
    applicable score is located to the right of the
    score box
  • Light Green Notes supporting each score must be
    provided
  • Tan Location of detailed information in bid
    packet must be provided

All three parts of all twelve (12) scoring items
must be filled out (total of 36 inputs). Once
they are all filled out, you will get the
Complete code (like the Product Description
Tab). If no complete code, the submission is
deemed invalid and the form will be returned to
you.
36
Project Viability Worksheet (contd)
8
Select score from list of options provided.
Our management team members have developed three
new generation facilities totaling 1,500 MW. The
names of the facilities are x (Wind), y (Wind),
and z (Solar PV).
Provide supporting notes for the score.
Note the location in the bid packet where more
detailed information can be found.
See page B-3 of bid for details
Your scoring on this worksheet will provide the
initial inputs we need. Our evaluation team will
review and verify all of the scores.
37
Validation Tab
38
Validation Tab (contd)
39
Attachment D to be updated
  • The CPUC is considering modest changes to the
    Project Viability Calculator. A revised
    Attachment D form containing the modified Project
    Viability Calculator should be available by the
    end of this month.
  • Sellers should make sure to download a final
    Attachment D, with updated Project Viability
    Calculator, and use that form when submitting an
    offer.
  • PGE will notify market participants by email
    when the offer form is updated, and posted on the
    website.

40
Shortlisting Evaluation Methodology
41
Evaluation Criteria
  • Ranking based on combination of Quantitative and
    Qualitative factors
  • Quantitative Evaluation
  • Market Valuation
  • Transmission Adders
  • Qualitative Evaluation
  • Project Viability
  • Portfolio Fit
  • Consistency with RPS Goals

See Section XI and Attachment K of the
Solicitation Protocol
42
Three Step Quantitative Evaluation Process
  • Evaluate all valid offers
  • Determine net market value without transmission
    cost
  • Provides a first ranking
  • Determine transmission cost based on first
    ranking
  • Added to offers cost
  • Second ranking using revised cost values
  • Shortlist chosen from second ranking

43
Market Valuation
  • Market-Based Valuation
  • Value of contract is capacity plus the net of the
    energy benefit and cost
  • Cost is calculated as energy generation times
    offer price times TOD factors for each period
  • The energy benefit is computed using market
    prices
  • Locational Marginal Pricing (LMP) multipliers
    applied to reflect congestion and losses
  • Capacity value is based on
  • The net economic carrying cost of a gas-fired
    power plant
  • Contribution to PGEs Resource Adequacy
    requirements

44
Transmission Adders
  • Generator cost responsibility - Include in bid
    price
  • Direct Assignment Facilities (Gen-tie)
  • Wheeling charges to Delivery Point
  • Customer cost responsibility Considered in bid
    evaluation
  • Network upgrades
  • Cost estimates from
  • CAISO/WDT Interconnection Process (Phase 1/Phase
    2 Studies)
  • Transmission Ranking Cost Report proxy costs

See Section X of the Solicitation Protocol
45
PGE Substations Associated with Renewable
Resource Clusters
  • Clusters for Bid Evaluation Purposes only
  • Clusters do not have to be Points of
    Interconnection
  • Out of area resources
  • NorthRound Mountain
  • SouthMidway
  • East Summit


46
Project Viability
  • All offers will be evaluated and scored using
    modified version of CPUC Project Viability
    Calculator (PVC)
  • Company/Development Team
  • Project development experience
  • EPC experience
  • Ownership and OM experience
  • Technology
  • Technical feasibility
  • Resource quality
  • Manufacturing supply chain
  • Development Milestones
  • Site control
  • Permitting status
  • Project financing status
  • Interconnection progress
  • Transmission requirements
  • Reasonableness of Commercial Operation Date

Sellers are asked to complete PVC in offer forms
47
Portfolio Fit
  • Differentiates offers by the firmness of their
    energy delivery and by their energy delivery
    patterns
  • Firmness (predictability) is preferred
  • Delivery when PGE is short is preferred
  • Flexibility in online date is preferred

48
Consistency with RPS Goals
  • CPUC-stated goals
  • Legislative goals
  • Governors order on biomass
  • Impact on water quality
  • PGEs supplier diversity (WMDVBe)

WMDVBe Women-, Minority-, Disabled Veteran-owned
Business enterprises
See Section VIII of the Solicitation Protocol
49
Consultation with PRG and IE
  • Discuss proposed shortlist and evaluation
    methodology
  • Solicit feedback on whether certain offers should
    be included and whether certain offers should be
    excluded
  • Incorporate feedback and finalize shortlist

50
Imperial Valley Sunrise Powerlink
51
Regulatory Landscape
  • CPUC 2009 RPS Decision (D.) 09-06-018 directed
    the three IOUs to hold special Bidders
    Conferences to increase the likelihood that
    renewable developers propose viable,
    competitively priced projects in the Imperial
    Valley in the 2009 RPS solicitations
  • 2009 Bidders Conference held July 21, 2009
  • Summary of CPUC Decision approving Sunrise
    Powerlink
  • Summary of Sunrise Powerlink project and status
  • Encouragement of offers that could take advantage
    of Sunrise Powerlink
  • References for additional information
  • 2009 RFO Results/Need for Remedial Measures for
    2010
  • Robust response no remedial measures needed
  • Number of bids from Imperial Valley roughly
    proportional to renewable development potential
    throughout the rest of service territory
  • CPUC 2011 RPS Decision (D.11-04-030)
  • Declines to order remedial measures
  • Directs continued special monitoring of Imperial
    Valley offers
  • Encourages continued outreach to Imperial Valley
    bidders

52
Imperial Valley Bidder Information
  • PGE encourages offers from projects within the
    Imperial Valley and projects that may create
    significant flows on Sunrise
  • Projects may be within Imperial Irrigation
    District or directly connected to the CAISO
  • Offers should clearly specify how power will get
    to CAISO, including any transmission arrangements
    with Imperial Irrigation District and firmness of
    energy at CAISO import point

53
Project Status
  • Approximate in service date 6/30/2012
  • The overhead construction on the Sunrise
    transmission started this past quarter
  • SDGE is working closely with the resource
    agencies to resolve a mitigation measure that is
    presenting construction delays
  • Cost unchanged at 1.883 billion
  • Actual spending to date 766.8 million through
    3/31/11
  • 65 of the towers and all of the underground
    cable have been delivered
  • Project Permitting
  • SDGE-Citizens Energy agreement reached a
    development and coordination agreement on May 11,
    2009
  • The USFS issued its Special Use Permit to SDGE
    on December 3, 2010
  • See http//www.sdge.com/sunrisepowerlink/ for
    more information

54
PPA Overview
55
PPA Contracts
  • One form (Attachment H-1) for most PPAs
    (as-available, baseload, dispatchable)
  • Confirm to EEI Master Agreement for short-term
    REC Energy offers (Attachment H-2)
  • REC only (Attachment H-3)

56
PPA Key Commercial Terms
  • PPA designed to require minimal negotiation
  • Contract Price is /MWh (all-in) for all products
    except
  • Dispatchable - /kW-year for capacity, /MWh for
    energy
  • Seller receives Contract Price as adjusted by TOD
    Factors
  • Delivery Point is PNode for those projects
    delivering energy onto the CAISO system
  • Seller commitment to construction start date and
    commercial operation date Provisions for excused
    delay for force majeure, transmission and
    permitting
  • Minimum performance criteria apply to all
    products

57
PPA Key Commercial Terms (cont'd)
  • Certain non-modifiable terms (highlighted in form
    PPA)
  • PGE is Scheduling Coordinator for projects in
    CAISO control area
  • As-Available resources provide weather and
    availability data PGE does forecast and bears
    imbalance risk
  • Baseload resourcesSeller provides schedule and
    bears imbalance risk
  • PGE has economic curtailment rights and pays for
    energy deemed delivered Seller is not paid for
    curtailments called by CAISO, PTO or Reliability
    Coordinator

58
PPA Provisions for Short-term Offers
  • Contract Price is /MWh (all-in)
  • Price may be fixed /MWh or
  • Index price (e.g. NP15, COB) /MWh adjustment
  • Seller may propose price with or without TOD
    factors
  • No bid deposit or exclusive negotiations required
  • Relaxed performance requirements
  • Sellers in CAISO control area to use Attachment
    H-1 See Attachment H-2 and H-3 for firmed and
    shaped and REC-only offers

59
Time of Delivery (TOD) Factors
  • As-Available
  • Payment Contract Price TOD Factor MWh
  • Baseload
  • Payment Contract Price TOD Factor MWh
  • Short-term ERRs may price without TOD

See Section IX of the Solicitation Protocol
60
Key Changes to 2011 Form PPA
  • Excused delays in construction start and
    commercial operation for permitting and
    transmission have been reduced to provide more
    certainty in online date
  • 180 days for transmission and permitting,
    cumulative delays not to exceed 180 days
  • Force majeure remains at 360 days
  • Guaranteed Energy Production (GEP) PPA specifies
    minimum delivery amount
  • 160 of annual contract quantity for wind and
    solar over two years (P-95 for wind eliminated)
  • 90 of contract quantity for baseload (unchanged)

61
Key Changes to 2011 PPA (contd)
  • Curtailment
  • Seller must curtail in response to CAISO, PTO,
    Reliability Coordinator Curtailment
  • Buyer can direct curtailment for a certain number
    of hours per year Seller is paid for energy that
    would have been delivered during curtailment
    period
  • Buyer curtailment includes Buyer failure to
    submit a self-schedule, and Energy Supply Bid
    that is not accepted by CAISO
  • Seller to propose the number of hours, and price
    for curtailment
  • 0-150 Hours Seller must propose price that is
    no more than contract price
  • 151-250 Hours Seller must propose a price, but
    it may exceed contract price
  • 251 Hours Seller may propose price for
    additional of hours of curtailment

62
Key Changes to 2011 PPA (contd)
  • Baseload Resources
  • Seller provides schedule for expected output and
    bears imbalance risk for variations from schedule
    in excess of 1 MW
  • Eliminated requirement for sellers to provide
    meteorological data
  • Supplier Diversity
  • Sellers to make good faith efforts toward meeting
    diverse supplier targets provided with offer
  • Sellers to report on progress toward meeting
    supplier diversity goals

63
Generation Interconnection Study Processes
64
Topics to Cover
  • Overview of Wholesale Generation Interconnection
    Process
  • Transmission Connections
  • Distribution Connections
  • Timelines for Study Processes

65
Wholesale Generator Interconnection Study
Processes
  • Interconnection process must be complete for
    generator to deliver power to grid and meet
    obligations of the contract
  • Generator responsible for timely applications and
    timely completion of applicable process
  • Interconnection Process is NOT part of RFO
    solicitation

66
Overview of Wholesale Generation Interconnection
Process
Technical Studies
Application Processing
Technical Scoping Meeting
Interconnection Agreement
Project Implementation
  • Transmission Interconnections
  • Governed by California Independent System
    Operator Corporation (CAISO) Tariff
  • PGEs transmission interconnections are for 60
    kV and higher
  • All applications must be submitted to the CAISO
  • These slides are per CAISO Tariff which is
    subject to the CAISO
  • Distribution Interconnections
  • Governed by PGEs Wholesale Distribution Tariff
    (WDT)
  • PGEs distribution voltage level is defined as
    facilities operating below 60 kV
  • All applications must be submitted to PGE
  • PGE has filed and received FERC approval for its
    updated WDT

67
Wholesale Interconnection Study Process Criteria
and Timeline
  • Transmission
  • 5 MW Limit
  • 6 Test Screens
  • Distribution
  • 2 MW on 12kV and 3 MW on 21 kV and 5 MW on higher
    voltages
  • 10 Test Screens

Fast Track
Initial and Supplemental Review 120 business days
Independent Study Process
  • Distribution and Transmission
  • Electrical Independence Screens
  • Commercial Operation Date Screen for Transmission
  • No MW limit
  • Financial security requirements

System Impact and Facilities Study 200 business
days for Distribution 240 business days for
Transmission
Cluster Study
  • Default process, no MW limit
  • One annual study
  • Financial security requirements

Phase I and II Studies (420 days)
  • All processes may apply for full capacity.
    Deliverability assessment will be conducted by
    CAISO in CAISOs cluster process.

68
Intermission
69
Q A
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