NPC 2009 IRP Transmission Section by yurtgc548

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									                                   New Projects




West Connect Annual Stakeholders Meeting, February 17,
                2011, Las Vegas, NV
     The SSPG requests that WECC study three specific scenarios in order to
      determine the differential cost of each of the scenarios relative to the
      base case. This will provide insight into the viability of the proposed
      projects and their performance relative to other previously proposed
      projects. The three scenarios requested by SSPG are as follows:

(1)        1000 MW Lassen Municipal Utility District (“LMUD”) trans-Sierra tie
           line with full renewable energy capacity subscription

(2)        (2) 1000 MW Great Basin HVDC trans-Sierra tie line with full
           renewable energy capacity subscription, and

(3)        (3) 2000 MW trans-Sierra capability (combination of Scenarios #1
           and #2) with 80% renewable subscription and 20% economic dispatch
           capacity.
This analysis should produce a least cost view of
resource and transmission investments over the
relevant planning horizon. Due to the high capacity
factors of renewable energy in Northern Nevada,
the short distances between generators and end-
users, the project “right sizing” to allow an
expedited in-service date, and the use of existing
corridors and/or innovative transmission
technologies to facilitate permitting, any of the
three scenarios are likely to be highly competitive
with other larger scope projects that SSPG and
others have requested TEPPC to investigate in their
2010 and 2011 study programs.
SSPG recommends that a base case be developed using current regulator
approved utility integrated resource plans (IRPs) – specifically, yearly
supply side resource and load forecast data. Below is a list of additional
assumptions SSPG believes need to be addressed in the base case.

    Compliance with existing state Renewable Portfolio Standards (RPS)
     and Demand Side Management (DSM) standards
    Includes renewable generators in-service, under construction or with
     state approved Purchased Power Agreements
    Base case to use normal weather load forecast with sensitivity to an
     adverse weather and low load forecast
    Capacity needed and associated costs for balancing intermittent
     resources
    Default assumption of no federal carbon regulation

SSPG is requesting this base case for benchmarking our requested studies
against and to allow a common base to compare previously run cases.
SSPG requests that this case be constructed with the following modifications
to the Reference Case:

   A new PROMOD path be created connecting the Sierra Pacific Power
    Balancing Authority Area (“BAA”) (a new Viewland 345/230 kV substation
    interconnected with the Hilltop-Fort Sage 345-kV line) to the Sacramento
    Municipal Utility District (“SMUD”) BAA (Olinda 230 kV)
   This path would have a 1000 MW capability
   This path is a new double circuit, double bundled 230 kV line
    approximately 130 miles long
   In-service is expected to be 4/01/15.
   Capital investment in the tie line is estimated at $250-$300 million.
   Capital investment in the collector system to source this line is estimated
    to be $400 million (costs are based on the NVE 2010 Conceptual
    Renewable Energy Trans. Plan)
   This path will be 100% subscribed by the following:
    o   33%   wind
    o   33%   Geothermal
    o   20%   CSP
    o   13%   PV
   These resources will have the following capacity factors:
    o   25-30% wind
    o   90% Geothermal
    o   60% CSP
    o   25% PV
   These resources will have the following incremental generation credit:
    o   0% wind
    o   90% Geothermal
    o   90% CSP
    o   70% PV
   These resources are estimated to cost:
    o   o   Wind $105 /MW Levelized Cost of Energy (LCOE)
    o   o   Geothermal $98 /MW LCOE
    o   o   CSP $147 /MW LCOE
    o   o   PV $146 /MW LCOE

Note: Prices are out of the 2010 PUCN RPS proceeding
SSPG requested that this case be constructed with the following modifications to the
   Reference Case:
  A new PROMOD path be created connecting the Sierra Pacific Power BAA (Tracy 345 kV)
   to the SMUD BAA (O’Banion 230 kV)
  This path would have a 1000 MW capability
  This path is a new +400 kV HVDC underground line approximately 125 miles long
    o This path will be 90% subscribed by geothermal
    o with 10% reserved for economic transfers
   These resources will have the following capacity factors:
    o 90% Geothermal – based off summer nameplate
   These resources will have the following incremental generation credit:
    o 90% Geothermal
   These resources are estimated to cost:
    o Geothermal $98 /MW LCOE
       Note: Prices are out of the 2010 Public Utilities Commission of Nevada (PUCN) RPS proceeding
   In-service is expected to be 12/01/2016
   Capital investment in the tie line is estimated at $750 million.
   Capital investment in the collector system to source this line is estimated to be $300
    Million (based on the NVE 2010 Conceptual Renewable Energy Transm. Plan)
SSPG requested that this case be constructed from the
Reference Case and include both of the previously
listed projects compiled into a single case with a total
capacity of 2000 MW from the Sierra Pacific BAA into
the SMUD BAA.

  ◦ Capital investment in the collector system to source this line is
    estimated to be $590 million (based on the NVE 2010
    Conceptual Renewable Energy Transm. Plan)
   SSPG will be conducting the technical electrical
    analysis (power flow and stability) of these three
    cases in parallel with the requested TAS economic
    analysis. SMUD, Sierra Pacific, Transmission Agency
    of Northern California (TANC), and Western have
    each committed to provide staff to perform these
    regional studies.

								
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