HomeMy WebLinkAbout5 Electric Facilities Fees Agenda Item # 5
4
Memorandum
To: Board of Directors
From: Steve Hollabaugh, Assistant General Manager
Date: August 2, 2002
Subject: Proposed New Electric Facilities Fees
Electric Facilities Fees have remained unchanged for over 20 years, since March 16,
1982. The 2002 Electric Master Plan, adopted by the Board in July of this year, identifies
the capital improvement projects necessary to provide adequate electric capacity for
anticipated load growth over the next 15 years. A proposed methodology and schedule
of facility fees, based on the new Master Plan, was presented to the Board at the May 15
meeting. Using this same methodology, we have prepared a schedule of fees for
residential and commercial customers for your consideration and possible approval.
The District received a letter from Joe Burns, Executive Director of the Contractors
Association of Truckee Tahoe (GATT) outlining an alternate methodology for setting new
facility fees. We have concerns about their alternate methodology, and we plan to meet
with Mr. Burns and other CATT representatives, to discuss their proposal as soon as a
meeting can be arranged. We will convey the results of those discussions to the Board
at our scheduled meeting.
Recommendation
I recommend the Board of Directors adopt the proposed new Electrical Facility Fee
Schedule.
ELECTRICAL FACILITIES FEES
PROPOSED FEE SCHEDULE
Residential, 1 phase
Existing Proposed
Voltage Panel Size Fee Fee
120/240 100 $200 $1,200
200 $200 1 $1,200
Commercial
1 Phase 3 Phase
Existing Propos d Existing Propo
sed
osed
Voltage Panel Size Fee Fee Fee Fee
120/240 100 $384 $1,200 $665 $1,200
120/240 200 $768 $1,200 $1,330 $2,078
120/240 400 $1,536 $2,400 $2,660 $4,157
120/240 600 $2,304 $3,600 $3,991 $6,235
120/240 800 $3,072 $4,800 $5,321 $8,314
120/240 1000 $3,840 $6,000 $6,651 $10,392
120/240 1200 $4,608 $7,200 $7,981 $12,471
120/240 1400 $5,376 $8,400 $9,312 $14,549
120/240 1600 $6,144 $9,600 $10,642 $16,628
120/208 100 $333 $1,200 $576 $1,200
120/208 200 $666 $1,200 $1,153 $1,801
120/208 400 $1,331 $2,080 $2,306 $3,603
120/208 600 $1,997 $3,120 $3,459 $5,404
120/208 800 $2,662 $4,160 $4,611 $7,205
120/208 1000 $3,328 $5,200 $5,764 $9,007
120/208 1200 $3,994 $6,240 $6,917 $10,808
120/208 1400 $4,659 $7,280 $8,070 $12,609
120/208 1600 $5,325 $8,320 $9,223 $14,411
120/208 2000 $6,656 $10,400 $11,529 $18,013
277/480 100 $768 $1,200 $1,330 $2,078
277/480 200 $1,536 $2,400 $2,660 $4,157
277/480 400 $3,072 $4,$00 $5,321 $8,314
277/480 600 $4,608 $7,200 $7,981 $12,471
277/480 800 $6,144 $9,600 $10,642 $16,628
277/480 1000 $7,680 $12,000 $13,302 $20,785
277/480 1200 $9,216 $14,400 $15,963 $24,942
277/480 1400 $10,752 $16,800 $18,623 $29,098
277/480 1600 $12,288 $19,200 $21,283 $33,255
277/480 2000 $15,360 $24,000 $26,604 $41,569
08/02/2002
CAPITAL IMPROVEMENT PROJECTS
Electric System Master Plan
Introduction and Summary
The Truckee Donner Public Utility District (District) owns and operates an electric
distribution system serving approximately 12,000 residential and commercial customers.
The electric system consists of 4 substations and approximately 164 miles of 12.47kV
distribution lines including about 12 miles of underground distribution cables. During
December 2001, the system supplied 13,400,00 kWH of energy and a peak demand of
29,040 kW. Over the next 15 years, the District's electric energy sales and peak loads are
projected to grow 2 to 3 percent on an annual basis. This Master Plan therefore reflects a
15-year planning period, for the calendar and fiscal years 2003 through 2017.
Capital improvements to the District's system will be required to provide for the
projected load growth over the 15-year planning period,increase system capacity, and
expand or maintain the operating flexibility of the electric system. Recommended capital
improvements include some of the previously identified projects in the 1992 Electric
Master Plan that have not yet been constructed. The proposed distribution system and
substation capital improvement projects are listed in Table 1 and depicted in Exhibit 1.
After construction of these proposed improvements, the District's system will be capable
of serving projected loads through the year 2017 without low voltage or conductor
overloads during peak loads at normal and contingency conditions.
Cost estimates have been prepared for the proposed capital improvements to the District's
electrical distribution system. The dollar amounts listed below and in Table 1 are based
on unit costs prepared for varying types of underground, overhead, and substation
construction and include allowances for construction (labor and materials), engineering
services, overheads, and contingencies. All costs are in 2002 dollars. The following list
summarizes the annual cost of the proposed improvements by fiscal year:
Year Cost
2003 $156,300
2004 $151,500
2005 $482,900
2006 $402,000
2007 $362,900
2008 $908,700
2009 $340,400
2010 $282,600
03/29/02 Page 1 of 4
2011 $494,500
2012 $535,900
2013 $946,100
2014 $774,800
2015 $708,700
2016 $1,957,100
2017 $886,000
15-Year Total $9,390,400
The average cost to the District to implement the proposed capital improvements is
approximately$626,000 per year.
Cost Estimate Methodology
Unit construction cost estimates were developed for varying types of new overhead and
new underground distribution line construction on a per-mile basis, for the upgrade of
Donner Lake Substation, and for a new substation to serve District loads in the Glenshire
area. Cost estimates include allowances for construction, engineering services, overheads,
and contingencies. Construction costs include materials, labor, and other services, such as
outside contractors, necessary for each type of construction. Material and labor costs
reflect the District's current standard construction costs updated with year 2002
overheads. The civil site work costs for trenching and excavation were based on actual
bid costs received from area contractors for similar District projects completed within the
last three years. An allowance of 20 percent of construction costs has been included to
cover construction contingences associated with each cost estimate. An additional
allowance of 20 percent of construction costs has been included to cover engineering,
legal, administrative costs. Unit construction costs are listed and summarized by type of
construction in Table 2.
The costs of overhead distribution line construction were estimated using 397MCM size
conductors with 160-foot spans between pole locations, for a total of 34 poles per mile on
average. Pole size was assumed to be the District's standard 45 foot, class 2 Douglas Fir
treated wood pole. Variations to overhead line construction included modifying the
number of angles and deadend poles per mile (Table 2 —heavy, and light feeder
construction). A separate estimate was prepared for performing a reconductor project on
an existing overhead distribution line where the conductors are replaced with a larger,
higher capacity conductor. In addition, an estimate was also prepared for underbuilding a
distribution circuit on Sierra Pacific's existing 60kV wood pole transmission line.
The costs of underground distribution line construction were estimated using 500MCM
and 1/0 AWG size aluminum conductor medium voltage cables, placed in 6-inch conduit
for mainline circuits and 4-inch conduit for distribution loops. Conduit runs were limited
to a maximum of 500 feet between pulling locations in accordance with good cable
03/29/02 Page 2 of 4
installation practices. Variations to underground line construction included modifying the
number of vaults, switches,junction enclosures, road crossings, and transformers per
mile (Table 2 -heavy, medium, light and express feeder construction). In addition, a
special estimate was prepared for those locations were the District has previously
installed conduit in joint trenches with other utilities in anticipation of future use.In these
areas, only the installation of electrical equipment and vaults are required to complete the
underground system (fable 2 - special feeder construction).
The cost to upgrade Donner Lake Substation includes the installation of new
transformers, voltage regulators, high and low side distribution bus, and the removal of
old equipment. Site work costs such as a new entrance road,foundations, and a
grounding system are also included. It is proposed to increase the existing capacity of
Donner Lake substation from 3.75MVA to 15MVA,the same capacity as the District's
other three substations. This will increase the District's overall reliability by allowing
load transfers among substations upon the loss of any one substation during an
emergency condition.
The District's electrical distribution system in the Glenshire area is presently served via a
primary meter from Sierra Pacific's Glenshire substation at a voltage of 14.4kV (this is
Sierra Pacific's standard distribution system voltage). It is proposed that the District
extend Truckee Circuit 1 along Glenshire Drive and install a small substation to convert
from the District's standard 12.47kV system voltage to 14.4kV. The new Glenshire
substation would consist of a 2.5MVA, 12.47kV to 14.4kV transformer, and associated
switches, disconnects, transformer foundation, grounding system, fence, and entrance
road to be constructed on property owned by the District and located along Glenshire
Drive near Berkshire Circle. The construction of this substation and extension of Truckee
Circuit 1 to Glenshire will give the District the capacity to serve customers in the event of
a Sierra Pacific system outage. In the past, these outages have included transmission
system, distribution system, and substation outages upstream of the District's current
primary metering point, which are all outside of the District's control to restore service.
Project Justifications
Table 1 includes a column where the justifications of individual projects are briefly
noted. These justifications are grouped into the following categories and are briefly
explained below:
• Upgrade main line to 397MCM
• Provide full capacity feeder ties
• Provide capacity for looping
• Load growth/transfer capacity
• Capacity addition to reduce dependence on SPPC
• Increase Feeder Outlet Capacity
03/29/02 Page 3 of 4
Upgrade main line to 397MCM: The District is currently using 397MCM size conductors
for main line feeder overhead circuit configuration (main line refers to the main or
backbone 3 phase feeder sections which carry the bulk of the load on a feeder circuit).
This conductor size allows feeder loading to not exceed 50 percent of the conductor
ampacity rating under normal maximum operating conditions. This allows for up to 100
percent loading during contingency or emergency operating conditions such as picking
up the load from an adjacent feeder.
Provide fidl capacity feeder ties: The District's distribution feeders should have back-up
ties to other feeders, including feeders from other substations. Providing sufficient full
capacity feeder ties to feeders from other substations is necessary to cover the loss of any
one substation during an emergency condition and to provide operational flexibility for
equipment maintenance and repair.
Provide capacity for looping: Currently, some of the District's main distribution feeders
are a radial only configuration. This means that for an outage on a feeder, all customers
downstream of the outage point will be without power. The construction, where possible,
of loops within individual feeders allows the District during emergency conditions to
backfeed customer areas and remove from service the smallest possible line sections,
affecting the smallest number of customers, while repairs are made.
Load growth transfer capacity: Adequate reserve substation transformer capacity must be
provided to serve District loads with any one substation out of service. See also the
discussion about the Donner Lake Substation in the Cost Estimate Methodology section
above.
Capacity addition to reduce dependence on SPPC: The construction of the new Glenshire
Substation will give the District the capacity to serve customers in the event of a Sierra
Pacific system outage. See the discussion about the new Glenshire Substation in the Cost
Estimate Methodology section above.
Increase Feeder Outlet Capacity: Feeders out of substations should be placed
underground using 750MCM size conductors where practical. Individual feeder
capacities will be increased and the station reliability will be improved due to reduced
exposure to outages associated with exposure to trees, animals, vehicles, and weather
related phenomena,This will allow trees and shrubs to be planted around the substation
perimeter, virtually camouflaging the station from the public's view.This will not only
be aesthetically pleasing but may also reduce vandalism.
In summary, this master plan provides for adequate capacity to meet existing and
projected District loads in a reliable manner. This is achieved because the District's
system will be flexible enough to be operated as necessary to handle project loads under
normal and emergency conditions to keep the highest possible number of customers in
service. The proposed improvements will provide adequate capacity and reliable service
to District customers through the year 2017 while providing for projected load growth.
03/29/02 Page 4 of 4
TABLE 1
SUMMARY OF CAPITAL IMPROVEMENT PROGRAM PROJECTS
Electric System Master Plan -2002
Const. Unit Construction Cost
Year Substation/Feeder Description of Project(1) Justification(2) Code(3) Quantity Units Cost(4) Project Subtotal
2003 Martis Valley 1 Reconductor existing 3ph overhead Upgrade main line to 397MCM OH-RC 1,600 feet $27.91 $44,661
line from Highway 267 to the intersection
of Ponderosa and Palisades Dr.
Martis Valley 1 Reconductor existing tph overhead line Provide full capacity feeder tie OH-RC 4,000 feet $27.91 $111,654
to 3 ph adjacent to Jeffrey Pine from the to MV2
intersection of Ponderosa and
Palisades Dr.to Highway 267 $156,300
2004 Truckee 5 Reconductor existing 1 ph overhead line Provide looping capacity for T5 OH-RC 3,500 feet $27.91 $97,697
to 3 ph through Sugar Pine Estates
along Alder Drive to Alder Creek Rd.
Truckee 5 Construct new 3 ph overhead line along Provide looping capacity for T5 OH-HF 1,300 feet $41.36 $53,773
Alder Creek Rd.from the intersection of
Alder Drive to Highway 89 and the
Prosser Lakeview area $151,500
2005 Tahoe Donner 3 Reconductor existing 3ph overhead line Upgrade main line to 397MCM OH-RC 6,600 feet $27.91 $184,229
along Northwoods Blvd.from the
intersection of Northwoods and
Northwoods to Donner Pass Rd.
Truckee 5 Reconductor existing 3ph overhead line Upgrade main line to 397MCM OH-RC 10,700 feet $27.91 $298,674
from the intersection of Alder Dr.and
Beacon Rd.to Pannonia Ranchos via
Alder Dr., Rainbow Dr. and
Prosser Dam Rd. $482,900
2006 Tahoe Donner 1 &2 Reconductor existing 3ph overhead line Upgrade main line to 397MCM OH-RC 14,400 feet $27.91 $401,953
along Northwoods Blvd.from the
substation to Muhlebach and from the
substation to Ramshorn $402,000
08/02/2002 Final Draft Page 1 of 6
TABLE 1
SUMMARY OF CAPITAL IMPROVEMENT PROGRAM PROJECTS
Electric System Master Plan -2002
Const. Unit Construction Cost
Year Substation/Feeder Description of Project(1) Justification(2) Code(3) Quantity Units Cost(4) Project Subtotal
2007 Tahoe Donner 3 Reconductor existing 3ph overhead line Upgrade main line to 397MCM OH-RC 4,400 feet $27.91 $122,819
along Skislope Way from the
substation to Herringbone Dr.
Martis Valley 3 Reconductor existing 3ph overhead line Upgrade main line to 397MCM OH-RC 5,600 feet $27.91 $156,315
along Deerfield Dr.from Highway 89S
to Coldstream Rd.
Martis Valley 3 Reconductor existing 3ph overhead line Upgrade main line to 397MCM OH-RC 3,000 feet $2T91 $83,740
from the intersection of Deerfield Dr.
and Coldstream Rd.to the end of the
circuit at Northwoods and
Donner Pass Rd. (includes crossing
of 1-80 near the A . Inspection Station) $362,900
2008 Donner Lake Upgrade Substation from 3.75 to 15MVA Load growth/transfer capacity Sub-DL 1 each $908,683 $908,683
Substation $908,700
2009 Tahoe Donner 3 Reconductor existing 3ph overhead line Upgrade main line to 397MCM OH-RC 5,700 feet $27,91 $159,107
along Skislope Way from the
intersection of Skislope and
Herringbone Dr.to Teton Way
Truckee 5 Reconductor existing tph overhead line Provide full capacity feeder tie OH-RC 4,500 feet $27.91 $125,610
to 3 ph through Pannonia Ranchos to T6
from the intersection of Prosser Dam
Road and Mt. Roseview Dr.along
Mt. Roseview Dr.and Dove Terrace
Truckee 5 Convert existing 1 ph underground tap Provide full capacity feeder tie UG-SP 1,200 feet $46.43 $55,714
line to 3 ph configuration between to T6
Dove Terrace and Union Mills Rd.
the road to CHP scales) $340,400
08/02/2002 Final Draft Page 2 of 6
TABLE 1
SUMMARY OF CAPITAL IMPROVEMENT PROGRAM PROJECTS
Electric System Master Plan -2002
Const. Unit Construction Cost
Year Substation/Feeder Description of Project(1) Justification(2) Code(3) Quantity Units Cost(4) Project Subtotal
2010 Truckee Substation Convert existing overhead feeder Increase Feeder Outlet Capacity UG-MF 1000 each $161.82 $161,818
getaway circuits to an underground
configuration for feeder circuits T2,
T3, and T4
Truckee Substation Convert existing overhead feeder Increase Feeder Outlet Capacity UG-SP 1200 each $46.43 $55,714
getaway circuits to an underground
configuration via existing 6"conduit
for feeder circuit T1
Tahoe Donner 3 Extend 3 ph feeder under SPPC's Provide full capacity feeder tie UG-SP 500 feet $46.43 $23,214
60kv line for connection to TD1 to TD1
via existing 6"conduit installed in 2000
Tahoe Donner 3 Reconductor existing 1 ph overhead line Provide full capacity feeder tie OH-RC 1,500 feet $27.91 $41,870
to 3 ph along Skislope Way from to TD1
Teton to Davos and along Davos to
Northwoods Blvd. $282,600
2011 Donner Lake 3 Construct new feeder to be underbuilt Provide full capacity feeder tie OH-UB 11,500 feet $43.00 $494,511
on SPPC's 60kV line that connects circuit between DL and
Donner Lake and Tahoe Donner TD substations
substations $494,500
2012 Donner Lake 2 Reconductor existing 1 ph overhead line Provide full capacity feeder tie OH-RC 1,600 feet $27.91 $44,661
to 3 ph along So. Shore Dr.from to DL1
14036 So. Shore Dr.to Donner St. Park
Tahoe Donner 1 &2 Reconductor existing 3ph overhead line Upgrade main line to 397MCM OH-RC 17,600 feet $27.91 $491,276
along Northwoods Blvd. from
Muhlebach to Ramshorn $535,900
08/02/2002 Final Draft Page 3 of 6
TABLET
SUMMARY OF CAPITAL IMPROVEMENT PROGRAM PROJECTS
Electric System Master Plan-2002
Const. Unit Construction Cost
Year Substation/Feeder Description of Project(1) Justification(2) Code(3) Quantity Units Cost(4) Project Subtotal
2013 Donner Lake 1 Convert existing 1 ph underground tap Provide full capacity feeder tie UG-XF 7,100 feet $94.73 $672,574
line to 3 ph configuration through to DL2
Donner State Park from Donner Pass
Rd.to the end of South Shore Dr.
Martis Valley 3 Reconductor existing 3ph overhead line Upgrade main line to 397MCM OH-RC 9,800 feet $27.91 $273,552
along West River St.between
Highway 267 and Deerfield Dr. $946,100
2014 Martis Valley 2 Extend underground 3 ph feeder along Provide looping capacity for MV2 UG-LF 2,600 feet $115.87 $301,253
the new section of Soaring Way between
the end of the existing Soaring Way
and Joerger Rd.
Martis Valley 4 Extend 3 ph underground feeder from Provide full capacity feeder tie UG-SP 1,600 feet $46.43 $74,286
Martis Valley Well area along Joerger Rd. to MV2
to TSD offices via existing 6"conduit
Truckee 1 Extend 3 ph feeder underground along Capacity addition to reduce UG-SP 8,600 feet $46.43 $399,287
Glenshire Dr.and through the dependence on SPPC
Glenshire bridge via existing 6" conduit
installed in 2000 $774,800
2015 Truckee 1 & New Glenshire Substation,2.5MVA, Capacity addition to reduce Sub-Glen 1 each $152,552 $152,552
Glenshire 1 12.5/14.4kV, located along dependence on SPPC
Glenshire Drive near Berkshire Circle
Martis Valley 4 Extend 3 ph underground feeder along Provide full capacity feeder tie UG-LF 4,800 feet $115.87 $556,159
Joerger Rd.from the TSD offices to MV2
to Highway 267 $708,700
Oal0212002 Final Draft Page 4 of 6
TABLE 1
SUMMARY OF CAPITAL IMPROVEMENT PROGRAM PROJECTS
Electric System Master Plan-2002
Const. Unit Construction Cost
Year Substation/Feeder Description of Project(1) Justification(2) Code(3) Quantity Units Cost(4) Project Subtotal
2016 Truckee 5 Extend 3 ph underground feeder along Provide full capacity feeder tie UG-HF 9,500 feet $206.01 $1,957,093
Pioneer Trail Rd.from the intersection to TD3
of Pioneer Trail Rd.and Thayer Dr.to
Northwoods Blvd.(Pioneer Trail Rd. is
the proposed new third access road
into Tahoe Donner) $1,957,100
2017 Truckee 4 Extend 3 ph underground feeder along Provide full capacity feeder tie UG-HF 3,850 feet $206.01 $793,137
Bridge St. and Euer Valley Rd.from the to T5
intersection of Bridge and Jibboom
Streets in downtown Truckee to
Pioneer Trail Rd. (new third access road
into Tahoe Donner)
Martis Valley 3 Extend feeder to serve end of MV3 at Provide full capacity feeder ties UG-SP 2,000 feet $46.43 $92,857
Northwoods and Donner Pass Rd. to T4 and TD3
via existing conduit installed through
new DPR bridge over 1-80. Remove
existing overhead crossing of 1-80
adjacent to A . Inspection Station $886,000
15-Year Total Cost $9,390,400
08/02/2002 Final Draft Page 5 of 6
TABLE 1
SUMMARY OF CAPITAL IMPROVEMENT PROGRAM PROJECTS
Electric System Master Plan-2002
Contt. Unit Construction Cost
Year Substation/Feeder Description of Project(1) Justification(2) Code(3) Quantity Units Cost(4) Project Subtotal
Cost Subtotals by Year
Notes: Year Cost
1. See Exhibit 1 for a depiction of project locations. 1 2003 $156,300
2. See Master Plan report for an explanation of project justifications. 2 2004 $151,500
3. See Table 2 for a description of construction codes. 3 2005 $482,900
4. Costs are in 2002 dollars and include allowances for construction contingencies of 20 percent 4 2006 $402,000
and allowances for engineering administration of an additional 20 percent. 5 2007 $362,900
6 2008 $908,700
7 2009 $340,400
8 2010 $282,600
9 2011 $494,500
10 2012 $535,900
11 2013 $946,100
12 2014 $774,800
13 2015 $708,700
14 2016 $1,957,100
15 2017 $886,000
15-Year Total Cost $9,390,400
08/02/2002 Final Draft Page 6 of 6
TABLE 2
COST DETAIL SUMMARY
Electric System Master Plan-2002
Type of Cost
Construction Configuration Description Code $/Mile $/Foot
Overhead Heavy Feeder 3 Phase, 397AAC, 45/2 poles, 160 ft. spans OH-HF $218,400 $41
8 tangent, 20 light angle, &6 deadend poles per mile
Light Feeder 3 Phase, 397AAC, 45/2 poles, 160 ft. spans OH-LF $199,800 $38
22 tangent, 8 light angle, &4 deadend poles per mile
Reconductor 3 Phase, 397AAC, 45/2 poles, 160 ft. spans OH-RC $147,400 $28
replace 25% of existing poles&all crossarms
Underbuild SPPC 3 Phase, 397AAC, 50/113 poles, 240 ft. spans OH-UB $227,000 $43
6 tangent, 12 light angle, &2 deadend poles per mile
Underground Heavy Feeder 3 Phase, 500MCM cable, 5 vaults, 5 switches, 5 JEs, UG-HF $1,087,700 $206
10 road crossings, 5 - 3ph transformers with 10 services,
and 10 - 1 ph transformers with 20 services per mile
Medium Feeder 3 Phase, 500MCM cable, 3 vaults, 8 switches, 3 JEs, UG-MF $854,400 $162
5 road crossings, 3 -3ph transformers with 5 services,
and 5 - 1 ph transformers with 10 services per mile
Light Feeder 3 Phase, 500MCM cable, 9 vaults, 1 switches, 2 JEs, UG-LF $611,800 $116
2 road crossings, 2 - 3ph transformers with 4 services,
and 2 - 1 ph transformers with 4 services per mile
Express Feeder 3 Phase, 500MCM cable, 9 vaults, 2 road crossings, UG-XF $500,200 $95
no transformers, switches, or junction enclosures
Special Feeder 3 Phase, 500MCM cable, 9 vaults, 2 road crossings, UG-SP $245,100 $46
no transformers, switches, or junction enclosures
Existing conduit, only vault installation required.
Substations Description Code Cost
Donner Lake Upgrade capacity to 15MVA Sub-DL $908,700
Glenshire Install 2.51VIVA, 12.5/14.4kV transformer to serve Sub-Glen $152,600
Glenshire area from Truckee Circuit 1
Notes:
1. Costs are in 2002 dollars.
2. Costs include allowances for construction contingencies of 20 percent and allowances for engineering and
administration of an additional 20 percent.
08/02/2002 Final Draft
ELECTRICAL FACILITIES FEES
PROPOSED FEES AND CALCULATION METHODOLOGY
Electric Master Plan -Final Draft
Summary of Capital Improvements Program Projects-2003 to 2017
15 Year Total Cost $9,390,400
Average $/Year $626,027
Residential kWh compared to Total System kWh- 1996 to 2001
Res—kWh 54.04% average
Res_kWh* 53.87% average -after deleting high and low values
New Residential Customer Increase per Year- 1996 to 2001
Res_Cust 300 average
Res_Cust' 272 average -after deleting high and low values
Facility Fees Proposed Calculation - Residential
Res. Facilities Fee= [ (Average$/Year) ' (Res—kWh)J/Res_Cust
Res. Facilities Fee $1,129.13
Res. Facilities Fee` $1,239.95 (using data with high and low values deleted)
$1,200 Proposed Residential Facilities Fee
Since typical residential panel size is 200amps, a "dollar per amp" value can be calculated which
is$6 per amp. Facilities fees for the wide range of commercial type panels with varying voltages and
amperages can be calculated using this$6 per amp figure as the basis for setting the fees.
Proposed Basis for Setting Commercial Facilities Fees:
$6 Dollars per Amp
ELECTRIC SALES STATISTICS SUMMARY
1 2 3 4 5 6 7 8 9 10 11 12
KWH JANUARY FEBRUARY MARCH APRIL MAY JUNE JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER TOTAL
SUMMARY
1996 11,360,504 10,199,292 10,418,774 9,131,687 8,031,397 8,119,066 8,021,250 8,338,111 8,350,106 8,012,396 8,431,384 9,749,143 108,163,110
1997 12,865,046 11,045,900 10,307,853 9,569,675 8,861,499 7,837,335 8,128,952 9,101,791 8,178,205 8,335,883 8,190,956 9,970,258 112,393,353
1998 13J41,312 10,790,758 10,928,946 10,128,639 9,158,129 8,781.699 8,961,279 8,894,230 8,882,058 8,457,932 8,532,042 10,753,749 117.410.773
1999 13,389,870 11,455,252 11,923,492 11,227,737 9,206,910 8,660,421 9,237,633 9.556,000 9,421,835 8,786,354 8,875,043 11,026,891 122,767,438
2000 12,839,977 11,477,479 11,377,332 10,795,959 9,170,656 9,627,987 9,807,163 9,502,180 10,279,134 8,566,394 9,511,297 13,245,365 126,200,923
2001 13,126,702 11,702,421 11,959,074 9,921,846 9,473,300 8,340,900 9,138,652 9,855,501 9,904,876 Q454,393 9,375,987 11,228,523 122,482,175
KWH
RESIDENTIAL
1996 7,041,135 5,956,691 6,244,451 5,203,341 4.237,179 3,971,225 3,862,740 3,816,088 3,836,695 3,724.285 4,446,444 5.672,453 58,012,727
1997 7,879,018 6,557,232 6,012,442 5,349,416 4,689,385 3,902,135 4,066,374 4,129,964 3,849,492 3,988,737 4,327,971 5,787,816 60,539,982
1998 8,450,413 6,459,965 6,605,339 5,988,897 5,092,843 4,736,371 4,454,747 4,087,367 4,087,131 4,142,369 4,716,343 6,513.791 65,335,576
1999 8,388,749 7,024,681 7,108,636 6,655,644 5,101,913 4.468,760 4,426,389 4,355,696 4,376,942 3S71,791 4,609,934 6,491,887 66,981,022
2000 7,831,451 6,992,623 6,910.299 6,059,900 4,968,650 4,652.109 4.420,330 4,292,229 4,602,468 3,960,239 5,232,744 7,516,878 67,439,920
2001 8,026,096 7,096,973 7,223,116 5,676,441 5,028,531 4,050,942 4,077,741 4,445,392 4,311,536 3,861,834 4,720,236 6,495,897 65,014,735
%Residential KWH to Total Summary
1996 61,98% 58.40% 59.93% 56,98%# 52.76% 48,91% 48.16% 45.771/6 45,95% 46,48% 5274% 58.18% 53.631%
1997 61.24% 59.36% 58.33% 55.909%# 52.921. 49.79% 50.02% 45.38% 47.07% 47.85% 52.84% 5S05% 53.86%
1998 64.30% 59,87% 60.44% 59.13%# 55,61% 53.93% 49,71% 45.961/6 46,02% 48.98% 5528% 60.57% 55,65%
1999 62.65% 61,32% 59.62% 59.28%# 55,41% 51.60'/ 47.92% 45.58% 46.485/6 45,20% 51,94% 5887% 54.56%
2000 60.99% 60.92% 60,74% 56.13%# 54,18% 48.32% 45.07% 45.17% 44.77% 46.23% 55,02% 56.75% 53.44%
2001 61.14% 60.65% 6040% 57,21%# 53.08% 48.57% 44.62% 45,11% 43.53% 45.68% 50.34% 57.85% 53.08%
average 54.04%
average(delete high and IOW values) 53.87%
1 2 3 4 5 6 7 8 9 10 11 12
CUSTOMER CNT JANUARY FEBRUARY MARCH APRIL MAY JUNE JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER TOTAL
SUMMARY
1996 9522 9573 9591 9609 9626 9670 9716 9746 9763 9795 9610 9,828
1997 9862 9864 9870 9B86 9912 9953 9994 10011 10031 10089 10100 10,129 301
1998 10140 10142 10153 10204 10190 10023 10054 10089 10116 10154 10164 10,190 61
1999 10222 10232 10250 10258 10291 10321 10372 10397 10429 10478 10510 10,534 344
2000 10557 10565 10583 10591 10625 10655 10705 10734 10769 10823 10834 10,827 293
2001 11105 11057 11073 11159 11177 11219 11289 11373 11382 11387 11421 11,441 614
CUSTOMER CNT
RESIDENTIAL
1996 8492 8504 8533 8547 8554 8581 8607 8632 8664 8694 8713 8,740
1997 8774 8783 8788 8795 8812 8837 8869 8880 8906 8960 8971 9,013 273
1998 9037 9049 9059 9109 9091 8930 8944 8979 9008 9039 9050 9,080 67
1999 9118 9120 9128 9136 9151 9164 9196 9215 9244 9289 9321 9,352 272
2000 9385 9402 9420 943E 9455 9480 9507 9522 9555 9612 9642 9.623 271
2001 10021 9973 9989 9990 10005 10045 10089 10166 10173 10177 10213 10,238 615
average 300
average(delete high and low values) 272
ELECTRICAL FACILITIES FEES
COMPARISON OF PROPOSED vs. EXISTING FEES
Residential, 1 phase
Existing Proposed
Voltage Panel Size Fee Fee
120/240 100 1 $200 $1,200
200 $200 $1,200'
Although the proposed fee reflects a significant percentage increase, it is readily apparent that
the existing fee is so small as to be ineffectual in offsetting the cost of capital improvements
required due to residential loads over the years. The proposed fee is, we believe, a fair and
reasonable amount, that more accurately reflects the residential sector's responsibility to the District.
Commercial
1 Phase 3 ...Phase
Existing Proposed Existing Proposed
Voltage Panel Size Fee Fee Fee Fee
120/240 100 $384 $1,200 $665 $1,200
120/240 200 $768 $1,200 $1,330 $2,078
120/240 400 $1,536 $2,400 $2,660 $4,157'
120/240 600 $2,304 $3,600 ' $3,991 $6235
120/240 800 $3,072 $4,800 $51321 $8,314
120/240 1000 $3,840 $6,000 $6,651 $10,392
120/240 1200 $4,608 $7,200 $7,981 $12,471
120/240 1400 $5,376 $8,400 $9,312 $14,549
120/240 1600 $6,144 $9,600'; $10,642 $16628
120/208 100 $333 $1,200 $576 $1,200
120/208 200 $666 $1,200 $1,153 $1,801
120/208 400 $1,331 $2,080 $2,306 $3,603';
120/208 600 $1,997 $3,120 $3,459 $5,404
120/208 800 $2,662 $4,160 $4,611 $7,205
120/208 1000 $3,328 $5,200 $5,764 $9,007
120/208 1200 $3,994 $6,240 $6,917 $10808
120/208 1400 $4,659 $7,280 $8,070 $12609
120/208 1600 $5,325 $8,320 $9,223 $14,411
120/208 2000 $6,656 $10,400' $11,529 $18,013
277/480 100 $768 $1,200; $1,330 $2,078
277/480 200 $1,536 $2,400' $2,660 $4,157
277/480 400 $3,072 $4,800 $5,321 $8,314
277/480 600 $4,608 $7,200 $7,981 $12,471
277/480 800 $6,144 $9,600 $10,642 $16,628
277/480 1000 $7,680 $12,000 $13,302 $20,785
277/480 1200 $9,216 $14,400 $15,963 $24,942
277/480 1400 $10,752 $16,800 $18,623 $29;098
277/480 1600 $12,288 $19,200 L $21,283 $33,255
277/480 2000 $15,360 $24,000 1 $26,604 1 $41,569
Commercial % Fee Increase 56.3% 56.3%
Existing commercial fees have remained unchanged for 20 years. A 56.3% increase after 20 years
is equivalent to an annual increase in fees of 2.25% applied for each of the past 20 years.
ORDINANCE NO. 82G91
OF THE
y TRUCKEE DONNER PUBLIC UTILITY DISTRICT
RESCINDING RESOLUTION NO. 7709 AND
ESTABLISHING ELECTRIC CONNECTION AND FACILITIES FEES
; . WHEREAS, the cost of providing electric facilities has increased sharply
during the past several years;
NOW, THEREFORE, BE IT ENACTED by the Board of Directors of the Truckee
Donner Public Utility District as follows:
1. Effective with the effective date of this Ordinance, all
prior resolutions and ordinances pertaining to Electric De-
partment connection and facilities fees are rescinded and of
no further force and effect.
2. That Exhibit "A", Electric Connection and Facilities
Fees, a copy of which is attached 'hereto, is hereby adopted.
3. The effective date of the Connection and Facilities Fees
Schedule shall be / q,F_'U.�S ;,� 1982.
4 . The Clerk of the District shall immediately cause a copy
of this ordinance to be published once in the local. newspaper
and copies shall be posted in at least three public places
• within the District
PASSED AND ADOPTED by the Board of Directors of the Truckee Donner Public
Utility District at a regular meeting thereof duly called and held within said
District on the ` ='u- day of ,�'-�F�,,.F'..,,;,/t.' 1982, by the following rol.l. call
1 vote:
AYES:
NOES:
ABSENT:
TRUCKEE DONNER 110:>LIC UTILIT`i DISTRICT
A.. Ma,:.ss, Pres .de:,t
1 .
AP BEST
, '} SUS . M. CrLliq, Depu*� District Clerk
..'�.�`�:r`• �.. Exhibit „,
ELECTRIC CONNECTION AND FACILITIES FEE SCHEDULE
Availability
• Service hereunder is available throughout the District's service area.
Applicability
The Charges hereunder are applicable to all OlrPl.ivants for service at locations
not previously served by the District.
Rate
The initial charge for service to applicants under- the District's electric tariff
shall consist of a connection fee and, .if ap:,Dlicable, a facilities fee as follows :
Size of service Connection Fee Facilities Fee
1 0 Residential Service
-wise OVERHEAD $450.00 $200.00
.1 0 Residential Service
3-wire UNDERGROUND $500.00 $200.00
i
3 0 208, 240 or 480V
9-wine OVERHEAD $600.00 Demand z $BO
kw
3 (9 20 , 240 or 480V kw
Demand x $80
• 4-wire UNDERGROUND $650.00
The service required in all sizes includes 200 feet (overhead)and 100 feet (under-
ground) of wire, an overhead or pad mount standard voltage transformer, and one
meter. If additional meters are required, they shall be billed a set up fee plus
the actual cost of the meters.
Any needed extensions of thz service wire for more than the footage allowance
wi11 bw billed on the basis of actual cost of the wire.
/1G/
Exidbit
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