A13-84 - PUC Interchange

Transcription

Page VI - 2
VI. TRANSITION PLANS
TABLE 6-1: PROJECTED ANNUAL INVESTMENTS
First Transition 2011 - 2014
«AIriyestment'êsaiptiori. -
Distribution Facilities
New Member Line Extensions
` `Totaj
$10,618,272
System Improvements
New Tie Lines
Line Conv. & Chartges
$307,500
$2,204,800
Substations
New Stations
Power Transformers
Subtotal (Substations)
$6,000,000
$640,000
$6,640,000
Misc. Distr. Equipment
Transformers/Meters
Service Wire Sets
Security Lights
Sectionalizing Equip.
SCADA
Voltage Regulators
Capacitors
Subtotal (Misc. Distr. Equip.)
Ordinary Replacements
$13,899,318
$345,094
$318,548
$1,061,827
$1,061,827
$546,000
$895,000
$18,127,614
$4,884,405
$42,782,590
Subtotal Distribution
Transmission Facilities
New Line
New Station
$1,349,400
$2,000,000
$318,548
Subtotal Transmission
$3,667,948
$46,450,539
Grand Total
Reprint
A13-84
249
V!. TRANSITION PLANS
Page VI-, 3
1. Transmissign System
Several improvement to the transmission system serving the LEC system is scheduled for completion
during the First Transition period. The cooperative plans to construct five new substations. Two
new 115-7.2/12.47 kV 10 MVA substations named Claudow and Tokio-Brown, and three new 1387.2/12.47 kV 10 MVA substations, titled Key-Mesa, 44eRhwest Lamesa, and Patricia (2013) in order
to solve major voltage problems and accommodate new growth in these areas.
The Claudow substation will relieve load off of two existing substations, Clauene (115-24.94/14.4 kV
10 MVA) and Meadow (69-24.94/14.4 kV 7.5 MVA). To accomplish this, approximately 4.8 miles of
new 477 MCM ACSR 115 kV Transmission Line, from the Clauene substation, will be built as a
requirement for this Substation's construction.
The Tokio-Brown substation will relieve load off of two existing substations, Tokio (69-24.94/14.4 kV
10 MVA) and Brownfield (69-24.94/14.4 kV 7.5 MVA). To accomplish this, approximately 0.5 miles
of new 477 MCM ACSR 115 kV Transmission Line will be built as a requirement for this Substation's
construction.
A third substation, Key-Mesa (138-24.94/14.4 kV 10 MVA), eliminating two metering points, will be
located within close proximity to an existing 138 kV transmission line, and need less than 0.25 miles
of 477 MCM ASCR tap line. This substation will relieve load off of two existing metering points, Key
and South Lamesa The new 477 MCM ACSR 115 kV Transmission Line will be built as a requirement
for this Substation's construction.
The final transmission improvement during the Frist Transition, is located in the southern portion of
the LEC service area.
A single tap from a 138 kV transmission line will feed two new 10 MVA
substations eliminating the West Lamesa metering point. Patricia (138-24.94/14.4 kV 10 MVA) and
^Pie"west Lamesa (138-24.94/14.4 kV 10 MVA) will be powered from this new line. To accomplish
this, approximately 4.62 miles of new 477 MCM ACSR 138 kV Transmission Line will be built north to
reach Ner#*west Lamesa, and approximately 6.85 miles of new 477 MCM ACSR 138 kV Transmission
Line will be built south to reach Patricia, as a requirement for these Substation's construction.
Tokio-Brown
Claudow
Key-Mesa
Northwest LaMesa
Patricia
115 kV
115 kV
138 kV
138 kV
138 kV
0.5 miles
4.8 miles
0.2 miles
4.6 miles
6.9 miles
Reprint
A13 - 85
250
Page VI - 4
Substations
A number of LEC substation investments are expected during the First Transition period to provide
power to the distribution system. During the first five years, it is expected that five new substations
are to be constructed. Also at this time, New Moore and Meadow will need to have their current
7.5 MVA transformer increased to 10 MVA. Once that is completed, the 7.5 MVA transformers can
be placed at Wilson and Hackberry.
Dis1ribution System
During the First Transition period, line voltage regulators are to be installed at selected locations
throughout the system to defer premature investments.
Capacitor banks are to be installed
throughout the system to improve voltage and decrease losses. Eleven major improvement projects
are planned for the distribution system in the First Transition period. The following table lists each
foreseen major distribution line project.
During the First Transition, Hackberry will construct a new 4/0 ACSR circuit to provide power solely
to the industry plant located 0.22 miles to the west of the substation. The Ackerly and Seagraves
substations will each remove one circuit, an underground line, from use during this transition phase.
Reprint
A13 - 86
251
Page VI - 5
TABLE 6-2: SYSTEM IMPROVEMENT COST DETAIL
First Transition 2011 - 2014
Pro ect
Circuit
1
Changes/Description
Cost
substation
convert 1.45 miles of #4 to 477
Claudow
2
convert 1.26 miles of #2 to 4/0
3
build 0.75 miles new 1/0 tie
Meadow
1
3
Plains
build 2.03 miles new 4/0
substation
Tokio-Brown
3
build 0.55 miles new 4.0
convert 2.46 miles of #41f6 to 1/0 30
1
Pleasant hill
build 1.03 miles new 1/0 tie
new 10 MVA transformer
1
convert 5.15 miles of 1/0 to 477
New Moore
convert 3.5 miles of #410 to 1/0 30
1
build 1.81 miles new 1/0 tie*
convert 3.8 miles of #410 to 1/0 30*
substation
Patricia
4
convert 2.05 miles of 1/0 to 4/0
substation
Key-Mesa
3
convert 4.45 miles #2 & #4 to 4/0
4
build 0.13 miles new 4/0 circuit
5
Hackberr y
relocation of 7.5 MVA transformer
Wilson
relocation of 7.5 MVA transformer
NW LaMesa
substation
- oii ioaa aepenaance; coud ne done in 2nd transition
1
$1,200,000
$93,600
$63,000
$45,000
$67,500
$199,000
$101,500
$1,200,000
$81,200
$200,000
$34,400
$98,400
$41,200
$600,000
$334,100
$140,000
$72,400
$152,000
$1,200,000
$225,000
$102,500
$1,200,000
$225,000
$223,500
$13,000
$20,000
$20,000
$1,200,000
$9,152,300 1
Distribution system improvements are prompted by thermal capacity or delivered voltage
considerations. Each improvement has been scheduled based on expected load. The following two
maps illustrate the above system improvements.
Reprint
A13 - 87
252
253
^, ®"°
Hde»„nra
Sq T^ 8-
^^
n,
o-
T D^r
R9
car"
-
®.>ea sMu
-.
_
.^,,:
.
.
` ..
.. -.
i,
,.
.-
. -^
_:
^. _
_
•
..^... -_
__
...
:
!;
..-..
_
^.:.: ^.
^ .
'^'9'
^, ._.
..
-
..
;.
. .
_
.
-
Fbl
..
^
-
Ye
..
^
r.
.
•
.
_ _
.
^
.
,.
,..
_.
...:^`
'
"
.
CAI
..
W
MfI
â,.
^
_.
;
.
a
.
ca
254
Page V1 - 8
Ackerlv Service Area
During the First Transition period, only the application of capacitors and regulators are expected.
The removal of two 600 kVAR capacitors (Feeder 1 and 4) with one 300 kVAR capacitor being turned
on (Feeder 1). Feeder 3 will need two 300 kVAR capacitors added to it along with the relocation of
the regulator.
Feeder 4 will need two 450 kVAR capacitors placed on it.
No major line
improvements are anticipated to be needed in the Ackerly Service area for this duration of the Long
Range Plan. Capacitor size and proper placement will need to be verified annually.
Arvana Service Area
The Arvana metering point is expected to be eliminated during the Second Transition period, but
during the First Transition, a new 0.35 mile 1/0 ACSR tie line will need to be constructed. This new
line will help to more evenly distribute the current load as well as when the metering point is
eliminated and a new substation is built. It will also help maintain proper power flow and insure
better reliability on the circuit as 750 kVAR and one voltage regulator are added during this time
period.
Ashmore Service Area
During the First Transition period, 450 kVAR of capacitance will need to be added (Feeder 1) and 300
kVAR relocated (from Feeder 1 to Feeder 2) along with the addition of one regulator to Feeder 2 to
maintain proper voltage levels.
Brownfield Service Area
During the First Transition period, two 300 kVAR in capacitors (Feeders 1 and 3) will need to be
added and one 600 kVAR removed (Feeder 3) while one regulator is added to Feeder 1 to maintain
proper voltage levels.
Central Service Area
During the First Transition period, one 300 kVAR capacitor will need to be added and one regulator
relocated to maintain proper voltage levels.
Clauene Service Area
During the First Transition time period, the removal of four large (600 kVAR) capacitors from
Feeders 1, 3, 5, and 6, will precede the application of four 300 kVAR (Feeders 1, 3, 4, and 5) and one
Reprint
A13 - 90
255
Page VI - 9
V1. TRANSITION PLANS
450 kVAR capacitor (Feeder 2). Circuits 1 and 5 will also need voltage regulators to maintain proper
voltage levels.
Feeder 1 is not expected to experience voltage problems during this First Transition Period. Feeder 2
will need one 300 kVAR capacitor and one regulator placed. Feeder 3 will need one 600 kVAR capacitor
removed.
Doc Webber Service Area
Feeder 1 is not expected to experience voltage problems during this First Transition Period. However,
one 600 kVAR capacitor will need to be relocated and one 300 kVAR capacitor added. Feeder 2 should
not experience any problems. Feeder 3 will need one 300 kVAR capacitor relocated and a 450 kVAR
capacitor added. Feeder 4 will need a 600 kVAR capacitor removed but a 300 kVAR capacitor added.
Draw Service Area
Feeder 1 is not expected to experience voltage problems during this First Transition Period and would
only require the application of one 150 kVAR capacitor. Feeder 2 will need 750 kVAR added and one
regulator. Circuit three can have both regulators removed. Circuit 4 (new) will need one 300 kVAR
capacitance added to it.
Flore Service Area
Feeder 1 will need to have its regulator relocated and upgraded to 100 Amps along with 300 kVAR
added. Feeder 2 will only need a regulator added during this First Transition Period.
Foster Service Area
Feeders 2, 3, and 4 are not expected to experience voltage problems during this First Transition Period.
Feeder 1 will need one 300 kVAR added.
Gail Service Area
The Gail service area will only need one 600 kVAR capacitor removed or turned off and the current 100
Amp regulator relocated during this First Transition Period.
Reprint
A13 - 91
256
Page VI - 10
Hackberry Service Area
During this First Transition Period, a fifth feeder, if possible, will need to be added and run exclusively to
the plant 0.13 miles west of the substation. This Feeder will need a 1800 kVAR capacitor placed just
outside the plant. Feeder 1 will only need a 600 kVAR capacitor removed, while Feeders 2 and 4 have
no anticipated changes. Feeder 3 will need a 300 kVAR capacitor added.
less Smith Service Area
There are no expected changes to Feeders 1 or 2 during this First Transition Period. Feeder 3 will
need a 600 kVAR capacitor relocated. Feeder 4 will need a 600 kVAR capacitor removed and a 300
kVAR capacitor added to it.
Key Service Area
It is anticipated that the Key metering point will be removed from service during this First Transition
period. Until it's removal, two 600 kVAR and one 300 kVAR capacitor are to be removed and two
450 kVAR capacitors added to it.
Lakeview Service Area
Feeder 1 is expected to experience voltage problems during this First Transition Period, so a 300
WAR capacitor and a regulator will need to be added. Feeder 2 will need a 600 WAR capacitor
turned ON with a large regulator being added. Feeder 3 will only need a 300 kVAR capacitor, and
Feeder 4 should experience no problems.
Levelland Service Area
Feeder 1 is not expected to experience voltage problems during this First Transition Period, but will
need to have a 600 kVAR capacitor removed or turned OFF. Feeder 2 will need to relocate a 600
kVAR capacitor, while Feeder 3 will need a voltage regulator added. Feeder 4 should have a 600
kVAR capacitor removed and a 450 put in its place.
McConal Service Area
Feeder 1 is not expected to experience voltage problems during this First Transition Period, but will
require a 300 kVAR capacitor being added. Feeder 2 should not experience and voltage problems,
but Feeder 3 should have a 600 kVAR capacitor relocated. Feeder 4 could have a 600 kVAR
capacitor removed or turned OFF and the current regulator could be removed.
Reprint
A13-92
^ .
257
Pau2Vl -11
Meadow Service Area
Because of increased load, Feeder 1 will need to have 1 mile of #4 ACSR converted to 4/0 ACSR
during this First Transition Period. A single 300 kVAR capacitor will also need to be added. Feeder 2
is not expected to need any changes made to it. Feeder 3 should have a 600 kVAR capacitor
removed and a 300 kVAR put in its place. Feeder 4 will need two 300 kVAR capacitors.
New Home Service Area
During this First Transition Period, Feeder 1 could have a 450 kVAR capacitor placed at the location
of a 600 kVAR capacitor. Feeder 2 should have a 450 kVAR capacitor replace a 300 kVAR currently in
place. Feeder 3 will need a voltage regulator, while Feeder 4 will require one 300 kVAR capacitor.
New Moore Service Area
Feeder 1 is expected to experience significant voltage problems during this First Transition Period,
so a 600 kVAR capacitor will be added along with 5.14 miles of 1/0 ACSR being converted to 477
MCM ACSR directly out of the substation, going east. Should an oil field load increase to the south
during this time period, the conversion of a 10 #4 ACSR to 30 4/0 ACSR segment and construction of
a new tie line would be necessary.
Feeder 2 should have a 600 kVAR capacitor relocated along with one being removed. Feeder 3 has
no anticipated changes.
North Lamesa Service Area
The North Lamesa metering point is expected to be eliminated during the Second Transition period,
but during the First Transition, the relocation of a 300 kVAR capacitor is all that will be needed.
Plains Service Area
Feeder 1 is not expected to experience significant voltage problems during this First Transition
Period, so only the application of one 450 kVAR capacitor is recommended. Feeder 2 is currently
experiencing voltage problems prompting the addition of a 600 kVAR capacitor and changes to
Feeder 3. To reduce load one Feeder 2 and increase voltage levels to the southeast portion of the
Plains service area, a 2 mile 4/0 ACSR line will need to be constructed south out of the substation,
meeting existing #4 ACSR lines. These lines will need to be converted to 4/0 ACSR for 3.98 miles to
reach the south line. There are no changes needed at this point for Feeder 4.
Reprint
A13 - 93
258
Page VI -12
Vi TRANSITION PLANS
Pleasant Hill Service Area
The eastern feeder, Feeder 1, is expected to experience voltage and capacity problems in the First
Transition period. To redirect some of the load flow and increase voltage levels, a 10 #4 ACSR line
will need to be converted to 30 1/0 ACSR for 2.5 miles, then continued north as a 1.03 mile tie line.
The redirected flow will make it possible that only one 300 kVAR capacitor will be needed. Feeder 2
and Feeder 3 will each need one 300 kVAR capacitor added during this First transition period.
Prentice Service Area
The Prentice metering point load will be assumed into the Tokio service area eliminating it from
service during the First Transition period.
Punkin Center Service.Area
It is anticipated that the Punkin Center metering point will be removed from service during the
Second Transition period. Until it's removal, one 600 kVAR and one 300 kVAR capacitor are to be
relocated be facilitate better voltage values.
Ropes Service Area
It is anticipated that the Ropes substation will be removed from service during this Long Range
Planning period. This could be done during either the first or second transition period. No changes
to this system are needed to the Ropes service area at this time.
Sawyer Flat Service Area
Feeders 1 and 2 are not expected to experience voltage problems during this First Transition Period,
so no changes are suggested. Feeder 3 will need one 600 kVAR and one 300 kVAR capacitor are to
be relocated be facilitate better voltage values.
Seagraves Service Area
Feeder 1 will need a 300 kVAR capacitor added to this circuit while no changes for Feeder 2 are
expected. Feeder 3 will need one 600 kVAR capacitor removed and one relocated while a 300 WAR
capacitor will need to be added. Feeder 4, an underground line, can be removed from service and
free a location for future growth. Feeder 5 can have one 600 kVAR capacitor removed or turned
OFF.
Reprint
A13 - 94
259
Page VI -13
Seminole Service Area
Feeder 1 and 2 will each need a 600 kVAR capacitor added to the circuit. Feeder 3 will need the
voltage regulator relocated and increased during this First Transition Period.
South Lamesa Service Area
It is anticipated that the South Lamesa metering point will be removed from service during the
Second Transition period. Until it's removal, two 600 kVAR and one 300 kVAR capacitor are to be
removed while two 450 kVAR capacitors will need to be placed, to maintain better voltage values.
Sundown Service Area
Feeder 1 can have one 600 kVAR capacitor turned OFF or removed and a 300 kVAR capacitor added
during this First Transition Period. Feeder 2 will only need one 600 kVAR capacitor relocated.
Feeder 3 will need one 600 kVAR capacitor turned ON while another can be removed.
Tokio Service Area
Feeder 1 is not expected to experience voltage problems during this First Transition Period. Feeder
2 can have one 600 kVAR capacitor removed and a 300 kVAR capacitor installed. Feeder 3 can also
have one 600 kVAR capacitor removed and a 450 kVAR put in its place. Feeder 4 will only need one
300 kVAR capacitor added to it while Feeder 5 is not expected to need any changes.
Two Draw Service Area
Feeder 1 will require one 300 kVAR capacitor during this First Transition Period. Feeder 2 is not
expected to experience voltage problems and requires no changes.
Welch Service Area
It is anticipated that the Welch metering point will be removed from service during the Second
Transition period. Until it's removal, two 600 kVAR capacitors can be removed and one 300 kVAR
capacitor added. The regulator will need to be relocated.
Wellman Service Area
Feeder 1 will need the application of one 600 kVAR capacitor and 100 Amp voltage regulator during
this First Transition Period. Feeder 2 will only require the relocation of one 300 kVAR capacitor.
Reprint
A13 - 95
260
Page VI -14
Vl. TRANSITION
PLANS
..
.
..
Feeder 1 should have a 600 kVAR capacitor removed or turned OFF along with adding a voltage
regulator. Feeder 2 will not need any changes, however a regulator should be added to Feeder 3.
M
NEW SUBSTATIONS
Claudow Service Area
The Claudow substation should be constructed during the First Transition period to relieve high load
from both Cluene and Meadow. Once constructed, Feeder 1 to the east will need 1.44 miles of #4
ACSR converted to 477 MCM ACSR and the addition of one 600 kVAR capacitor. Feeder 2, going
north, will need to convert 1.26 miles of #2 ACSR to 4/0 ACSR and the addition of one 450 kVAR.
Feeder 3 serving the south will need the addition of a 1/0 tie line to add in proper power delivery. A
600 kVAR capacitor can be removed from this circuit and a voltage regulator added to insure proper
voltage levels. Feeder 4 will need the relocation of one 600 kVAR capacitor.
Key-Mesa Service Area
The Key-Mesa 138 kV substation should be constructed during the First Transition period to
eliminate two metering points, Key and South Lamesa. Feeder 1(north) changes will be done prior
to construction completion and according to the Key recommendations above. Feeder 2 (northeast)
changes will be completed prior to substation construction according to the South Lamesa
guidelines above.
Feeder 3 which will serve the southeast area will require 4.45 miles of #4 and #2 ACSR to be
converted to 4/0 ACSR immediately east out of the substation. Feeder 4, to the west, will need
conversion of 1/0 ACSR to 477 MCM ACSR for 3.43 miles out of the substation. Because of these
conversions, no additional capacitors or voltage regulators are needed to maintain proper voltage
levels.
-Wa4k4est Lamesa Service Area
The Northwest Lamesa substation is suggested to be completed during the First Transition period
and will split the West Lamesa metering point load into two 10 MVA substations. Feeder 1 (north)
will require one 600 kVAR capacitor and one 300 kVAR capacitor to be removed or turned OFF. One
600 kVAR capacitor will have to be relocated and a voltage regulator is suggested.
Reprint
A13 - 96
261
Page VI -15
Feeder 2 (southeast) will need four 600 kVAR capacitors removed or turned OFF, the relocation of
one 300 kVAR capacitor, and the addition of two 450 kVAR capacitors.
Feeder
3
to
the
southwest will only need a larger, relocated voltage regulator.
Patricia Service Area
Patricia is the second substation that will split the West Lamesa metering point load into two 10
MVA substations. The 25 kV express feeder will no longer be needed. However, Feeder 4 to the
west will require conversion of the 1/0 ACSR to 477 MCM ACSR for 7.11 miles starting from the new
substation. At the end of the new 477 MCM line, an addition 2.05 miles of conversion to 4/0 is
needed as well as the addition of two 450 kVAR capacitors and the relocation of one 600 kVAR
capacitor. This feeder will also require a voltage regulator.
Feeder 1(north) will only require adding one 300 kVAR capacitor and a voltage regulator. Feeder 2
(south) is estimated needing two 450 kVAR capacitors, the relocation of one 300 kVAR capacitor,
and a new voltage regulator. Feeder 3 (southeast) can have one voltage regulator removed and
adding one 300 kVAR capacitor.
Tokio-Brown Service Area
The Toklo-Brown substation should be constructed during the First Transition period to relieve the
increasingly high load from both Tokio and Brownfield. Once constructed, Feeder 1 to the east will
need one 600 kVAR capacitor added to it to maintain proper voltage levels. Feeder 2 (north) will
need one 600 kVAR capacitor turned OFF. Feeder 4 (west) can have one 600 kVAR capacitor
removed along with the voltage regulator.
Feeder 3 (south) will need the #4 ACSR out of the substation converted to 477 MCM ACSR for 1.24
miles. Then the next 3.98 miles of the #4 ACSR will need to be converted to 4/0 ACSR. At the end of
the above conversions, a 0.55 mile 4/0 ACSR tie line will need to be constructed to maintain proper
load balance and voltage levels. On this feeder, one 300 kVAR capacitor will need to be relocated
and one 600 kVAR capacitor added.
Reprint
A13 - 97
262
Page VI -16
B. Second Transition 2016 - 2020
The Second Transition was developed to address system requirements during the five-year period of
2016 through 2020.
Table 6-3 below indicates annual investments expected during the Second Transition period.
Reprint
A13 - 98
263
Page VI -17
TABLE 6-3: PROJECTED ANNUAL INVESTMENTS
Second Transition 2016-2020
Investment Description
System Improvements
New Tie Lines
Line Conv. & Changes
Substations
New Stations
Power Transformers
Transformers/Meters
Service Wire Sets
Security Lights
SCADA
Voltage Regulators
Capacitors
Total
$12,309,487
$652,500
$2,118,700
$6,000,000
$640,000
$6,640,000
$16,113,118
$400,058
$369,285
$1,230,949
$1,230,949
$1,092,000
$1,017,500
$21,453,859
$5,662,364
$48,836,910
New Line
New Station
Grand Total
$5,228,500
$0
$369,285
$5,597,785$54,434,694
Reprint
A13 - 99
264
Page VI -18
TRANSITION
VI.
._... .,,,
.., .,, ._.,^...^ PLANS
1. Transmission System
Some improvements will need to be made to the transmission system during the Second Transition
period to allocate power to the new substations.
Lakeadow
Sea-Hill
Semino-Conal
Punk-Welch
North Arvana
115 kV
5.1 miles
115 kV
69 kV
138 kV '
138 kV
3.0 miles
6.0 miles
9.1 miles
7.6 miles
Substations
The cooperative plans to construct five new substations during this transition period, listed above.
Two new 69-7.2/12.47 kV 10 MVA substations, including Lakeadow and Semino-Conal, one new
115-7.2/12.47 kV 10 MVA substation named Sea-Hill, and two new 138-7.2/12.47 kV 10 MVA
substation, including North Arvana and Punk-Welch, will be added during this second transition
period.
During the Second Transition, the three 5 MVA transformers (Seminole, Wilson, Hackberry) can be
placed at Central, Florey, and Wellman according to time of need. LEC will then have three 3.75
MVA transformers available for future use.
During the Second Transition, the Draw substation will need to add a 0 circuit, leading south, to
supply power to the southwest portion of the service area due to increasing load in the southern
region. An additional circuit will also need to be added to Meadow when the Ropes substation load
is moved onto Meadow. Proceeding north out of the Meadow substation, a new circuit will be
constructed to deliver power to the northwest service area.
Distribution System
During the Second Transition period, line voltage regulators are to be installed at selected locations
throughout the system to defer premature investments. Capacitor banks are also to be installed
throughout the system to improve voltage and decrease losses. Fourteen major improvement
projects are planned for the distribution system in the Second Transition period. The following table
lists each foreseen major distribution line project.
Reprint
A13 - 100
265
Page VI -19
TABLE 6-4: SYSTEM IMPROVEMENT COST DETAIL
Second Transition 2016-2020
Project
Sundown
Changes
Circuit
1
Meadow
2
4
build 1.92 miles of new 1/0 tie
substation
1
La k ea d ow
Dixon
Sea-Hill
2
convert 0.38 miles of #4 10 to 1/0 30
Cost
$76,100
$600,000
$76,800
$109,200
$1,200,000
$19,200
$25,600
$166,400
$16,500
$32,300
3
2
build 0.3 miles of new 1/0
$22,500
$35,100
$75,000
2
substation
4
$1,200,000
$50,000
convert 2.12 miles #4 to 477
convert 3.0 miles #4 to 4/0
$139,700
$150,000
$1,200,000
Punk-Welch
substation
New Moore
build 1.81 miles new 1/0tie*
convert 3.8 miles of #4 10 to 1/0 30*
$600,000
$72,400
$152,000
relocation of 5 MVA tansformer
convert 2.92 miles of #4 10 to 477 30
$189,800
1
2
Draw
S em i no-Cona l
Central
A c kerl y
build 0.52 miles of new 477
$35,000
convert 1.03 miles of #41{D to 477 30
$67,000
4
1
substation
$207,000
$1,200,000
$165,000
$76,000
substation
$66,500
$1,200,000
3
N orth A rvana
$20,000
1
1
0
1
1
relocation of 5 MVA tansformer
convert 0.66 miles of #4 10 to 1/0 30*
Doc Webber
3
*oil load dependance; could be done in 1st transition
$160,000
$58,500
$28,000
$20,000
$76,000
$26,400
$21,600
$9,411,200
Reprint
A13 - 101
266
Page VI - 20
Distribution system improvements are prompted by thermal capacity or delivered voltage
considerations. Each improvement has been scheduled based on expected load. The following two
maps illustrate the system improvements stated above in Table 6-4.
Reprint
A13 - 102
267
y.
r
'^
V1$II!!3C5"-'
...
'
ÊSÊ
• - ^.
..
..,,
.
.
^„^
187ltJl^
^
•
-
Q+
,.
,
11v07Afk .-
^
^
.
•
;
,
`
...
-"^
.
.
`^PWu
,
.:
^
.
----
'. ,
a :
<...
:. _. ._
51r,nn
.r
x
_x
tg
_ __
.
, _.
..
loM.aal
_^
^1
,
_ Brosn!nla
^ ^.
.___
1-_ _ _
... _
.
^^
..-
..
.
.
'..
,
.
_
'
..
O
.
® 5•+
ì^
3NNMfC^L"'^--
P"^4 a7
.
,..^.
^'"
. - .
-
.
-
t
rape^
^ tatsâ^,
^
, ....__
'...:
^•.®. ..-
1
.._^ ^ .
..
.
.
..t ,t ,.. '^ «
-:.,_. .;
.4..
..^'•
...
VtSHb
_
-
IP
..
^
:.
^^
^+«
'
f -
'
^
1ubbockl ^
®Bn H4
8m^
^•.•.1
.
-__-._
.
Y
,
^ ^Î
NenLpt,ts
ttSte
t^
^
"'q17aF^.. ` -__..._
!
'a; Q
_.
_
®
West , 'rwr
i.
.
A^'r^
^
..
Txx^71
'
..
^,.
:.
`^
-
^
®NwvMron
^^
onM
s..um...
w.^c y
!^3
®
A^
s.ww Nn
-
®..........._
®,^,•,
-
Mccenr
wm^w«a
sw^.âôm.+
N„yA,,,^,.
Sagar9ecMcCOOWratiw.INC
T eoLnnewub
second rramAfw, T)baôn
Inprovemw18 NmIR
268
.WsamAh
f^
,
^Sa N6 0 aên91A PioWemri
n
.
_
.
. ... - ., ®
'
^^.,
.
.
_
^l
5
.
.
.
.
Bit
-^t -.
_^
_
^
^
13
®
AbC Or^ l
^ ^
^..
El
^
^r^^•
__
^
^
.
-
^SMbroie
{
-
.
.
.
-....
....,
.
i
.
:....
•
_
^
•.
_
.
.
-yJ ,^^
`ry^,,
^
.,
-.
^
-^
.
_ .-..
-
.
'
^-
. -
:..Y
•
..
. - .
• ^
.
}^
^
^
.
•
^
^
,.+i
.
^!-
.
}^s^
:--
^^1.l^
^y
^-^)
.
•
^
_
.
^
._
PurdWNC^
fi
rRX r'.:'-
^
..
tRk neR .
^.
-
1
.
`
..
.
u,^v
.^
]
^. ..
Cl
.
y
.
^
.
^
..
.
...
:_
AKph`
a.r.n..r^.n
-
^
.
.
LNitperElachioCoope^ntlve.INC
EEuORn
lovroveRbnta 6aulh
269
Page VI - 23
Ackeriy Service Area
During the Second Transition period, on Feeder 1, a new 1/0 ACSR tie line is suggested to reach an
oil load to the east. This tie line will be 1.89 miles long following County Road 224, reaching an
existing 10 #4 ACSR line that will need to be converted to 30 1/0 ACSR for 0.66 miles. During this
time, a 450 kVAR capacitor will need to be added. Feeder 2, an underground line was removed from
service during Transition 1. Feeder 3 will need a voltage regulator while Feeder 4 will need a 300
kVAR capacitor as well as a voltage regulator.
Arvana Service Area
The Arvana metering point is expected to be eliminated during the Second Transition period,
therefore there are no changes being suggested.
Ashmore Service Area
During the Second Transition period, we estimate that Feeder 1 will need a 450 kVAR capacitor and
the application of a voltage regulator. Feeder 2 will only need a 450 kVAR capacitor, while no
changes are recommended for Feeder 3.
Brownfield Service Area
During the Second Transition period, one 300 kVAR capacitor and a voltage regulator will need to be
added to Feeder 1. Feeder 2 is estimated to need a one 300 kVAR capacitor while Feeder 3 will
need one 450 kVAR capacitor. Feeder 4 will need one 600 kVAR capacitor to maintain proper
voltage levels.
Central Service Area
During the Second Transition period, one 300 kVAR capacitor is predicted"to be necessary on both
circuits to maintain proper voltage levels.
Clauene Service Area
During the Second Transition time period, Feeder 1 will need 750 kVAR in capacitors while Feeder 2
will only require a voltage regulator. Feeder 3 and Feeder4 will each need one 300 kVAR capacitor
and Feeder 4 will need one 450 kVAR capacitor. Feeder 6 should require no changes during this
transition period.
Reprint
A13 - 105
270
Page VI - 24
VI.
TRANSITION PLANS
^._
Claudow Service Area
The Claudow substation is scheduled to be constructed during the First Transition period to relieve
high load from both Clauene and Meadow. During the Second Transition period, Feeders 1 and 3
will each need a 300 kVAR capacitor with a voltage regulator added to Feeder 3. Feeder 2 and 5 will
each require a 450 kVAR capacitor with an added 300 kVAR capacitor needed on Feeder 5.
Dixon Service Area
Feeder 1 is not expected to experience voltage problems during this Second Transition Period. Feeder 2
will need 900 kVAR capacitor added to it as well as 1.5 miles of #4 ACSR to 4/0 ACSR conversion. Feeder
3 will need one 300 kVAR capacitor added.
Doc Webber Service Area
Feeder 1 will require one 300 kVAR capacitor during this Second Transition Period. Feeder 2 should not
experience any problems. Feeder 3 will need one 300 kVAR capacitor and one voltage regulator added
to it. A 0.27 mile new tie line will need to be built to more efficiently direct load flow. Feeder 4 will
need two 300 kVAR capacitors added.
Draw Service Area
At this time, The Draw service area is expected to exceed the FA rating of the existing transformer and
will need a larger one installed. The 5.25 MVA transformer from Seminole is suggested after it is
upgraded. Feeder 1 is not expected to experience voltage problems during this Second Transition
Period. Feeder 2 will need two 450 kVAR capacitors added along with several miles of conversions.
Depending on load growth to the southeast during Transition One, 2.92 miles of 10 #4 ACSR will need to
be converted to 30 477 MCM ACSR to reach the southeast. At the end of the above conversion, 0.52
miles of 477 MCM ACSR tie line will be needed to reach another 10 #4 ACSR line that will be converted
for 1.03 miles to 30 477 MCM ACSR. Feeder 3 is not expected to need any adjustments during
Transition Two.
A new circuit will need to be added south to feed the southwest service area. A 4.14 mile long 4/0 ACSR
line will be expected to feed this southwest area.
Flo rev Service Area
Feeder 1 and 2 will each need one 300 kVAR capacitor added to them during this Second Transition
Period.
Reprint
A13 - 106
271
..r,
Page VI - 25
Foster Service Area
Feeders 2, 3, and 4 are not expected to experience voltage problems during this Second Transition
Period. However, Feeder 1 will need one 450 kVAR capacitor added.
Gail Service Area
The Gail service area will only need one 450 kVAR capacitor added during this Second Transition Period
to maintain proper voltage levels.
Hackberry Service Area
During this Second Transition Period, due to expected load growth, a larger (7.5 MVA) transformer is
expected to be needed due to exceedance of the FA rating. This larger transformer could come from
New Moore. There are no expected changes to the new "plant" circuit and Feeder 1 will need the
addition of a 450 kVAR capacitor. Feeder 2 will require the relocation of one 300 kVAR capacitor.
Feeder 3 will need one 450 kVAR capacitor and the replacement of one voltage regulator. Circuit 4 will
only need one 150 kVAR capacitor.
Jess Smith Service Area
It is expected that all four Feeders will require the addition of one 300 kVAR capacitor during this
Second Transition Period. Only Feeder 1 will need the addition of one voltage regulator.
Key Service Area
It is anticipated that the Key metering point will be eliminated during the First Transition period,
therefore there are no changes being suggested.
Key-Mesa Service Area
The Key-Mesa 138 kV substation is expected to be constructed during the First Transition period to
eliminate two metering points, Key and South Lamesa. During the Second Transition period, Feeder
1 will need the relocation of one 600 kVAR capacitor as well as the application of one voltage
regulator with the previous one being removed. No changes are expected for Feeders 2 and 3.
Feeder 4 will need two 450 kVAR capacitors added to the circuit along with one voltage regulator.
Lakeview Service Area
Feeder 1 is not expected to experience voltage problems during this Second Transition Period, but it
will be necessary to adjust its service area slightly once Lakeadow is constructed. Feeder 2 will need
two 300 kVAR capacitors. Feeder 3 will also need two 300 kVAR capacitors and the replacement of a
voltage regulator.
Feeder 4 should experience only slight problems and need one 150 kVAR
capacitor.
Reprint
A13 - 107
272
^®^..
Pam VI - 26
Levelland Service Area
Feeder 1 is not expected to experience voltage problems during this Second Transition Period, but
might need a 300 kVAR capacitor replaced with a 450 kVAR capacitor. Feeder 2 will need a voltage
regulator, while Feeder 3 will need a 150 kVAR capacitor. Feeder 4 should have a 450 kVAR
capacitor added.
McConai Service Area
Feeder 1 is expected to experience only slight voltage problems during this First Transition Period
and will require a 600 kVAR capacitor and voltage regulator being added. Feeder 2 will need one
300 kVAR capacitor, while Feeder 3 should have a 600 kVAR capacitor, previously turned OFF,
turned ON. Feeder 4 could have a 450 kVAR capacitor added to it.
Meadow Service Area
Due to estimated increasing load, the 7.5 MVA transformer will need replacement with a 10 MVA
during the Second Transition Period. (it can be moved to Wilson for continued growth in that area.)
With the larger transformer in place, the Ropes substation can be taken off line and supplied by
Feeder 1. Feeder 1 will now require two 300 kVAR capacitors and a voltage regulator. By absorbing
Ropes, Feeder 2 will need to be added to the substation and the building of 1.92 miles of new 1/0
ACSR line to the north to supply the northwest service area.
Feeder 3 will need a 450 kVAR capacitor added to it. Feeder 4 is estimated to grow, prompting the
conversion of the 1/0 ACSR line to 477 MCM ACSR for 1.92 miles west out of the substation. A 300
kVAR capacitor and replacement of the voltage regulator will also be needed.
New Home Service Area
During this Second Transition Period, Feeder 1 could have a 450 kVAR capacitor placed at the
current location of a 600 kVAR capacitor. Feeder 2 is not expected to experience any changes.
Feeder 3 will need a 300 kVAR capacitor added, while Feeder 4 will require one 450 kVAR capacitor.
New Moore Service Area
Expected load growth and possible increasing oil load, a new 10 MVA transformer could be needed
during this Second Transition time. It would be necessary to add a 450 kVAR and 600 kVAR
capacitor to Feeder 1 close to the oil load as well as a voltage regulator. It will require converting
3.8 miles of 10 #4 ACSR to 30 1/0 ACSR. Feeder 2 will need a 300 kVAR and 600 kVAR capacitor.
Feeder 3 will only need one 300 kVAR capacitor added to it.
Reprint
A13 - 108
273
V!. TRANSITION PLANS
Page VI - 27
North Lamesa Service Area
The North Lamesa metering point is expected to be eliminated during the Second Transition period
by the Punk Welch substation.
Northwest Lamesa Service Area
The Northwest Lamesa substation is suggested to be completed during the First Transition period,
splitting the West Lamesa metering point load into two 10 MVA substations. Feeder 1 (north) will
require one 450 kVAR capacitor and a voltage regulator during the Second Transition period. Feeder
2 can have a 600 kVAR capacitor turned ON and the addition of one 300 kVAR capacitor. No
changes are expected for Feeder 3.
Patricia Service Area
Patricia is the second substation from the First Transition that will split the West Lamesa metering
point load into two 10 MVA substations. The 25 kV express feeder will no longer be needed. The
north feeder, Feeder 1, will need an additional 300 kVAR capacitor. Feeder 2 will need 750 kVAR of
capacitance added along with a voltage regulator to maintain proper voltage levels. Feeder 3 will
need one 300 kVAR capacitor while Feeder 4 will need one 450 kVAR capacitor. One 600 kVAR
capacitor will also need relocating on Feeder 4.
Feeder 1 will need 900 kVAR of capacitance added to it and Feeder 2 will need 600 kVAR. Feeder 3
will need an estimated 600 kVAR and one voltage regulator. Feeder 4 will need 450 kVAR.
Pleasant Hill Service Area
Assuming the recommended line conversion was done in Transition 1, Feeder 1 will need one 300
kVAR capacitor and a voltage regulator to maintain proper voltage levels. Feeder 2 will need one
300 kVAR capacitor and Feeder 3 will need 750 kVAR capacitor support along with a voltage
regulator.
Prentice Service Area
The Prentice metering point load was assumed into the Tokio service area eliminating it from
service.
Punkin Center Service Area
It is anticipated that the Punkin Center metering point will be eliminated during the Second
Transition period, therefore there are no changes being suggested..
Reprint
A13 - 109
274
Page VI - 28
^.._
Ropes Service Area
It is anticipated that the Ropes substation will be removed from service during this Long Range
Planning period. This could be done during either the first or second transition period. No changes
to this system are needed to the Ropes service area at this time.
Sawyer Flat Service Area
Feeder 1 is not expected to experience voltage problems during this Second Transition Period, so no
changes are suggested. Feeder 2 will need one 300 kVAR capacitor and Feeder 3 is expected to
need one 300 kVAR capacitor and voltage regulator to maintain proper voltage values.
Seagraves Service Area
Feeder 1 will need a 300 kVAR capacitor and a voltage regulator added to this circuit while no
changes for Feeder 2 are expected. Feeders 3 and 5 will each need one 300 kVAR capacitor added
to them while Feeder 4, an underground line, was removed from service in Transition 1.
Seminole Service Area
Feeder 1 and 2 will each need a 300 kVAR capacitor added to them while Feeder 2 will also require a
voltage regulator.
Feeder 3 will need one 600 kVAR capacitor added to it during this Second
Transition Period.
South Lamesa.Service Area
It is anticipated that the South Lamesa metering point will be removed from service during the First
Transition period with the construction of the Key-Mesa substation.
Therefore, any required
changes will be under Key-Mesa.
Sundown Service Area
It is suggested that Feeder 1 have 0.78 miles of 1/0 ACSR converted to 477 MCM ACSR beginning at
the substation and going north. This circuit will also need 750 kVAR of capacitance added to it and
the relocation of the voltage regulator. Feeder 2 will require the addition of one 450 kVAR capacitor
while Feeder 3 is not expected to have any changes.
Tokio Service Area
Feeder 1 could have a voltage regulator removed in either the First or Second Transition. Because
the northeast load flow was shifted from Feeder 2 onto Feeder 5, only the application of a voltage
regulator is suggested for the Second Transition. A 450 kVAR capacitor will also be needed on
Feeder S. Feeder 3 will need one 300 kVAR capacitor as will Feeder 4. A voltage regulator will also
be needed on Feeder 4.
Reprint
A13 - 110
275
Page VI - 29
The Tokio-Brown substation is expected to be constructed during the First Transition period to
relieve the increasingly high load from both Tokio and Brownfield. During the Second Transition,
Feeder 1 to the east will require one 300 kVAR capacitor and a voltage regulator.
Feeder 2 will need one 450 kVAR capacitor. Feeder 3, to the south, will need one 450 kVAR
capacitor as well as a voltage regulator. Feeder 4 is expected to need one 450 kVAR capacitor.
Two Draw Service Area
It is anticipated that Feeder 1 will require one 600 kVAR capacitor during this Second Transition
Period. Feeder 2 will require one 300 kVAR capacitor.
Welch Service Area
It is anticipated that the Welch metering point will be eliminated during the Second Transition
period, therefore there are no changes being suggested..
Wellman Service Area
Feeder 1 will need the application of one 150 kVAR capacitor during this First Transition Period,
while Feeder 2 is not anticipated as needing any changes.
Wilson Service Area
It will be necessary to install a 7.5 MVA transformer (possibly from Wilson). Feeder 1 should have a
300 kVAR capacitor installed. Feeder 2 will also need a 300 kVAR capacitor placed on this circuit
while Feeder 3 will need a 450 kVAR capacitor.
Sea-Hill Service Area
The Sea-Hill substation is expected to be needed during the Second Transition period. Feeder 1, the
eastern circuit, will not need any changes once the substation is constructed. Feeder 2, to the
north, because of the stations central location, will need 1.0 miles of #4 ACSR converted to 4/0 ACSR
directly out of the substation.
It is expected that Feeder 3, to the south, will require the application of two 300 kVAR capacitors
and one voltage regulator. Feeder 4, going west, will also need line conversions. Approximately
2.12 miles of #4 ACSR will need to be converted to 477 MCM ACSR directly out of the substation. At
the end of this conversion, another 3.0 miles of #4 ACSR will need to be converted to 4/0 ACSR to
Reprint
A13 - 111
276
VI. TRANSITION
..^.......^ PLANS
- -
Page VI - 30
maintain load and voltage stability. One 600 kVAR capacitor and voltage regulator will also need to
be applied to this circuit.
Semi2o-Conal Service Area
The Semino-Conal 10 MVA substation is expected to be needed during the Second Transition period
due to increasing load at both Seminole and McConal substations. Feeder 1 will need to be
converted from #4 ACSR to 477 MCM ACSR out of the substation, east for 2.54 miles. Then the #4
ACSR line will need to be converted to 4/0 ACSR for another 1.52 miles, due to the large load to the
southeast.
Feeder 2 to the north is only anticipated as needing one voltage regulator. Feeder 3, to the south, is
expected to need 1.33 miles of #4 ACSR converted to 4/0 ACSR to maintain proper load flow and
voltage values.
Lakeadgw Service Area
The Lakeadow substation is expected to be needed during the Second Transition period. Several
conversions will be needed to deliver power to large load centers. Feeder 1, east, will require the
construction of a 1/0 tie line to better direct load flow to the area north of Meadow. A current 10,
#4 ACSR line will also need to be converted to 30, 1/0 ACSR to maintain the proper flow and voltage
levels for this circuit. A 600 kVAR capacitor and voltage regulator will also be needed.
Feeder 2 will need 2.56 miles of #4 ACSR converted to 477 MCM ACSR, south out of the new
substation. An additional 0.43 miles of 10, #4 ACSR to 30, 4/0 ACSR will be needed to carry power
to the southwest. A small, 0.43 mile, 4/0 ACSR tie line will be added to the above conversion with
another 0.3 mile conversion of #4 ASR to 4/0 ACSR. 750 kVAR of capacitance is also expected to be
needed on this circuit along with the relocation of one 600 kVAR capacitor. A voltage regulator will
also be needed.
The final conversion is 0.27 miles of #4 ACSR to 477 MCM ACSR, west out of the substation. One
600 kVAR capacitor will need to be relocated along with three 300kVAR capacitors added
throughout the circuit. A voltage regulator will also be needed.
Punk-Welch Service Area
The Punk-Welch 10 MVA substation is expected to be built during the Second Transition period
eliminating the Punkin Center and Welch metering points. Four 300 kVAR and two 450 kVAR
capacitors are expected to be needed. Capacitor size and its proper location(s) will need to be
verified by LEC.
Reprint
A13 - 112
277
Page VI - 31
North Arvana Service Area
The North Arvana 10 MVA substation is expected to be constructed during the Second Transition
period eliminating two metering points, North Lamesa and Arvana. A new circuit will need to be
constructed east out of the substation. It is expected that 3.2 miles of new 4/0 ACSR will need to be
built to reach a #4 ACSR line. This line will need to be converted to 4/0 ACSR for 0.78 miles to
facilitate flow to the east. A regulator will need to be added to this circuit along with a 300 kVAR
and 450 kVAR capacitor.
Feeders 2 and 3, north and south respectively, is not anticipated as needing any changes. Feeder 4,
west, will need the application of one 150 kVAR capacitor.
C. Transition Summary
The following sections present major facets of the transition plans in comparative or sequential
format.
1. Distribution System
Table 6-5 illustrates the magnitude of distribution line miles constructed, re-constructed or
improved per transition period.
TABLE 6-5: DISTRIBUTION LINE MILES
(Transition Summary)
First Tansition
Second Transition
Total
6.65
0.00
12.93
0.00
19.58
0.00
Distribution Converstions
Overhead
Underground
40.94
28.47
69.41
0.00
0.00
0.00
Total
47.59
41.40
88.99
New Distribution
Overhead
Underground
Reprint
A13 - 113
278
Page VI - 32
2. Transmission System
Table 6-6 illustrates the magnitude of transmission line miles constructed or improved per transition
period.
TABLE 6-6: NEW TRANSMISSION LINE MILES
_l:
,
î.rst Tansition
. . . , 'i^ -^', .,-
.:•.. _
§e^qnd Transitton
rd
,Y+
s;r,u
^ Tqtal
^'S
New Distribution
Overhead
69 Kv
115 Kv
138 Kv
Distribution Converstions
Overhead
69 Kv
Total
13.70
13.70
13.41
28.40
55.51
0.00
5.30
11.71
17.01
8.11
16.69
38.50
0.00
7.70
7.70
115 Kv
0.00
0.00
0.00
138 Kv
0.00
0.00
0.00
7.70
0.00
7.70
17.01
46.20
63.21
Reprint
A13 - 114
279
Page VI - 33
3. Transition Investments
Table 6-7 Illustrates comparative transition investment estimates by investment category.
TABLE 6-7: PROJECTED INVESTMENTS
Investment Description
1stTransition
2nd Transition
$10,618,272
$12,309,487
$22,927,759
$307,500
$2,209,900
$652,500
$2,118,700
$4,328,600
$6,000,000
$6,000,000
$12,000,000
Total
System Improvements
New Tie Lines
Line Conv. & Changes
Substations
New Stations
$960,000
Power Transformers
$640,000
$640,000
$1,280,000
$6,640,000
$6,640,000
$13,280,000
$13,899,318
$16,113,118
$400,058
$30,012,436
$745,152
Transformers/Meters
Service Wire Sets
$345,094
Security Lights
$318,548
$369,285
$687,833
$1,061,827
$1,061,827
$2,292,776
$2,292,776
$546,000
$895,000
$18,127,614
$1,230,949
$1,230,949
$1,092,000
$1,017,500
$21,453,859
$1,638,000
$1,912,500
$39,581,473
$4,884,405
$5,662,364
$10,546,769
$42,787,690
$48,836,910
$91,624,600
$1,349,400
$2,000,000
$318,548
$5,228,500
$0
$6,577,900
$2,000,000
$369,285
$687,833
$3,667,948
$5,597,785
$9,265,733
$46,450,539
$54,434,694
$100,724,033
SCADA
Voltage Regulators
Capacitors
New Line
New Station
Grand Total:
Reprint
A13 - 115
280
PaS2 VII_-1
VII. EXPLORATORY PLANS
A. Plan Selection
Four exploratory plans were developed and compared by region (see region map on following page).
Based on the expected long-term load and growth in each region, three possible adjustments could
be made. The first choice, Exploratory 0, is to do nothing to the system, letting it function as it is
currently set. While this is not a viable option, the losses on the system are evaluated to give a
baseline cost. The second possibility, called Exploratory A, is to redistribute power flow in each
service area. Depending on the size of the existing transformer, it may be replaced with a larger one
or adding a 10 MVA transformer in parallel with the transformer currently at the substation and
then evaluating necessary distribution line improvements.
This plan is also called, "No New
Substations." Adding a second transformer is more cost effective than building a new substation,
however it is not always possible as space within a substation is often limited and losses within the
area could offset the savings.
Reprint
A13-116
281
juudaU
t '4.r•r=
`
L=e
._...
^
Cochran
r
^
ka Y ^^ ^
- H
..^^*i
Lubbock
.
.
-
Lev$N9cM
^- Srâw^-^.=
^..
, .,,
:. ^
rE
- _.
;^:*.n•>^â
•.,, 1 ^'^'^} -•_.,
^ Lubbock
•;,t^'*..^.- r`
^
Crosby
âll_^:7rr
F^D
51^ 3n
^
REGIOi51
-
-
^"M'eatlow '
c
New Ho"
az_
;
,
,
^?^q c
i
4
i
-
.,
....-
..
- .
^
,
>
^
8r
REGION
-
,..S T
Yoaku
.
_
'
croe
H . ..
REGIO 3
^..1 vo Draw
Mow
' .._
.
.- _
_,H
- ^
rekl ,
.
_
f
,
3^8j^.----
t ^^•:ra::
Jess Smm ^.
^.I•'ri
^•tr
,. .
_.-,
aL%RV
'
"
e.;yaL
=
•
.
-_
s
_
•
^ g.i
Ne^'KAo pre
REGION 5
,.
,
^
.
.ôu
Ast^noce^ =
Fla^
µ^
;,
`° . -
-
kl+
^.
-•
.
.z^
REGlON 6
l ®'_ kpi center„•_
-
^-^1
..
_
^s.
^
^:^1:
-
-
^
^^ ^
..
A4
Gaines
$, ^^'t'-t •^^ C
__
a6REG10N 4
_
^
QFbreY
LEGEND'
, ^ - ® ^:^-...
'
.,....
..^:,..^^:
`^- BStLemBSP
.
^ x .an*ss
^Y
_
'
_. -
'
`
,
_
. ..-.
-
BC+.
Borden
^
.,
•
f_
Gail
ACkeny
..
maw.
10
VIE
- 30
^,, sw- .
= i<;^dêws
,
Lyntegar Electric Cooperative, INC
Martln, :..
`
•,r}^
Texas 60 Lynn County
Region Compansion Map
Page VII - 3
The second model, Exploratory B, was designed around building a new substation in an overloaded
area to more evenly distribute power and determining necessary distribution line improvements.
Seven substations were placed into this model, three in the northern service and four in the western
service area. Each new substation impacted up to three existing substation service areas. Because
of this, six regions were used to compare the two exploratory plans to evaluate cost effectiveness.
Exploratory C was first developed to correct current and future problems with no new substations.
This was done in Exploratory A, so instead, Exploratory C was developed by turning the current
metering points into substations thereby eliminating the metering points. This was accomplished
through two possibilities. The first was utilizing three 20 MVA large-capacity substations using two
parallel 10 MVA transformers, called Exploratory C1. The second element was developing five
smaller 10 MVA substations spread throughout the area, termed Exploratory C2. Both components
included the building or conversion of distribution line improvements.
Plan Name, '.
Description
Exploratory A NO New Substations
Exploratory B
ExploratoryC
1.
NEW Substations
Eliminating Metering Points (Exp. A)
C1
Three 20 MVA Substations
C2
Five 10 MVA Substations
Explanation of Exploratory, A
Exploratory A, no new substations, was used in all regions of the Lyntegar service area (see following
map). In region one, three substations required additional 10 MVA transformers, Clauene, Meadow,
and Lakeview. In region two, Brownfield and Jess Smith will each increase in capacity. In region
three, Hackberry was the only affected substation. In region four, Seminole was the only substation
effected while region five affected both Seagraves and Pleasant Hill required an additional
transformer. See map following the Exploratory A summary table below.
Explo.raioryAChange3,•;4;
^
New/Additio na l Trans former
New and Converted 477
New and Converted 4/0
New regulators
Capacitors
AgiouptAffected .
,..
Clauene, Meadow, Lakeview, Brownfield, Jess Smith
Hackberry, Seminole, Seagraves, Pleasant Hill
69.4 miles
3.8 miles
8.51 miles
33 (100 Amp or 150 Amp)
108,750 total kVAR
Reprint
A13 - 118
283
•
^.^';.
-
.
^
a!
4
}
J
F
(7`,
_
.
.
.
- ^ ,,,i J l ^:
^
i-:
.
`
•
7
.
^ .i
L
^
,^
^
t
.
.. d
^
`7'"'
f
..re.
t
-.
.
^ 'J
.
-f
.
._
.
i'
.
k.
W' Gx^W
_
,4
I-
r:.}-' 4
r•^-t--r-C-.li .
L^
r ^
r
rµ'
4
,
.
. 4
.
^
.ti_
C•^•^:
!^
r
vTrìMii 5tln
-TLEaEND
-+g
® ra,.'sw-a,
® Nm...a e,p.ey _^
m
enruts&ftW_
,aAcea
.,,,ri0nasê
an uaeACSR
•
^
.
.
^
`_.___.^_ ..-..
^
. ... ..:.
._._
Lyntegar Electric Cooperative, Inc.
Texas 60 Lynn County
5
aY.*
10
Y5
^^.
..
_
.
•
,
^P lorato 1Y Plan k
-,
284
Page VII - 5
V11. EXPLORATORY PLANS
2. Explanation of Exploratory B
Exploratory B, adding new substations, was applied only to regions 1 through 5 of the Lyntegar
service area. In region one, two new substations, Substation 2 and 3, were placed between Clauene
and Meadow. In region two, Substation 1 was placed between Brownfield and Plains, eliminating
the need for additional capacity at Brownfield and Jess Smith. In region three, Substation 4 was
positioned between Lakeview and New Home. In region four, Substation 7 was located between
Seminole and McConal while Substation 6 was sited in region five between Seagraves and Pleasant
Hill. Line conversions in all regions were reduced significantly.
Exploratory B CiiangeS
Area Affected
New Substations
Substation 1, 2, 3, 4, 5, 6, and 7
Increased Capacity
Hackberry
New regulators
Capacitors
24.02 miles
11.49 miles
10.27 miles
22 (100 Amp or 150 Amp)
69,900 total kVAR
See following map for a summary of Exploratory B changes.
Reprint
A13 - 120
285
286
Page VII - 7
3. Explanation of Exploratory Cl
Exploratory C began as no new substations, however, it is identical to Exploratory A. Therefore,
Exploratory C was changed to C1 and C2, two alternate ways of eliminating the nine metering
points. Exploratory C1 utilizes three 20 MVA substations for region 6 and eliminates the seven
southern metering points. These are Welch, Punkin Center, North Lamesa, Arvana, West
Lamesa/Dawson, South Lamesa and Key. (See map on following page.)
The first 20 MVA substation is located directly across the street from the North Lamesa substation
eliminating Punkin Center, half of Arvana, and half of Welch. (The other half of Welch is absorbed
by Ashmore, Foster, and New Moore.) The second large substation is located across the street from
Ackerly and eliminates Key, South Lamesa, and the remaining half of Arvana. The final substation is
located approximately 4.2 miles south of West Lamesa.
ExpioratQry:Cl`lrtiange ,;
New Substations
K
easAffected
New North Lamesa, New Ackerly, Southwest Lamesa
42.27 miles
17.57 miles
New regulators
Capacitors
18.4 miles
18 (100 Amp or 150 Amp)
22,850 total WAR
See map on following page for visual summary.
Reprint
A13 - 122
287
288
Page VII - 9
4.
Explanation of Exploratory C2
Exploratory C2 utilized the installation of five 10 MVA substations to eliminate the 7 southern
metering points. While is this less capacity than the three 20 MVA facilities, fewer line conversions
and voltage devises are needed.
The first substation is located approximately 5 miles south of Welch and northwest of Punkin
Center. Punk-Welch will eliminate both Welch and Punkin Center as well as a majority of North
Lamesa. The second new substation, New Arvana, is located about 2 miles east of North Lamesa
and will eliminate Arvana and the rest of North lamesa. A third new substation, Key-Mesa, will
eliminate both Key and South Lamesa, while the West Lamesa/Dawson will be split into two new
substations, Patricia and Northwest Lamesa.
Expioràtor^-t^Charige's
New Substations
`
f
Areas Add t^^
fDiMz
Punk-Welch, North Arvana, Ke y-Mesa, NW Lamesa, Patricia
11.54 miles
New regulators
Capacitors
6.05 miles
5.02 miles
12 (100 Amp or 150 Amp)
12,300 total kVAR
See map on following page for visual summary.
Reprint
A13 - 124
289
290
Page VII -11
VII EXPLORATORY PLANS
5.
Examination of the Transitions
Each of the exploratory plans was examined for the relative ability to evolve to the planned system
in an orderly sequence by comparing required investments to load growth. Each plan is compared
for the ability to minimize premature investments and to defer as long as practical any investments
that eventually prove to be unnecessary. Each plan is further compared for the ability to serve
increasing load beyond the planning period by addressing excess capacity.
a.
Exploratory Plan Flexibility
Flexibility considerations pertain to two periods of system development.
During the planning
period, each plan is judged for the ability to be modified as necessary in response to changing
conditions without shortening the useful life of facilities. Usually the plan that defers investments
longer fulfills this objective most successfully. At the end of the planning period, each plan is judged
for the ability to defer additional improvements beyond the planning period. Usually the plan that
has excess substation and distribution capacity fulfills this objective most successfully.
In the North-Central portion of the system (Region 1:
Clauene, Lakeview, Meadow, Ropes),
Exploratory Plan A is considered most flexible during the planning period because adding additional
transformers to existing substations increases capacity to serve 51 MVA, while adding two new 10
MVA substations in Plan B allows only 47.5 MVA of total capacity.
In the Central portion of the system, (Region 2: Brownfield, Dixon, Doc Webber, Foster, Jess Smith,
& Tokio) neither Exploratory Plan is considered more flexible during the planning period because
both possibilities end with 60 MVA total capacity. Adding a new 10 MVA substation or a 10 MVA
transformer to an existing substation does not increase capacity.
In the Northeast portion of the system, (Region 3: Central, Hackberry, New Home, Two Draw, &
Wilson) Exploratory Plan B is considered most flexible during the planning period even though no
new substations are being added to this area. By increasing the number of substations and
transformers in other regions, this makes larger (7.5 and 5 MVA) transformers available to be moved
into the Region 3 substations increasing total capacity from 26.5 MVA to 35.5 MVA.
In the Southwest portion of the system, (Region 4: Florey, McConal, Sawyer Flat, & Seminole)
Exploratory Plan B is considered most flexible during the planning period because of the addition of
a new substation and relocation of a transformer, the total capacity went from 26.5 MVA to 38.75
MVA, a 46% increase in capacity.
Reprint
A13-126
291
V11. EXPLORATORY PLANS
Page VII -12
In the Western portion of the system, (Region 5: Pleasant Hill, Seagraves, & Wellman) Exploratory
Plan B is considered most flexible during the planning period because of the addition of a new
substation increasing the total capacity from 23.75 MVA to 33.75 MVA.
In the South-Central portion of the system, (Region 6: Ackerly, Ashmore, New Moore, & 7 Metering
Points) Exploratory Plan C1 is considered most flexible during the planning period because the
addition of four 20 MVA large-capacity substations and one 10 MVA substation, the previous 65
MVA total capacity was increased to 105 MVA. For the C2 plan, five new 10 MVA substations
increase total capacity to only 75 MVA.
b.
Exploratory Plan Sequence,
Sequence considerations pertain to the need to increase capacity in various substations in an
orderly fashion.
Three facets are considered:
1) the number of times substation power
transformers must be moved should be minimized, 2) reducing excess transformer capacity should
minimize investments, and 3) reducing the quantity of transformers to be purchased should make
required investments more effective.
c.
Economic Justifications
The exploratory plans were compared based on economic considerations. Evaluations include cost
analysis in three forms: initial investments, power cost and present worth.
Analysis of initial
investments pertains to expenses incurred annually that are considered proportional to an
individual plant investment. Those expenses include operation, maintenance, depreciation, taxes
and interest. Analysis of power cost considers losses, service charges, and load diversity. Analysis of
losses pertains to the expected wholesale power costs (demand- and energy-related) of losses.
d. Exploratory Plan Economics
The two factors considered in this process are investments and losses. Economic considerations
pertain to the cost of each plan if implemented at present-day costs and amortized over a 35-year
period in addition to the cost of losses over the same time period beginning with present day power
costs.
The individual Net Present Value determinations, by region, can be seen following the
Exploratory Plan Conclusions.
The following monetary values are examples of the Net Present Value of investments and losses
over the 35-year life of the facilities.
Reprint
A13 - 127
292
Page VII -13
...
Exploratory Plan A requires the least improvement investment, however it has the greatest loss
value, so it's NPV was estimated at approximately $19.4 million. Exploratory Plan B requires the
most investment yet has the fewest long-term losses making its NPV approximately $18.8 million.
& Tokio) Exploratory Plan A requires the least improvement investment, however it has the greatest
loss value, so it's NPV was estimated at approximately $18.5 million. Exploratory Plan B requires the
Wilson) Exploratory Plan A requires the least improvement investment, however it has the greatest
loss value, so it's NPV was estimated at approximately $5.5 million. Exploratory Plan B requires the
In the Southwest portion of the system, (Region 4: Florey, McConal, Sawyer Flat, & Seminole)
Exploratory Plan A requires the least improvement investment, however it has the greatest loss
value, so it's NPV was estimated at approximately $11.8 million. Exploratory Plan B requires the
In the Western portion of the system, ( Region 5: Pleasant Hill, Seagraves, & Wellman) Exploratory
Plan A requires the least improvement investment, however it has the greatest loss value, so it's
NPV was estimated at approximately $12.8 million. Exploratory Plan B requires the most investment
yet has the fewest long-term losses making its NPV approximately $12.1 million.
Points) Exploratory Plan C2 requires the least investment (NPV of $25.4 million and NPV losses of
$12.4 million).
Exploratory Plan C1 requires the most improvement investment (NPV of $76.9
million) with NPV losses of $10.9 million due to the construction of three 20 MVA large-capacity
substations and one 10 MVA substations and the large amount of line conversions and regulators
needed under this plan.
e. Other Justification
Each of the options presented above are further compared based on two other important factors:
reliability and environmental acceptability.
Reprint
A13 - 128
293
Tti
Vtil. EXPLORATORY PLANS
f.
Page Vil -14
Exploratory Plan Reliability
Reliability issues pertain to the ability to maintain power delivery to all consumers during any singlecontingency occurrence.
In the North-Central portion of the system (Region 1: Clauene, Meadow, Claudow, Lakeview,
Lakeadow, and Ropes), Exploratory Plan 8 is considered more reliable than other plans due to the
increase in service substations and number of feeders to the same area. Currently, 16 circuits are
used to service this area. With the addition of Claudow in the First Transition and Lakeadow during
the Second (Ropes is removed during the Second Transition), there will be a total of 21 circuits now
supplying a slightly smaller service area as previous.
& Tokio), Exploratory Plan B is considered more reliable than the other plans because of the addition
of the Tokio-Brown substation, there is a growth from 24 to 28 feeders. Due to this new substation
during the First Transition, load balancing between the other substations will keep the surrounding
service areas well below their OA base ratings.
Wilson), Exploratory Plan B is considered most reliable than other plans because two circuits will be
added to increase reliability as well as increasing the transformers. Hackberry and Wilson will each
receive a 7.5 MVA transformer (from New Moore and Meadow) during the Second Transition phase.
In the Southwest portion of the system, (Region 4: Florey, McConal, Sawyer Flat, & Seminole),
Exploratory Plan B is considered more reliable than other plans because Semino-Conal substation
will be built during the Second Transition phase, adding three eircuits to the area and allow the
other service to remain below their OA base ratings via load balancing.
In the Western portion of the system, (Region 5: Pleasant Hill, Seagraves, & Wellman), Exploratory
Plan B is considered most reliable than other plans because of the addition of the Sea-Hill
substation. The increase of four circuits will increase reliability somewhat as well as balancing out
the other substations.
Points), Exploratory Plan C1 is considered more reliable than plans A or C2 because it removes
several metering points on five 10 MVA substations rather than three 20 MVA large-capacity
substations. By spreading the new substations over the large area, there is significantly fewer losses
Reprint
A13 - 129
294
Page VII -15
as well as fewer line conversions. Each new substation consisted of three or four circuits serving a
smaller area than the previous metering point, significantly increasing reliability.
g.
Ex loratory plan Environmental Acceptability
Environmental issues pertain to protection of the environment from undue disturbance resulting
from construction, operation or maintenance of facilities.
Exploratory Plan A Is considered the most environmentally acceptable plan to pursue because it
incorporates the least amount of disturbed area since no substation are constructed, transformers
are merely added to existing locations. Plan B is based on the conttruction of new substations
which disturbs an acre of land and occasionally requires the addition of new line.
& Tokio), Exploratory Plan A is considered the most environmentally acceptable plan to pursue
because it incorporates the least amount of disturbed area since no substation are constructed,
transformers are merely added to existing locations. Plan B is based on the construction of new
substations which disturbs an acre of land and occasionally requires the addition of new line.
Wilson), Both Plan A and Plan B had the same line improvements. The difference between the plans
is with increasing the substations capacity over new substations. Since building and upgrading
substations in other regions, the New Substations (Plan B) allow for transformers from other regions
to be moved into one or more of the existing substations in this region. Plan A called for purchasing
new transformers and Plan B used transformers from other stations. Since moving transformers is
cheaper than purchasing new, Plan B is considered more acceptable than Plan A.
In the Southwest portion of the system, (Region 4: Florey, McConal, Sawyer Flat, & Seminole),
Exploratory Plan A is considered the most environmentally acceptable plan to pursue because it
incorporates the least amount of disturbed area since no substation are constructed, transformers
are merely added to existing locations. Plan B is based on the construction of new substations
which disturbs an acre of land and occasionally requires the addition of new line.
In the Western portion of the system, (Region 5: Pleasant Hill, Seagraves, & Wellman), Exploratory
Plan A is considered the most environmentally acceptable plan to pursue because it incorporates
the least amount of disturbed area since no substation are constructed, transformers are merely
Reprint
A13 - 130
295
Page VII -16
V11 EXPLORATORY PLANS
added to existing locations. Plan B is based on the construction of new substations which disturbs
an acre of land and occasionally requires the addition of new line.
Points), Exploratory Plan C1 is considered the most environmentally acceptable plan to pursue
because it incorporates the least amount of disturbed area. Plan C1 addresses the construction of 4
substation (three 20 MVA and one 10 MVA) while Plan C2 is based on the construction of five 10
MVA substations. Since the size of a 10 MVA and 20 MVA substation is not different, fewer new
substations is considered more environmentally acceptable.
Overall, Exploratory Plan A/Cl is considered the most environmentally acceptable plan to pursue
because it integrates the least amount of disturbed area.
B. Exploratory Plan Conclusions
Each of the issues concerning options presented above is tabulated below by region to summarize
the resulting conclusions. In Regions 1 through 5, Plan A is to redirect power flow and add a second
transformer in parallel with the one currently at the substation, while Plan B is to build a new
substation in the area to even out the load and service areas. In each regional assessment, the first
choice is given a weight of two while the second is given a weight of one. In Region 6, Plan A, C1,
and C2 are viable options, where C1 is comprised of large-capacity substations and C2 is smallercapacity substations. Here, the Choice One will have a weight of 3 points, Choice Two has a weight
of 2 points, and Choice Three will be worth 1 point.
Each of the considerations were given equal weight except the economic considerations, which
were given one point of extra weight.
Reprint
A13 - 131
296
Pa Le VII -17
1. Region 1: North Central substation s
2.
Plan
Plan
Considerations
A
B
Flexible:
1
2
Economics:
2
3
Reliable:
Environment:
1
2
2
1
TOTAL:
6
8
Plan
A --
Plan
Region 2: Central substations
0
2
B
0
3
Reliable:
1
2
Environment:
2
1
TOTAL:
5
6
Plan
A
1
2
Plan
B
2
3
Reliable:
1
2
Environment:
2
1
TOTAL:
6
8
Plan
A
Plan
B
Flexible:
1
2
Considerations
Flexible:
Economics:
3.
Region 3: Northeast substations
Considerations
Flexible:
Economics:
4.
Region 4: Southwest substations
Considerations
Economics:
2
3
Reliable:
1
2
Environment:
2
1
TOTAL:
6
8
Reprint
A13-132
297
Page VII -18
5. Ramn%--WeA-wbstations
Plan
A
1
Plan
B
2
2
3
Reliable:
1
2
Environmgnt:
2
1
TOTAL:
6
8
Plan
A
Plan
C1
Flexible:
1
3
2
Economics:
Reliable:
Environment:
3
1
3
2
4
2
2
3
1
TOTAL:
8
9
10
Considerations
Flexible:
Economics:
6.
Region 6: ONCOR Metering Points
Considerations
Plan
C2
Reprint
A13 - 133
298

A13-84 - PUC Interchange

Transcription

Similar documents

Reprint - PUC Interchange

long grove, illinois

Visit Wild Birds Unlimited Today. Now thru 4/8, Hummingbird Feeder

Hyatt Place Cincinnati

Visit Wild Birds Unlimited Today.

Industrial Embedded Testing sensors

31.18 Acres | PEDERNALES RIVER ESTATE SITE | Gillespie

Student Workbook—Exploration 6 Feeder Birds Coloring Book

Beginners Guide To Generators - Draft2v3

Manual - HP Archive

Chapter 7 Review of Power System Plans