Specification E-649
Feb. 10, 2009
Page 13 of 18
ATTACHMENT II
ORIENTATION OF BAR CODE CHARACTERS
L
0,05L or O24"
QUIET
ZONE
*
Mfg.
I.D.
Code
Serial Number
*
QUIET
ZONE
* Start/Stop Character
PUC Docket No. 40627
Response to OPC 1-52, Attachment 2
Page 14 of 19
250
Specification E-849
Feb.10, 2009
Page 14 of 18
ATTACHMENT III
TRANSFORMER SPADE SUPPORTS DRAWING
SttPl'C7R"f ANOLT~"`, ,,
,.-°"°
3
FLAT WASHER
FLAT a'ASIM
ChTSt.'Ti.(s"VC_.
'``^... ..:.
TiARRTBR STMMAT
`^.
^
"A, NIX NUT
LCICIC WASHER
TlARRTER ST?tKtAT CAPSCRBW
STAR WASHER
t^)
^?
^^
T!'C)sHrTlfi Sf..Arx';
ba..-,.v,..-.w..^
_.^--
PUC Docket No. 40627
Response to OPC 1-52, Attachment 2
Page 15 of 19251
SpecNication E-649
Feb. 10, 2009
Page 15 of 18
ATTACHMENT IV
GENERAL INF0RI4fATIC3N
1
SIGNACL
a
b00.1i «t t
st,a,^.r
SIGNAGE-PAD MOUNT 3 PF3
.,_^^..r.^.^ ^.. .. .
1000-14A SIGNAGE-PAD MOUNT 3PH
TYPICAL SIGNAGE PLACEMENT FOR 3 PHASE TRANSFORMER
T :^iC xiBER .Y °^ T^
^ IktC`l`i_
'^`
61'^[7R\S'R ` t lffttK
THREE IN ONE
NA xkIN f„ Ss<..N
r _^
c>R^^,^^
^
3 KA+tS F()FR'
KU 1: Et. IS SET
TO NORMAL r,t'r N
s:.ST'k' Yl.? `:Y.AItlc2:R
\
It
4
NO rc:ss
^
^f,•^
^ ^^^
EAULT INDICATOR
T.*t.^T,T C:Y^FT4ATOR
.
^
.. ,,,..,,.. „..
...^:..
... .,.
....... .....,..
^
j3^^T.A9£, PAD 11_,f.y!C`."rL[3
"^'21:A^...,,:^ cix i^^'9.^3^n_:_.
ri^ca„5^.
a CITY OF AUSTC.V DB.+. AUaTtN BMERi;iV ?(h73
PUC Docket No. 40627
Response to OPC 1-52, Attachment 2
Page 16 of 19252
Specification E-649
Feb. 10, 2009
Page 16 of 18
ATTACHMENT Wa
TYPICAL EXTERNAL SIGNAGE MATERIAL
REQUIREMENTS OF 3-PHASE PAD-MOUNTED
TRANSFORMERS
"No PCBS" ecal; 6 inch X 6 inch, blue, Base Film: 0.0035-inch cast polyvinyl chloride, with UV inhibitors as
per MqL-]v1-22106A, Cyasorb tJV-9 light absorber C14H1203, Gloss SOUL 94 rated. Over lamination: 002PVF
(pnlyvlnyltyouride) tedlar UV screening film from E.I. Dupont. Cold-seal bonded. Adhesive: 0.002-inch permanent
acrylic hi-tack, with high-temperature-resistant Elasticisors for adhesion at 40 deg. F, PSTC test method: #1
modified for a 15 minute dwell time, with 2 mils of adhesive, 56 oz/inch width rating. Ink: Silkscreen type 4, with
automotive grade pigments and binders, 0.0004-inch thick + 0.0001, inch high pigment volume concentration total
PVC 40-50 (copper phthalocyanines). Liner: 0.0007-inch ± 0.001-inch Kraft, coated one side chemical resistant.
Salt spray 240 hours 5%, at 100 degrees, with no blistering, color change, or other material degradation. No effect
when immersed in diesel fuel, motor oil, anti-freeze, detergent 2 °fa, ammonium hydroxide (12% and 391A),
kerosene, acetic acid, acetone and water. Service temperature range: -+30 to 4 170 deg. F. Minimum lifetime exterior
durability of 15 years from installation date with proper surface preparation.
Approved Manufacture or equal: Mitrographers, catalog number COA-001
"SIZE KVA" decal: width as required, 2 7/8 inches tall, Engineer Grade, adhesive reflective vinyl. Yellow
numbers, black background.
113 In 1" decal: Dimensions will be approximately 10" wide X 10.5" tall. Sign shall be worded as followes:
WARNING To Report Problems Call (512) 322-9100 HIGH VOLTAGE Hazardous voltage inside. Can shock,
bum or cause death. Keep out if open or unlocked, immediately call electric power and light company.
ADVERTENCIA Para Reportar Problemas Llame al: (512) 322-9100 ALTA TENSION Contiene voltaje
peligroso. Puede producir descarga o sacudida el6ctrica, quemaduras o ausar muerte. Prohibida Is entrada. si esti
abierto o sin llave, inmediatamente flame a la central e1&trica. WARNING To Report Problems Call: (512) 3229100 Keep shrubs and structures at least 10 feet away from this side of equipment for safe utility maintenance and
operation. ADVERTENCIA Para Reportar Prob{emas Llame al: (512) 322-9100 Mantenga arbustos y
construccibn por lo menos a 10 pies de distancia de este lado del equipo para seguridad on el mantenimiento y
operacibn. ONE CALL SYSTEM of TEXAS 1-800-545-6005 CALL BEFORE YOU DIG IT'S THE LAW
UNA LLAMADA SISTEMA de TEXAS 1-500-545-6005 LLAME ANTES DE EXCAVAR ES LA LEY.
Base film; ,0035 cast palyvinylchloride with uv inhibitors mil-m-22106a. (cyasorb uv-9 light absorber cI4h1203).
Gloss 80 ul 94 rated. Overiamination: ,002pvf (polyvinyttlouride). Tedlar uv screening film from e.i. dupont. Cold
seal bonded. Adhesive .002 permanent acrylic hi-tack with high temperature resistant elasticisors for adhesion at 40
degrees f. Pstc test method: #1 modified for a 15 min dwell time with 2 mils of adhesive 56 oz/inch width rating,
Ink: silkscreen type 4 with automotive grade pigments and binders .0004" thick dry +/- .0001" high pigment volume
concentration total pvc 40-50 (copper phthalocyanines). Liner: .0007" +!- .001" kraft coated one side. Chemical
resistance: salt spray 240 hours 5% at 100 degrees f if no blistering, color change, or other material degradation. No
effect when immersed in diesel fuel, motor oil, anti-freeze, detergent 2%, ammonium hydroxide (12% and 39°/u),
kerosene, acetic acid, acetone and water. Service temperature range: -40 to + 170 degrees f. Labels shall have a two
year shelf life and a minimum lifetime exterior durability of 15 years from installation date with proper surface
preparation. All stick on signs will have a written guarentee of no fading or pealing for 15 years or they will be
replaced in the field free of charge.
Approved Manufacturer or equal:
Uticom, no catalog number
Electromark, no catalog number
Mitrographers, no catalog number
PUC Docket No. 40627
Response to OPC 1-52, Attachment 2
Page 17 of 19253
Specification E-649
Feb. 10, 2009
Page 17 of 18
ATTACHMENT IV B
GENERAL INFORMATION
SIGNAGE
^^art a+s
_ _
1000-14B
SPECIFICATION-PAD MOUNT JPH
...._...
..._,^
,_,__...._...-.-........
SPECIFICATION-PAD MOUNT3PH
^^....s» a...^
1'f'PICAL SIGNAGE PLACEMENT FOR J PHASE TRANSFORMER
NOTE, COVER FOR
19164" SMALL HAVE A
STUD THAT FITS
THROUGH THE HOLE
WITH A DOLT TO
HOLD COVER IN
PLACE.
T HR E E: IN (> N I:
S4`a.RN INc: sI A; -1
1
^
1
1
NO PC'BS
^
SIZE K%'A
10164" COVERED
i)LE FOR FAA+LT
H
ltiIDICATOIi 1.iGHT
FALTLT ^„^,
I '^',BICA'COR.
0 CITY OF AUSTIN DBA AUSTIN ENERGY :002
PUC Docket No. 40627
Response to OPC 1-52. Attachment 2
Page 18 of 19254
Specification E-849
Feb. 10, 2009
Page 18 o118
ATTACHMENT V
AUSTIN ENERGY TRANSFORMER TEST REPORT FORM
fnsert name of manufacturer)
CERTIFIED TRANSFORMER TEST REPORT
VENDOR NAME
VENDOR PURCHASE ORDER NUMBER:
AUSTIN ENERGY PURCHASE ORDER NUMBER:2;
AUSTIN ENERGY STOCK NUMBER-
12F.
ANSI I
SE$I8,4.
NUMBER
PERCENT
IMPEDANCE
PHAS
3PH
EXCITING
CURRENT
MANUFACTURER ORDER NUMBER
MFO CATALOGUE NUMBER:
-^ MANUFACTURER INVOICE NUMBER
^
MFG DRAWING NUMBER.
TEST DATE
SHIP DATE:
FR Q i NCY
60 Hz
K66
LOSSES
_ASV_IRFQ
ME&WEDry_ ^
Nn•LOAD LOSS LOAD LOSS
{ i11VWA61;,
HIGH VOLTAGE
- - ----.•. 1/d3EGULAT4sjN AT
MF.E1W=
TOTAL LOSfi
DOE
^ ^^ ^Y9
t ^^pNTEED LC^SSES;
NOTES:
to 96°C.
1 ► Lomas are measured at 100% of rated voltage, No-load loss data corrected to 20° C Load Loadd data corrected
2) All uwtsfom»rs were manufactured using rtisulalmg huid containing less than 1 PPM PCB. ASTM D4059 Test
Certficatfon avadaaeL
3)'t'tte winding tanspaer:au,re rise ^b ^ rs .^ Cvart tanVerattre does not exceed 65'C
d) E^ Gng t^ent is rr^^rrs ;red at i C1i?%rated ioa+3,
5) All xenefomrowtt titled hwe recciveti and pissed the krlvNmg test in accordance with ANStAEEE C57.12.00 West
edmon Csntnwy. Rato, Lou, Pdw.ruy and Phase Rebikwi", Routine impulse. induced Voltage, Applied Voltage
THE MANUFACTURER CERTIFIES THAT THIS TEST REPORT 19 A TRUE AND ACCURATE RECORD OF FINAL PRODUCT IOWLINE
TEST THAT WERE CONDUCTED IN ACCORDANCE WITH CURRENT ANSI TRANSFORMER TEST STANDARDS, AND THAT THE
ABOVE TRANSFORMERS WITHSTOOD THESE TESTS
NAME OF CERTIFYINV INDMDUAL:
PUC Docket No. 40627
Response to OPC 1-52, Attachment 2
Page 19 o11255
PUC Docket No. 40627
Response to OPC 1-52, Attachment 3
Page 1 of 7
Specification E-708
CITY OF AUSTIN - AUSTIN ENERGY (AE)
PURCHASE SPECIFICATION
FOR
TRANSFORMER, NETWORK, THREE-PHASE, 12.47 KV
APPROVAL
PROCESS MANAGERIM&ESS MANAGER
DATE
PREPARED BY
ISSUANCEIREVISION
05/29/97
Steve Booher
Revision
George Martinez / Peter Soosay_m _
03/10/99
George Martinez
Revision
George Martinez ! David Sloan
03/22199
George Martinez
Revision
George Martinez I David Sloan
07/16/99
George Martinez
Revision
Carl Nance / George Martinez
03/04/05
Steven Booher
Revision
t18/27/11
Steven Booher
Revision
REASON FOR REVISION
03/10/99 - Change to 12.47 KV
AFFECTED PARAGRAPHS
Title change, remove 1.1.3, change ratings 1,2.2,
Change BIL 1.2.4, remove contacts 3.3, add contacts
3.4, bushing 4.1, changed 4.3, added 4.9, changed
losses and evaluation 7.1.
3122l99 -Change LV throat requirements. Move General
Requirements to Supplemental Terms and Conditions
07116199 - Network Transformer to Include
2500 KVA, 4801277V
Revised transformer ratings, Added sudden pressure
Relay, Revised Evaluation
6/27/11 Add DOE requirement and revised loss
requirements
Section 4.2, 6.0, 8.0, 9.0
1 2 2, 42, 4.8
1.2.2, 3.7, 6.1
3,8 and 6.1
This specification, until rescinded, shall apply to each future purchase and contract for the commodity described herein.
Retain for future reference.
256
PUC Docket No. 40827
Response to OPC 1-52, Attachment 3
Page 2 of 7
Specification E-708
June 27, 2011
Page I of 5
CITY OF AUSTIN- AUSTIN ENERGY (AE)
PURCHASE SPECIFICATION
FOR
TRANSFORMER, NETWORK, THREE-PHASE, 12.47 KV
1.0
SCOPE AND CLASSIFICATION
1.1
1.2
2.0
Scope
1.1.1
This specification covers three-phase oil filled network type transformers.
1.1.2
No deviations from this specification will be permitted.
Classification
1.2.1
Voltage shall be 12,470 Volts delta, 480Y/277, or 216Y/125 Volts.
1.2.2
Transformer rating shall be 500, 750, and 1000for 2l6Y/125 and 500, 750,
1000, 1500, and 2000 kVA for 480Y/277 as specified on bid request.
1.2.3
No-load high voltage taps shall be 5% below, 2 1/2% below, rated 2 1/2%
above, and 5% above.
1.2.4
Basic Insulation Level (BIL) shall be 125 kV for windings, 95 kV for bushings.
APPLICABLE STANDARDS
Network transformers furnished under these specifications shall meet all applicable, ASTM,
EEl-NEMA, ANSI, AND IEEE Standards, latest revision.
2.1
ANSI C57.12.40 - Subway and Vault Types (Liquid Immersed) Requirements.
2.2
ANSI/ASTM D3487 - Mineral Insulating Oil Used in Electrical Apparatus.
2.3.
ASTM D2300 - Standard Test Method for Gassing of Insulating Oils under Electrical
Stress and Ionizing. Modified Pirelli Method R (1991)
2.4
ASTM D1816 - Standard Test Method for Dielectric Breakdown Voltage of Insulating
Oils of Petroleum Origin Using VED Electrodes.
2.5
ASTM D877 - Standard Practices for Sampling Water-Formed Deposits. R (1994)
2.6
ASTM D971 - Standard Test Method for Interfacial Tension of Oil against Water by the
Ring Method.
2.7
ASTM/D1500 - Standard Test Method for ASTM Color of Petroleum Products.
(ASTM Color Scale) (1P Designation: 196/91)
2.8
ASTM D1524 - Standard Test Method for Visual Examination of Used Electrical
Insulating Oils of Petroleum Origin in the field.
2.9
ASTM D1533 - Standard Test Method for Water in Insulating Liquids. (Karl Fisher
Method)
2.10 ASTM D924 - Standard Test Method for Dissipation Factor and Relative Permittivity of
Electric Insulating Liquids.
257
PUC Docket No. 40627
Response to OPC 1-52, Attachment 3
Page 3 of 7
3.0
4.0
Specification E-708
June 27, 2011
Page 2 of 5
FUNCTIONAL REQUIREMENTS
3.1
Transformers shall be self-cooled, 65 degrees (°) Centigrade (C) temperature rise above
ambient, vault type construction, suitable for occasional submerged operation
3.2
Marking of terminals, winding connections, and vector relationships of windings shall be
as shown on the attached drawing (Attachment I).
3.3
The transformer shall be equipped with a glass or magnetic type liquid level indicator on
all oil filled compartments. The liquid level gauge shalt have a dark dial face with light
markings and a light indicating hand, The dial markings shall show the 25 degrees O
centigrade (C) level and the minimum and maximum levels. The words "Liquid Level"
shall be on the dial or on a suitable nameplate mounted adjacent to the indicator.
3.4
The transformer shall be equipped with a dial type thermometer on the main tank for
indicating liquid temperature. The thermometer shall have a black indicating hand and a
red maximum indicating hand. The main tank thermometer shall be provided with
electric alarm contacts.
3.5
A three pole, three position switch for disconnecting and grounding the high voltage
feeder shall be provided on the transformer. The switch shall remain it alignment under
normal installation and operating conditions. The switch shall have a continuous rating
of 200 amperes at 60 cycles. The switch shall be provided with three operating
positions: "OPEN," "CLOSED," and "GROUND," and shall be marked as such. In the
closed position, the switch shall be capable of withstanding the full short circuit duty of
the transformer. In the ground position, the switch shall be capable of withstanding
15,000 amperes short circuit current. An electrical interlock slid] prevent movement of
the switch from any position when the transformer is energized. The sequence of
operation shall be open, closed and ground, and the switch shall be designed so that
when it is moved from open to ground, or ground to open. The operSor shall pause in
the closed position to give the electrical interlock time to engage if the transformer is
energized. The operating handle shall be equipped for padlocking the switch in each
direction.
3.6
Alarm contacts shall be suitable for interrupting:
a.
0.02 ampere direct-current inductive load
b.
0.02 ampere direct-current noninductive load
c.
2.5 ampere alternating-current noninductive or inductive load
d.
250 volts maximum in all cases
3.7
A sudden pressure relay shall be mounted on the main tank to respond to sudden
increases in internal gas pressure. A seal-in relay with contacts for alarm and tripping
and a reset switch shall be externally mounted. Normal operating voltage of the sealin
relay shall be 125VAC. Adequate surge suppression to prevent false operations due to
transient voltages on control leads shall be provided. The sudden pressure relay shall be
designed such that external vibration or mechanical shocks shall not cause false
operations. All mechanical provisions and equipment for testing shall be provided. In
addition, the seal -in relay and wiring shall be rated for in-circuit testing with remote
lockout relay.
3.8
All transformers supplied to AE shall meet or exceed the efficiency values in accordance
with Department of Energy 10 CFR 431 part III - Energy Conservation program for
Commercial Equipment: Distribution Transformers Energy Conservation Standards
table 1. 1. Certified test data by serial number shall be provided with each transformer.
PHYSICAL REQUIREMENTS
258
PUC Docket No. 40627
Response to OPC 1-52, Attachment 3
Page 4 of 7
4.1
The transformer shall have 600 ampere minimum sidamounted apparatus bushings on
the high side. The bushings shall be bolted to the tank for ease in replacement. Welded
bushings are not acceptable. Bushings provided shall be Elastimold K650•S 1(copper)
or AE approved equivalent.
4.2
The low voltage throat and bushings shall be in accordance with ANSI C57.12.40,
Figure 3 for 216Y/125V transformers rated 500 kVA and 480Y/277V transformers rated
500, 750, and 1000 kVA. Figure 4 for 216Y/125V transformers rated 750, 1000, and
1500 kVA; and 480Y/277V transformers rated 1500, and 2000 kVA.
4.3
The neutral bushing shall be insulated from the transformer tank. The ground to tank
shall be made by a flexible copper braid bolted between the transformer tank and the
neutral bushing of the transformer, Copper braid size shall be equal to 500 MCM bare
copper. The neutral bushing shall have a four hole NEMA pad for 1000 kVA and
smaller and a six-hole NEMA pad for 1500 and 2000 kVA transformers.
4.4
The high voltage compartment shall be completely sealed and filled with insulating oil
prior to shipping.
4.5
The tap changer shall be designed for de-energized operation. An indicator shall clearly
show the position of the tap changer.
4.6
The transformer tank shall be of a sealed construction, consisting of a welded main
cover equipped with lifting lugs and hand-hole cover(s) with gasket.
4.7
Jack pads or bars shall be provided so that there is three inches (3") of clearance up from
the bottom of the transformer for lifting jacks.
4.8
Transformer sizes listed below are maximums and shall not be exceeded.
KVA
500
750
1000
1500
2000
4.9
5.0
Specification E-708
June 27, 2011
Page 3 of 5
EiGI
ETh
7'0"
7'0"
7'6"
8'0"
8'6"
6'0"
6'2"
6'2"
6'6"
61"
3'6"
4'0"
4'0"
4'6"
510„
All high voltage windings shall be made of copper.
INSULATING OIL REQUIREMENTS
5.1
The insulating oil shall be non polychlorinated biphenyl (PCB), defined as containing
less than one part per million (ppm) PCB. Certification of the non-PCB oil shall be
furnished and shall include the method of testing used.
5.2
The transformer nameplate shall be marked "non-PCB." In addition, a blue "non-PCB"
label of a minimum 1"X 2" size shall be installed directly below the nameplate.
5.3
The oil shall conform to the latest revision of ANSI/ASTM D3487, Type [l. The
gassing coefficient shall be negative when tested in accordance with ASTM D2300,
Section 2.0.
5.4
The Contractor shall supply test reports, which verify compliance with the oil
performance requirements given below:
Test and Method
Dielectric Strength,
ASTM D-18S6, kV
minimum,
0.04 inch gap:
0.08 inch gap:
20 kV
40 kV
259
PUC Docket No. 40627
Response to OPC 1-52, Attachment 3
Page 5 of 7
Dielectric Strength,
ASTM D-877, kV
minimum
30 kV
Power Factor, ASTM D-924,
% maximum; 25°C
0.15
% maximum; 100 ° C
1.50
Interfacial Tension,
ASTM D-971, mN/m
minimum:
35
Color, ASTM D-1500,
ASTM Units:
Visual Examination,
ASTM D-1524
Specification E-708
June 27, 2011
Page 4 of 5
1.0
Bright and Clear
Water Content,
ATSM D-1533,
ppm, maximum:
5.5
25
The Contractor shall be subject upon request, to furnish laboratory test data for the
insulating oil. Oil furnished under these specifications shall be subject to tests and any
insulating oil failing these tests will be returned to the Contractor at the Contractor's
expense.
6.0
COST EVALUATION
6.1
All network transformer bids will be evaluatedand awarded based on purchase price,
guaranteed no load losses, and guaranteed winding losses. The founula and cost of
losses are as follows:
Total Evaluated Bid (owning cost) = Bid Price + ( cost of no load losses) x (quoted
guaranteed no load losses) + (Cost of winding losses) x (quoted guaranteed winding
losses)
Cost of no load losses =$5,239.00/kW
Cost of winding losses = $3,123.00/kW
6.2
Each Bidder shall quote the guaranteed no load losses and guaranteed winding losses at
the time of bid opening.
6.3
Before or upon delivery, Contractor's certified factory test reports shall be provided to
AE for final review.
6.4
Losses shall be the actual tested losses corrected to 20°C no load and 85°C for load,
reported by serial number and City of Austin purchase order number for each
6.5
The actual losses of any one transformer on an ordershall not exceed the quoted
guaranteed losses by more than the following percentages:
transformer delivered.
No load losses
Network Transformer
6.6
10%
T t 1 osses
6%
Penalty
260
PUC Docket No. 40627
Response to OPC 1-52, Attachment 3
Page e of 7
Specification E-708
June 27, 2011
Page 5 of 5
For each transformer where the actual losses exceed the quoted guaranteed losses, a
penalty will be assessed through a price reduction for each transformer.
Penalty =
2I($5,239.00/kW) (actual no load losses - quoted guaranteed no load
losses) +(53,123.00/kW) (actual winding losses - quoted guaranteed
winding losses)]
261
PUC Docket No. 40627
Response to OPC 1-52, Attachment 3
Page 7 of 7
Specification E-0709
CITY OF AUSTIN - AUSTIN ENERGY (AE)
PURCHASE SPECIFICATION
FOR
k
TRANSFORMER, NETWORK, THREE-PHASE, 34.5 KV
ISSUANCElREVISION
APPROVAL
PROCESS SUPV. I MATERIALS SUPV.
DATE
PREPARED BY
05/29/97
Steve Booher
Revision
George Martinez / Peter Soosay
03/10/99
George Martinez
Revision
George Martinez 1 Peter Soosay
03/22/99
George Martinez
Revision
George Martinez / David Sloan
07/16199
George Martinez
Revision
Peter Soosay / George Martinez
03/04/05
Steven Booher
Revision
06/29/11
Steven Booher
Revision
REASON FOR REVISION
Network Transformetr to Include
AFFECTED PARAGRAPHS
Sections: 1.2.2.4.2,4.8
2500 KVA, 480/277VAdd sudden pressure device,
revised evaluation, Revised transformer size ratings,
added Warranty, and drawing with test reports.
Section 3.7, 8.1
8/27/11 Added DOE requirements and revised loss
requirements
Section 7.0 - 7.6
Section 3.8 and 8.1
6/27111 Added 2500 KVA 4160/2400 requirements
Section 1.2.2 and 4.3
Section 1.2.2
This specification, until rescinded, shal apply to eaoh future purchase and contract for the commodity described herein,
Retain for future reference.
262
specification E-709
June 29, 2011
Page 1 of 6
CITY OF AUSTIN- AUSTIN ENERGY
PURCHASE SPECIFICATION
FOR
TRANSFORMER, NETWORK, THREE-PHASE, 34.5 KV
1.0
SCOPE AND CLASSIFICATION
1.1
1.2
Scope
1,1.1
This specification covers three-phase oil filled network type transformers.
1.1.2
No deviations from this specification will be permitted.
Classification
1.2.1
Voltage shall be 34,500 Volts delta, 480Y/277 or 216Y/l25 Volts.
1.2.2
Transformer rating shall be as specified on bid sheet.
a. 500, 750, and 1000 for 216Y/125
b. 500, 750, 1000, 2000 and 2500 kVA for 480Y/277
c. 2500 kVA for 4160/2400 '
1.2.3
1.2.4
2.0
No-load high voltage taps shall be 5% below, 2 1/2% below, rated 2 1/2% above, and 5%
above,
windings, 150 kV for bushings.
Basic Insulation Level ( BIL) shall be 200 kV for
APPLICABLE STANDARDS
ASTM, EEI-NEMA,
Network transformers furnished under these specifications shall meet all applicable,
ANSI, AND IEEE Standards, latest revision.
Liquid Immersed) Requirements.
ANSI C57.12.40 • Subway and Vault Types (
2.1
in Electrical Apparatus.
ANSI/ASTM D3487 - Mineral Insulating Oil Used
2.2
Electrical Stress and
Standard Test Method for Gassing of Insulating Oils Under
2.3. ASTM D2300 Ionizing. Modified Pirelli Method R (1991)
2.4
ASTM D1816 -
Standard Test Method for Dielectric Breakdown Voltage of Insulating Oils of
Petroleum Origin Using VED Electrodes.
2.5
ASTM D877 -
2.6
ASTM D971 -
2.7
ASTMID 1500 -
Standard Practices for Sampling Water-Formed Deposits. R(1994)
Standard Test Method for Interfacial Tension of Oil Against Water by the Ring Method.
(ASTM Color Scale)
Standard Test Method for ASTM Color of Petroleum Products.
( 1P Designation: 196/91)
18
ASTM D1524 -
Examination of Used Electrical Insulating Oils
Standard Test Method for Visual
of Petroleum Origin in the field.
PUC Docket No. 40627
Response to OPC 1-52, Attachment 4
Page 1 of
h3
Specification E-709
June 29, 2011
Page 2 of 6
2.9
ASTM D1533 -
Standard Test Method for Water in Insulating Liquids. (Karl Fisher Method)
2.10
ASTM D924 -
Standard Test Method for Dissipation Factor and Relative Permittivity of Electric Insulating
Liquids.
3.0
FUNCTIONAL REQUIREMENTS
3.1
Transformers shall be self-cooled, 65 degrees (°) Centigrade (C) temperature rise above ambient, vault
type construction, suitable for occasional submerged operation.
3.2
Marking of terminals, winding connections, and vector relationships of windings shall be as shown on
the attached drawing (Attachment I).
3.3
The transformer shall be equipped with a glass or magnetic type liquid level indicator on all oil filled
compartments. The liquid level gauge shall have a dark dial face with light markings and a light
indicating hand. The dial markings shall show the 25 degrees (°) centigrade (C) level and the
minimum and maximum levels. The words "Liquid Level" shall be on the dial or on a suitable
nameplate mounted adjacent to the indicator.
3.4
The transformer shall be equipped with a dial type thermometer on the main tank for indicating liquid
temperature. The thermometer shall have a black indicating hand and a red maximum indicating hand.
The main tank thermometer shall be provided with electric alarm contacts.
3.5
A three pole, three position switch for disconnecting and grounding the high voltage feeder shall be
provided on the transformer. The switch shall remain in alignment under normal installation and
operating conditions. The switch shall have a continuous rating of 200 amperes at 60 cycles. The
switch shall be provided with three operating positions: "OPEN,', "CLOSED", and "GROUND", and
shall be marked as such. In the closed position, the switch shall be capable of withstanding the full
short circuit duty of the transformer. In the ground position, the switch shall be capable of
withstanding 15,000 amperes short circuit current. An electrical interlock shall prevent movement of
the switch from any position when the transformer is energized. The sequence of operation shall be
open, closed and ground, and the switch shall be designed so that when it is moved from open to
ground, or ground to open. The operator shall pause in the closed position to give the electrical
interlock time to engage if the transformer is energized. The operating handle shall be equipped for
padlocking the switch in each direction.
3.6
Alarm contacts shall be suitable for interrupting:
3.7
3.8
a.
0.02 ampere direct-current inductive load
b.
0.02 ampere direct-current noninductive load
c.
2.5 ampere alternating-current noninductive or inductive load
d. 250 volts maximum in all cases
A sudden pressure relay shall be mounted on the main tank to respond to sudden increases in internal
gas pressure. A seal-in relay with contacts for alarm and tripping and a reset switch shall be externally
mounted. Normal operating voltage of the seal-in relay shall be I2SVAC. Adequate surge suppression
to prevent false operations due to transient voltages on control leads shall be provided. The sudden
pressure relay shall be designed such that external vibration or mechanical shocks shall not cause false
operations. All mechanical provisions and equipment for testing shall be provided. In addition, the seal
-in relay and wiring shall be rated for in-circuit testing with remote lockout relay.
All transformers supplied to AE shall meet or exceed the efficiency values in accordance with
Department of Energy 10 CFR 431 part I11- Energy Conservation program for Commercial
Equipment: Distribution Transformers Energy Conservation Standards table 1.1. Certified test data
by serial number shall be provided with each transformer.
PUC Docket No. 40627
Response to OPC 1-52, Attachment 4
Page 2 of 6264
Specification E-709
June 29, 2011
Page 3 of 8
4.0
PHYSICAL REQUIREMENTS
4.1
The transformer shall have 600 ampere minimum side-mounted apparatus bushings on the high side.
The bushings shall be bolted to the tank for ease in replacement. Welzled bushingI are not accefst;ablc.
Bushings provided shall be Elastimold 750-S1 (copper) or AB approved equivalent.
4.2
The low voltage throat and bushings shall be in accordance with ANSI C57.12.40, Figure 3 for
216Y/125V transformers rated 500 kVA and 480Y/277V transformers rated 500, 750, and 1000 kVA.
Figure 4 for 216Y/125V transformers rated 750, 1000, and 1500 kVA; and 480Y/277V transformers
rated 1500, 2000 and 2500 kVA.
4.3
On the 2500 kVA 4160/2400 transformer the low side bushings shall be bolted to the tank for ease in
provided shall be Elastimold 750-S1
replacement. Welded bushings are not ai;gotable. Bushings
(copper) or AE approved equivalent. The network protector throat is not required on the 2500 kVA
4160/2400 volt transformer.
4.4
The neutral bushing shall be insulated from the transformer tarik. The ground to tank shall be made by
a flexible copper braid bolted between the transformer tank and the neutral bushing of the transformer.
Copper braid size shall be equal to 500 MCM bare copper. The neutral bushing shall have a four hole
NEMA pad for 1000 kVA and smaller and a six hole NEMA pad for 1500, 2000 and 2500 kVA
transformers.
4.5
The high voltage compartment shall be completely sealed and filled with insulating oil prior to
shipping.
4.6
The tap changer shall be designed for de-energized operation, An indicator shall clearly show the
position of the tap changer.
4.7
The transformer tank shall be of a sealed construction, consisting of a welded main cover equipped
with lifting lugs and gasketed hand hole cover(s).
Jack pads or bars shall be provided so that there is three inches (3") of clearance up from the bottom of
4.8
the transformer for lifting jacks.
4.9
Transformer sizes listed below are maximum and shall not be exceeded.
500
750
1000
1500
2000
2500
6'0"
6'21'
6'2"
6'6"
6187'0"
7'0„
7, 01,
7,V
81011
8'6"
9'010
3,6»
4:09.
4.0„
4'6"
5,0"
5.6„
4.10 All high voltage windings shall be made of copper.
5.0
INSULATING OIL REQUIREMENTS
5.1
The insulating oil shall be non-PCB (polychlorinated biphenyl), defined as containing less than one
part per million (ppm) PCB. Certification of the non-PCB oil shall be furnished and shall include the
method of testing used.
5.2
The transformer nameplate shall be marked "non-PCB". In addition, a blue "non-PCB" label of a
minimum 1"X 2" size shall be installed directly below the nameplate.
5.3
The oil shall conform to the latest revision of ANSI/ASTM D3487, Type ll. The gassing coefficient
shall be negative when tested in accordance with ASTM D2300, Section 2.0.
PUC Docket No. 40627
Response to OPC 1-52, Attachment 4
Page 3 of 6
265
Specification E-709
June 29, 2011
Page 4of6
5.4
The Contractor shall supply test reports, which verify compliance with the oil performance
requirements given below:
est and Method
Dielectric Strength,
ASTM D-1816, kV
minimum,
0.04 inch gap:
0.08 inch gap:
Dielectric Strength,
ASTM D-877, kV
minimum
20 kV
40 kV
30 kV
Power Factor, ASTM D-924,
% maximum; 25° C
% maximum; 100 ° C
0.15
1.50
Interfacial Tension,
ASTM D-97 1, rnNlm
minimum:
Color, ASTM D-1500,
ASTM Units:
35
Visual Examination,
ASTM D-1524
Bright and Clear
Water Content,
ATSM D-1533,
ppm, maximum:
5.5
6.0
1.0
25
The Contractor shall be subject upon request, to furnish laboratory test data for the insulating oil. Oil
fumished under these specifications shall be subject to tests and any insulating oil failing these tests
will be returned to the Contractor at the Contractor's expense.
COST EVALUATION
All network transformer bids will be evaluated based on purchase price, guaranteed no load losses, and
6.1
guaranteed winding losses. The formula and cost of losses are as follows:
Total Evaluated Bid (owning cost) = Bid Price + (cost of no load losses) x (quoted guaranteed no load
losses) + (Cost of winding losses) x(quoted guaranteed winding losses)
Cost of no load losses = 55,239.00/kW
Cost of winding losses = 53.123.00/kW
6.2
Each Bidder shall quote the guaranteed no load losses and guaranteed winding losses at the time of bid
opening.
6.3
Before or upon delivery, Contractor's certified factory test reports shall be provided to AE (Section
6.3) for final review.
6.4
Losses shall be the actual tested losses corrected to 20°C no load and 85°C for load, reported by serial
see section 6.2).
number and City of Austin purchase order number for each transformer delivered (
6.5
The actual losses of any one transformer on an order shall not exceed the quoted guaranteed losses by
more than the following percentages:
PUC Docket No. 40627
Response to OPC 1-52, Attachment 4
Page 4 of ^66
Specftation E-709
June 29, 2011
Page 5of8
No load losses
Network Transformer
6.6
10%
Loldhim
6%
Penalty
For each transformer where the actual losses exceed the quoted guaranteed losses, a penalty will be
assessed through a price reduction for each ttansfotmer.
Penalty =
2[(55,239.O0/kW) (actual no load losses - quoted guaranteed no load lossas) +
($3.123.00/kW) (actual winding losses - quoted guaranteed winding losses
PUC Docket No. 40627
Response to OPC 1-52, Attachment 4
Page 5 of $67
Specification E•709
June 29, 2011
Page 6018
ATTACHMENT I
X0 tKU^►T^^►^m
iJIIIII I IL
xa
k2
HI
O
K
xa
X2
X1
IIIII
TERMINAL DESIGNATIONS
X2
H2
xl
Mt
^
xo
X3
DELTA - WYE
VECTOR RELATIONSHIPS
TERMINAL DESIGNATIONS AND VECTOR RELATIONSHIPS
FOR NETWORK TRANSFORMERS
ATTAdIMENT I
PUC Docket No. 40627
Response to OPC 1-52, Attachment 4
Page 6 of 6
68
Specification E-1579
February 11, 2009
Page 1 of 14
CITY OF AUSTIN ELECTRIC UTILITY DEPARTMENT
PURCHASE SPECIFICATION
FOR
TRANSFORMER, SINGLE-PHASE OVERHEAD-TYPE DISTRIBUTION
(3 kVA through 167 kVA)
DATE
PREPARED BY ISSUANCEIREVISION
07/08/99
Gary Noble
issuance
01/01/03
Steve Booher
Revision
05/30/03
Steve Booher
Revision
06/06/03
Steve Booher
Revision
09/05/03
02/18/04
Steve Booher
Leonard Hough
Revision
Revision
04/28/05
Dennis Patrick
Revision
2/11/09
Arthur Gonzalez
Revision
APPROVAL
PROCESS SUPV. /MATERIALS SUPV.
AFFECTED PARAGRAPHS
REASON FOR REVISION
01l01/03: Referred to part not used on this transformer.
3.6.7
01/01103: changed the ground requirement from 1 lug to
2 lugs
3.7.7
01/01/03: Added ground requirement for two-bushing
transformer. Added bushing ground length requirement
3•7,7
05/30/03: changed arrester rating requirements and
added Arrester style number
3.8.2
Attachment il
08/08/03: Updated attachment II
3.8 & 4.0
09/05/03: Added arrester connection & animal guard
02/18/04: Added labeling instructions
3.7.8
05/04/05: Added verbage and chart
3.5.1
05/04105:
Added grounding for 4 bushing Xfmr
^_
12/28/05: Added arrestor wire details
^... .-. _
3.7.7
3.8.1
04/28/05: Changed Mfg Part No. Added new Mfg with
part number.
3.8.2
04/28J05: Changed approved Mfg and Mfg Part No's.
4.0
04/26/05: Restructured Data Requirements
7•0
04126/05: Added Warranty Requirements
11.4
04/26/05: Changed Sticker Requirements.
Attachment VI
PUC Docket No. 40627
Response to OPC 1-52, Attachment 5
Page 1 of 14269
Specification E-1579
February 11, 2009
Page 2 of 14
This specification, until rescinded, shall apply to each future purchase and contract for the commodity described herein.
Retain for future reference.
PUC Docket No. 40627
Response to OPC 1-52, Attachment 5
Page 2 of 1470
Specification E-1 579
February 11, 2009
Page 3 of 14
CITY OF AUSTIN ELECTRIC UTILITY DEPARTMENT
PURCHASE SPECIFICATION FOR
TRANSFORMER, SINGLE-PHASE OVERHEAD-TYPE DISTRIBUTION
(3 kVA through 167 kVA)
1.0
SCOPE AND CLASSIFICATION
1.1
Scope
The City of Austin Electric Utility Department, hereinafter referred to as Austin Energy (AE), requires
a qualified Vendor, to provide, single phase, 60 hertz, dual HV bushings with tank-mounted surge
arrester, oil-filled, conventional distribution transformers rated 3 kVA through 167 kVA.
1.2
2.0
Classification
1.2.1
No deviation from these specifications on the part of the Vendor shall be allowed. Any item
supplied under these specifications which is not in complete compliance with these
specifications will not be accepted and will be returned to the Manufacturer.
1.2.2
All Manufacturers furnishing transformers under these specifications shall have at least ten
(10) years experience in the manufacture and sale of distribution transformers.
APPLICABLE SPECIFICATIONS
All Characteristics, definitions and terminology, except specifically covered in this specification shall be in
accordance with the latest revision of ANSI/IEEE C57.12.20 and C57.12.31.
3.0
FUNCTIONAL REQUIREMENTS
3.1
Voltage and kVA Ratings
The voltage ratings shall be in accordance with the table in Attachment I.
3.2
Maximum Guaranteed Transformer Losses
The single phase distribution transformer maximum guaranteed losses (both No Load and Load Loss)
shall be in accordance with Attachment II. All units, exceeding the maximum guaranteed losses will
be rejected. There is no additional tolerance allowed on these values.
3.3
High Voltage (HV) Taps
Manufacturer shall not provide taps for the transformers described herein.
3.4
3.5
High Voltage Bushings and Terminals
3.4.1
The High Voltage Terminals shall be in accordance with ANSI C57.12.20.
3.4.2
High voltage bushing shall be in accordance with ANSI C57.12.20, IEEE C57.19.00 and
IEEE C57.19.01.
Low Voltage (LV) Bushings and Terminals
3.5.1
The low-voltage bushings and terminals shall be 2-hole spades for 3 kVA - 15 kVA
transformers. 25 kVA - 167 kVA transformers shall have 4-hole spades. All secondary
bushings shall have captive, compression limited, fully shielded conductor and flange seals.
Bushings shall be certified to withstand the following cantilever loading without leaking. The
bushings for the 100 kva and the 167 kva pole mounted transformers shall be Central
PUC Docket No. 40627
Response to OPC 1-52, Attachment 5
Page 3 of 1 427,i
Specification E-1579
February 11, 2009
Page 4 of 14
Moloney Intermediate Speedmount NPA0010I8. Terminal designation and markings shall be
in accordance with ANSI C57.12.70.
. . . . . _..
3.5.2
3.6
SECONDARY VOLTAGE
__._......_.._..,_.._. .._. .,..^,...^._..._._._..u......
277
240/480
_
KVA
120/240
10-50
100FTLBS
100FTLBS
100FTLBS
75
300 FT LBS
100 FT LBS
100 FT LBS
100
300 FT LBS
100 FT LBS
100 FT LBS
167
300 FT LBS
300 FT LBS
300 FT LBS
250
400 FT LBS
360 FT LBS
400 FT LBS
333
400 FT LBS
300 FT LBS
400 FT LBS
500
400 FT LBS
400 FT LBS
400 FT LBS
_ ...-....
The terminals shall be finished on both sides to enable a complete connection to either side.
CORE AND COIL
3.6.1
The transformer coils shall be designed to maintain their nameplate kVA rating throughout
the temperature range. The continuous kVA ratings shall be based on an average winding
temperature rise by resistance of 65°C as per ASNSI/IEEE C57.12.00.
3.6.2
All materials used shall be of the 65°C (85° C Hot Spot) Class and be thoroughly tested for
compatibility with all transformer components.
3.6.3
Oil ducts shall be strong enough to withstand full short circuit forces.
3.6.4
The windings shall be a mechanically rigid assembly to resist axial and radial short circuit
forces.
3.6.5
The primary coil shall be wound in such a manner, that when properly cured, will have an
effective bond both turn to turn and layer to layer.
3.6.6
The primary coil shall be wound with continuous conductor without splices, joints or welds
inside the windings.
3.6.7
High Voltage (HV) leads shall be trained and appropriately insulated to avoid dielectric
breakdown between adjacent cables. Spacers, permanently held in place, shall be used to
prevent a phase-to-ground short.
3.6.8
The secondary coils shall be wound with a roctangular or strip conductor. Each secondary coil
shall be wound with a continuous conductor without splices, joints or welds inside the
windings.
3.6.9
LV bushing leads shall be cold or thermally welded, where joined to the winding material
3.6.10
Aluminum low voltage leads shall be connected to their bushings, with hardened aluminum
connectors which have been cold or thermally welded to the leads.
Pl1C Docket No. 40627
Response to OPC 1-52, Attachment 5
Page 4 of 14272
specification E-1579
February 11, 2009
Page 5 of 14
3.6.11
3.7
The core and coil assembly shall be rigidly held together as a unit with a core clamp whose
design shall maintain reasonable pressure on the assembly throughout the life of the unit.
Tank
3.7.1
Leak Resistant
The transformer tank shall be leak resistant throughout the operational life of the transformer.
3.7.2
Covers
The transformer cover shall be insulated. The transformer shall have removable cover with
nitrile rubber gaskets. The cover, when secured in place, shall prevent any moisture from
entering the tank.
3.7.3
Pressure
The transformer tank and cover shall be designed to withstand pressure in accordance with
ANSI C57.12.20.
3.7.4
Pressure Relief Valve
An automatic pressure-relief valve shall be furnished on all transformers. The location of the
valve shall be in accordance with ANSI C57.12.20, Figures 1, above the oil and in segments 2
or 4 of these figures.
3.7.5
Hand Holes
The transformers shall not have hand holes.
3.7.6
Support Lugs (Hangers)
All transformers shall have support lugs for one (1) position mounting. The support lugs shall
be in accordance with ANSI C57.12.20, Section 7.5.2 (Figure 1 and Figure 111).
3.7.7
Grounding
The transformer shall have two tank ground provisions as per ANSI C57.12.20, Section
7.5.4.1, Figure 11.
Transformers with three LV bushings shall be externally grounded to the tank with a ground
strap of sufficient length to attach to the adjacent bushings.
Transformers with two LV bushings shall have a grounding strap attached from the X2
bushing to a grounding lug on the tank centered between X1 and X2.
Transformers with four LV bushings shall have a grounding strap attached from the X2
bushing to a gounding lug on the tank centered between the X2 and X3.
3.7.8
Labels
The Vendor shall place all labels required by AE Distribution Construction Standard #1000-17,
and shown in Attachments V and VI, on the tank of each transformer. This includes the "SIZE
KVA" and the "NO PCBS" labels.
3.8
Arresters
3.8.1
An arrester shall be mounted on the transformer adjacent to the Hi bushing. The arrester shall
be connected from the top of the arrester the H I transformer bushing. The arrester wire shall
be 24 inches long; #6 compressed soft stranded copper transformer riser wire, polyethylene
covered. A single hole tin plated compression connector shall be utilized to connect the wire
PUC Docket No. 40627
Response to OPC 1-52. Attachment 5
Page 5 of 14273
Specification E-1579
February 11, 2009
Page 6 of 14
to the H1 bushing to the arrester. The connection from the bottom of the arrester shall be solid
copper strap rated for l OKA and bolted to the bottom of the transformer tank. All connections
to the arrester shall be properly installed as per arrester manufacturer instructions
3.8.2
4.0
The arrester supplied shall have a rating of 10 kV, 8.4 kV MCOV, polymer, metal- oxide
type, with wire nut and wire clamp on top terminal. The transformers shall be delivered with
one of the arresters listed:
a.
Cooper catalog number UHS 10050A I A I A 1 A
b.
Ohio Brass catalog number 213709-7214
c.
Maclean catalog number ZH^,-0000000
WILDLIFE GUARDS
All transformers shall be delivered with the below listed animal guard properly installed on the HV bushing
and arrestor:
a.
5.0
Howard Industries 0060-0021634Q5
TRANSFORMER DIELECTRIC OIL
The dielectric fluid shall be bio-based biodegradable electric insulating and cooling liquid. The coolant shall
be a list less-flammable fluid meeting the requirements of National Electric Code Section 450-23 and the
National Electric Safety Code, Section 15. The fluid shall be Factory Mutual Approved and be UL Classified.
The dielectric fluid supplied with all transformers shall be in accordance with IEEE C57.147. The
manufacturer shall provide batch test reports of the oil characteristics to the AE Standards Engineer.
The PCB content in the dielectric fluid shall be less than 1 ppm. The vendor shall provide written certification
to the City that all dielectric fluid contains less than I ppm. The PCB content shall be shown on the
nameplate of the transformer.
6.0
PAINT REQUIREMENTS
The unit shall be painted ANSI 70 Light Gray, Munsell Notation 5BG 7.0/0.4.
7.0
DATA REQUIREMENTS
The Vendor shall provide for the AE Specifications Engineer, upon receiving a new shipment of transformers
to Vendor's receiving site, including but not limited to the following information on each transformer:
7.1
The tol{crwi^tgil;ern^ sl^ i^ prir^ i!<<1 t<>rReacll ir^nsfa^,c^ ^..n..:^V.^r^...slll:p^^
7.1.1
Serial Number
7.1.2
kVA Ratina
7.1.3.1
Voltage Rating
7.1.4
Core aron) losses at rated load , corrected to 85°C
7.1.5
Copper losses at rated load, corrected to 85°C
PUC Docket No. 40627
Response to OPC 1-52, Attachment 5
Page 6 of 14
Specification E-1579
February 11, 2009
page 7 of 14
7,2
8.0
7.1.6
percentage (%@ impedance
7.1.7
Exciting curre
7.1.8
Pereentare f°!o1 rezu)P-Ocat,8il°^powcr ta4 ar ^nc#^r ted L(NW
7,1.9
^ltat:e ("^a) rggr^la^sn^t 100"l^w^ 8S or and^t^djpid
i'erco
7.1.10
^iicle4l.ct (lt^i used in he tr^ns(ormer
i
Gailc^ttc,^..l^l^gr^tiabi^
7.1.11
Percentage (%) efficienc,y(gDOE efficiency criteri
100% rated v
The followin}^ t^nts shall be tsrovid^ ^! ►?^ yearly repo^ with evt*ry ti^ tihiy,^_^^^lt oF evcr
7.2.1
Drawings
7.2.2
Total transformer weig)Ilz #I}^5^ widt t1i1 and with arrester maunted
7,2.3
Windina, Material
7.2.4
9211 mm"
7.2.5
Conductor temperature at rated load (Design Test)
7.2.6
Hot Soot tenanerature at rated load (Design Test)
7.2.7
Top Oil temperature at rated load (Design Test)
7.2.8
Thermal time constant ( Design Test)
7.2.9
^hort-Circuit Withstand Caoability ( Design Test)
7.2.10
Exciting current at I In/ rated vQlta^e (Desien Test)
7.2.11
Ftadio Influence Volta^e (R_l_V) at110N raeAvolta >a, (.I7^^ T_est
ez^r:
NAMEPLATE
The nameplate of the transformer shall be in accordance with ANSI/IEEE C57.12.00, Table 10 (Nameplate
A). The following additional information shall be provided on the nameplate:
9.0
8.1
Bar Code (Section 9.0)
8.2
PCB content (No-PCB or Less than I PPM)
PERMANENT BAR CODE
The bar code shall be in accordance Attachment IV and with the latest revision of the following standards:
ANSI X3.17, ANSI X3.182, ANSI X3.4, ANSI X3.49, and ANSI MH10.8M
PUC Docket No. 40827
Response to OPC 1-52, Attachment 5
Page 7 of 14 275
specification E-1 579
February 11, 2009
page 8 of 14
10.0 AUSTIN ENERGY REQUIREMENTS
Austin Energy or its designated representative reserves the right to inspect and test transformers and materials
in all stages of manufacturing and testing, at whatever location the manufacturing is performed, at no charge
to Austin Energy.
11.0 OTHER REQUIREMENTS
All transformers supplied to AE shall meet or exceed the efficiency values in accordance with
11.1
III - Energy Conservation program for Commercial
Department of Energy 10 CFR 431 part
Energy
Conservation Standards table I.1. Certified test data by
Equipment: Distribution Transformers
with
each
transformer.
be
provided
serial number shall
11.2
A decal shall be placed on the transformer in accordance with Attachments V and VI, The decal shall
be colored blue with white lettering. The decal shall be 6" tall by 6" wide and shall have the precise
wording, in capital letters, "NO PCBS".
11.3
The Vendor shall provide the information in Section 7 (numerical values and/or pass/fail, as
applicable) to the AE Distribution Standards Engineer:
AE Distribution Standards Engineer
4411-B Meinardus Drive
Austin, TX 78744
The test reports shall clearly state Austin Energy's specification number E-1579 and the type of
transformer (Polemount).
11.4
If any defect in the equipment supplied, or failure to comply with this specification, shall appear
within the period of 18 months from date of final acceptance of the equipment, the Contractor shall be
notified, and the Contractor shall thereupon correct without delay and at Contractor's own expense the
defect or failure of compliance by repairing the defective part or parts, by supplying a non-defective
replacement or replacements, and/ or by correcting a deficient design as required. The Contractor
shall further replace or repair all other similar equipment if such defect may reasonable be expected to
develop or occur in said similar equipment. Removal and installation cost of the defective parts or
equipment shall be at Contractors expense. In the event the Contractor shall correct any defectts) or
failure of compliance by repair, replacement, or correction as required above, then with respect to the
equipment corrected, the aforesaid warranty period shall begin from the date of completion of
installation of such correction and acceptable therefore, provided same is not unreasonably delayed by
Austin Energy.
PUC Docket No. 40627
Response to OPC 1-52, Attachment 5
Page 8 of 14276
Speclficatbn E-1579
February 11, 2009
Pape9of14
ATTACHMENT I
TRANSFORMER VOLTAGE RATINGS
FOR
SINGLE-PHASE DISTRIBUTION TRANSFORMER
_._. ^^...
.^^ ^.........^..
HIGH VOLTAGE
HV BIL kV
LOW VOLTAGE
LV BIL kV
7200/12470Y
95
120/240
30
7200/12470Y
95
240/480
30
7200/12470Y
95
277
30
PUC Docket No. 40627
Response to OPC 1-52, Attachment 5
Page 9 of 14277
Specification E•1579
February It 2009
Page 10 of 14
ATTACHMENT H
MAXIMUM GUARANTEED TRANSFORMER LOSSES
._.__
^edance (%)
Transformer (kVA)
No-Load Losses Watts
Load Losses (Watts)
3
14
43
2.0
10
31
141
2.0
15
47
164
2.0
25
70
178
2.0
50
11 ]
409
2.0
75
135
652
2.0
100
192
730
2.0
167
250
1295
3.0
85° C
PUC Docket No. 40627
Response to OPC 1-52, Attachment 5
Page 10 of 14 27$
Specification E-1579
February 11, 2009
Page 11 of 14
ATTACHMENT III
TANK-MOUNTED SURGE ARRESTERS FOR
SINGLE-PHASE DISTRIBUTION TRANSFORMER
Nominal
System Voltage
BIL*
(L-L) kV RMS
*
(kV)
Manufacturer
(W)
anufacturer
PM art Number
12.47
95
Cooper
8.4
UHS10050A1A1A1A
12.47
95
Ohio Brass
8.4
213709-7214
12.47
95
Maclean
8.4
ZHPOIO-0000000
MCOV Rating**
Minimum BIL of Surge Arrester Housing with Metal Oxide Blocks
** MCOV - Maximum Continuous Operating Voltage
PUC Docket No. 40627
Response to OPC 1-52, Attachment 5
Page 11 of 14279
Speckicatfon E•1579
February 11, 2009
Page 12 of 14
ATTACHMENT IV
BAR CODING AND MANUFACTURING CODES
FOR
SINGLE-PHASE DISTRIBUTION TRANSFORMER
1.0
ORIENTATION OF BAR CODE CHARACTERS
L
0.15L
QUIET
ZONE
MFG
SERIAL NUMBER
CODE
QUIET
ZONE
*Start/Stop Character
2.0
MANUFACTURER IDENTIFICATION CODES
The Manufacturer Identification Codes suggested below represent, in part, codes which are utilized for bar coding
distribution transformers. The above listing does not represent an inclusive list of distribution transformer
manufacturers.
AB
-
Asea Brown Boveri
CM
-
Central Moloney
CP
-
Cooper
GE
-
General Electric
HI
-
Howard Industries
KU
-
Kuhlman
PUC Docket No. 40627
Response to OPC 1-52, Attachment 5
Page 12 of 1 4_80
Specification E-1579
February 11, 2009
Page 13 of 14
ATTACHMENT V
SIGNAGE FOR SINGLE-PHASE POLE-MOUNTED
TRANSFORMERS
(AE DISTRIBUTION CONSTRUCTION STANDARD #1000-17)
c;BNERAL INFORMATION
p0t7
8IClYACE414LE MOU.'T1' TRANSF'ORMER
eev. DKC 0vi 5+04 _ ;
^....._,,^..^...__-.---.--.,••....-w..^--^....._
^....._
91G.NACE POI.E MOUNT TRANSFORMER
1Ug(1-]7
a^'"^«..
'''l
F 1 ^m1
t
1,y^ l•s^
t^
^ --...,.^
>AJ
^^....... ;^
^
..^.
^.^=
J
N4
f
rI7Y w
1,11,1170 'IT 10,1 TOP Of
l71! TR.AN91"()RM ER ON
TIM RIQIIT•ITABTD SIDE
Wwf:RL' IT is YtSmix FR0N
THE RT'RP.FTIYARI).
- SIZE AY .4
LOl'A7HD IN 17lB
vrNTUR ABOVE
-rut-. PCs.-, 110 MR
WHIM. LT IS YI9TTIT E
k12OM T8E S'fRkETIYAkD.
NO 1'C83
i.('W.xAV D 1.14 THE
CENTER OF TIM
Ilk AW3100114 FR UN 111R
THE SIZE K VA STICKER
FVITP,kE ITLSVTSTnLE
MOW ML STRLTL^TIYAKU,
PUC Docket No. 40627
Response to OPC 1-52, Attachment 5
Page 13 o114281
Specifloation E-1579
February 11, 2009
Page 14 of 14
ATTACHMENT VI
TYPICAL EXTERNAL SIGNAGE MATERIAL
REQUIREMENTS POLE-MOUNTED TRANSFORMERS
"NO PCBS" decal. 6 inch X 6 inch, blue. Base Film: 0.0035-inch cast polyvinyl chloride, with UV inhibitors as
per M[L-M-22106A. Cyasorb UV-9 light absorber C14H1203. Gloss 80 UL 94 rated. Over lamination: 002PVF
(polyvinyltlouride) tedlar UV screening film from E.I. Dupont. Cold-seal bonded. Adhesive: 0.002-inch permanent
acrylic hi-tack, with high-ternperatura-resistant Elasticisors for adhesion at 40 deg. F. PSTC test method: #1
modified for a 15 minute dwell time, with 2 mils of adhesive, 56 ozlinch width rating. Ink: Silkscreen type 4, with
automotive grade pigments and binders, 0,0004-inch thick j- 0.0001, inch high pigment volume concentration total
PVC 40-50 (copper phthalocyanines). Liner: 0.0007-inch t 0.001-inch Kraft, coated one side chemical resistant.
Salt spray 240 hours 5%, at 100 degrees, with no blistering, color change, or other material degradation. No effect
when immersed in diesel fuel, motor oil, anti-freeze, detergent 2°fo, ammonium hydroxide (1211/6 and 39%),
kerosene, acetic acid, acetone and water, Service temperature range: -40 to + 170 deg. F. Minimum lifetime exterior
durability of 15 years from installation date with proper surface preparation.
Approved Manufacture or equal: Mitrographers, catalog number COA-001
"SIZE KVA" decal: width as required, 2 7/8 inches tall, Engineer Grade, adhesive reflective vinyl. Yellow
numbers, black back ground.
"City lp Number" decal: width as required, 2 7/8 inches tall, Engineer Grade, adhesive reflective vinyl. black
numbers, Yellow back ground.
PUC Docket No. 40627
Response to OPC 1-52, Attachment 5
Page 14 of 14282
PUC Docket No. 40627
Response to OPC 1-52, Attachment 6
Page 1 of 1
Specification E-0815
4.4,
Losses
4.4.1.
The transformer losses will be used in the evaluation of the offers. No-load and load
loss values at the I raise OLTC position at the self cooled (18 MVA, 24MVA, 30
MVA or 40 MVA) rating shall be supplied with the Offer and will be used in the
evaluation. If the transformer has an OLTC, which uses variable volts per turn
design, the no-load losses shall be guaranteed on the OLTC position having the
highest no-load losses.
The Offeror shall state in the Offer the DETC and OLTC positions with the highest
no-load losses as the guaranteed losses in the case of variable volts per turn design.
The Offeror shall also submit with the Offer the auxiliary load at the maximum
forced cooled rating for use in the evaluation.
The following life cycle costs will be used.
Cost of no-load losses
Cost of load losses
Auxiliary losses
4.4.2.
- $ 5,300/kW
- $ 3,970/k W
- $ 1,250/kW
The Offeror shall submit with the Offer the maximum percent total measurement
error for the no-load loss measurement and the load loss measurement systems. The
errors must contain all components of the error including probable calibration errors
and other uncertainties in the measurement system. Certified data for the loss
measurement errors shall be submitted with the Offer. The data shall be traceable to
the United States National Institute of Standards and Technology or other equivalent
standardization organization. Equivalency will be determined by AE using
supporting documentation provided by the Offeror as part of the Offer. A system
check to insure that all errors have been properly applied may be required. Failure to
submit a loss measurement system error or the submission of an error that is
obviously erroneous will result in the rejection of the offer. The maximum loss
measurement error that is acceptable is ± three (3) percent as per ANSI/IEEE
C57.12.00. Loss measurement errors greater than ± three (3) percent will result in
the rejection of the Offer.
4.4.3. The no-load losses and excitation current at room temperature after impulse tests
shall be used as the guaranteed values and shall not deviate from the no-load losses
and excitation current values measured before impulse tests by more than five (5)
percent. If the difference between the before and alter values are greater than five
(5) percent, AE shall be contacted and a course of action determined. It is expected
that the manufacturer shall determine the cause and correct any problems that result
in deviations in no-load losses and excitation current that are greater than five (5)
percent. AE reserves the right to reject the transformer if satisfactory explanations or
corrections are not made.
4.4.4. A transformer which, after factory testing, has losses exceeding the guaranteed losses
as stated in the Offer shall have its selling price reduced. The amount of reduction
will be calculated by the kW difference ( actual tested minus calculated guaranteed)
multiplied by the evaluated cost per kW
283
SOAH Docket No. 473-13-0935
PUC Docket No. 40627
City of Austin's Response to OPC's lst RFI
OPC 1-53
Please state the value of energy and capacity used when making economic
comparisons among bidders when purchasing transformers; provide the source of
those figures; and provide the date when the figures were developed.
RESPONSE:
Responsive information for distribution transformers is found in Austin Energy's response to
OPC 1-52. For Substation class transformers, see section 4.4.1 of the excerpt from the City of
Austin Electric Utility Department Purchase Specification E-0815, revision 07/24/2012, for 13812.47 kV, 30, 40, 50, 67 MVA three phase power transformers states the life cycle costs used to
make economic comparisons when purchasing substation size transformers. Section 4.4.1 was
implemented September 8, 2005. This excerpt was provided in the response to OPC 1-52.
Prepared by:
Sponsored by:
David Wood
David Wood
284
SOAH Docket No. 473-13-0935
PUC Docket No. 40627
to OPC's 1st RFI
Response
City of Austin's
OPC 1-54
Please estimate the average price premium that Austin Energy currently pays over
the transformer with the lowest capital costs in each size range in order to avoid
losses.
RESPONSE:
Austin Energy does not have any information responsive to this request.
Prepared by:
Sponsored by:
David Wood
David Wood
285
SOAH Docket No. 473-13-0935
PUC Docket No. 40627
City of Austin's Response to OPC's 1st RFI
OPC 1-55
Please identify gross and net plant for capacitors and indicate in which account
costs are included.
RESPONSE:
See Attachment I for the requested information.
Attachment 1- Summary for Capacitors at 09-30-2009, 1 page.
Prepared by:
Sponsored by:
Ann Little
Ann Little
286
t^
kA
0.,a_
4
H
'
^
19'
C
O
8 ^
m ^
O
^
14 9
888l
o
4
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0
= cr
c ^
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ONNG ► t^
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^
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4CA ► tO 9 0
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Oh)C)7 C
A ^a co w9
NtoD{J0^
^0
2
0 0
0
n
^ -^ V
287
SOAH Docket No. 473-13-0935
PUC Docket No. 40627
City of Austin's Response to OPC's 1st RFI
OPC 1-56
Please provide workpapers supporting the customer weighting and allocation
factors for meters.
RESPONSE:
Customer weighting and allocation factors for meters is described on pages 55-56 and in shown
in Table 14 of Mr. Mancinelli's Direct Testimony. Additionally, this information is show in
WP/F-2.3 of the RFP.
Prepared by:
Sponsored by:
Joe Mancinelli
Joe Mancinelli and Beverly Bonevac
288
SOAH Docket No. 473-13-0935
PUC Docket No. 40627
to OPC's 1st RFI
Response
City of Austin's
OPC 1-57
Which types of meters or sizes of customers use (a) Current Transformers (CTs)
and/or (b) Potential Transformers (PTs).
RESPONSE:
Residential customers up to 400 amps do not require CTs. However, 200 amp to 400 amp
(residential) service have the option of CTs. All other customers over 200 amps (commercial or
industrial) use CTs. Additionally, service voltages above 600V, require PTs and CTs regardless
of amps.
The typical types of meters that are CT-rated include:
-Form 9S for 3-phase
-Form 3S (2 wire) or Form 4S (3 wire 120/240V) for single phase
-Form 5S (or Form 45S) for 3 wire 120/208V
Prepared by:
Sponsored by:
David Wood
David Wood
289
SOAH Docket No. 473-13-0935
PUC Docket No. 40627
City of Austin's Response to OPC's 1st RFI
OPC 1-58
Please provide any studies or analyses prepared on the cost of service drops by
customer class and/or by single-phase versus three-phase service.
RESPONSE:
Austin Energy does not have any documents responsive to this request.
Prepared by:
Sponsored by:
David Wood
David Wood
290
SOAH Docket No. 473-13-0935
PUC Docket No. 40627
City of Austin's Response to OPC's 1st RFI
OPC 1-59
Please provide all available information on the length of service drops by
customer class.
RESPONSE:
Austin Energy has no statistics on its system as built. Please refer to Austin Energy's Design
Criteria Sections 1.5.2.1.G and 1.5.2.3.B for criteria governing service drops.
Attachment 1- Austin Energy's Design Criteria, 168 pages.
Prepared by:
Sponsored by:
David Wood
David Wood
291
PUC Docket No. 40627
Response to OPC 1-59, Attachment 1
Page 1 of 168
City of Austin Electric Utility
Austin Energy
Design Criteria
Effective January 1, 2010
Cost: $15.00
292
PUC Docket No. 40627
Response to OPC 1-59, Attachment 1
Page 2 of 168
293
PUC Docket No. 40627
Response to OPC 1-59, Attachment 1
Page 3 of 168
TABLE OF CONTENTS
TABLE OF CONTENTS ...................................................................................................................1
1.1.0
INTRODUCTION ..............................................................................................................7
1.2.0
RELEVANT CITY OF AUSTIN BUSINESS OFFICES .............................................................7
1.3.0
CHARACTERISTICS/ BASIC REQUIREMENTS OF ELECTRIC SERVICE ................................9
1.3.1
AE Electric Distribution Service Voltages and Maximum Demand Ampacities ...................................... 9
1.3.2
Availability of AE Facilities ............ ............................................................................................... 9
1.3.3
One Service Point and One Service Voltage ................................................................................... 9
1.3.4
Service Point (Point of Delivery) ................................................................................................... 9
1,3.5
Electrical Facility Ownership ......................................................................................................... 9
1.3.6
Easements ...............................................................................................................................10
1.3.7
Color Coding of Customer's Service Conductors .............................................................................10
1.3.8
Customer Electrical Facilities that Cross Property Lines ................. .................................................12
1.3.9
Single-Phase/Three-Phase Service ...............................................................................................12
1.3.10
Voltage Stability and Continuity ..................................................................................................13
1.3.11
Electric Service Reliability ...........................................................................................................13
1.3.12
AE Line Extension Policy .............................................................................................................13
1.3.13
AE Excess Facilities/Excess Cost Policy .........................................................................................13
1.3.14
Front Lot Line Construction Requirement ......................................................................................15
1.3.15
Customer Switchover Policy ........................................................................................................15
1.3.16
Three Mega-Watt Demand and Larger Customer Requirements .......................................................15
1.3.17
Underground Only Service Areas ( Non Network Areas) . .................................................................15
1.3.18
Americans with Disabilities Act ....................................................................................................15
1.4.0
REQUESTING/OBTAINING ELECTRIC SERVICE . ............................................................16
1.4.1
Applying for Electric Service .......................................................................................................16
1.4.2
AE Service Area Questions ..........................................................................................................16
1.4.3
Electric Service Requests ............................................................................................................16
1.4.3.1
Service Only Requests ......................................................................................................16
1.4.3.2
All Other Information, Cost, or Service Requests ..................................................................16
1.4.3.3
Submittal of Customer Drawings Required with Electric Service Requests ...............................17
1.4.4
ESPA Approval ..........................................................................................................................18
1.4.5
Electric Permits for AE Electric Service within COA .........................................................................19
1.4.6
Electric Permits for AE Electric Service Outside of COA ...................................................................19
1.4.7
COA Electric Inspection ..............................................................................................................19
1.4.8
'Service Only' Service Drop and Service Lateral Installations ...........................................................19
1.4.9
Service to Residential, Commercial, and Other Types in Non-Network Area .......................................21
1.4.10
Service Requests in the AE Network Area .....................................................................................23
1.4.11
Truck Access to AE Construction and Existing Facility Sites .............................................................23
1.4.12
Customer Demand Load Determination ........................................................................................23
1.5.0
TYPES OF PERMANENT ELECTRIC SERVICE ...................................................................24
July 31, 2009
Austin Energy Design Criteria
m Austin Energy 2009 - All Rights Reserved
294
PUC Docket No. 40627
Response to OPC 1-59, Attachment I
Page 4 of 168
1.5.1
1.5.2
1.5.3
1.6.0
1.6.1
Network Service ....................................................................................................................... 24
1.5.1.1
Underground and Vault Service Only ................................................................................. 24
1.5.1.2
Available Network Service ................................................................................................ 24
1.5.1.3
Existing Overhead Service - RESIDENTIAL AND COMMERCIAL .............................................. 25
1.5.1.4
Underground 216Y/125V Service - RESIDENTIAL ................................................................ 25
1.5.1.5
Underground 216Y/125V Service - COMMERCIAL ................................................................ 26
1.5.1.6
Network Transformer Vault Service ................................................................................... 27
1.5.1.7
Inspections of Customer Installed Civil Work in the Network Area ......................................... 28
COMMERCIAL Service in Non Network Areas ................................................................................ 28
1.5.2.1
General Conditions and Requirements - Commercial ............................................................ 28
1.5.2.2
Available Commercial Electric Service ................................................................................ 31
1.5.2.3
Overhead Secondary Voltage Service - Commercial ............................................................. 32
1.5.2.4
Customer-installed Underground Services and Civil Work for AE Infrastructure ....................... 36
1.5.2.5
Underground Secondary Voltage Service From Secondary Riser - Commercial ........................ 40
1.5.2.6
Padmounted Transformer Secondary Voltage Service - Commercial ....................................... 41
1.5.2.7
Primary Voltage Service (Overhead and Underground) - Commercial ..................................... 44
1.5.2.8
Service from Open Bushing Transformers in Fenced Enclosures - Commercial ......................... 47
1.5.2.9
Secondary Voltage Service to Multiple-Meter/Shell Commercial Buildings ............................... 47
1.5.2.10
Secondary Voltage Service to Combination Commercial/Residential Buildings ......................... 49
1.5.2.11
Electric Service Inspections - Commercial .......................................................................... 50
1.5.2.12
Safety and Clearances - Commercial .................................................................................. 51
RESIDENTIAL Service in Non Network Areas ................................................................................ 51
1.5.3.1
General Conditions and Requirements - Residential ............................................................. 51
1.5.3.2
Available Residential Electric Service ................................................................................. 53
1.5.3.3
Overhead Residential Installations ..................................................................................... 53
1.5.3.4
Underground Residential Electric Service Installations .......................................................... 59
1.5.3.5
Service to Mobile Home, Modular Home, and Manufactured Home Parks ................................ 65
1.5.3.6
Service to Multiple-Metered Residential Buildings (Overhead and Underground) ...................... 66
1.5.3.7
Service to Apartments, Townhouses, and Condominiums ..................................................... 67
1.5.3.8
Electric Service Inspections - Residential ............................................................................ 67
1.5.3.9
Safety and Clearances ..................................................................................................... 68
STREETLIGHTING AND OUTDOOR LIGHTING ................................................................ 70
General Information .................................................................................................................. 70
1.6.2
Streetlights in Existing Residential Areas within Austin's City Limits ................................................ 70
1.6.3
Streetlights in Newly Annexed Residential Areas ........................................................................... 70
1.6.4
Streetlights in New Residential Subdivisions IN Austin's City Limits Inside and Outside Austin Energy's
1.6.5
Streetlights in Residential Subdivisions OUTSIDE Austin's City Limits Inside Austin Energy's Service Area
.................................................................................................................. 71
1.6.6
Streetlights in Commercial Areas IN Austin's City Limits Inside and Outside Austin Energy's Service
Area ....................................................................................................................................... 71
1.6.7
Streetlights in Commercial Areas OUTSIDE Austin's City Limits Inside Austin Energy's Service Area.... 72
Service Area ............................................................................................................................ 71
1.7.0
2
TEMPORARY POWER ..................................................................................................... 73
Austin Energy Design Criteria
© Austin Energy 2009 - All Rights Reserved
July 31, 2009
295
PUC Docket No. 40627
Response to OPC 1-59, Attachment 1
Page 5 of 168
Temporary Service - General Conditions and Requirements ............................................................73
. ...73
Temporary Power Availability .................................................. ...................................... .
1.7.1.1
Costs for Temporary Power .................................................... ...........................................73
1.7.1.2
1.7.1
1.7.1.3
1.7.1.4
Seasonal Service .................................................................. ...........................................73
Temporary Power Designations ............................................... ...........................................73
Interim Service ..................................................................... ...........................................74
Interim Service is required for speculative buildings and long-term tempora ry service . ............................74
1.7.1.5
Temporary Overhead Service ........................................................... ...........................................74
Temporary Underground Service ...................................................... ...........................................75
1.7.2
1.7.3
1.8.0
CUSTOMER ELECTRIC EQUIPMENT REQUIREMENTS ......................................................77
Customer's Wiring, Service, and Electric Equipment Installation ........... ...........................................77
New Installations ........................................................................... ............................................77
1.8.1
1.8.1.1
Modifications to Existing Facilities .................................................... ............................................77
Customer's Electric Equipment Load ................................................ ............................................77
1.8.1.2
1.8.2
1.8.2.1
General .............................................................................. ............................................77
1.8.2.2
Motors ................................................................................ ............................................78
1.8.2.3
Welders, Furnaces, and Such ................................................. ............................................80
1.8.2.4
Special Apparatus ....... ......................................................... ............................................80
1.8.2.5
Radio Antennae .................... ............................................... ............................................80
1.8.2.6
Cell Towers .................. ....................................................... ............................................80
Computer Equipment ............................................................ ............................................80
1.8.2.7
1.8.3
Customer Power Generation Interface with AE ........... ....................... ............................................80
1.8.4
Customer's Main Disconnect .......... ................................................. ............................................81
1.9.0
1.9.1
METERING ....................................................................................................................82
Meters, Metering Equipment, and Metering Services .......................... ............................................82
General ............. ................................................................. ............................................82
1.9.1.1
1.9.1.2
Metering Equipment . ............................................................ ............................................82
1.9.1.3
Service Conductors in Meter Socket .... ................................... ............................................83
1.9.1.4
Service Connections to Meter Sockets ..................................... ............................................83
1.9.1.5
Setting and Removing of Meters ......... ................................... ............................................84
Meter Tampering and Seals ................................................... ............................................84
1.9.1.6
1.9.1.7
1.9.1.8
Identification of Customer Meter(s) ..... ...............................................................................84
Old Type, Damaged, and Obsolete Equipment .................. ...................................................84
1.9.1.10
Current Transformers (CTs) and Enclosures ..... ...................................................................84
Metering Large Capacity Services .......................................... .............................................86
1.9.1.11
Application of Metering Equipment ........................................ .............................................87
1.9.1.12
Primary Metering ................................................................ .............................................87
1.9.1.13
Load Profile Services ........................................................... .............................................87
1.9.1.9
1.9.2
Clearances and Mounting Heights for Metering Equipment and Enclosu res ........................................87
1.9.3
Installation of Electric Meters ......................................................... .............................................88
Location of Meter Sockets, Transockets, and Enclosures .......... ........ .....................................88
1.9.3.1
July 31, 2009
Austin Energy Design Criteria
© Austin Energy 2009 - All Rights Reserved
3
296
PUC Docket No. 40627
Response to OPC 1-59, Attachment 1
Page 6 of 168
1.9.3.2
Mounting of Meter Sockets, Transockets, and Enclosures ..................................................... 89
1.9.3.3
Grouping of Meters ....................................................................................................... ... 89
Submetertng - Residential and Commercial .............................................................................. ... 90
1.9.4
1.9.4.1
General ....................................................................................................................... ... 90
1.9.4.2
Approval ..................................................................................................................... ... 90
1.9.4.3
Submetering Rules and Responsibilities - Residential and Commercial ................................ ... 90
1.10.0 CLEARANCE AND SAFETY REQUIREMENTS .................................................................. ..92
1.10.1
Safety .................. ................. ................................................. ......... ..... ... .. ..... ........ ......... ..... ... 92
1.10.2
Minimum Working Clearances from Energized Overhead Electric Utility Lines ................................ ... 92
1.10.3
Permanent Clearances from AE Overhead Lines and Facilities ...................................................... ... 92
1.10.4
Clearances from AE Padmount Equipment and Distribution Vaults ................................................ ... 94
1.10.5
Clearances for AE Underground Cable, Conduit, and Underground Facilities .................................. ... 96
1.10.6
Clearances for AE Facilities from Customer's Service Entrance Facilities ........................................ ... 97
1.10.6.1
General ....................................................................................................................... ... 97
1.10.6.2
Service-Drop Conductor Clearances ................................................................................ ... 97
1.10.7
Clearances from Swimming Pools, Hot Tubs, Saunas, and Man-Made Retention Ponds .................... ... 99
1.10.8
Clearances from Septic Systems and Drain Field Systems ........................................................... ... 99
1.10.9
Clearances for Metering Equipment and Enclosures .................................................................... ... 99
1.10.10
Customer Activities in Utility Easements ................................................................................... ..100
1.10.10.1 Excavations ................................................................................................................. ..100
1.10.10.2 Fences and Structures .................................................................................................. ..100
1.10.10.3 Landscaping ................................................................................................................ ..100
1.10.10.4 Digging ....................................................................................................................... ..101
1.11.0 GLOSSARY .................................................................................................................. 102
1.12.0 NETWORK TRANSFORMER VAULTS ............................................................................. 108
1.12.1
General Requirements for Transfonner Vaults ........................................................................... ..108
1.12.2
Transformer Vault Construction Standards ................................................................................ ..110
1.12.3
General Vault Inspection Requirements and Details ................................................................... ..110
1.12.4
Network Area Map ................................................................................................................. ..112
1.13.0 WORK FLOW PROCESSES ........................................................................................... 113
1.13.1
Basic'Service Only' Work Flow Process ...................................................................................... .113
1.13.2
Basic Residential/Commercial Work Flow Process ........................................................................ .114
1.13.3
Summary of Basic Processes with Approximate Time Requirements ............................................. ..115
1.14.0 MISCELLANEOUS ........................................................................................................ 117
4
1.14.1
Distribution Service Enclosure (Tap Box, )unction Box) & Wireway Specification ............................. .117
1.14.2
AE'S Requirements for Distributed Generation Interconnection (under 50 kW) ............................... .118
1.14.2.1
Manual Disconnect ........................................................................................................ .118
1.14.2.2
Voltage .......... ........ ......... ...... ... ............ ... ........................................... ...........................118
1.14.2.3
Frequency .....................................................................................................................118
1.14.2.4
Harmonics .....................................................................................................................118
1.14.2.5
Flicker .................................................................................................. ....................... .119
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1.14.2.6
Power Factor .................................................................................................................119
1.14.2.7
Loss of Source ...............................................................................................................119
1.14.2.8
Coordination and Synchronization ....................................................................................119
1.14.2.9
Metering .......................................................................................................................119
1.14.2.10 interconnection Study ....................................................................................................119
1.14.2.11 Protection Requirements .................................................................................................120
1.14.2.12 Additional requirements for three-phase generators ...........................................................120
1.14.3
CAD Drawing Requirements ......................................................................................................121
1.14.4
Metering to Measure Solar Energy Credits .....................................................................................122
1.15.0 APPENDIX C -EXHIBITS
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Response to OPC 1-59, Attachment I
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