CRITERIA kV A - Nuclear Regulatory Commissionsection from Wescosville 230 kV Substation to a point approximately 1 mile from the Siegfried 230 kV Substation is a reconstruction of

DESIGN CRITERIA

500 kV STEEL POLE STRUCTURE

TRANSMISSION LINES

A REPORT BY

TRANSMISSION ENGINEERING SECTION

BULK POWER ENGINEERING DEPARTMENT

PREPARED BY:

R. J. GEIGERSENIOR PROJECT ENGINEERTRANSMISS IOiN ENGINEERING

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APPROVED:

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TABLE OF CONTENTS

'~Pa e

General

Types of Lines

Right of Way Clearing

Clearances

Structure Location

Structures

Electrical Characteristics

Foundations

Insulators and Hardware

Conductor and Shield Wire Data

Counterpoise and Grounding

Electric and Magnetic Field Effects

Lake Crossing

12

32

37

43

46

58

59

64

DESIGN CRITERIA500 kV STEEL POLE STRUCTURE

TRANSMISSION LINES

Forward

A major departure from the construction of conventional lattice towerswhich were used for the original Keystone 500 kV transmission lines tothe use of steel pole structures was adopted in 1972 on the Siegfried-Wescosville 500 kV line. For aesthetic reasons, in the highly visiblearea in the vicinity of Route 22 and 309, a portion of the line wasconstructed on steel pole structures. Since that time approximately 150miles of steel pole structure lines have been built or engineered.

This report is a documentation of the design criteria applied to these500 kV lines utilizing steel pole structures. While this manual providesinformation on all aspects of the design, special emphasis is placedwhere the criteria used is substantially different from the Keystonecriteria.

1. General

This manual documents the. fundamental factors in the electrical andstructural design of the PPGL 500 kV lines utilizing steel polestructures. It does not serve as an engineering design manual, butrather presents the design criteria from which detailed specifi-cations were prepared in connection with various physical componentsin the construction of the lines. The manual also gives the criteriaused for structure spotting and right of way clearing.

For the most part, the criteria used in the design of the 'linescovered in this report is similar from one line to another, however,special attention is given to areas made where the criteria isdifferent.

The lines are generally single circuit lines supported by 'H'ramesteel pole structures, however, some of the lines have been designedfor double circuit construction. A portion of the Alburtis-Wescosvilleline is single pole structures supporting the single circuit. Thedouble circuit lines are supported by double circuit 'H'rame steelpole structures.

The 'H'rame configuration for the single circuit structures is twouprights with a single cross-arm with the phases, arranged horizontally.The double circuit configuration utilizes a 'H'rame with twouprights and two cross-arms. The phases are arranged four on thebottom arm and two on the top arm. A circuit is arranged in atriangular configuration on each side of the structure with onephase on the top arm and two phases on the bottom 'arm. The singlepole structure has three horizontal 'V'.,'s arranged in a deltaconfiguration with one on one side of the pole and two on the otherside. The following is a table of the lines discussed in thisreport.

TABLE I

TYPES OF LINES

Line Name

DoubleSingle Length Year Circuit Length YearCircuit T~e Miles Const. H-Frame Miles Const. Remarks

1. Susquehanna-Wescosville,

Susquehanna-Siegfried Section

Siegfried-Wescosville Section

X

X

H 54

H 5

78-81

74-, X 78-80 Portion onTowers

2. Stanton-Susquehanna /j2 X

Sunbury-Susquehanna 82 X

H 30

H 40

76-79

79-82 X

2 miles230 kv

95% owned"by AlleghenyElectric

4. Susquehanna-Generator X$/2 Leads

5. South ManheimConnection

H 0.25 82

0.5 78 Part of230 kV Line

6. Alburtis-Wescosville XX

H 2.8Sing 2.8Pole

80-81 X80-81

5.7 80-81

4

Sus uehanna-Wescosville I,ine

The Susquehanna-Wescosville 500 kV Line provides a portion of the trans-mission to integrate the Susquehanna SES into the bulk power system.

The line consists of two distinct line sections. The original 10 milesection from Wescosville 230 kV Substation to a point approximately 1mile from the Siegfried 230 kV Substation is a reconstruction of theSiegfried-Wescosville 230 kV line on a combination of steel pole

'H'rames,painted green and galvanized steel lattice towers. The remainingone mile of this line section was completed as part of the Susquehanna-Siegfried line. This portion of the line utilizes double circuit

'H'rameswith one circuit position initially vacant.

The line route for the conversion from 230 kV to 500 kV construction fol-lowed the original Siegfried-Wescosvi'lie 230 kV line corridor except fora small relocation in the vicinity of the Lehigh Service Center. Startingat Wescosville Substation in Upper Macungie Township, Lehigh County, theline extends ll mil'es through South Whitehall Township and North WhitehallTownship, Lehigh County.

The second section of line from Susquehanna to Siegfried is 54 mileslong, single circuit arrangement with steel pole 'H'rame constructionusing corrosion resistant steel. This line section extends from theSusquehanna 500 kV Switchyard in Salem Township, Luzerne County to theSiegfried-Wescosville 500 kV line, described above, in the vicinity ofthe Siegfried Substation in Allen Township, Northampton County. The lineroute parallels the Sunbury-Susquehanna 500 kV line across the

Susquehanna'iver,

to an intersection of the existing Sunbury-Susquehanna 230 kVline. At. this point, the Susquehanna-Siegfried line parallels the existing230 kV line northeast to a point near Council Cup. At Council Cup theline leaves the existing 230 kV line, forming a new right of way, in aneasterly direction across the southern portion of Iuzerne County andsouth into Carbon County. The route then passes in a southeasterlydirection across a portion of Carbon County to an intersection with theEast Palmerton-Christmans 66 kV line. At this intersection, the Siegfriedline and the East Palmerton-Christman line form a parallel right of waysouth toward East Palmerton Substation. East of the substation, theSusquehanna-Siegfried joins the Siegfried-Harwood 230 kV line and continuesin a common corridor south to the Siegfried-Wescosville 500 kV line onthe Lehigh River in Northampton County. The line, in general, is centeredin a 200 foot right of way. Where the line is in a common corridor withother transmission lines, the right of way width varies in each case from200 feet to 325 feet.

Stanton-Sus uehanna i/2 500 kV I.ine

The Stanton-Susquehanna 500 kV line provides one of the transmission out-lets for the Susquehanna SES. In addition, it reinforces the bulk powersupply to the PAL Wyoming Valley Region.

The line is 32 miles long and is constructed on steel pole 'H'rame'susing corrosion 'resistant steel and double circuit single poles paintedgreen. The'ouble circuit steel pole section is approximately 2 mileslong and constructed for 230 kV operation. The line wi'll be reterminatedat the Susquehanna 500 kV Switchyard when required. Starting at theSusquehanna 230 kV Switchyard in Conyngham Township, Luzerne County, theline extends to the Stanton 230 kV Substation near Pittston, ExeterTownship, Luzerne County.

The line parallels the Montour-Susquehanna 230 kV line across the Susque-hanna River to a point approximately 2000 feet northwest of the SusquehannaSES. Leaving the Montour-Susquehanna 230 kV line, the Stanton line tra-verses north to the vicinity of Schickshinny where it'turns northeast ex-tending past the UGI-Hunlock Substation and intersects,a UGI-66 kV doublecircuit tower line. The Stanton Line parallels the UGI line in a commoncorridor to the vicinity of the UGI-Mountain 230 kV Substation. Near theMountain Substation the Stanton line intersects the Stanton-Mountain 230kV line and parallels it in a common corridor to the intersection withthe Stanton-Schwoyersville and Stanton-Exeter 66 kV double circuit line.From this intersection to the Stanton 230 kV substation, all three linesare in one common corridor.

Sunbur -Sus uehanna /j2 500 kV Line

The Sunbury-Susquehanna line provides one of two 500 kV transmission out-lets for the Susquehanna SES.

The line is 44 miles long and ownership is divided between PPM and Alle-gheny Electric Cooperative, Inc. PPSL's portion is 4.3'/ of the line (1.9miles) and is located at the Sunbury and Siegfried end of the line.

The first 4.2 miles from Susquehanna SES are double circuit steel pole'H'rames. One position occupied by the Sunbury line and the otherposition for future system development. The structures on the north sideof the Susquehanna River are painted green while the remaining structuresutilize corrosion resistant steel. The balance of the line is singlecircuit 'H'rames utilizing corrosion resistant steel.

The line starts at the Susquehanna 500 kV Switchyard in Salem Township,Luzerne County and extends to the Sunbury Substation in Monroe Township,Snyder County. Leaving the Susquehanna Switchyard, the route crosses theSusquehanna River in a southerly direction in a common corridor with theSusquehanna-Siegfried line and intersects the existing Sunbury-Susquehanna230 kV line. From this intersection the route parallels the existingline to the west. The two lines, in a common corridor, parallel theSusquehanna River in a southwesterly direction as they cross parts ofColumbia, Montour and Northumberland Counties. At a point 1.2 milessouth of Sunbury the line crosses the Susquehanna River to the SunburySubstation on the west bank in Snyder County.

Sus uehanna Generator 82 Leads

The Susquehanna generator 82 leads serves as the connection for the gener-ator 82 output. to the 500 kV substation. This short 500 kV line consistsof two single circuit steel pole 'H'rames painted green and extends1400 feet from the unit Jj2 dead end structure to the 500 kV switchyard.This facility is located on the Susquehanna plant site, consequently noright of way is required.

South Manheim Connections

These lines provide the present 230 kV supply to the South Manheim 230 kVSubstation and the connection to the future 500 kV substation. Beginningat the South Manheim 230 kV Substation in Penn Township, I,ancaster County,the line extends to the west on a 200 foot right of way 0.68 miles to the230 kV double circuit tower line near PA Route 72. The first 0.53 milesof the line are 500 kV double circuit steel pole 'H'rames painted greenand the remaining 0.15 miles are 230 kV double circuit single pole paintedgreen.

Alburtis-Wescosville 500 =kV Line

The Alburtis-Wescosville line provides system reinforcement necessary todeliver bulk power into the Pennsylvania-New Jersey-Maryland Interconnec-tion network. ,In addition', the line will reinforce the power supply tothe PPSL Lehigh region.

The line is 11.3 miles long and consists of three distinctly differentsections of line. The first section, about 2.8 mile's in length fromWescosville in Upper Macungie Township, Lehigh County to Route 100, theline is constructed on single steel poles painted green. Continuing west2.8 miles from Route 100 to the Alburtis-Bossards right of way, the lineis constructe'd on steel pole 'H'rames painted green. Turning south andcontinuing on the Alburtis-Bossards right of way, the line extends 5.7miles to the Alburtis Substation in Lower Macungie Township, LehighCounty, on double circuit steel pole 'H'rames painted green. Thesecond circuit position is for future system development. Right of waywidth varies from 140 feet in the single pole section to 200 feet in

the'ingle

and double circuit H-frame section.

3. Ri ht Of Wa Clearin

To provide for the proper clearance of power conductors to surroundingvegetation, the PPGL Vegetation Management Specifications wereapplied to clearing the right of way corridor for 500 kV steel polestructure lines. This specification coveys the initial removal ortrimming of trees and brush and selective spraying of growth on theright of way.

Detailed instructions for specific clearing plans are on the Planand Profile Construction Drawings for each line. In addition,access roads and erosion and sedimentation control measures areshown.

Erosion control plans are required by the DER wherever there isearth moving activity and require a permit whenever an activityaffects more than 25 acres simultaneously. 'Construction practicesof PPSL limit the total acres affected to less than 25 acres at one,time. For PPGL Company transmission line construction, the plan andprofile drawings used for constructing the line along with thespecifications for Soil and Erosion and Sedimentation Control onTransmission Rights of Way (A-118231), which is made part of theplan and profile by cross reference, is considered the erosioncontrol plan for the project.

For the three Susquehanna transmission outlets, the additionalcriteria of complying with the final environmental statement relatedto the construction of Susquehanna Steam Electric Station preparedby the NRC was imposed. To insure compliance, Environmental Auditswere performed monthly by the transmiss'ion engineering section.

4. Clearance

The ground clearances for 500 kV Transmission Lines are designed toprovide, at all times a safe distance from the energized conductorsto ground. All clearances are calculated according to Section 23 ofthe National Electrical Safety Code (NESC) and shown on Table II.The following 500 kV Lines are considered in this report:

1. Susquehanna-Wescosville2. Stanton-Susquehanna $/23. Susquehanna Generator g2 I,eads4. Sunbury-Susquehanna5. South Manheim Connections6. Alburtis-Wescosville

With the exception of the Alburtis-Wescosville Line, the groundclearance requirements for the above, lines were based on the 6thEdition of the NESC (see Table II). PPScL Co. also practicesmaintaining a clearance of 41 feet at maximum thermal sag at roadcrossings in order to limit the current due to electrostatic effectsto 5.0 milliamperes, rms, if the largest anticipated truck, vehicle,or equipment under the line were short-circuited to ground.

Clearances for the 'Alburtis-Wescosville Iine originally were designedin accordance with the 1977 Edition of the NESC. This edition madethe provision that if switching surge factors could be determined,the vertical clearance 'to ground could be reduced. However, as thedesign of the line proceeded, it was determined that the electrostaticeffects of the line were not the sole governing condition for clearanceOther criteria 'such as corona, electric field gradient and audiblenoise were used to determine the ground clearance requirements onthis line. The double circuit portion of the line utilizes triplebundle conductors with a clearance of 30 feet at 900C thermal rating.This provides a maximum electric field gradient of 9a8 kV/m. Thesingle pole single circuit portion, due to the narrow easement,utilizes the triple bundle configuration. To achieve a maximumelectric field gradient of 5 kV/m, the conductors have a groundclearance of 45'hermally rated at 90 C.

9

TABLE II500 kV TRANSMISSION LINE CIEARANCES IN FEET

FOR LINE CONDUCTOR TEMPERATURE OF 100 C

IN ACCORDANCE WITH THE NESC.

Pedestrian Travel

Roads

Railroads

Power Lines

Communication I,ines

Future Power Lines at Roads

6th Edition

28

33

41-

15

17

54

1977 Edition

28

33

41

15

17

56

1977 EditionWith Known

Switching Surgefactors

23.6

28.6

36.6

15

17

54

Alburtis-Wescosville

Line

see note

see note

36.6

15

17

54

Note: 30'f clearance is required for triple bundled conductor, double circuit portion, at 90 C.45'f clearance is required for triple bundled conductor, single circuit portion, at 90 C.31'f clearance is required for double bundled conductor.

pd/47P-A

5. Structure Location

Structure locations were determined by aesthetic, engineering designand electrical code concerns. Structures at angles are a necessitybut spotting structures to reduce visual impact was considered inlocating structures. A minimum distance of 200'rom roads wasmaintained and high points were avoided unless extreme engineeringconditions would have resulted.

The Keystone criteria governed the engineering design of the lineexcept that structures were designed for specific spans as opposedto the Keystone family of towers. In addition to the aesthetic andengineering concerns, the National Electric Safety Code criteriaalso influenced the location of structures. The clearances specifiedin the code (See clearance section) were maintained. The heights ofthe structures were limited for economic reasons, which restrictedthe span lengths and structure locations. Where lines paralleledexisting transmission line facilities, the location of new structureswere determined by the maximum offset from existing structures tomaintain NESC clearances to adjacent lines.

Structures

General Back round

Steel pole structures were used selectively on several of the first500 kV tower lines such as the Berks and Hosensack-Quarry lines andwere mainly interspersed at locations requiring unique conductorarrangements, line crossing points, or special tension change points.Steel poles were conveniently used at those locations because theycould be custom designed for the precise loadings to be applied andrepresented cost savings over special designed, non-standard, latticetype structures.

On later 500 kV lines, tubular steel structures were used entirelybecause of either (1) competitive overall steel pole installed costswhich represented savings over comparable lattice tower designs or(2) environmental consideration for a more aesthetically pleasingstructure compared to lattice towers. Again, all structures andfoundations are custom designed for their particular application inorder to realize the greatest cost savings. Ioadings are developedaccordingly for each structure location and provided to the selectedpole manufacturer. In the case of long lines involving many structuresthe manufacturer generally groups loadings within the various differentpole types and designs and fabricates a number of structures by theheaviest loading in a given group.. This design method results in acertain percentage of overdesign on a large number of structures butoptimizes overall savings by cutting down on engineering costs andmanufacturing shop set up time by duplicating many fabricationunits.

Since each structure is designed for actual applied loads, specificmaximum allowable horizontal and vertical spans cannot be assignedto a given structure type as is the case in lattice towers designedas a family to cover a wide range of loadings.

Table "III"on page 14 summarizes the major 500 kV steel pole linewhich was designed by PL between 1973 and 1979. Table "IV" on pages15 and 16 identifies the various structure types and associatedoutline drawings which are specified on each of the line designs.

Unswe t Arms Vs. Strai ht Arms and Un ainted Vs. Painted Structures

A 3.0 mile segment of the Siegfried-Wescosville section of theSusquehanna-Wescosville line was the first major steel pole 500 kVline construction on PL's system. Painted structures with upsweptarms were utilized on the line section in the vicinity of Routes 22and 309 and Wescosville Substation. Tower construction was used inthe remaining 8.0 mile portion of the line towards Siegfried Substationbecause steel pole construction could not be economically justifiedwith the structure types being evaluated at that time.

12

When the time came to design the approximately 128 miles of 500 kV

lines which would serve as outlets for Susquehanna S.E.S. generation(namely the Stanton-Susquehanna /f2, Susquehanna-Siegfried section ofthe Susquehanna-Wescosville and Sunbury-Susquehanna 82 lines) theeconomics of different structure types were evaluated and it was

determined that considerable savings could be realized over towerconstruction with the use of tapered straight conductor arms andOHGW arms, and corrosion resistant steel. Since large portions ofeach of these lines are in rural or wooded areas, a corrosionresistant steel provided an improved visual impact over latticetowers. However, painted structures were purchased for the linesections in the immediate vicinity of Susquehanna S.E.S. in order tocoordinate with the existing green facilities. Painted structuresare used exclusively on the Alburtis-Wescosville and South ManheimTap lines since they also are located in areas considered to be moreenvironmently sensitive. In all'ases painted structures have a

higher initial cost and are more costly to maintain.

13

TABLE "III"500 KV STEEL POLE LINES

Summar Of Structure T es and Confi urations

I,ine Name

1. Susquehanna-WescosvilleSiegfried-Wescosville lineSusquehanna-Siegfried Section

2. Stanton-Susquehanna $/2 Line

3. Susquehanna-Generator 92 Leads

4. South Manheim Taps

5. Alburtis-Wescosville I,ine

Structure~T6"H" Type

"H" Type

I IHII

IIHII

"H" Type

"H" Type"H" TypeTriangular

Strut

Single orDouble Circuit

Single

Single S

Double

Single

Single

Double

DoubleSingleSingle

Painted onUn ainted Corten

Painted

Painted 6Unpainted

Unpainted

Painted

Painted

PaintedPaintedPainted

ArmT~e

Upswept

Straight

Straight

Straight

Straight

StraightStraight

GeneralStructureSeries

5SPjj11005SPH12005SP jjT5SHPT

5SPHT

5DPHT

5DPjjT5SHPT5SPT

6. Sunbury-Susquehanna 92 Iine "H" Type"H" Type

Hll Type

SingleDoubleDouble

UnpaintedUnpaintedPainted

Straight 5SPHTStraight 5DPjjTStraight 5DPHT

TABLE "IV"

500 KV STEEL POLE LINESSTANDARD STEEL POLE STRUCTURE OUTLINE DRAWING REFERENCE

Structure Desi nation

SINGLE CIRCUIT

5 SPH 1100 Series

Structure T e

Single Circuit "H", tangent(Upswept Arms)

V String Susp. DB 1067 'P.144

5 SPH 1200 Series Single Circuit "H", 1 -15 . V String Susp.(Upswept Arms)

DB 1067 P.155

5 SP 1300 Series5 SP 1400 Series

5 SP 1600 Series5 SP 1700 Series

5 SP 202 6 203SP 301 6 302

5 SP 600 Series

Single Circuit, Unguyed,Angle Deadend, 3 Pole Str.

Single Circuit,Unguyed,'ngle

Deadend, 3 Pole Str.

Single Circuit, Unguyed,Angle Deadend, 3 Pole Str.

Single Circuit, Single Pole,Guyed, Angle Deadend

Tension

Tension

Tension

Tension

DB 1067 P.143

DB 1067 P.145

DB 1066 P.813

DB 1069 P.531

5 SPHT Series

5 SPHA Series

5 SPHA Series

Single Circuit "H", Tangent(Straight Arms)

Single Circuit "H", 1 -15(Straight Arms)

Single Circuit "H", 16 -30(Straight Arms)

V String Susp. DB 1067 P..193

V String Susp. DB 1067 P.194


5 SPHD Series

'5 SPD Series(Horizontal)

5 SPT Series

5 SPA Series

e5 SPD Series(Triangular)

Single Circuit "H", Guyed,Angle Deadend, 0 -30(Straight Arms)

Single Circuit, Guyed,Angle Deadend, 3 Pole Str.

Single Circuit, Single Pole,Triangular Tangent Strut.

Single Circuits, Single Pole,Triangular Angle Strut 1 -10

Single circuit, Guyed, HeavyAngle Deadend, 2 Pole Str.

15

Tension

Tension

Strut Susp.

Strut Susp.

Tension

DB 1067 P.200

DB 1067 P.196

DB 1085 P.55

DB 1085 P.55

DB 1085 P.57

4

Structure Desi nation

5 SPD Series(Vertical)

DOUBLE CIRCUIT

Structure e

Single Circuit, Guyed, Single TensionPole, Angle Deadend

DB 1085 P.58

5 DPHT Series

5 DPHA Series

5 DPHA Series

Double Circuit "H", tangent* (Straight Arms)

Double Circuit »H", lo-15o(Straight Arms)

Double Circuit iiH« 16o 30o(Straight Arms)




5 DPHD Series

5 DPD Series

Double Circuit, "H", Guyed,Angle Deadend, 0 -30(Straight Arms)

Double Circuit, Guyed,Angle Deadend, 4 Pole Str.

Tension

Tension

DB 1067 P.228

DB 1067 P.229

16

"H" Deadend Vs. Sin le Pole Deadend Structures

"H" type deadends were introduced in the design of the Susquehannalines and proved a design advantage over single pole deadends inthat horizontal offsets between OHGW and conductors are readilyprovided to obtain clearances for ice on-ice off and gallopingconductor criteria. Stringing on "H" deadends is more costly due tothe temporary guying that is necessary to prevent arm deflection dueto stringing tension unbalances. In addition, unanticipated problemswere encountered during stringing due to rotation of the conductorarm and OHGW mast which was inherent in the design tolerances providedin the pinned and bolted connections. In the end the two types ofstructures were nearly a trade off economically, although the use ofan "H" deadend may have an aesthetic value over a typical multipolestructure. Due to economics "H" deadends were limited to line breakangles 304 and below.

Un u ed Vs Gu ed "H" T e Structures (V-Strin runnin an les)

Cross braces are utilized on "H" structures on all lines to providefor a more rigid design and help support transverse loads in lieu ofangle guys. Angle guys cannot be justified taking into considerationaesthetic impact. Rigid cross braces a'e'pecified'n lieu ofinterpole guying due to the ease of installation and savings inlabor costs. Cross braces are limited to one per structure on alllines except the Siegfried-Wescosville line; the intent is toprovide space to walk the crane during erection as a one piecestructure. V-string assemblies are limited to line break angles ofapproximately 30~, within the capacity limits of the assembly,similar to tower line construction.

Un u ed Vs. Gu ed Deadend Structures

Due to the extremely large conductor tensions commonly used in the500 kV designs it is usually cost prohibitive to purchase a self-supporting structure to sustain unbalanced tensions resulting fromstringing, ice on-ice off, or broken conductor loading conditions.Therefore, most deadend structures whether they are "H" type orsingle pole are head and back guyed to support longitudinal loads.Guying on "H" deadends is only specified to support the typicalunbalanced longitudinal loadings mentioned. above. Single poles areadditionally guyed to support maximum conductor deadend designloads. A total of 4 head and 4 back guys (2 per leg) are typicallyused on single circuit "H" deadend designs to support all conductorsand OHGWs and a maximum of 4 head and 4 back guys per conductorposition are typically specified on single poles. The number ofguys is limited to satisfy aesthetic requirements and optimizeoverall installed costs.

17

OHGW positions typically are not guyed on "H" structures because of.electrical clearance requirements and the large vertical loads thatare generated in the static arms. OHGW positions on single ormultipole structures are generally not guyed on line angles below55 because of minimum electrical clearance requirements to'nergizedconductors at the lower elevation.

Guy attachments are specified at a minimum vertical distance belowconductor attachments to provide electrical clearances. This re-quirement generally applies to "H" deadends with large line anglesand multipole structures with shallow line angles.

Sin le Pole Tan ent Structures

A new single pole structure equipped with strut insulator. assemblieson a triangular configuration was developed. for the section of theAlburtis-Wescosville line out of Wescosville Substation for use onthe narrow 140'ide R/W strip in that segment. Increased groundclearances and triple bundled 1590 kcmil phase conductors areincorporated on the single pole section in order to reduce RIV andaudible noise interference levels.

Une ual Le I,en ths and Structure Hei hts

"H" type structures are typically purchased in height increments of.5'.g. 120', 125', 130'tc. Structures on the Stanton-Susquehanna//2 and Susquehanna-Siegfried lines are not in inciements of 5'. Thedistance from the top of structure to the conductor elevation changedfrom 25'o 27'uring the course of design but after structuralsteel was purchased by the manufacturing and Steel Pole. Detail andPlan Profile drawings were near completion; and it was easier tochange the OHGW arm lengths and designated structure heights thanchange leg lengths and design drawings. I,ater designs compensatedfor this change and use height increments of 5'.

Unequal leg lengths on multilegged structures or unequal pole heightson multipole structures are utilized to limit foundation pedestal-lengths to 18" below grade. where cross sectional groundlines vari'es.Typically these unequal'engths are also in 5'ncrements and theremaining differences in elevation is compensated for by foundationpedestal lengths. However, one foot increments are used on theSunbury-Susquehanna //2 and Susquehanna-Siegfried lines in order toreduce the number and length of concrete pedestals.

Structure Desi nation And Le Identification

The typical 500 kV structure type designations and the definition ofeach character in the designations are described on pages 21 and 22.You will note. that structure designations conform to the format oftypical 138 kV and 230 kV structures on the earlier lines up to andincluding the Siegfried-Wescosville line. Designations were alteredfor the purchase of structures for the Susquehanna lines in order tomore precisely identify the line and location where a particular

18

0

structure was to be shipped and at the same time provide at a glanceadditional information about configuration, insulator type, orientation,and whether or not it was to be guyed. The pole manufacturer identifiedthe specified designation on the structure nameplate.

The pole manufacturer also labels each pole or leg section with theorientation specified on the job bill of material. The standardorientation is shown on Page 13. Physical identification is usuallywith beads of weld placed on baseplates, arm saddles, or flangeplates and at a minimum consist of the structure number, line codeletter, and orientation, e.g. 24AL1. Other structural members suchas arms, x-braces, etc. are labelled, again with beads of weld, inaccordance with the manufacturer's identification and detaileddrawings. In addition, the manufacturer supplies section orien-tation marks on parts that are shop fitted such as flange plateconnections.

Steel Pole Climbin

Step bolts and/or climbing and working ladder support brackets areinstalled on all steel pole structures to provide working access toall conductor and OHGW positions under, both initial installation andhot line maintenance conditions. Step bolt nuts and ladder supportbrackets are welded to structural members by'the- pole manfuacturerin accordance with PPGL Steel Pole Fabrication SpecificationLA-50181.

'Permanent step bolts were'he accepted means of climbing when theSiegfried-Wescosville line was installed and therefore were the soletype of climbing assist. During the design of the later Susquehannalines, removable climbing and working ladders became the newer meansof climbing and represented cost savings over permanent steps. Stepbolts are provided, however, on "H" structure OHGW arms and otherstructural members on all structure types where ladder provisionsare impractical. High reaching aerial equipment is generally usedby construction in lieu of actually climbing the structure when'suchequipment is available and can be readily moved to the structuresite.

For specific details and location of the climbing assists providedon a given structure refer to the individual steel pol'e detaildrawings referenced on the job Plan and Profile drawing.

Seel Pole Loadin Conditions

Structure loading conditions for 500 kV line designs generallyconform to Stone 6 Webster criteria on the Keystone lines. Loadingsummaries are prepared by computer for each individual structure andused by the manufacturer in their designs. The computer generatesnormal PPSL loadings, similar to 138 kV or 230 kV poles, but thenformats those loads into the various Keystone conditions.

19

Ce In the case of longitudinal loads on V-string equipped structures,Keystone loads are substituted for PPM, loads to keep loadings to a

minimum. The loadings that are substituted, see Table V, are selectedby comparing actual vertical and horizontal spans with lattice towertypes that fall in the same range. Refer to Page 31.

Some Keystone loading conditions are also eliminated from the manu-facturers summaries because they are not applicable or are readilyde'fined as non-governing loadings. The Keystone loading conditionsand an explanation of their application on steel pole structures areshown on pages 24 through 30.

The. one major exception to meeting Keystone loading criteria is onthe Siegfried-Wescosville line. The heavy ice loading condition onthat line was limited to 1 1/4" ice, Og wind in lieu of the normal 1

1/2" ice, Og wind loding. A smaller condition jf9E loading was

selected on the basis of historical ice studies of the PAL systemand the lower U.S.G.S. elevation that the line is located.

The use of Keystone criteria 'on double circuit structures is similarto single circuit designs. Worst case longitudinal unbalances underthe condition g5, broken conductor, condition //6, stringing, and ~

condition g7, ice on - ice off loadings were applied.

20

500 KV STEEL POLE DESIGNATIONS

Example of Typical Structure Type and Definition of Each Character in the Designation(Used on lines prior to and including the Siegfried-Wescosville Line)

Designates Voltage

Absense of No. = 66 kV1 = 138 kv2 = 230 kV5 = 500 kv

5S PH1 1 OiThese 2 characters distinguish theloadings by which the structure

was'esigned.

Designates Type of Framing

I,etter Indicates Circuits

D = Double CircuitS = Single Circuit

1

2 =36a

Tangent Suspension V-StringAngle Suspension V-StringUnguyed Tension Deadend7 = Guyed Tension Deadend

Letters Indicate Structure Type

P = Single Steel PolePH = Steel "H" Type Structure

Use of 4 characters indicatesthe following:

66 kV - Designed for 556.5 kcmilACSR, 500'vg. spans

230 kV - Designed for 1590 kcmilACSR, 550'vg. spans

500 kV - Designed for 2493 kcmilACAR, 1500'vg. spans.

p

500 KV STEEL POLE DESIGNATIONS

--" Example of Typical Structure Type and Definition of Each Character in the Designation

Indicates 500 kV

Letter Indicates CircuitsS = Single CircuitD = Double Circuit

Letter Indicates StructureP - Single Steel PolePH- Steel "H" Type Str..

T = Tangent V StringA = Angle V StringD = Deadend Tension

Structure Number

G For Guyed Structure~(Blank for Unguyed Structure)

L = Left Pole of Multiple Pole Str.M = Middle Pole of Multiple Pole Str.R = Right Pole of Multiple Pole Str.

(See Note --'elow)

(No I,etter for "H" Type Structures.On Structures with more than3 Poles, Label Li L2 Ry R2 Etc.from the structure center)

-Designates I,ineA = Susq.-SiegfriedB = Susq-Stanton jj2C = Sunbury-Susq j12D = So.Manheim TapsE = Alburtis-WescosvilleSusq.Generator 82 Leads

NOTE Most Important Code I,etter of Structure Designation. Each Structureis custom designed for a specific location on a specific line. Onlya structure with the proper code may be used on a given line.

NOTE"--: Refer to "Steel Pole Leg Identification" section for typical orientation. I,eftThrough right are viewed with your back to the source end of the line and theproper orientation shall be indicated on the structure bill of material and Plan6 Profile drawing.

NOTE---": Standard Designation after the Siegfried-Wescosville Line.

STEEL POLE LEG IDENTIFICATION

Multilegged or multipole steel structures are identified and labelled left to rightwith your back to the source end of the line as shown in the diagrams below.

H-FRAME STR. THREE POLE STR.

~+Leg gl Left

FOUR POLE STR.

0 Leg gl Left 2

(Source)

Leg jjl Left

Leg jj2 Right

(Source) ++Leg jj2 Middle

I,eg g2 Left 1'

(Source)

Leg 93. Right 1

++Leg g3 RightLeg

TANGENT STRUCTURE WITHOUT BREAK ANGLE

~Leg gl left ~Leg~r;eg

(Source)

Leg jul Left

(Source) ~Leg f/2 Middle

Leg j/2 Right ~r.eg'Leg 83 Right

ANGLE STUCTURE WITH BREAK ANGLE TO RIGHT

84 Right 2

jjl Ieft 2

g2 Left I

jj3 Right 1

jj4 Right 2

(Source)

Leg gl Left

Leg N2 Right

CY 'Ieg /$ 1 left

(Source) CY

I,eg g2 Middle

Leg jj3 Right

C( Leg gl Left 2

Ieg //2 Ieft 1

J

(Source)

Ieg g3 Right I

~Leg (I4 Right 2

ANGLE STRUCTURE WITH BREAK ANGLE TO LEFT

- The source is the starting point of the line designated by the transmission designengineer.

23

Sus ension Structures

All tangent and angle steel pole structures with V-strings are designedfor each of the individual numbered loading conditions as follows:

1. All cables intact, NES Code heavy loading which consists of 4 psfwind on 1/2 in."radial ice, O~F, on ground wires and conductors, and4.0 psf wind on structure with the following overload factors:

a. Transverse wind load and wind on structure 2.54b. Transverse and longitudinal wire pull loads 1.65c. All vertical loads 1.27-

This loading condition meets the requirements of the NES Code rule261A3a and 261A3b.

='verload factors on the Alburtis-Wescosville line are 2.50 and1.50 respectively-NESC 1977 rule 250, 252, and 261Al.

2. No cables on structure, a transverse wind of 25.0 psf (1) on structurewith an overload factor of 1.10 for all loads.

This loading condition meets the requirements of NES Code rule261A3c, 24 psf.

(1) PPSL hurricane wind load.

3. NOTE: This condition is not applicable to steel ole structures.

All cables intact, NES Code heavy loading which consists of 4 psfwind on 1/2 in. radial ice, O~F, on ground wires and conductors, and6.4 psf wind on 1.5 faces of tower with an overload factor of 2.0for all'oads.

4. All cables intact on steel pole structure in combination with atransverse hurricane wind of 25 psf (100 mph) on bare ground wiresand conductors, at 60~F, and 25.0 psf wind on str. with an overloadfactor of 1.25 for all loads.

5. NES Code heavy loading, O~F, combined with a longitudinal loadproduced by a broken subconductor in any one phase plus 100 per centimpact factor, all other phases and ground wires intact, with anoverload factor of 1.25 for all loads except an overload factor of1.0 for longitudinal long produced by a broken conductor.

6a. A longitudinal stringing load which would be produced by the groundwire 'binding in the stringing block and producing a longitudinalswing of the supporting bracket of 45 deg at any one ground wireattachment point, the other ground wire intact, no conductors onstr., a 4 psf wind on bare wire with 4.0 psf wind on str. of1.25 for all loads.

24

~ g

6b. A longitudinal stringing load which would be produced by two subcon-ductors in any one phase binding in the stringing block and producinga longitudinal swing of the insulator of 45 deg, the other phasesand ground'wires intact, a 4 psf wind on bare wire with 4.0 psf windon structure, O~F, with an overload factor of 1.25 for all loads.

For "H" frames, the cantilever length of arm is designed for a

camber equal to the deflection at the free end of arm calculatedunder loading condition.

7. A differential ice loading, incurred by ice falling from the groundwires or conductors in the span on one face of the tower, based on 1

in. radial ice to bare cable, no wind, 30 F, and producing a longitudinalload on the structure. The differential ice loading is applied tothe structure as follows:

a. Differential ice loading on one ground wire, 1 in. radial iceon the other ground wire and all three phases (see 7b)

b. Differential ice loading on both ground wire, and 1 in. radialice on all three phases (condition 7a was determined to controldesign between 7a 6 7b)

c. Differential ice loading on one outside-and middle phase; 1 in.radial ice'on the other phase and both ground wires.

d. Differential ice loading on all three phases with 1 in. radialice on both ground wires.

The overload factor is 1.25 for all loads and differential iceloading is always applied to the same face of the structure.

8. All cables intact, an 8 psf wind on 1 in. radial ice O~F, on groundwires and conductors, and 8.0 psf wind on str. with an overloadfactor of 1.25 for all loads

9. All cables intact, 1 1/2 in. radial ice, no wind, 0 F, with anoverload factor of 1.25 for all loads and combined as follows:

a ~

b.

1 1/2 in. ice on one ground wire, the other ground wire and phasesbare (see 9e.)

1 1/2 in. ice on both ground wires and all phases bare (see 9e.)

c ~ 1 1/2 in. ice on both ground wires, one outside phase and the middlephase; the other phase bare (see 9e.)

d. 1 1/2 in. ice on both ground wire and outside phases, and the middlephase bare (see 9e.)

e. 1 1/2 in. ice on all ground wires and phases - this condition wasdetermined to control design.

25

10. All steel pole structures are designed for a vertical pickup fromthe crossarm directly above the apex of the V-string. Condition 9eloads are used.

ll. NOTE: This condition is not applicable to steel pole structure.

For the bottom chord lacing and chord angles on all tower crossarms,a 400 lb ultimate vertical load is applied at the center of thesemembers in combination with the loading produced by the stringingconditions as specified for each of the different tower types.

All other horizontal or near horizontal redundant members are designedto withstand an ultimate vertical load of 400 lb applied to producemaximum bending.

Insulation Wei ht

The weight of insulator strings for use in steel pole structuredesign is as follows and is based on using 25 units for V-stringleg:

Single V-string (50 insulators) = 900 lb

Double V-string (100 insulators) = 1,800 lb

26

Tension Structures

All deadend steel pole and deadend "H" frame structures are designed foreach of the individual numbered loading conditions as follows:

l. All cables intact, NES Code heavy loading which consists of 4 psf on

1/2 in. radial ice, 0 F, on ground wires and conductors and 4.0 psfwind on structure with the following overload factors:

a. Transverse wind load and wind on structure 2.54 "=

b. Transverse and longitudinal wire pull load 1.65c. All vertical loads 1.27-

This loading condition meets the requirements of the NES Code rules261A3a and 261A3b

"= Overload factors on the Alburtis-Wescosville line are 2.50 and1.50 respectively-NESC 1977 rule 250, 252 and 261 Al.

2. No cables on structure, a transverse wind of 25.0 psf (1) on stripwith an overload factor of 1.10 for all loads

This loading condition meets the requirements of NES Code rule261A3c, 24 psf.

(1) PPGL hurricane wind load

3. NOTE: This condition is not applicable to steel pole structures.

All cables intact, NES Code heavy loading which consists of 4 psfwind on 1/2 in. radial ice, 0 F, on ground wires and conductors, and6.4 psf wind on 1.5 faces of tower with on overload factor of 2.0for all loads.

4. All cables intact on steel pole structure in combination with a

transverse hurricane wind of 25 psf (100 mph) on bare ground wiresand conductors, at 60 F, and 25.0 psf wind on structure with anoverload factor of 1.25 for all loads

5. NES Code heavy loading, 0 Fp combined with a longitudinal loadproduced by a broken subconductor in any single phase plus 100 percent impact factor, all other phases and ground wires intact, withan overload factor of 1.25 for all loads except an overload factorof 1.0 for longitudinal load produced by a broken conductor.

6a. A stringing condition resulting from the ground wires and conductorsbeing dead 'ended with a 4 psf wind on bare cable, 0 F, and 4.0 psfwind on str. with an overload factor of 1.25 for all loads andcombined as follows:

27

a. One ground wire dead-ended, no other cables on structure (see6a-d)

b. Two ground wires dead-ended, no conductors on structure (see6a-d)

c ~ Two ground wires, one outside and middle phase dead-ended; noconductors at other phase location

d. All ground wires and conductors dead-ended - this condition wasdetermined to control design between 6a-a, 6a-b, 6a-d, 6b 6 6c

e. The above combinations shall always be dead-ended on the sameface of the tower.

6b. A stringing condition resulting from the ground wire being dead-endedwith a 4 psf wind on bare cable, O', and 4.0 psf wind on structurewith an overload factor of 1.25 for all loads and combined as follows:

a. One ground wire dead-ended, no other cables on structure.

b. Two ground wires dead-ended on the same face, no conductors onstructure.

NOTE: See 6a-d

6c. A longitudinal stringing load which would be produced by two sub-conductors in any single phase binding in the stringing block andproducing a longitudinal swing of the insulator of 45 deg, the otherphases and ground wires intact, a 4 psf wind on bare wire with 4.0psf wind on structure O~F, with an overload factor of 1.25 for allloads.

NOTE: see 6a-d

7. A differential ice loading, incurred by ice falling from the groundwires or conductors in the span on one face of the structure, basedon 1 in. radial ice to bare cable, no wind, 30 F, and producing alongitudinal load on the structure. The differ'ential ice loading isapplied to the structure as follows:

a ~ Differential ice loading on one ground wire, 1 in. radial .iceon the other ground wire and all three phases (see 7b)

b. Differential ice loading 'on both ground wires and 1 in. radialice on all three phases (Condition 7a was determined to controldesign between 7a and 7b)

Co Differential ice loading on one outside and middle phase, 1 in.radial ice on the other phase and both ground wires.

— 28

d. Differential ice loading on all three phases with 1 in. radialice on both ground wires.

The overload factor is 1.25 for all loads and differential iceloading is always applied to the same face of the structure.

8. All cables intact, an 8 psf wind on 1 in. radial ice, 04F, on groundwires and conductors, and 8.0 psf wind on structure with an overloadfactor of 1.25 for all loads.

9. All cables intact, 1 1/2 in. radial ice, no wind, O~F, with anoverload factor of 1.25 for all loads and combined as follows:

a. 1 1/2 in. ice on one ground wire, the other ground wire andphases bare (see 9e)

be 1 1/2 in. ice on both ground wires and all phases bare (see 9e)

c. 1 1/2 in. ice on both ground wires and outside and middlephases; the other phase bare (see 9e)

d. 1 1/2 in. ice on both ground wires and outside phases, and themiddle phase bare (see 9e)

e. 1 1/2 in. ice on all ground wires and phase - condition 9e wasdetermined to control design

10. NOTE: Condition 10 not applicable because loading apply to deadend structure.

All towers with V-strings are designed for a vertical pickup fromthe crossarm directly above the apex of the V-string. This consistsof a vertical load equal to the weight span times 2 times bare cableweight with an overload factor of 1.25 at an one hase oint.

11. NOTE: This condition is not applicable to steel pole structures.

For the bottom chord lacing and chord angles on all tower crossarms,a 400 lb ultimate vertical load is applied at the center of thesemembers in combination with the loadings produced by the stringingconditions as specified for each of the different tower types.

All other horizontal or near horizontal redundant members are designedto withstand an ultimate vertical load of 400 lb applied to producemaximum bending.

Insulator We iths

The weights of insulator strings for use in steel pole design are asfollows:

29

2 Strings for each leg of the V-string = 1 800 lb er hase

3 Strings for flat leg and 2 strings for the other leg of the V-string= 2 200 lb er hase

For structures with strain insulators, the weight of insulators is2,000 lb per phase on one face of the tower.

S ecial Steel Pole Structure Loadin s

All line deadend structures at substation or switchyard terminalswere designed to sustain all cables down on one face of the structure,the other side intact, NES Code heavy loading, 0 F, with an overloadfactor of 1.50 for all loads.

2. On single pole deadends with line break angles 55 and below anadditional condition 810 and j/10a were included to split thetransverse loads from condition //8 into loads supported separatelyby pole and guys. The intent was to compensate for wind loads thatwould be sustained by the pole rather than the guys on shallow lineangles. Guys were assumed to support deadend loads only.

30

03

TABLE V

500 KV STEEL POLE TRANSMISSION LINES

Summary of Keystone Iongitudinal Loads Substituted For PLGenerated I,oads on Tubular Steel Structure I.oading Summaries

Horizontal Span Vertical Span Conductor I.oad") (fj Lon xtudznal)nn

Condition 85 Condition $/6 Condition 87

OHGW Load(jj Lon itudinal)

AJ

Condition j/5 Condition 86 Condition jj

00

00

0'o 1399 0'o 1767'7201400 to 1800'800'o 2287'9500

7000

9400

4200

10920

3880

8940

0 — 15 1400'o 1800'800'o 2287'2260 7800 6600 3880

15 - 30 1400',to 1800'800'o 2287'0900 9260 5560 An 3880

NOTES:

4n PL generated loads were used on OHGW positionKeystone Condition NumbersPL generated loads were used on any structure which did not fall into a range that met line angle, horizontal span,and vertical span simultaneously.

7. Electrical Characteristics

Line Im edances - ohms er mile

Name Resistance Reactanc'e

Stanton-Sus uehanna - single circuitPositive and negative sequenceZero sequence

0.0250.478

0.6041.602

Sus uehanna-Wescosville - single circuitPositive and negative sequenceZero sequence

0.0250.478

0.6041.602

Sus uehanna-Wescosville - double circuitPositive and negative sequenceZero sequenceMutual

0.02470.46990.445

0.58211.7501.035

Sunbur -Sus uehanna - single circuitPositive and negative sequenceZero sequence

0.0250.478

0.6041.602

Sunbur -Sus uehanna - double circuitPositive and negative sequenceZero sequenceMutual

0.02470.46990.445

0.5821l. 7501.035

Alburtis-Wescosville - single circuit, twinbundle

Positive and negative sequenceZero sequence

0.0250.478

0.6041.602

Alburtis-Wescosville - double circuit, triplebundle

Positive and negative sequence .Zero sequenceMutual

0.02260.'46780.445

0.52381.69161.035

Alburtis-Wescosville - single circuit, triplebundle

Positive and negative sequenceZero sequence

0.02260.4985

0.51371.5910

South Manheim Connections - double circuitPositive and negative sequenceZero SequenceMutual

0.02470.46990.445

0.58211.7501.035

Sus uehanna Gen. 82 Leads - single circuitPositive and negative sequenceZero Sequence

0.0250.478

0.6041.602

32

Conductor Surface Volta e Gradient-Calculated

Line Name

Maximum Kilovolts per cm

line o eratin at 525 kVPosition of

Phase

Stanton-Susquehanna 16.11 inside

Susquehanna-Siegfriedsingle circuit portiondouble circuit portion

16.1116.38

insideinside bottoms

Sunbury-Susquehannasingle circuitdouble circuit

16.1117.73

insideinside bottom

Alb'urtis-Wescosvillesingle circuit-twin bundlesingle circuit-triple bundledouble circuit-triple bundle

16.1115.09.15. 69

insidebottominside bottom

South Ma'nheim Connections

Susquehanna Gen..j/2 Leads

17.73

16.11

.inside bottom

inside

33

Shield Wire Confi uration - ical Sus ension Structure

Two 19 No. 9 Alumoweld shield wires are installed at the top of eachstructure in a horizontal plane as follows:

Line NameHt Above Outermost Shield Angle to

Phase Offset 'utermost Phase

Stanton-Susquehanna 25' I 20o

Susquehanna-Wescosville(single circuit portion)

25' t 20o

Susquehanna-Wescosville(double circuit portion)

56'3'3oSunbury-Susquehanna

(single circuit portion)25'- 91 20o

Sunbury-Susquehanna(double circuit portion)

56'3'3oAlburtis-Wescosville

(single circuit - twin bundleportion)

25'I 20o

Alburtis-Wescosville(double circuit portion)

'6'3'34Alburtis-Wescosville

(single circuit - triplebundle portion)

] 7 I 4ll 7.5'3 4o

South Manheim Connections 56'3'30Susquehanna Gen. /f2 Leads 25'I 20o

34

Conductor Confi uration and S acin

Name of I,ineNumber of

SubconductorsSubconductorConfi uration

Subconductor SpacingCenter to Center Conductor

Stanton-Susquehanna

Susquehanna-Wescosville(sc 6 dc portions)

horizontal

horizontal

18"

1 8ll

2493 kcmil ACAR

2493 kcmil ACAR

Sunbury-Susquehanna(sc 6 dc portions)

horizontal ] 81I 2493 kcmil AGAR

Alburtis-Wescosville(sc H-frame portion)

horizontal 18lt 2493 kcmil ACAR

Alburtis-Wescosville(dc portion and sc singlepole portion)

triangular 18" 1590 kcmil ACAR

South Manheim Connections

Susquehanna Gen. /I2 I.eads

horizontal

-horizontal

18

18"

2493 kcmil AGAR

2493 kcmil AGAR

Name Descri tion of Phase S acin

1)2)3)

4)

Stanton-SusquehannaAlburtis-Wescosville (H-Frame portion)Susquehanna-Wescosville(single circuit portion)Sunbury-Susquehanna(single circuit portion)

35 ft. Horizontal (flat)35 ft. Horizontal (flat)35 ft. Horizontal (flat)

35 ft. Horizontal (flat)

5)

6)

7)

Susquehanna-Siegfried(double circuit portion)Alburtis-Wescosville(double circuit portion)Sunbury-Susquehanna(double circuit portion)

4 conductor positions on bottom arm and2 conductor positions on top arm. Horizontal phasespacing is 33 ft. on both arms. Vertical phasespacing is 32 ft.

8) Alburtis-Wescosville(single circuit - single poleportion

Triangular configuration with 2 phase positions on oneside of the pole and one on the other. The middle phaseis located 37'orizontally and 10'8" vertically fromthe bottom phase. The top phase is located 25'erticallyand 1'9" horizontally from the bottom phase.

9) South Manheim Connections 4 conductor positions on bottom arm and 2 conductor positionson top arm. Horizontal phase spacing is 33 ft. on both arms.Vertical phase spacing is 32 feet.

10) Susquehanna Gen. i/2 I,eads 35 ft. Horizontal (flat)

8. Foundations

Stanton-Susquehanna /j2 500 kV Line

Susquehanna-Wescosville 500 kV Line

Susquehanna-Siegfried section

Siegfried-Wescosville 500 kV section

South Manheim 500 kV Connections

Sunbury-Susquehanna /32 500 kV Line

Alburtis-Wescosville 500 kV Line

General

The foundations for the above captioned lines are designed using alaterally loaded caisson design approach as developed by GAI Consultantsand Duquesne Light Company except the Siegfried-Wescosville 500 kVline which is designed using the non-specific classical method forsteel pole foundations. Table VI following this narrative givesspecific design criteria used on each line. The purpose of thisnarrative is to address, in general terms, the highlights of theevolution of the laterally loaded caisson design approach. For morespecific information you are directed to the appropriate DB and ERfiles. See the Bibliography for references.

Subsurface Related Information

o U liftResistance

The cone of soil approach to uplift resistance was replaced byskin friction/adhesion because outside testing informationreported the cone of soil to be applicable only for relativelyshallow foundations.

o Correlation of K as f (Eh)

Ba'sed on in-house testing it was determined that the Terzaghiequation:

K = E1. 35B

was not applicable and that the spring constant, K, was moreaccurately represented by the Yoshida-Yoshinaka equation:

K = 2.31E (B) 1/4 power3 (Bo)

37

o De th to first resistin medium

As experience with the laterally loaded design concept progressed,it was discovered that by selectively ignoring the parametersof some soil strata foundation depth could be optimized.

Desi n Load Related Information

o Base reactions

As more experience with and knowledge of the computer program,used for design, grew, the deviation of base reactions changed.Originally the ABAR value was assumed to be the distance betweenthe baseplate and the inflection point on the shaft. It wasdiscovered later that ABAR equals ground line MOMENT divided bymanufacturer's base reactions directly.

Factors of safety were applied in accordance with previouslyestablished transmission section policy. Manufacturer's basereactions were modified to account Xor the differences betweenthe overload capacity factors, (olcf), and the desired factorsof safety. Initially base reactions resulting from loadshaving an olcf of 1.25 were multiplied by .85 instead of .88 toarrive at a factor of safety of 1.1. Also at one time theuplift base reactions having an olcf of 1.25 were multiplied by1.25 instead of 1.2 to arrive at a factor of safety of 1.5.This explanation documents the reasons for the factor of safetydiscrepancy between some of the lines.

For the most recent lines designed the manufacturer's calculatedbase reactions were appropriately modified by equations internal'o

the computer program..

Reinforced Concrete Desi n Related Information

~Slinin

Reinforcing for initial lines was originally ordered for towerfoundations. This reinforcing was received prior to the decisionto use tubular steel H-frame and augered caisson construction.Due to this, these two lines have foundation reinforcing splicedto the required length supplemented with bar ordered in

30'engthsto make up the difference.

The only splicing used on the balance of the lines is thatrequired due to field revisions. All these splices meet theACI Code requirements.

o Flexural Reinforcin Desi n

Flexural reinforcing was consistently designed using the working

38

stress equation:

As = ZHf jd

For the Siegfried-Wescosville section all flexural reinforcingfor all diameters was designed using d = 48 which is onlyaccurate for 5'6" diameter foundation. This resulted in conserva-tism. Also, for foundations on this ER the standard reinforcingcage as called out on E-118150 was used if it satisfied theabove equation.

In general the balance of lines had flexural reinforcing customdesigned for the individual structure base reactions and wasconsistent with the ACI Code.

Flexural reinforcing in foundation pedestals was originallydesigned as a separate cage to be spliced to the verticalcaisson reinforcing. To optimize the installation, designprocedures were altered to treat the pedestal flexuralreinforcing as a direct extension of the vertical caissonreinforcing with no splic'es.

Shear Reinforcin Desi n

Generally the minimum shear reinforcing as specified by the ACICode was sufficient to carry shear loads.

Shear reinforcing was specifically checked and sized per theACI Code for Sunbury-Susquehanna and Alburtis-Wescosvillelines.

39

BIBLIOGRAPHY FOR REFERENCES

Bulk Power Civil/Structural Files for Pressurements testing results forthe following sites:

BossardsBeach HavenSouth Manheim ConnectionsSunbury - Susq. j/2 500 LineAlburtis-Wesc. 500 Line

ER File 121219 - Susq.-Stanton 500 Line

ER'File 121233 - Susq.-Siegfried 500 Line

ER File 121243 - South Manheim 500 kV Tap

ER File 122026 - Montour-Susq. 230 kV Relocation

ER File 121242 - Susq. Generator 81 Leads

ER File 121234 - Sunbury-Susq. 500 kV Line

ER File 121236 - Alburtis-Wescosville 500 kV Line

SAO File 907128 - Bossard's Foundation Testing

Reprint of "Soils and Foundations" Vol. 12, No.3 September 1972Issue - Japanese Society of Soil Mechanics and FoundationEngineering, by IWAO Yoshida and Ryunoshin Yoshinaka.

Report prepared by Sargent 6 Lundy for PPGL dated August, 1977"Transmission Pole Caisson Foundation Tests"

Report prepared by General Analytics Inc. dated March, 1972"Laterally Loaded Caisson Embedded in a Multi-I,ayered Elastic Media".

Report prepared by A.M.DiGioia, Jr., T.D.Donovan, and F.J.Cortest-February 1975, "A Multi-Layered/Pressuremeter Approach to LaterallyI,oaded Rigid Caisson Design"

Report prepared by GAI Consultants, Inc. for PPSL, dated February, 1978."Pressuremeter Testing and Geotechnical Design Parameter Correlations-Sunbury-Susquehanna 500 kV Line."

Report prepared by GAI Consultants, Inc. for PPSL, dated December, 1977."Design Approach for Laterally Loaded Drilled Piers".

40

0

o Bulk Power Civil/Structural Files for the following Design Books

DB 1121-DB 1118-DB 1123-DB 1124-DB 1122 "DB 1103-DB 1104 "

Stanton-Susq. /$2 500 kV - Foundation DesignSusq.-Siegfried 500 - Foundation DesignS. Manheim 500 kV Tap - Foundation DesignMontour-Susq.Relocation - Foundation DesignSusq. Generator Nl - Foundation DesignSunbury-Susq. /j2 500 kV - Foundation DesignAlburtis-Wesc. 500 kV - Foundation Design

ZNE NAtK ER 4

0o

MCCOgl

M

O

1 O&I R

g CO

.I ICQ Q

Ãg

5! 3

NmO

BO

RgWO

Qg&O

55

J

OgH

>usa. -Stanton 500,'R 121219

I

Centerhub

'. at Structure

'dns.Designed-1975-76 .'I

g.'

PPMiNo

I

t

N/A IUsed Used Used,

. Cone Coneof ofuplift uplift uplift

Ter zahi

:[email protected] 500Z 121233

:,, Centerhub

at structure'dns. designed-1977-78;

I

; PPM No'/orGAI

GAI ..75ksf.:;9ksf. 7.2ksf. Terzaghi

Yoshida

lunbury-Susg. 500,"R 121234

Centerhub

. at Structure'dns. designed - 1979 .

GAI Yes GAI '.4ksf. 0 75 7 2ksf YoshidaGAI-

BS8TI

esc. goolR 123236

'dns.designed-1979

- Centerhub

at Structure;~ - at leg in

limestone

PPM Yes. STS 'PP8cL 0.4ksf. '0 75ksf.

BSEcT

7 2ksf Yoshida

;. Manheim Sub Tap:R 323243

'dns. designed-1978

Representative'locations ga Wagondrill: m

PAL ,75ksf, 9ksf. 7.2ksf. Yoshida

BSM

.tont our-Susq,.leloc. ER 122026

'dns.Designed-lg77-78

Center hubat Structure

Yes'TS,PPM .4ksf .75ksf. 7.2ksf. T rzahiEe

BM:T

>usq,.Gen.gl Leads:R 321242

.Centerhub

'at Structure'dns.designed-1977-78

PPM'es STS PPM .4ksf ..75ksf. 7.2ksf Terzsghi

BSLT

'<e fried.-Wescosville Center hub Items of019 'at Structure

I

ot: For more information see Narrative Documentation, Bibliography~ an /o

I

II%5~oR4

o

55

g~RIBago

A5

CQ 1

~ 'I

DEVIATION OFBASE REACTIONS

FACTORS OF

SAFETY

Yes 3ff No Moment Mfgr's.ABAR

Gales.

.66 di.st. Mfgr's- No '.06 1.06 1.25 1.25 N/Abetwee:nbottomi Calcs ~

of I

. X-bracerobase l.ate

Yes 1" or0.25) 5guyed0.5tangent

Yes Mfgr's. Mfgr's. MomentShear

Calcs. Gales.

Mf&r s. Yes 1.06 1.06 1.06i.or or or 1.56 N/A

Calcs. 1.1 1.1 1.1

YesI

0.25 "g 5 Yesguyed. strs.0.5'angents

0.254

0.5'fgr's.Mfgr's, Moment

Shearcalcs. Calcs.

Mfgr 's. Mfgr 's.Moment'alcs.

Calcs. Shear

Mfgr 's. Yes 1.1 1.1 1.1 1.5 Yes

Calcs.

1.1Calcs.

.25'P aguyed

.~ 5tangent

Yes Mfgr's. Mfgr's. Moment Mfg Yes 1.06 1.06 1.06 1.56 N/ACalcs. Calcs. Shear Gales.

Yes 0 25 ~ Yes Mfgr '~ Mfgx'. Moment

Ca1cs. Calcs . Shear

Mfgr's.'es 1 1 3. 1 1 1 1-5 YesCa1cs.

Yes 0 25oMfgr 's. Mfgx's. Moment

Calcs. Calcs. Shear

Mfgr's. Yes 1.1 1.1 1.1 3..5 Yes

Calcs.

~ Not Performed - Classical Method Used

gnL Books. SUSQUEHANNA SESRELATED TRANSMISSION LINES

FOUNDATION DESIGN DO C~TATZPITABLE VI

DEVIATION OP

BASE REACTIONSFACTORS OF

SAFETY I

I I 5V Q

g

Moment Mfgr's ..66 di.st. Mfgr's ~ NoABAR betwee:n

Calcs. bottoms Calcs.of

... X-brac ega

base l.ate

'.06 1.06 1.25 l.25 N/AI

. As~0.0268M Not YesII Used

, Mfgr's. Mfgr's.

Calcs. Calcs.

Moment Mfgr 's Yes 1.06 1.06 1.06Shear I or ~ or or 1.56 H/A

Calcs. 1.1 1.1 1.1

Same asSunbury

I

Not 'esUsed per ACI

Code

Mfgr's. Mfgr's. MomentShear

calcs. Calcs.

Mfgr 's. Yes 1.1 1.1 1.1 l. 5 Yes

Calcs.

As~

5+5

As')As 6.

68M per ~ Oniy inACI 'ielf re-

22M Code visions18M per ACI

's. Mfgr's.Moment: Mg'.Ye 11 1.1 1.1 1.5 Y~ ~

Calcs. Calca. Shear Calcs.

M gr's. M gr's. Moment g'

Y 1.06 1.06 1.06 1.56 N/Gales. Calcs. Shear Calcs.

SameSunb

Same

Sunb

per 'nly inACI field re-Code visions

per ACI

Hot Only iny used, . field re

visionsper ACI

Mfgr 's. Mfgr 's. Moment

Calcs. Calcs. Shear

Mf I

Yes 1.1 1.1 1.1 1.5 YesCalcs.

Sameas

Sunbury

. Not,'esUsed 'evised

per ACI, I Code

Mfgr's. Mfgr's. Moment

Calcs. Calcs. Shear

Mfgr's Yes 1.1 1.1 l.l. 1.5 Yes

Calcs.

Same&s

I

Sunbury

Not - Yesrevised'er ACI

Code

ssi al Method Used

SUSQUEHANNA SESRELATED TRANSMISSION LINES

FOUNDATION DESIGN DPC~TATIONTABLE VI

A.W.MetrerJan.1980

9. Insulators and Hardware

Insulators

Standard ANSI approved 5-3/4 x 10" ball and socket type porcelainsuspension insulators are used on 500 kV steel pole construction.These insulators are used on 'V'trings, deadends, idler stringsand horizontal 'V'ssemblies. Classes of insulators used are:

ANSI Class M&E Ratin Proof Test Color

52-5

52-8

25,000 or 30,000 lbs. 12,500 or 15,000 lbs. Grey

36,000 or 40,000 lbs. 18,000 or 20,000 lbs. Royal Blue

The hardware connections for the two classes of insulators are notcompatible between insulators or hardware of different classes.Color coding also helps identify the insulator class and strength toprevent intermixing.

All 'V'tring leg, horizontal-'V'eg and vertical strings use 25insulators. All deadend assemblies use 27 insulators.

Insulator Hardware Assemblies

PPSL utilizes five different types of insulator assemblies for 500kV steel pole structures:

o Suspension, 'V'tring Assembly: These assemblies are used ontangent structures or very small (less than 5 ) angles. Thespecific assembly type is dictated by vertical and horizontalspans. Insulators in this category are Types A, B, C, C-l, D,D-l, AAA, BBB, CCC, and DDD.

Restrained Angle 'V'tring Assembly: These assemblies utilizethe 'V'tring shape and are used for angles up to 30 (0 to15 and 16 to 30 ). The line break angle and the vertical spandictate the strength of assembly to be used. The assemblies inthis category are Types F-outside, G-center, FFF and GGG.

Idler'ssembly: These assemblies are used to support loops ondeadend structures. A single string with a weight at theconductor attachment point is employed., These assemblies areTypes M and MMM.

Horizontal-'V'ssembly: These assemblies are used on tangentsand small angles (less than 10 ) to support conductors from a

single pole structure.

Deadend Assembly: Several deadend configurations are used forhigh or low tension, twin or triple bundles. Turnbuckles are

43

employed in each assembly coupled to each subconductor to allowfor variation in assembly length to match conductor sags in abundle. Compression fittings are used for deadends and terminallugs. Assemblies in this category are the Types Hl, HHH, JJJand KKK.

Application of each suspension and restrained angle assembly must bedetermined through checking the insulator grading chart as well aschecking buckling of the insulator

string.'nsulator

assembly hardware is purchased from several manufacturersin complete assembly units. Each assembly is made of ten or moresub-components. To achieve interchangeability of components, each"supplier is required to design their assembly based on the initialKeystone design. Except for a few minor exceptions, all items areinterchangeable between manufacturers. At most, two or three sub-components must be replaced at one time to achieve interchange-ability. The Transmission Construction Specifications providesdetails for the assemblies which note the items that can beinterchanged and which items must be replaced with one or two othersub-components at the same time.

~Sacess

Spacers are used to stablize the bundle of conductors. Under switchingconditions the sub-conductors will attract one another causingbundle collapse. To prevent collapse of the bundle, spacers are

.installed on specified intervals, ho greater than 250'n length,along the span. Twin conductor bundles are horizontally spaced at18". Either bolted clamps with closed spring spacers or preformedhelical rod spacers are employed. The triple bundle applicationutilizes a configuration of an equilateral triangle with 18" spacing,two conductors on the horizontal plane at the top with one sub-conductorsuspended below. The triple bundle application utilizes spacerdampers. These devices are intended to maintain the bundle spacingwhile reducing aeolian vibration and subspan oscillation.

D~ae ess

Dampers are employed on the static and twin bundle conductors.Their purpose is to reduce aeolian vibration levels. Several manu-facturers have been approved for supply of these dampers. Applicationof each manufacturer's damper is independent of another. This meansthat dampers are installed per each manufacturer's recommendation.The same span will require various quantities and different placementlocations of dampers dependent on the manufacturer of the damperbeing installed. Therefore, if two or more damper designs are usedon one line, the dampers will be installed in deadend span sections.This is necessary to meet the manufacturer's recommendation forinstallation as closely as possible.

44

Armorrods

Preformed armorrods are used at all suspension points on the staticand phase conductors. The armorrods are wrapped around the cable atthe suspension clamp posj.tion. The rods are intended to reduce wearon the conductors due to aeolian vibration at the conductor clamp.

45

10. Conductor and Overhead Ground Wire Data

In the application of steel pole structures for 500 kV lines, severalmodifications of the Keystone design for conductors and OHGW cableshave taken place. 500 kV construction is characterized by a bundleof conductors for each phase. This bundle arrangement provides fora larger effective Geometric Mean Radius (GMR) than can be obtainedby a single larger conductor. The large GMR reduces the surfacegradient along the phase wires which in turn reduces the audiblenoise, RIV, TVI and corona losses.

Lightning protection is achieved through the application of twoshield wires. All lines of 500 kV construction on the PPGI, systemutilize Alumoweld wire for the overhead ground wire. With theexception of the Beltzville Crossing of the Susquehanna-Wescosville500 kV line which utilizes 19 No. 5 Alumoweld, 19 No. 9 Alumoweld isused for the overhead ground wires. The appropriate electrical andmechanical characteristics of these cables are listed in Tables Xand XI.

In the case of the phase conductors, there are three differentconductors utilized in two configurations:

Twin bundle - 2493 kcmil 54/37 AGAR

Susquehanna-Stanton 500 kV lineSusquehanna-Wescosville 500 kV lineSusquehanna'enerator //2 500 kV leadsSunbury-Susquehanna //2 500 kV lineSouth Manheim 500 kV linesAlburtis-Wescosville 500 kV line (Single Circuit.H-frame Portion)

Twin bundle - 1970.7 kcmil 69/37 ACSR

Susquehanna-Wescosville 500 kV line (Beltzville Lake Crossing)

Triple bundle.-. 1590 kcmil 45/7 ACSR

Alburtis-Wescosville 500 kV line (Double Circuit and SingleCircuit -Single Shaft Portions)

The twin bundle 2493 kcmil 54/37 AGAR is the bundle configurationdeveloped by the Keystone Design Committee. For the long spanapplication at the Beltzville Crossing a higher strength conductorwas required.. The 1970.7 kcmil 69/37 ACSR is to provide the mechanicaland electrical properties required for this application. Two situationson the Alburtis-Wescosville 500 kV line necessitate the applicationof triple bundle conductors to achieve desirable audible noiselevels. First, in the double circuit application, depending on theline phasing, a wet conductor may cause audible noise levels higherthan levels which are desirable based on operating experience.Secondly, a portion of the line utilizes a 140'asement (200',isthe standard 500 kV easement). To achieve desirable AN levels onthis section of the line, a triple bundle conductor is required.

46

The accompanying Table VII, VIII, IX provide the parameters for eachconductor and overhead ground wire..

47

TABLE VII

CABLE DATA

CONDUCTOR - 2 493 MCM 54/37 ACAR

Nominal diameter, in.Weight per foot, lb

'rea,sq. in.Number of strands

EC aluminum6201 aluminum allow

EC strand diameter, in.EC strand area, sq. in.6201 strand diameter, in.6201 strand area, sq. in.

1.8212.341l.9589154370.16550.021510.16550.02151

Mechanical Data

Rated ultimate strength, lb.Modulus of elasticity, final psiModulus of elasticity, initial, psiCoefficient of linear expansion per degree FCreep constants

KM

N

EC strand wireTensile strength, minimum, psi

Individual testsAverage for lot

Minimum elongation, per cent in 10 in.6201 strand wire

Tensile strength, minimum psiStress at.l percent extension, minimum psiUltimate elongation, minimum percent in 10 in.

Electrical Data

63,0008)286)0006,500,0000.0000128

0.608 x 102.100.275

23,00024)0002.0

46,00044,1603.0

Circular milsCircular mils, 62/ equivalent ECEC strand wire, cm6201 strand wire, cmConductivity, percent IACS, minimum

EC aluminum6201 alloy

Temperature coefficient of resistance, perdeg. C at 20 C

EC aluminum6201 alloy

48

2,843,0002,345,00027,39027,390

6252.5

0.004010.00352

Electrical Data (Cont.)

Current carrying capacity, amperes, based on50 C rise over 25 C ambient with 2 fps crosswindInductive reactance, Xa, 60 cycles, ohms/mileCapacitive reactance, Xa', 60 cycles, megohmmile. 18 in spacingResistance

D-C ohms per mile at 20 C

A-C ohms per mileat 20 C

at 50 C

at 100 C

l)870

0.341930.0322

0.038259

0.04510.04900.0554

Conductor tensions are limited to the following range:I

20 percent of ultimate strength at bare cable, no wind, O~F,

final sag condition t

50 percent of ultimate strength with 1 in. ice and 8 lb. at 0 F

60 percent of ultimate strength at l~g in. radial ice, no wind,O~F, final sag condition

Reel Data

Overall diameter, in.Drum diameter, in.Inside width, in.Overall width, in.Hub

Diameter, in.Length inside, in.

Maximum cable length for full reel, ft.Weight, lb.

EmptyWith wrappingWith wrapping and laggingShipping, full reel

96426068.5

51~

346,665

1,6201,6752,22017,823

49

TABLE VIII

CABLE DATA

CONDUCTOR - 1 970.7 kcmil 69/37 ACSR

Nominal diameter, in.Weight per foot, lbArea, sq. in.Number of strands

EC aluminumSteel

EC strand diameter, in.EC strand area, sq. in.Steel strand diameter, in.Steel strand area, sq. in.

1.8023.1281.57710669370.1690

'.1127

Mechanical Data

Rated ultimate strength, lb.Modulus of elasticity, final psiModulus of elasticity, initial, psiCoefficient of linear expansion per degree FCreep constants

KM

N

EC strand wireTensile strength, minimum, psi

Individual testsAverage for lot

Minimum elongation, per cent in 10 in.Steel strand wire

Tensile strength, minimum psiStress at 1 percent extension, minimum psiUltimate elongation, minimum percent in 10 in.

102,600

23,00024,0002.0

46700044,1603.0

-Electrical Data

Circular milsCircular mils, 62/ equivalent EC

EC strand wire, cmSteel strand wire, cmConductivity, percent IACS, minimum

EC aluminumSteel

Temperature coefficient of resistance, perdeg. C at 20 C

EC aluminumSteel

2,843,0002,345,00027,39027,390

618

50


Inductive reactance, Xa, 60 cycles, ohms/mileCapacitive reactance, Xa', 60 cycles, megohmmile. 18 in spacingResistance


A-C ohms per mileat25 C

at 50 C

at 100 C

0.33640.0768

0.0464

0.04910.05350.0623

Conductor tensions are limited to the following range:

Reel Data

20 percent of ultimate strength at bare cable, no wind, O~F,final sag condition

50 percent of ultimate strength with 1 in. ice and 8 lb. at O~F

60 percent of ultimate strength at l~< in. radial ice, no wind,O~F, final sag condition


Diameter, in.I.ength inside, in.



96426068.5

5g3'4

1,6201,6752,220

51

TABLE IX

CABLE DATA

CONDUCTOR - 1590 kcmil 45/7 ACSR

Ph sical Data

Nominal diameter, in.Weight per foot, lbArea, sq. in.Number of strands

EC aluminumSteel

EC strand diameter, in.EC strand area, sq. in.Steel strand diameter, in.Steel strand area, sq. in.

1.5041.7921.335524570.18800.02780.12530.0123

Mechanical Data

Rated ultimate strength, lb.Modulus of elasticity, final psiModulus of elasticity, initial, psiCoefficient of linear expansion per degree FEC strand wire

Tensile strength, minimum, psiIndividual tests-Average for lot

Minimum elongation, per cent in 10 in.Steel strand wire

Tensile strength, minimum psiStress at 1 percent extension; minimum psiUltimate elongation, minimum percent in 10 in.

42,20011,223,690

0.0000128

23,00024,0002.0

190,000160,0005.0

,Electrical Data

Circular milsCircular mils, 62/ equivalent ECEC strand wire, cmSteel strand wire, cmConductivity, percent IACS, minimum

EC aluminumTemperature coefficient of resistance, perdeg. C at 20 C

EC aluminumCurrent carrying capacity, amperes, basedon 40 C rise over 40 C ambient with 2 fpscross wind and emissivity'actor of 0,5without sun

1,699,722

35,34315j700

61

0.004031,335

52


Inductive reactance, Xa, 60 cycles, ohms/mileCapacitive reactance, Xa, 60 cycles, megohmmile. 18 in spacingResistance


A-C ohms per mileat20Cat 50 C

at 75 C

0.3640.0822

0.05755

0.06230.06780.0734

Conductor tensions are limited to the following range:

20 percent of ultimate strength at bare cable, no wind, 0 F,final sag condition


60 percent of ultimate strength at 15 in. radial ice, no wind,0 F, final sag condition

Reel Data


Diameter, in.I.ength inside, in.



96426068 '

5<3g6,665

1,6201,6752,22014,163

53

TABLE X

CABLE DATA

OVERHEAD GROUND WIRE " 19 NO. 9 ALUMOWELD

Ph sical Data

Nominal diameter, in.Weight per foot, lbArea, in sq. in.Number of strandsStrand diameter, in.Strand area, sq. in.

.572

.5658

.1954190.11440.01028

Mechanical Data

Rated ultimate strength, lb.Modulus of elasticity, final, psiModulus of elasticity, initial, psiCoefficient of linear expansion per degree F

Electrical Data

34,29023,000,00020,500,0000.0000072

Circular milsResistance

ra, d-c at 20 C, ohms per milera, 60 cycles, a-c at 20 C, ohms per mile

Inductive reactance, Xa, 60 cycles, a-cat 1 ft. spacing, ohms per mileShunt capacitive reactance, x'a, 60 cycles a-cat 1 ft. spacing, megohms per mile

248,800

1.0981.1200.701

0.1109

Ground wire tensions are limited to the following range:

20 percent of ultimate strength at bare cable, no wind, O~F,

final sag condition

Reel Data


60 percent of ultimate strength at 1$ in. radial ice, no wind,0 F, final sag condition

Nominal length of strand, ft.Net weight of strand, lb

6,7003>791

54

Reel Data (Cont.)

Weight of reel and lagging, lbTotal shipping weight, lbDiameter of head, in.,Diameter of drum, in.Traverse width, in.Overall width, in.Arbor hole diameter, in.

5204,311563639-5/16443

55

TABLE XI

CABLE DATA

OVERHEAD GROUND WIRE - 19 NO. 5 ALUMOWELD

Ph sical Data

Nominal diameter, in.Weight per foot, lbArea, in sq. in.Number of strandsStrand diameter, in.Strand area, sq. in.

0. 9101.4300.4940190.18190.02600

Mechanical Data

Rated ultimate strength, lb.Modulus of elasticity, final, psiModulus of elasticity, initial, psiCoefficient of linear expansion per degree F

Electrical Data

73,35023,000,00020,500,0000.0000072

Circular milsResistance

ra, d-c at 20 C, ohms per milera, 60 cycles, a-c at 25 C, ohms per mile

Inductive reactance, Xa, 60 cycles, a-cat 1 ft. spacing, ohms per mileShunt capacitive reactance, x'a, 60 cycles a-cat 1 ft. spacing, megohms per mile

Desi n Data

628,.900

0.43420.45070.645

0.0971

Ground wire tensions are limited to the following range:

20 percent of ultimate strength at bare cable, no wind, O~F,final sag condition


60 percent of ultimate strength at lg in. radial ice, no wind,O~F, final sag condition

Reel Data

Nominal length of strand, ft.Net weight of strand, lbWeight of reel and lagging, lb

6,7009,580520

56

Reel Data (Cont.)

Total shipping weight, lbDiameter of head, in.Diameter of drum, in.Traverse width, in.Overall width, in.Arbor hole diameter, in.

10,100563639-5/16443

57

ll. Counter oise 8 Groundin

A two step grounding and counterpoise system is applied to reduce,ground resistance to approximately 25 ohms.

Prior to 1977 the steps consisted of:

l. Installation of a driven ground rod at the bottom or side ofeach structure foundation. Each ground rod is connected to thesteel tower leg or pole. The resistance of the foundation withall piers interconnected is measured.

2. If the resistance of the foundation is greater than 25 ohms, acouterpoise, 500 feet in length (250 feet on each side of thestructure) is buried along the line.

In 1977, the method of grounding the tower leg was changed to includethe foundation concrete. The steps are as follows:

l. All metal components in the concrete, the anchor bolts andreinforcing cage, are bounded together and leads connected tothe steel tower or pole outside the concrete. The resistanceof the foundation with all piers interconnected is measured.

2. If the resistance of the foundation is greater than 25 ohms,counterpoise up to a total of 500 feet (250 feet on each sideof structure) is installed.

Lengths greater than this do not have an advantage in determiningthe lightning outage rate. If an isolated high resistance is encountered,there is no need to reduce'he resistance, other than installing theinitial counterpoise. The increased outage rate of this high resistancestructure has a small effect on the entire line outage rate,

If there is a large group of structures with high resistances, theremay be an effect on the outage rate and this should be investigated.An increase in the number of insulators may be more economical thanadditional grounding.

Grounding and bonding wires are 3/8 inch high strength galvanizedsteel. The buried counterpoise is installed at a depth of 18" inuncultivated areas and 24" in cultivated areas. The counterpoiseavoids roadways and underground facilities such as electric conduitsand cables, telephone lines, sewers, water lines, storm drains, andgas and oil pipelines.

58

12. Electric 6 Ma netic Field Effects

The electric and magnetic field effects of 500 kV lines are shown inTable XII.

PPM. has operated 95 miles of single circuit 500 kV line since 1966.A portion of this mileage consists of two single circuit lines on150 foot center lines. These circuits result in the maximum exposureto electric and magnetic field effects experienced by PPSL Company.

Hagnetic Flux Density 0.96 gaussElectric Field Gradient 9.9 kV per meterVet Conductor Audible Noise 55.0 dbaHeavy Rain Radio Interference 77.9 db

Experience since 1966 has resulted in few complaints. All but oneconsisting of complaints of spark discharges from ungrounded objects.Grounding these objects eliminated the complaints. The remainingone was a listener in a remote fringe area with poor radio receptionfor one station during early morning and late afternoon hours. Theradio station changed its antenna pattern during these hours and asa result the signal was not as strong as during the remaining 'hoursof the day. The transmission line did reduce the reception fromClass B to Class C standards.

The steel pole transmission lines have field effects of equal magnitudeto those experienced with the exception of the double circuit structuresand the single circuit single poles. These structures have audiblenoise levels of approximately 60 dba when a two conductor bundle isused. To alleviate this condition, a three conductor bundle hasbeen selected for the single pole structure and for double circuitstructures when they are used in urban areas and areas where potentialfor development exists.

The phasing that gives the'lowest electric field gradient for thedouble circuit structures shall be selected so as not to exceed llkV per meter.

Phasing arrangements must be checked when using these configurationon multicircuit right-of-ways. A rule of thumb is not to have likephases opposite each other.

All fences and other metallic structures on the right-of-way will begrounded in accordance with existing en'gineering standards.

Should a radio and television reception problem be evident, it willbe investigated and corrected if it is definitely shown to be causedby the transmission line.

RJG:pd/47P-A

59

TABLE XII

500 KV TRANSMISSIONELECTRIC AND MACNLTIC~ FIELD EFFECTS

Operating voltage 525 kVPhase current 4600 amperes2-2493 kcmil AGAR conductors per phase except + is 3-1590 kcmil ACSR conductors per phase.

Line Description

Tower Line

GroundClearance

Feet

Magnetic flux densitygauss

Le t R W Right R W

Edge Edge

Electric Field GradientKv/m

Wet ConductorAN - dBA

MaxLeft R W

EdgeRight R W Left R W Right R W

Edge Edge EdgeLeft R/W

EdgeRight R/W

Edge

Heavy RainRI-dB

Single circuit

Single circuit (keystone)

Double circuit

h hC B 8 C

h hC BA C

Single Pole Line *

Single circuit

Single circuit "H"

Heavy Rain is at 1000 kHa

33

31

33

33

30

30

0.93

1.00

0. 85

Q. 56

Q. 69

1.01

0. 19

0.19

0. 20

0. 13

0. 17

0.19

0.19

0. 19

0.20

0. 13

0. 19

0. 19

9.0

9.8

10.8

6 ~ 9

'.8

9.8

l.'63

1. 56

1.39

1.23

2. 30

1. 56

1.63

l. 56

1.39

l. 23

1.88

l. 56

53.2

53.8

58. 2

61.0

45 ~ 2

53. 7

53.2

53.8

58.2

61 '

46. 6

53. 7

73.0

74.0

78. 4

.80. 2

64.8

74.0

73.0

74.0

78.4

80.2

67.1

74.0

Sheet 1 of 4

I s

~ ~ ~'

~ ~

I ': ~ ~

I ~ a

I ~ ~

TABLE XII

500 KV TRANSMISSIONELECTRIC AND NAGNETIC FIELD EFFECTS

Operating voltage 525 kVPhase current 4600 amperes2-2493 kcmil ACAR conductors per phase except * is 3-1590 kcmil ACSR conductors per phase.

Line Description

Multi line R/W's

2 single circuit

Tower Lines

GroundClearance

Feet

31

Left R/WEdge

Right R W

Edge

Magnetic flux densityauss

HaxLeft R W Right R W

Edge Edge


Left R W

EdgeRight R M

Edge

Met ConductorAN dBA

Heavy RainRI — dB

Left R/W Right R/MEdge Edge

150'etween

ABC ABC

ABC CAB

125'etween

ABC ABC

ABC CAB

100'etween (ABC ABC

ABC CAB

0.96 0.22

1.02 0.18

0.96 0. 23

1.02 0.18

0. 96 0. 24

1.03 0.18

0. 22

0.18

0. 23

0. 18

0. 24

0. 18

9.9

10. 3

9.9

12.4

10. 0

14 ~ 5

1. 63

l.58

1. 65

1.58

l. 66

1. 60

1. 63

1.58

1. 65

1.58

l.66

1. 60

55. 0

54.5

55.6

54. 7

57. 7

55. 1

55. 0

54.5

55.6

54.7

57.7

55.1

77. 9

77.8

78. 1

77.9

79.2

78.1

77.9

77.8

78.1

77.9

79.2

78.1

Heavy Rain is at 1000 kHz

Sheet 3 of 4

TABLE XII

500 KV TRANSMISSIONELECTRIC AND HAGNETIC FIELD EFFECTS

Operating voltage 525 kVPhase current 4600 amperes2-2493 kcmil ACAR conductors per phase except * is 3-1590 kcmil ACSR conductors per phase.

Line Description

Hulti line R/M's125'etween

GroundClearance

Feet

Magnetic flux densitygauss

Le t R W Right R W

Edge Edge


Wet ConductorAN —d BA

Left R W

EdgeRight R M Left R/M Right R/W

Edge Edge . EdgeLeft R/W

EdgeRight R/W

Edge

Heavy RainRI -dB

Left line - single H

Right line - double H

C BABC A 8 'A C

40

0.64 0.15 0.20 8.0 1. 68 2.44 59.3 62.0 79.6 85.0

A BB C A C

B 8C A A C

A B

C B A C

0.65

0.73

0.66

0.14

0.12

0.13

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Lake Crossin

General Location

The line crosses the Beltzville I,ake approximately 2.7 miles east ofthe Beltzville Dam; the lake is approximately 1500 ft wide at thecrossing. (shoreline to shoreline).

1

Beltzville Lake is northeast of the Pennsylvania Turn'pike and Route209 intersection in Towamensing and Franklin Townships, southeastquadrant of Carbon County, eastern Pennsylvania. I,ocation on PohopocoCreek about 4.5 miles above its confluence with the Lehigh River.At normal conservation pool level, the lake covers over 947 acres.Recreational boating of all types is afforded by the reservoir inaddition to the water supply and flood control aspects of thefacility.In relation to Susquehanna Station and Siegfried Substation, BeltzvilleLake is approximately 35 miles southeast and ll miles north, respectively.

4

L~andsca e

The topography of the land transversed by the line is illustrated on

No. 5 J~ul 1976 (Amendment No. 5 in future references). Specifically,two miles north of the crossing the elevation approaches 1500 ft.above sea level then gradually slopes downward to approximately 800ft. one-half mile from the center of the lake at the crossing whichis 651 feet at "top of flood control pool elevation". The southernapproach to the crossing i's exactly the same as the north. "'efer todrawing LE-83849 Sheets 6 and 7 for plan and profile of this linesection.

lian-made features in the area consist of the East Palmerton-Wagners66 kV line (see E-155884 Sheet 2 for reconstruction) built in the1950's. The 500 kV centerline is 150 ft. west of the reconstructedEast Palmerton-Wagners 138 kV centerline. In addition, two pipelines(Mobil Oil and Buckeye Co.) are located within a 1500 ft. distanceeast of the 138 kV centerline.

The area is, mainly a forested, rural environment with land usedictated by Department of Environmental Resources for a State Park.

Transmission Line

The standard 500 kV line built by Pennsylvania Power and LightCompany is a Steel Tower or Steel Pole Structure equipped with 2static wires: 19 No. 9 AWG Alumoweld conductor, and 2-bundled Powerconductors per phase: 2493 kcmil AGAR 54/37 conductor. For furtherdetails see previous sections of this report under conductor dataand structure sections.

64

The line route was selected to minimize costs and environmentalimpacts. In environmentally sensitive areas, such as BeltzvilleState Park, appropriate engineering and construction techniques wereused. Amendment 5 in Parts V and Vl discusses the route impacts.

The PPM Standard 500 kV design was used on the 54 mile Susquehanna-Siegfried line except for the three-span (4930 ft.) section for theBeltzville crossing.

The change in design across Beltzville Lake was required, becausethe terrain adjacent to the Lake is not elevated and the long spanwould have needed structures higher then 200 feet to maintain NESCclearances.

The "Top of Flood Control Pool Elevation" of the lake is 651 ft.according to the Army Corps of Engineer's specification ER1110-2-4401Section 4. The power conductor for the 500 kV line must be 58 ft.above the 651 ft. elevation at maximum final sag.

To achieve the necessary clearances using 2493 kcmil AGAR 54/37would require a structure exceeding 250 ft. and 240 ft. on the southand north side of the I,ake, respectively. This would requirelighting and/or special painting of the structures resulting inincreased environmental impacts.- Therefore, a special conductor was,used to permit the use of structures less than 200 ft. high in orderto eliminate structure treatment and minimize environmental impacts.The basic design requirements were. submitted to approved suppliersfor bids:

o 3,470 amps. per phase at maximum thermal loading condition of100 C for ACAR, 125 C for ACSR, or 200 C for SSAC conductor at35DC, zero'nots wind ambient conditions. The loading is thesummer normal rating based on the PJM conductor rating method(see attached IEEE conference paper No. 74-003-0). The currentshall be considered equally divided between the subconductorsin the conductor bundle.

o The conductor may be composed of two or three subconductors.The minimum conductor dia. shall be 1.8" for two subconductorand .7" for three subconductor bundles.

The maximum subconductor tension shall not exceed 60$ of theultimate strength at 1.5" ice, zero degrees F, and zero poundswind loading condition.

o The maximum conductor sag shall not exceed 135'n the2,620'rossingspan under the above requirements.

Bids received were for the following conductor types:

o 2 subconductors of 1970 kcmil 69/37 ACSR

65

o 2 subconductors of 2505 kcmil 84/19 AACSR

o 2 subconductors of 2250 kcmil 84/19 AACSR

o 3 subconductors of 875.1 kcmil 54/37, ACSR

o 3 subconductors of 1138 kcmil 36/37 ACSR

Since all of the conductors listed fulfilled the specifications,other factors determined the preferred conductor type to use:

I

o 3 subconductors type involved greater weight 8 visual impact.

o 2 subconductors 2505 kcmil 84/19 AACSR and 2250 kcmil AACSRwere eliminated due to manufacturing difficulty, and handlingability during construction.

Additional comments and bid prices are available in the Bulk PowerDepartment's confidential files Purchase Recommendation EE-4930(Sept. 7, 1977).

The conductor selected for the Crossing was 1970 kcmil (69/37) ACSR.At the time of the conductor purchase, a 'spare phase of 2 subconductorsof 1970 kcmil (69/37) ACSR was acquired to be used in the event of aphase wire failure on the Beltzville Crossing. A sufficient lengthwas provided to guarantee that it could also be used on the 3 MileIsland-Peach Bottom 500 kV Line river crossing for a phase wirefailure, since this conductor is similar to the 2505 kcmil 84/19AACSR used on the river crossing.

Engineering data for the 1970 kcmil 69/37 ACSR can be found in theconductor data section of this report.

Spacers and dampers were provided by the conductor manufactureralong with engineering to determine their location. Aircraft markerspheres were installed on the OHGW's according to the Federal AviationAdministrations guidelines. Design locations for spacers and markerspheres are shown on Plan and Profile print LE-83849 Sheet 6 and 7

and Damper locations are on print A-176042 (1970 kcmil 69/37 ACSR)and A-176043 (19 No. 5 AWG Alumoweld).

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Copies to:W.F. HechtW. BarberichH.R. ClarkeT.M. Crimmins,W;G; GfbbardE.J. GoodwinE.A. GuroC.R. HornH.W. KeiserS.B. KuhnD.J. MorganH.V. Oheim

N-2N-4.N-5N-5N-5N-2N-2BN-2BSSESN-5N-5N-5

SUSQUEHANNA STEAM ELECTRIC STATIONSTATION BLACKOUT ANALYSISRE: YOURS OF FEBRUARY 12, 1982

This letter presents an evaluation of the frequency of loss of off-sitepower at Susquehanna and is a complete xesponse to your letter and to theadditional points of interest raised at our March 30, 1982 meeting andsubsequent discussions. In order to clearly and adequately address thefrequency of loss of off-site power issue for Susquehanna, our response is.provided in report format.

DESCRIPTION OF OFF-SITE POWER SYSTEM

A detailed desex'iption of the Susquehanna off-site power system and itsconnections to the PL transmission system is presented in the attachedcopy of Section 8.2.1 of the Susquehanna FSAR (See Appendix 1). In brief,off-site power at Susquehanna is provided by Startup Transformers I/10 and820 and their transmission connections to the bulk power system. Thetx'ansformers are physically and electrically remote from each other andeach one is connected to a 230 kV transmission line. The transmissionlines which supply Transformers //10 and i/20 occupy separate corridors anddo not terminate in the same switching station. With all facilitiesinitially in service, the total loss of any one of the four switchingstations, which terminate the two transmission lines from which Transfor-mers 810 and 820 are tapped, will not result in the loss of both StartupTransformers. If terminal problems occur on one of the txansmission linessupplying a Startup Transformer, the problem can be isolated, in mostcases automatically, by opening the breaker(s) at that terminal. Thiswould permit the Startup Transformer to remain in service via supply fromthe remaining terminal.

page 2

DEFINITION OF LOSS OF OFF-SITE POWER

of off-site power (LOOP) is def ined, for the purpose of this analy-as the simultaneous loss or unavailability of power supply to Startupsis, as

Transformers «10 and «20. Therefore, the determination of frequency ofLOOP takes into account the availability of the transmission system which

lies Transformers «10 and «20 and the availability of the transformersthemselves. This analysis does not take into account plant inducedoutages of the 13.8 kv and 4.16 kv startup busses which could result inisolating the plant from the off-site power system."

FRE UENCY OF LOOP AND ANTICIPATED RESTORATION TIME

The total frequency of LOOP at Susquehanna is conservatively estimated tobe .049 occurrences per year. The components of the total frequency ofLOOP include: LOOP due to independent outage events (.009/year) and LOOP

to common mode outage events ( ~ 04/year). The frequency of LOOP valueis dominated by common mode outage events (disasters and system blackout).

I

The time required to restore off-site power after LOOP is„ dependent on theextent of damage, if any, to the electric supply system caused by the LOOPinitiator event. In most cases, off-site power is expected to be restoredwithin 6 hours of LOOP. If there is no damage to system facilities,off-site power can be restored, within several minutes by automatic orsupervisory switching operations. On the other hand, if there is exten-sive damage to the off-site power system, the restoration time would bemany days.

DETERMINATION OF FRE UENCY OF LOOP

The determination of frequency of LOOP includes both the "sustained" and"transient" occurrences of LOOP expected on. the PL system. Transientoccurrences of LOOP are less than 3 minutes duration. The componentsconsidered in determining the frequency of LOOP at Susquehanna include:

Simultaneous forced outage of both 230 kV sources to the off-sitepower system due to independent events.

Forced (independent) outage of one 230 kV source while the othersource is scheduled out for maintenance.

Natural and man-made disasters — unusually severe weather events,earthquake, airplane crash, sabotage and war.

System blackout (widespread or local).Simultaneous forced outage of both 230 kV sources to the off-sitepower system due to dependent events (neither blackout nor disasterrelated).

Page 3

~ .

Since the 230 kV transmission lines supplying the off-site power system donot share the same switchyard sources and are on separate corridors, thenon-blackout non-disaster related dependent outage consideration wasassumed to be negligible. The frequency of LOOP'due to independent eventswas calculated using historical data for the PL system. An estimate" ofthe frequency of LOOP due to common mode;outage events (disasters andblackouts) was derived from an analysis of weather data and PL historicaloutage data. A detailed discussion of the determination of frequency ofLOOP caused by independent events and by common mod'e outage events ispresented below.

LOOP CAUSED BY INDEPENDENT EVENTS

The calculation of the annual frequency, of LOOP .caused by independentevents is based on the simultaneous and independent forced outage of both230 kV sources to the off-site power system,due to independent events, andthe independent forced outage of one 230 kV source while the other sourceis scheduled out for maintenance. The forced and scheduled outage hoursused in the calculation are based on PL historical outage data (1975-1981).It is important to note that these data do not'.reflect the urgency asso-ciated with restoring an outaged off-site source at Susquehanna. Sincethe frequency of LOOP is a function of the restoration time (see Appendix2), the calculated value for frequency of LOOP using historical data willtend to be conservative.

Based on PL historical outage data, the calculated value for frequency ofsustained LOOP caused by independent events is approximately .003 occur-rences per year. The calculation technique is presented in Appendix 2.This value corresponds to outage durations lasting longer than 3 minutes.It is generally expected that, on the bulk power system, a transient linefault will have been cleared and the outaged line restored to servicewithin 3 minutes by automatic reclosures. In general, a sustained outageis one which cannot be restored within this approximate 3 minute interval.Based on PL historical outage data, the frequency of LOOP due to transientinterruptions — less than 3 minutes duration — is approximately .006occurrences per year.

The curve shown in Appendix 3 illustrates the "annual frequency of LOOP >

T hours duration" as a function of "T hours duration". This curve, forindependent events only, was developed using available PL historicaloutage data. The 6-hour point highlighted on the curve is the averagetime to restore one of the off-site power sources in the event thatconstruction personnel are required to isolate a faulted section of one ofthe 230 kV lines which supplies Transformer 810 or Transformer /120.

LOOP CAUSED BY COMMON MODE OUTAGE EVENTS

eSince the 230 kV transmission lines supplying the off-site power system donot share the same switchyard sources and are situated on separate

page 4

corridors, the common mode outage events which could reasonably cause LOOP

are disasters (natural or man-made) and blackouts (widespread or local).Previous occurrences of disasters and blackout were reviewed and thelikelihood of such occurrences in the Susquehanna electrical area wasestimated.

The disaster component of common mode outages — earthquake, airplanecrash, sabotage, war, hurricane, tornado, flood, unusual hail,. ice or windstorms —is dominated by unusually severe weather events. There havebeen several instances of multiple 230 kV line outages caused by unusuallysevere weather events. In March 1958, a severe snow storm occurred in theLancaster Region and caused the collapse of two transmission structures-one on each of two adjacent 230 kV lines (Manor-Westport and Manor-River-side). One of the two circuits 'was restored in 4 hours by making tempo-rary connections between the usable portions of both circuits. In June1972, the rains associated with Hurricane Agnes caused severe flooding inthe Susquehanna River basin. The flooding resulted in the loss of bothgenerating units at the former Stanton generating plant, the loss of thethree, generating units at Brunner Island, the loss of the Brunner Island230 kV switchyard and the seven 230 kV lines terminated there. In January1978, unseasonably warm weather and persistent rain resulted in an ice jamand severe flooding at Safe Harbor Hydroelectric Station on the Susque-hanna River. The ice jam destroyed a double circuit 230 kV river crossingstructure located on an island near the down-river side of the dam. Forpostulated disaster scenarios similar to the 1972 flood and the 1978 icejam, there would not be a LOOP concern at Susquehanna. The loss of anyone of the source switchyards or the loss of any section of 230 kV linewould not result in LOOP.

The development of a multi-interconnected bulk electric supply systembegan after World War II. Therefore, there are less than 40 years ofhistory upon which to base a prediction of the impact of adverse weatheron the continuity of bulk electric supply. Weather records, however, dateback more than 100 years. Based on climatological data from the WilkesBarre-Scranton airport located approximately.30 miles north-northeast ofthe Susquehanna plant, there have been several severe storms worthy ofnote. The blizzard of 1888 began on March 11 as rain with winds up to 65miles per hour, changed to snow and resulted in 15 inches of accumulationwith 15 to 20 foot drifts. Although the incidence of tornados is verylow, two tornados did occur, August 1890 and August 1914, causing severaldeaths in the Wilkes-Barre area. In November, 1969, a freak storm charac-terized by heavy wet snow, severe icing and gusty winds caused extensivedamage to 69 kV and 12 kV electric supply facilities in the PL PoconoRegion. Hurricane Agnes (1972), previously mentioned, was the worstnatural disaster in the history of Pennsylvania causing record floodingand several deaths.

In order to minimize the impact of severe weather on the reliability ofthe electric supply system, all PL transmission lines are designed to

Page 5

conform with or exceed the rules set forth in the National ElectricalSafety Code (NESC). This conformance applies to mechanical strength aswell as electrical clearance. For the specific case of mechanicalstrength, 'all 230 kV lines in the vicinity of the Susquehanna plant aredesigned for 1 inch ice loading with an applied 8 pound per square footwind. The NESC specifies a 1/2 inch ice loading with an applied 4 poundper square" foot wind design requirement. In addition to complying withthe NESC, PL transmission design also provides for adequate lightningprotection, adequate clearance over flood levels (as designated by theArmy Corps of Engineers), and minimal environmental impact.

Extensive disruptions to the bulk power system resulting in LOOP can be,caused by the unpredictable but real occurrence of major floods, hurri-canes, tornados, unusually severe ice storms and by possible occurrencesof earthquakes, sabotage, airplane crashes, and war. The occurrence ofLOOP due to earthquakes, sabotage, airplane crashes, and war is expectedto be considerably less frequent than LOOP due to severe weather. Withregard to airplane crashes, a review of the Federal Vortac map indicatesthat, as of January 1, 1982, there are no major scheduled airline flightswithin 8 miles of the Susquehanna plant. Considering all of the possibleinstances of unusually severe weather and other disasters, loss of off-site power at Susquehanna due to disasters is conservatively estimated tooccur once every 50 years (.02 occurrences per year).

The blackout component of common mode outages is not readily predictablefrom historical data. There has been only one incident of a blackout onthe PL system. The incident occurred on June 5, 1967 and resulted in ablackout of the eastern portion of the PJM Interconnection. Since thereis only one recorded occurrence in 36 years of post-war history, it isimpossible to statistically predict the frequency of occurrence of ablackout. For the purpose of this analysis, a blackout can be either awidespread condition such as occurred in 1967, or a localized electricaldisruption affecting only a relatively small part of the bulk powersystem. A turbine-geperator trip which results in LOOP would be con-sidered a localized blackout occurrence. In order for the sudden genera-tion loss resulting from a turbine-generator trip to cause LOOP, the,transient stability limit of the local grid would have to be exceededcausing all four 230 kV switchyard .sources supplying. the offsite system tobe outaged.

Based on the PJM blackout experience and blackout experiences of otherutilities, a greater understanding of the causes of blackout has resultedin subsequent improvements in equipment design, systems engineering andoperator training. In addition, procedures and guidelines have beendeveloped to unload and unstress the electric supply system in order tominimize the exposure to widespread outages, cascading, and blackout.LOOP due to either a widespread or a local blackout is conservativelyestimated to occur once every 50 years (.02 occurrences per year).

Page 6

The estimated value, therefore, for frequency of LOOP due to disasters andblackouts is .04 occurrences per year.

RESTORATION OF OFF-SITE POWER AFTER LOOP

The time to restore off-site power after LOOP is dependent on the extentof damage, if any, to the electric supply system. In most cases, off-sitepower can be restored in less than one day if there is .only minor damageto the system. Obviously, if one postulates the simultaneous and catas-trophic physical failure of both Transformers //10 and //20 or of the 230 kVlines supplying them, the restoration time for an off-site source would beon the order of many days. The restoration time would be a function ofthe status of the remainder of the electric supply system, the availabi-lity of spare equipment, and weather conditions.

For a more reasonable LOOP scenario, without catastrophic failures ofmultiple components of bulk power related facilities, it is;. expected thatone of the off-site sources can be restored either within a few minutes byperforming remote switching operations or within 6 hours by isolating afaulted section of transmission line. ,The specific work involved inisolating a faulted section of line involves the removal of bolted jumperloop connections on the 230 kV transmission structure at or near the pointwhere the 230 kV tap line supplying the Startup Transformer is connectedto the grid. By removing the appropriate loops at the tap point, thefaulted section of line is isolated and the affected Startup Transformercan be re-energized from the remaining 230 kV source switchyard.

After a blackout, the restoration of the electric supply system followsestablished PJM restoration procedures. Following an event which causes ablackout, less than 1 hour would be required to determine the extent ofthe blackout and initiate the restoration procedure. A 230 kV supply linewould be provided at Susquehanna from Yards Creek Pumped Storage Hydro-electric Station in New Jersey. It is expected that an energized 230 kVcircuit, capable of providing off-site power at Susquehanna, would beavailable within 2 hours after a blackout.

By: G. Lac o

GL:mgLA-23

Attachments

SSES-PShR

APPENDIX 1

~S1 DRSCRTPTTQQ

2 1 'I ~TDaa eiSsion~sstee

The bulk500 KVsuppliesand Unitseparateplant issystem.

pover transmission system of PPGL operates at 230 KV andUnit 41 of the Susquehanna Steam El.ectric Stationpover to the 230 KV system through a 230 KV svitchyardS2 supplies pover to the 500 KV system through a500 KV svitchyard. The offsite pover system for thesupplied throuqh the 230 KV portion of the bulk 'pover

t

'Figure 8.2-1 shows the Susquehanna 230 KV and 500 KV svitchyardsand the transmission lines associated with each yard and in thevicinity of the plant. The fiqure shows the line arrangement'ith both units in operation. The two svitchyards are physicallyseparate and are tied toqether by a 230 KV yard tie line with a230-500 KV transformer in the 500 KV yard.

Tvo independent offsite pover sources.are supplied to theSusquehanna plant. One source is established by tapping the

~ ~ Montour-Mountain 230 KV line north of the plant and constructing~ 1300 ft. of 230 KV line on painted steel pole structures 'tostartup transformer 410. The Montour-Mountain line shares doublecircuit steel pole structures vith the Stanton-Susquehanna 42 230KV line in the vicinity of the plant. The double circuit lineextends to a point 1.5 miles east of the transformer 010 tap atwhich point the tvo circuits split as shown in Piqure 8.2-1. TheMontour-.Mountain line extends 16.8 miles north on douhle circuitlattice towers vith the Stanton-Susquehanna 41 230 KV line andterminates in the Mountain Substation. The Stanton-Susquehanna42 circuit extends southward on double circuit towers with theStanton-Susquehanna 41 circuit and terminates in the Susquehanna230 KV S witchyard.

To the west of the tap into the Susquehanna plant the Montour-Mountain 230 KV circuit extends 1500 feet on double circuit steelpole structures at which point the Stanton-Susquehanna S2 circuitseparat'es and extends northvard to Stanton Substation. TheMontour-Mountain 230 KV circuit then Joins the Montour-Susquehanna 230 KV circuit on double circuit steel la ttice towersand extends 29.0 miles to the Montour Switchyard. The totaldistance to Mountain Substation from the tap into the plant is18.7 miles. The distance from Montour to the tap is 29.7 miles.

Several lines feed the Montour Svitchyard and MountainSubstation, as can be readily seen in Pigure 8. 2-3. These lines

Rev. ~ 28, 1/82 8 2-1

SSZS-PS AR

eoffer a multitude of possible supplies for the tap intoSusquehanna startup transformer f10. contour Switchyard issupplied directly by generation from the tjontour Steam ElectricStation. Other generatinq stations are indirectly linked by thebulk pover grid system. The conductors for the transformer 410tap and the Nontour-tlountain line are 1590 kcmil 45/7 ACSR..andare supparted by single string insulator assemblies. Haximumconductor tension is limited to 16,000 pounds on steel pole linesections and 21,900 pounds on. lattice tower sections undermaximum anticipated loading conditions.

, The second offsite pover source is supplied at 230 KV from theyard tie circuit betveen the Susquehanna 500 kV and 230 kVSubstations south of the Susquehanna Steam Electric Station. Thesource is, provided by a sinqle 400 ft. span tap f rom the 230 KVYard tie circuit to startup transformer 420.

The yard tie line consists of 230 KV double circuit tubular steelpole structures supportinq tvo parallel circuits of 1590 kcmil45/7 ACSR conductors on single string insulator assemblies. hecircuits are tied together to farm a tvo conductor per phasesinqle circuit line. The 400 ft. tap to transformer $ 20 consistsof one 1590 kcmil 45/7 ACSR conductor per phase. The dj.stancefrom the tap point vest to the 500 KV yard is 1500 ft. Thedistance from the tap point east to the 230 KV yard is 1.6 miles.Maximum conductor tension is limited to 16 ~ 000 pounds in the yardtie line under laximum loadinq conditions.The second offsite paver supply is furnished by the multiplesources throughout the bulk power qrid system through the 230 KUand 500 KV lines emanating from the Susquehanna 230 KV and 500 KVswitchyards. See Piqvre 8. 2-3.

All transmission lines meet or exceed design requirements setforth by the National Electric Safety Code. One or two overheadground wires are employed on the transmission lines above thephase conductors to provide adequate lightning flashoverprotection. All lines meet the Army Corps of Enqineersrequirements for clearance over flood levels. All bulk powertransmission. lines are desiqned to withstand 100 mph hurricanevind loads on bare conductors.

The contour-gountain 230 KV line is crossed by the Stanton-Susquehanna 42 230 KV line. No transmission lines cross over theSusquehanna 500 KU to 230 KV, yard tie line or the tvo tap linessupplyinq transf ormers $ 10 and 420.

No single disturbance in the bulk paver grid system vill causecomplete loss of offsite power to the Susquehanna SES. This is abasic system design criteria.

Rev. 28, 1/82 8 2-2

SS ES- PS AR

a

~8.2. 1 Transsisgion Xnterconnection

PP6L is a member of the Pennsylvania, Rev Jersey, and MarylandInterconnection vhich permits economical exchanges of pover vithneiqhborinq utilities and provides emergency assistance. Directbulk pover ties are between PPSL and Philadelphia Electric,Luzerne Electric Division of UGI, Metropolitan Edison,Pennsylvania Electric, Jersey Central Power and Light, PublicService Electric and Gas, and Baltimore Gas and ElectricCompanies.

8 2 1.3 Svitchggrds

8 2 1. 3. 1 Sta~tu~T~ans~fo m~es $ 10 and 420

e

The contour-Nountain 230 KV line and the 239 KV yard tie linesupply vower to startup transformers $ 10 and 420, respectively,through motor operat'ed air break svitches. High speed positi veground svitches are installed between the motor operated airbreak svitches (NOABs) and the startup transformers. The startuptransformers and low side bus connections are discussed inSection 8.3.1. The startup transformer yards are physicallyseparated from each other, the Unit Sl and 42 main transf ormeryards and the 230 KV and 500 KV switchyards as can he seen onfiqure 8.2-1. 1590 kcmil 45/7 ACSR conductors connect the airsvitches to the startup transformers. 13.8 KV cables areinstalled in underground conduit between the startup transformersand the turbine building. Ron-seqregated phase bus duct"establish the tie to the 13.8 KV startup buses within the turbinebuild inq. See Figure 8. 2-4 for a one line diagram of the offsitepover system.

Line relay protection for the contour-Hountain 230 KV line andthe 230 KV yard tie circuit is provided by tvo independentdirectional comparison carrier blocking pilot relaying and twozone directional distance backup systems vhich ensure adequateline protection in the event of a malfunction. These relayingschemes detect faults on the transmission line and isolate thepover sources to the transformers by tripping the power circuitbreakers (PCBs) at the line term'inals. Breaker failure relaying,applied at each line terminal, detects a failure to trip orfailure to interrupt condition at the line terminal and trips allassociat ed PCBs necessary to isolate the line. Power to the linerelayinq facilities is supplied from the local switchyard poversources.

Startup transformers 410 and 420 are protected by high speedpercentage differential, sudden pressure and overcurrent

Rev. 28, 1/82 8 2-3

SSES-PSAH

relaying. Direct transfer trip facilities are utilized as theprimary relaying scheme to open the PCBs at the transmission lineremote terminals in the event of transformer tr'ouble. Backupprotection is provided by the high speed ground svitch on the 230KV si'de of the startup transformer. This svitch is closed toplace a positive fault on the 230 KV transmission line vhich vill

- be detected by the remote line terminal relaying systems if theprimary direct transfer trip scheme fails to function correctly.The motor operated air svitch automatically opens after the 230KV system is de-energized to isolate the startup transformer from

.,the transmission system and permit reclosing of the transmission'ine terminal PCBs.

A time delay undervoltaqe relay monitors the 13.8 KV startup busvoltaqe. On loss of offsite power the relay trips the startup bus

'incoming feeder breaker and initiates transfer < 'he bus loads'to the other startup transformer through closure of the startup

~ 'us tie breaker. The time delay undervoltage relay also preventsunnecessary automatic trip of the incoming feeder breaker for'hort duration disturbances on the transmission line.

\

Power to transformer 010-and 020 svitchqear, motor operated air-"break svitches, and hiqh speed ground svitches is supplied from

the station 125 V DC pover supplies.I

'8 2'-1 3. 2 S~g~ue ~pa U~ 4 t 230 KV Hain Transf ormer Leads

Overhead 1590 kcmil 45/7 ACSR conductors, bundled tvo per phase,tie the Unit 41 main stepup transformers, through a hiqh voltageDisconnect svitch-Synchronizing PCB-Disconnect switcharranqement, to the 230 KV svitchyard. The synchronizing breakerand disconnect svitch arrangement is provided at the SusquehannaSES site to improve reliability in synchronization andflexibility of operatinq Unit 1. Steel pole structures supportthe strain bus and the 2.2 mile 230 KV tie with single stringinsulator assemblies. The tie line is capable of transmittingthe full 1280 NUA output of the Unit fl generator.

Relay protection between the Unit $ 1 transformer and thesynchronizing breaker is provided by high speed percentagedifferential relays which trip Unit $ 1 and the synchronizingbreaker by the unit master trip lockout relays. A secondprotection scheme is provided by the Unit Sl overall differentialrelaying which also detects fault conditions betveen Unit ~1

transformer and the synchronizing breaker. Tvo directionalcomparison carrier blockinq pilot and tvo zone directionaldistance backup relaying systems provide fault protection betveenthe 230 KV synchronizinq PCB and the Susquehanna 230 KVSvitchyard. Breaker failure protection relaying is applied. at

Rev. 28, 1/82 8 2-4

SS ES- FS AR

e ach terminal to detect a failure to trip or failure to interruptcondi tion and to electrically isola fe the faulty ccmponen t.Control power to the synchronizing pover circuit breaker an0power to the onsite relaying equipment are provided by the plant125 V DC pover supplies.

8,2 1 3,3 Susquehanna 230 KV Switch~ad

The 230 KV svitchyard is an outdoor steel structure, comprised of6 bay'ositions containinq 14-230 KV pover circuit breakersarranged in a breaker and one half scheme. Terminating positionsare provided for seven lines, one generator lead, and a yard tieto the 500 KV svitchyard. 'he svitchyard breakers can beoperated by remote supervisory control from the PPGL SystemOperatinq Offices.

Service pover to the 230 KV svitchyard is provided by a .local 12KV distribution line with a backup diesel generator in the 230 KVsvitchyard. An automatic throvover scheme is employed in theevent of one source failure. Line protection equipment pover isprovided by a single 125 V DC svitchyard service battery equippedwith tvo full capacity chargers.

8.2. 1.3.4 Susquehanna Unit 42 500 KU HainT ansformer leads

Unit S2 qenerator output is connected to the 500 KV svitchyard bya 1400 ft. overhead 500 KV transmission line. 2493 kcmil 54/37ACAR conductors bundled tvo per phase are supported by V-stringinsulator assemblies cn steel pole H-frame structures. The t ieis capable of transmittinq the full 1280 NVA generator output ofUnif f2 to the 500 KV svitchyard.

Relay protection for the connection betveen the Unit f2transformer and the Susquehanna 500 KV svitchyard is provided byhiqh speed bus differential relays which trip Unit S2 and thethree 500 KV switchyard qeneratcr breakers by the master triplockout relays for a fault in the- connection. An overalldifferential protection scheme provides a second system to tripOmit S2 and the three PCBs connected to the generator in the 500KV svitchyard for a fault on the transformer leads. Breakerfailure protection is applied at each terminal to detect a.failure to trip or failure to interrupt condition and toelectrically isolate the faulty component.

Rev. 28, 1/82 8 ~ 2-5

SSES-PS AR

8.2.1 3.5 Su guehanna 500 KV Svitc~h~ad

The 500 KV switchyard is an outdoor steel structure, comprised ofthree bays containing five 500 KV paver circuit breakers arrangedin a modified rinq bus configuration. The switchyard providesfor ultimate future expansion to 5 bays in a breaker and one halfscheme. Terminating positions are provided for tvo lines, one500 KV generator lead circuit and a circuit to a bank of threesinqle phase 500-230 KV autotransformers. Manual operation ofthe 500 KV generator lead synchronizing circuit breakers is bythe plant control room operator. The remaininq PCBs can beoperated by PPSL'.s remote supervisory control or by the plantsupervisory control.Service power to the 500 KV svitchyard is provided by tvosources: one from the qeneratinq station, and the second fromthe tertiary vindinq of the yard tie autotransformers vith anautomatic low voltaqe throwover scheme in the even't of one sourcefailure. Line protection equipment is powered .by a single 125 VDC svitchyard service battery equipped with tvo full capacity

, battery chargers.

8 2 1.3.6 Montoux and Nougtain 230 kV Swit~ch ards

~ ~Figure 8.2-5 shows a one line diaqram of the off-site poversystem for Startup Tran former tl0.The Montour Svitchyard is an outdoor steel structure comprised offour bay positions containinq 11-230 kV pover circuit breakersarranged in a breaker and one half scheme. Tvo generating leadsfrom the contour Steam Electric Station and five transmissionlines are terminated in the yard. The switchyard breakers can beoperated by remote control from the PPGL System-.Operatingo ffices.

The Mountain Svitchvard is ovned and operated by IJGX Corporation,Luzerne Electric Division. It is an outdoor steel structure withtvo bay positions each containinq one 230 kV PCB. The tvo, PCBsare arranged back to hack betveen the Montour-Mountain andRountain-Lackavanna Lines. Between the tvo PCBs is a normallyopen MOAH to the Susquehanna-Stanton ~1 line. The PCBs and MOABcan be operated by remote supervisory control from the UGICorporation System operator's office PCB and NOAB status ismonitored by PPSL ~s System Operatinq offices.

'

Rev. 28, 1/82 8 2-6Al-6

SS ES-FS AR

PPSI. ~ s transmission lines are patrolled approximately three tiaesthroughout a year to ensure that the physical and electricalintegrity of the transmission line supports, hardvare,insulators, and conductors is maintained for safe and reliablecontinuity of service.The periodi" transmission li,ne patrol is conducted by helicopter.Less frequent foot patrols and selective structure inspectionsare performed depending on the age of the line.Honitoring of the Unit $ 1 and Unit ¹2 offsite paver sources inthe plant control .room is via a hardvired aimic bus arrangementvhich shovs startup transf'oraers ¹10 and ¹20, the transformer ¹10and ¹20 motor operated air break svitches, the 13.8 KV start-upbuses, the 13.8 KV bus feeder breakers, and the 13.8 KV bus tiebreaker. hnnunciation signals abnormal tripping to the controlroom operator. Control and status indication are provided forthe 230 KV tlOhB switches and the 13.8 RV breakers. Potentialindication for the PPSL grid and 13.8 KV bus and statusindication of the 230 KV high speed ground svitches are provided.h cathode raV tube (CRT) display is provided by the plant0 computer system which provides the operator with additionalinformation about the offsite pover sources. The display is amimic bus arrangement, similar to the hardwired mimic hus, andincludes the status of the PCBs at the remote terminals'of thetrans for acr ¹ 10 and ¹ 20 sup ply lines.Honitoring of the Unit ¹1 main generator output leads to the 230KV svitchyard is provided in the" control room. h har dvir ed miaichus arranqeaent provides control and status indication of thesynchron izi.nq PCB. P oten tial ind ication and monitoring ofcurrent, vatts, vars, vatt hours and voltage are provided.Annunciation siqnals an abnormal change in status of thesynchronizing PCB. The coaputer CRT display system provides theoperator with the status of all PCB's in the 230 KV svitchyardand the synchronizinq PCB via input from PPGL's supervisorycontrol system. hnnunciation accompanies a failure of thesupervisory system. Manual control of the 230.KV switchyard isby a supervisory system .from selected PPGL System Operatingfacilities.Nonitorinq of the Unit ¹2 maiKV svitchyard is provided in

, arrangement. PCB open-closeprovided far all PCBs in themain generator synchronizingdirectly to the control room500 KV PCB control and status

'I

n qenerator output leads and the 500the cont'rol room via a mimic husstatus indication and control are500 KV svitchyard. Except for thebreakers vhich are hardviredalonq with potential indication, allindication in the control room is

Rev. 28, 1/82 8 2-7

SS ES- PS AR

~ provided throuqh a supervisory system. Digital displays monitor~ output current, watts, vags, vatt hours, and voltage.Annunciation accompanies uncommanded PCB status changes, loss ofpotential, transformer trouble, fire protection system actuation,carrier equipment failure, and fault recorder failure. Controlof the 500 KV svitchyard fault recorder and tap change control onthe 500-230 KV transformer are made available to the operator.Similar information is provided to the control room operator viathe computer CRT mimic bus arrangement display through thesupervisory system. Primary ccntrol of the 500 KV switchyard is.via the System Operatinq supervisory control system except forthe main generator synchronizing breakers which 'can be controlledonly by the pla nt ope ra tor.Preoperational and initial startup testinq of all

apparatus,'quipment,relaying, and PCBs is conducted at transformers 410and f20 and the 500 KV and 230 KV svitchyards to ensurecompliance with desiqn criteria and standards.

PCB protective relay testing, maintenance, and calibrat ion in the230 KV and 500 KV svitchyards, Montour svitchyard and attransformers 010 and 020 vill be conducted approximately onceevery two years. PCB protective relay testing, maintenance andcalibration at Mountain svitchyard is performed approximatelyevery year ..

8.2 1.5 I+ustgg Sgagda~ds

The requirements, criteria and recommended practices set forth inthe followinq documents are implemented in the design of thetransmission system:

A

B

National Electric Saf ety Code, 7th Addition.PJM Interconnection Protective RelayingPhilosophy and Design StandardsMAAC Group Reliability Principles'nd Standards forPlanninq Bulk Power Electric Supply System of MAACGroup, July 18, 1968 (Appendix 8.2A)In general high voltage circuit breakers aremanufactured and tested in accordance vith the latestrecommendations and rules of the ANSI, XEEE, NE"lA,and AEIC.Pennsylvania Power 8 Liqht 'Company Substationand Relay and Control Enqineering InstructionManuals, Enqineerinq and Construction Standards,Operatinq Principles and Practices; Relay andControl Paci lities 3/3/76 and sound engineeringprinciples. The design criteria include consider-ation of aesthetics, reliability, economics, andsa fety.

Rev. 28, 1!82 8 2-8Ai-8

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Rev. l5, 4/80

SUSQUEHANNA STEAM ELECTRIC STATIONUNITS 'I AND 2

FINALSAFETY ANALYSISREPORT

* Sunbury line to be installed in l982.

TRANSHISSION lINEARRANGEHENT

FIGURE 8

P

SUSQUEHANNA STEAM ELECTRIC STATIONUNITS 1 AND 2


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BULK POHER SUPPLY SYSTE/IOF PPSL AND AMOINIHGSYSTEHS PLA'INED TllRU 1982

F IGURE

NOHTOUR

230KV

NOUNTAIH

L IHE

SUHBUAY

230KV - 500KV TARO TIE

NONTOURSTATION

230KV

SW I TCHYARD

TRAHSFORNEA

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E. PALNERTON HARWOOO JEHKIHS STAHTOH «I START-UP

FEED «I13.8KV

START-UP

FEED «2I3 BKV

SUHBURY WESCOSVILLE

500/230KVTAAHSFOANEA

UNIT «I UHIT «2

SUSQUEHANNA STEAM ELECTRIC STA'TIONUNITS I ANO 2


TRMISHISS ION SYSTEH

FIGURE

I

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SUSQUEHANNA

230 kV SWI'KNYARD ELINSPORT

LIQIAIIANNA

SUSQUEllANNASTARTUP

TRANSFORI!ERf10

STANTON SI

SUSQUENANNA230 kV SWITCNYARD

IlONTOURUNIT Wl

GENERATOR

NONTOUR

UNIT W2

GENERATOR

S UNBURY COLUNBIA

NONTOUR SW ITCNYARD NOUNTAIN SWITCIIYARD

Rev. 15, 0/80

SUSOUEHANNA STEAM ELECTRIC STATIONUNITS I AND 2

flNALSAFfTY ANALYSISREFORT

NONTOUR AND MOUNTAINSW ITCHYARDS

ONE LINE DIAGRAM

FIGURE

APPENDIX 2

CALCULATION OF FRE UENCY OF LOOP DUE TO INDEPENDENT EVENTS

The PL historical outage data (1975-1981) show that for approximately 1200miles of monitored 230 kV transmission lines, there were approximately 30instances of forced 230 kV line outages annually. The average durationassociated with each forced outage was approximately 8 hours. So as notto skew the Susquehanna LOOP calculation, the historical data were adjustedso that none of the forced outages exceeded 48 hours. This adjustment wasmade in recognition of the physical and electrical independence of theSusquehanna off-site power system and PL's commitment to the top priorityrestoration of an outaged off-site source at Susquehanna.

Since the Montour-Mountain 230 kV line, including the Transformer 810 tap,is approximately 50 miles in length, the forced outage frequency for thisline is predicted to be:

(50 mi —: 1200 mi). x (30 per year ) 1.224 occurrences per year.Similarly, for the 2.5 mile line supplying Transformer 820, the forcedoutage frequency is predicted to be

[(2.5 mi x 10) ~ 1200 mi] x [30 per year] '.612 occurrences per year.The length of the short line, 2.5 miles, was increased by a factor of 10to reflect the assumed higher frequency of terminal induced forced outagesfor short lines.

The predicted frequency of Transformer /310 and 820 failures is .005 pertransformer per year. Since a spare Startup Transformer will be locatedon site, a 3 day outage duration was assumed for postulated failures ofTransformer 810 or 820.

The annual frequency of sustained LOOP (X 1) at Susquehanna due to havingboth 230 kV sources in a simultaneous forced outage condition is:

4

X1 X2(r1+r2)S1 8760

combined annual frequency of loss of Transformer 810 and'ts 230 kV,1 source (.005 + 1.224 ~ 1.229).

combined annual frequency of loss of Transformer 820 and its 230 kVsource (.005 + .612 .617).

r ~ equivalent outage duration forA1.'.224x8

+ .005x721.229

= 8.3 hours)

A2-1

r = equivalent outage duration for X .

(.612x8 + .005x72.617

= 8.5 hours)

Therefore, X = ' = .0015 occurrences per year(1.229)(.617)(8.3+8.5)

Using a similar approach, the frequency of sustained LOOP at Susquehannawith one of the two 230 kV sources scheduled out for maintenance is:

m m m '(X1 X2r1) + (X2 Xl r2)2 8760

~ annual frequency of scheduled maintenance outage for Transformer /f10and its 230 kV source (1 occurrence per year).

A2 annual frequency of scheduled maintenance outage for Transformer /$ 20and its 230 kV source (1 occurrence per year).t outage duration for 11 (8 hours).

r2 outage duration for A2 (8 hours).

Therefore, (1) (. 617) (8)+ (1) (1. 229) (8) .0017 occurrences per year.

Combining the above two components of the independent event calculationyields a value of .0032 (.0015 + .0017) predicted occurrences of sustainedLOOP per year. The calculation for transient interruptions of off-sitepower is similar to the one above and is not presented.

The calculation technique used above is based on the IEEE paper "PowerSystem Reliability I — Measures of Reliability and Methods of Calculation".This paper was published in the July 1964 issue of the IEEE Transactionson Power Apparatus and Systems.

(MG/LA-23)

A2-2

ANNUALFBI'QUHNCY OF LOOP ) T HOURS DURATIONVS. HOURS DURATION (T].

FOR LOOP CAUSED BY INDL)PENDENT EVENTS

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TIME REQUIRED TO RESTORE OFF-SITE POWERIF IT IS NECESSARY TO ISOLATE A FAULTEDSECTION OF ONE OF THE 230 KV LINES WHICHSUPPLIES TRANSFORMER /j10 OR 820

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Documents

CRITERIA kV A - Nuclear Regulatory Commissionsection from Wescosville 230 kV Substation to a point approximately 1 mile from the Siegfried 230 kV Substation is a reconstruction of