2010 Ten-Year Transmission Assessment

Los Angeles Department of Water & Power

2010 Ten-Year

Transmission

Assessment

November 2010 Transmission Planning & Studies Power System Planning & Development

Table of Contents

EXECUTIVE SUMMARY ...... 1

INTRODUCTION ...... 5

METHODOLOGY ...... 7

WECC REFERENCE CASE...... 7 Table 2. POWER FLOWS ALONG MAJOR SOUTHERN CALIFORNIA TRANSMISSION CORRIDORS IN THE REFERENCE CASE ...... 7 ANALYSIS...... 8 CRITERIA...... 8 ASSUMPTIONS ...... 10

LADWP LOADS...... 10 Table 3. COMPARISON OF 1-IN-10 SYSTEM LOADS (MW) ...... 10 Table 4. RECEIVING STATION (RS) PEAK LOADS (MW) ...... 11 INFRASTRUCTURE IMPROVEMENTS AND EXPANSION...... 12 Table 5. PLANNED SYSTEM ENHANCEMENTS...... 12 GENERATION...... 12 Table 6. LADWP’s GENERATION MIX (MW) ...... 13 TRANSMISSION...... 13 Table 8. FLOWS ALONG MAJOR TRANSMISSION CORRIDORS IN STUDY CASES (MW)...... 14 ASSESSMENT RESULTS ...... 15

(N-0) OR NO CONTINGENCIES...... 15 (N-1) CONTINGENCIES...... 15 (N-2) CONTINGENCIES...... 15 Table 10a. Overloads on Scattergood-Olympic from (N-2) Contingencies ...... 15 Table 10b. Overloads on Northridge-Tarzana from (N-2) Contingencies...... 16 Table 10c. Overloads on Sylmar-Northridge from (N-2) Contingencies ...... 16 EXTREME EVENTS — MULTIPLE CIRCUIT OUTAGES...... 16 Table 11. OUTCOME OF MULTIPLE CONTINGENCIES...... 17 LIGHT WINTER SCENARIOS...... 18 Table 12. POWER FLOWS ALONG MAJOR SOUTHERN CALIFORNIA TRANSMISSION CORRIDORS IN LIGHT WINTER STUDY CASES ...... 18 Table 13. DISTRICT LOADS IN LIGHT WINTER STUDY CASES (MW) ...... 19 Table 14. GENERATION MIX IN LIGHT WINTER STUDY CASES (MW)...... 19 STABILITY...... 19 RECOMMENDATIONS ...... 20

Appendices

APPENDIX A. NERC/WECC PLANNING STANDARDS

APPENDIX B. RECEIVING STATION LOADS

APPENDIX C. GENERATION SCHEDULE FOR LADWP-OWNED FACILITIES

APPENDIX D. TRANSMISSION LINE CAPACITIES

APPENDIX E. ONE-LINE DIAGRAMS

APPENDIX F. LIST OF CONTINGENCIES STUDIED

APPENDIX G. SWITCHING SEQUENCES FOR TRANSIENT AND POST-TRANSIENT

APPENDIX H. POWER FLOW RESULTS

APPENDIX I. TRANSIENT AND POST-TRANSIENT STABILITY RESULTS

APPENDIX J. RENEWABLE TRANSMISSION EXPANSION PROJECT

APPENDIX K. LONG-TERM TRANSMISSION PLAN

ii LADWP’s 2010 Ten-Year Transmission Assessment

2010 Ten-Year Transmission Assessment

Executive Summary This 2010 Ten-Year Transmission Assessment covers years 2011 to 2020. At least one system (1-in-10 peak) condition is modeled for years 2011 through 2020.

As in the previous years, the Los Angeles Department of Water and Power’s (LADWP) 2010 Ten-Year Transmission Assessment is compliant with the four NERC Transmission Planning Standards:

1. TPL-001-0.1. System Performance Under Normal (No Contingency) Conditions (Category A)

2. TPL-002-0b. System Performance Following Loss of a Single Bulk Electric System Element (Category B)

3. TPL-003-0a. System Performance Following Loss of Two or More Bulk Electric System Elements (Category C)

4. TPL-004-0. System Performance Following Extreme Events Resulting in the Loss of Two or More Bulk Electric System Elements (Category D)

The 2010 Ten-Year Assessment meets the following NERC Standard Measurements:

1. The Bulk Electric System (BES) shall be tested for transient, dynamic, and voltage stability with all facilities in service, checking to find that all facilities are within their facility ratings and within their thermal, voltage, and stability limits.

2. The BES shall be tested for transient, dynamic, and voltage stability following a single contingency, checking to find that all facilities are within their facility ratings and within their thermal, voltage, and stability limits.

3. The BES shall be tested for transient, dynamic, and voltage stability following a multiple contingency, checking to find that all facilities are within their facility ratings and within their thermal, voltage, and stability limits.

With management’s approval, this transmission assessment shall be a publicly available document and therefore made available to NERC and WECC.

This 2010 Ten-Year Transmission Assessment (Assessment) is based on WECC-approved case 2010HS3-OP which models anticipated heavy summer conditions with heavy flows from the Pacific Northwest to California and moderate flows elsewhere.

LADWP system loads for each study year are shown in Table 3 and are modeled according to the April 2010 Peak Demand Forecasts issued on May 6, 2010. As in past assessments, steady state load flow analysis, transient stability analysis, and post-transient voltage stability analysis were performed during the Assessment after incorporating planned system improvements and expansions and resource acquisitions.

1 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

This Assessment does not show any Interconnection Reliability Operating Limit conditions in the next ten years and does not have any stability-limited contingencies.

Full analyses of all credible outages listed in Appendix F reveals the existing and planned system should be able to sustain every studied contingency except for the following:

(1) A simultaneous (N-2) outage of Rinaldi-Tarzana 230kV Lines 1 & 2 would overload Northridge-Tarzana 230kV Line 1 on the 2011 Summer Peak.

(2) A simultaneous (N-2) outage of the Tarzana-Olympic 230kV Line 1 & the Tarzana- Olympic 138kV Line 1 would overload Scattergood-Olympic 230kV Line 2 from 2011 Summer Peak through the 2013 Summer Peak.

(3) A simultaneous (N-2) outage of Rinaldi-Tarzana 230kV Lines 1 & 2 would overload Scattergood-Olympic 230kV Line 2 on the 2013 Summer Peak.

(4) A simultaneous (N-2) outage of Rinaldi-Tarzana 230kV Lines 1 & 2 would overload Sylmar-Northridge 230 kV Line 1 on the 2013 Summer Peak.

(5) A simultaneous (extreme event) outage of three elements (Rinaldi-Tarzana 230kV Lines 1& 2 and Northridge-Tarzana 230 kV Line 1) would cause local low voltages at RS-U (Tarzana) and RS-T (Canoga) on the 2015 Summer Peak.

(6) A single (N-1) outage of Sylmar-Haskell Canyon 230 kV Line 1 would overload the Olive-Northridge 230 kV Line 1 on the 2020 Summer Peak.

To mitigate these overloads, the following corrective actions are recommended. These measures will satisfy the applicable NERC planning standards for contingency or post- contingency system performancea :

(1) On the 2011 Summer Peak, continue using a selective load-shedding program at RS-U (Tarzana) to relieve the overload on the Northridge-Tarzana 230kV Line 1 during a double contingency outage of Rinaldi-Tarzana 230kV Lines 1 & 2. The load-shedding will be needed until completion of the currently budgeted project to increase the ampacity of Northridge-Tarzana 230kV Line 1 prior to Summer 2012.

The following three recommendations all utilize load shedding as an interim measure until the new Scattergood-Olympic 230 kV Line 1 is put in-service:

(2) From the 2011 Summer Peak through the 2013 Summer Peak, implement a selective load-shedding program at RS-K (Olympic) to relieve the overload on Scattergood-Olympic 230kV Line 2 during a double contingency outage of Tarzana- Olympic 230kV Line 1 & the Tarzana-Olympic 138kV Line 1. The load-shedding will be needed until completion of the new Scattergood-Olympic 230 kV Line 1 scheduled to be in service in June 2014.

(3) For the 2013 Summer Peak, implement a selective load-shedding program at RS-U (Tarzana) to relieve the overload on Scattergood-Olympic 230kV Line 2 during a double contingency outage of Rinaldi-Tarzana 230kV Lines 1 & 2. The load-shedding will be needed until completion of the new Scattergood-Olympic 230 kV Line 1 scheduled to be in service in June 2014.

a NERC TPL-002-0b for N-1 (Category B) , NERC TPL-003-0a for N-2 (Category C)

2 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

(4) For the 2013 Summer Peak, implement a selective load-shedding program in RS-U (Tarzana) to relieve the overload on Sylmar-Northridge 230 kV Line 1 during a double contingency outage of Rinaldi-Tarzana 230kV Lines 1 & 2. The load-shedding will be needed until completion of the new Scattergood-Olympic 230 kV Line 1 scheduled to be in service in June 2014.

(5) For the 2014 Summer Peak onwards, implement a selective load-shedding load program at RS-T for the simultaneous (extreme event) outage of three elements (Rinaldi-Tarzana 230kV Lines 1& 2 and Northridge-Tarzana 230 kV Line 1) to mitigate local low voltages at RS-U (Tarzana) and RS-T (Canoga).

(6) Before Summer 2020, resolve overloads on the Olive-Northridge 230 kV Line 1 during a loss of the Sylmar-Haskell Canyon 230 kV Line 1 by completing two projects:

• Relocate the 230/155 kV Banks from Olive Switching Station to Haskell Canyon Switching Station.

• Remove the existing twin 115 kV circuits between Haskell Canyon Switching Station and Olive Switching Station and replace with a single new 230 kV circuit (utilizing the existing 115 kV right-of-way) to connect Haskell Canyon Switching Station to Sylmar Switching Station via Olive Switching Station by stringing the currently vacant position between Olive Switching Station to Sylmar Switching Station.

3 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

Table 1 summarizes the findings and recommendations of the 2010 Assessment.

Table 1. FINDINGS AND RECOMMENDATIONS

Reliability Overloaded Line or Year Outage(s) Recommendation Category System Violation

Selectively shed load in RS- Summer Rinaldi-Tarzana C Northridge-Tarzana U (Tarzana) for short term Peak 2011 230kV Lines 1 & 2 (TPL-003-0a) 230kV Line 1 Upgrade Northridge-Tarzana 230kV Line 1 for long term

Summer Selectively shed load in at Tarzana-Olympic Peak 2011 Scattergood- RS-K (Olympic) for short term 230kV Line 1 & C Through Olympic 230kV Line Tarzana-Olympic (TPL-003-0a) Summer 2 Add new Scattergood- 138kV Line 1 Peak 2013 Olympic 230 kV Line 1 for long term

Selectively shed load in RS- Scattergood- U (Tarzana) for short term Summer Rinaldi-Tarzana C Olympic 230kV Line Peak 2013 230kV Lines 1& 2 (TPL-003-0a) 2 Add new Scattergood- Olympic 230 kV Line 1 for long term

Selectively shed load in RS- U (Tarzana) for short term Summer Rinaldi-Tarzana C Sylmar-Northridge Peak 2013 230kV Lines 1& 2 (TPL-003-0a) 230 kV Line 1 Add new Scattergood- Olympic 230 kV Line 1 for long term Rinaldi-Tarzana Summer 230kV Lines 1& 2 D Local voltage Suggested load shedding Peak 2014 and Northridge- (TPL-004-0) collapse program in RS-T Onward Tarzana 230 kV Line 1 Sylmar-Haskell B Olive-Northridge 230 Canyon 230 kV (TPL-002-0b) kV Line 1 Two projects are needed Line 1 • Relocate the 230/155 kV Banks from Olive Switching Station to Haskell Canyon Switching Station.

Summer • Remove the existing twin 115 kV circuits between Haskell Canyon Switching Peak 2020 Station and Olive Switching Station and replace with a single new 230 kV circuit (utilizing the existing 115 kV right-of-way) to connect Haskell Canyon Switching Station to Sylmar Switching Station via Olive Switching Station by stringing the currently vacant position between Olive Switching Station to Sylmar Switching Station.

4 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

Introduction The City of Los Angeles’ (City) transmission system consists of high voltage (above 500kV) alternating current (AC) and direct current (DC) transmission corridors and a 115kV-to-230kV in-basin network totaling more than 3,600 miles. Of those, high voltage AC and DC transmission lines alone account for 2,900 miles providing over 10,000MW of import capability. The City utilizes these resources to transport power from the Pacific Northwest, Utah, Arizona, Nevada, and within California to serve its customers and to wheel power for the Cities of Burbank and Glendale. In addition, the City’s transmission system is interconnected with other utilities in the Western Electricity Coordinating Council (WECC) to coordinate and promote electric reliability throughout the Western United States. Thus, the importance of the security and adequacy of the City’s transmission system extends beyond its physical boundaries. A drawing of LADWP’s Power System is provided in next page.

Transmission Planning annually performs a ten-year transmission assessment to:

• ensure the City’s electrical demand and energy requirements are met at all times under normal conditions (TPL-001-0.1);

• ensure the City’s electrical system is able to withstand and respond to unanticipated system disturbances, losses of system components (TPL-002-0b and TPL-003-0a), and disturbances arising from switching operations;

• ensure WECC/NERC Reliability Standards are met even when facilities are forced out of service; and

• assess system performance following extreme events (TPL-004-0).

By responsibly addressing any concerns identified in the assessments before they become critical system limitations, LADWP has also minimized system infrastructure costs, an important consideration in maintaining competitive electric rates.

Annual ten-year transmission assessments are required by the NERC Compliance Enforcement Program to adhere to the NERC/WECC Planning Standards in effect at the time of the assessment. As of October 1, 2010, these Planning Standards are:

1. TPL-001-0.1. System Performance Under Normal (No Contingency) Conditions (Category A)

2. TPL-002-0b. System Performance Following Loss of a Single Bulk Electric System Element (Category B)

3. TPL-003-0a. System Performance Following Loss of Two or More Bulk Electric System Elements (Category C)

4. TPL-004-0. System Performance Following Extreme Events Resulting in the Loss of Two or More Bulk Electric System Elements (Category D)

5 November 1, 2010 POWER SYSTEM DIAGRAM

CELILO MONA (BPA) PACIFICORP.

UPPER GORGE GONDER INTERMOUNTAIN (DW P) (SIERRA) 2-345 KV 230 KV OREGON MIDDLE GORGE 1-345 KV NEVADA +-500 KV D.C.

CONTROL GORGE MILFORD W IND 34.5 KV OW ENS VALLEY HOOVER (USBR) INYO TIE POW ER PLANTS: (SCE) PLEASANT VALLEY

230 KV V K 0 BIG PINE 3 INYO 2 NAVAJO

DIVISION CREEK CRYSTAL KV 34.5KV (SRP) COTTONW OOD (NPC) 8-230 HAIW EE 500 KV 34.5KV DIST. STATIONS: 150-159 PINE TREE W IND COTTONW OOD 161-170 MEAD

500 KV D.C. (W ESTERN) - + 500 KV 1 15 KV (SCE) 500 KV

BARREN RIDGE McCULLOUGH ELDORADO MOENKOPI SAN FRANCISQUITO 115 KV (DW P) (SCE) (APS) CASTAIC 2-230 KV 2-230 KV POW ER PLANT 1 500 KV

115 KV 500 KV 500 KV

SAN FRANCISQUITO 115 KV 5 0 500 KV POW ER PLANT 2 TOLSON 0

MARKETPLACE (NPC) 230 KV K (DW P) 500 KV 3-230 KV V V MERCHANT

K (NPC) 230 KV

0 MOHAVE YAVAPAI 0 FAULKNER (APS)

(SCE) 500 KV 2-500 KV 5 (NPC) 230 KV -

2 DAVIS (W ESTERN) 230 KV FOOTHILL ADELANTO 217 (DW P) 500 KV 2 4 -2 - (S C E ) 2 0 K V 5 OLIVE 5 0 0 287 KV

K 500 KV 107 V SAN FERNANDO 210 96 500 KV SYLMAR F V O VICTORVILLE LUGO W ESTW ING O K EAST T

H (DW P) (SCE) (APS) IL 0 L 86 227 0 SYLMAR SAN 5 226 FERNANDO T O

S S D C Y F E L AN WY. V . 109 M R G L O A D N A N E B V R A R L E L FO T 500 KV D 118 B 80 OTHIL W V L O IA R 82 RINALDI PACOIMA 134 K 142 HANSEN FLOOD 101 S CHATSW ORTH V A CONTROL N GRANADA K S BASIN 69 Y F BLVD 500 KV BLVD. 92 U DEVONSHIRE HILLS ST. N E R VALLEY 72 N DEVERS PALO VERDE A 88 68 N 48 0 D SUNLAND

FWY. (SCE) (APS) N4 O

BLVD. 3 AVE. A NORTHRIDGE V - V CHATSWORTH 2 2 141 - 220 RES. 3 E 0 210 138 63 5 R TUJUNGA 131 M 74 F K D WY 209 230 196 . NORTHRIDGE V R U 133 D DIEGO . 102 J PARTHENIA ST. 219 G 210 LA CRESCENTA O 2 67 GO - CHATSW ORTH ROSCOE AVE. PANORAMA LD EN 2 8 CITY 7 S 4 ALTADENA 1 10 BLVD. T 132 A K CANOGA PARK RESEDA 108 - SUN VALLEY T 2 E LA CANADA V 21 1 M 22 193 3 90 0 WINNETKA 81 62 O SHERMAN WAY 85 K U V 206 F 24 W N 140LANKERSHIM Y VAN NUYS . T

127 SAN JCT. A 77 3 60 - 4-230 KV 100 2 3-230 KV 5 I T 3 N 136 0 21

BALBOA S K S 2 CANOGA V TOLUCA H U TARZANA OXNARD ST. O L L 6- TOPANGA CANYON Y 69 VE W K 129 NTURA 101 BLVD. E V 71 O AIR W AY 65 57 O BURBANK 78 D (GLENDALE) 79 NUYS VAN NORTH TARZANA 130 73 35 3 0 K V FWY. HOLLYW OOD 170 2 -2 W OODLAND VE NTUR A CANYON MU HILLS 91 101 LH A O 2 LL D 83 134 AN ENCINO 3 210 D E STUDIO CITY V 0 1 13 S ENCINO 64 49 K 2 E K 9 V R 8 - RES. LVD. GRIFFITH B UNIVERSAL CITY 134 SHERMAN 2 0

L PARK EAGLE PASADENA 3 3 OAKS E

R 2 0 ROCK

122 U HOLLYW OOD - 1 14

DRIVE 124 A 1 15

2 L 30 K . RESERVOIR BLVD V M O V TT K UN T A HIGHLAND IN S PARK

BEVERLY GLEN B 8

E HOLLYWOOD ATW ATER 3 N 1 93 2

E NICHOLS RES. 405 D CANYON ELIZ

I F

C CYN. OS G 1 RES. L V

A - T 25 . SOUTH PASADENA IC FRANKLIN 54 K A Y 1 W N N 1 F O 3 HOLLYWOOD BLVD. SA M - SILVER LAKE E N T A 5 103 D 8 . 2 10 52 BLVD. RES. A T 3 4 3 SE S N S - 3 A 1 10 K U 0 S 36 BEL AIR HOLLYW OOD U 2 - P N V FRANKLIN 3 S 2 ALHAMBRA C 6 EL SERENO RES. W EST E 0 O K Y SAW TELLE T N 101 T 99 V . HOLLYW OOD 116 H 15 K 50 84 223 222 B V LV P D KENTER . A A BEVERLY HOLLYW OOD 94 87 N L CYN. 135 F E I 46 HILLS V W D S 55 Y. A A PACIFIC LOS ANGELES 26 S D K A 61 P E 1 1 ST. JOHN PALISADES WILSHIRE BLVD. S A MONTEREY 7 1 0 1 2 8 1 D . 38 42 R D 3 PARK . V W ESTW OOD 1 12 SCALE IN MILES L 29 B 8 75 - 43 ET S SUNS E 28 17 9 P 66 P 76 2 104 U

L W EST MARKET 97 V V FAIRFAX 1 PACIFIC HWY. E LOS ANGELES 16 K

OAST D D C SANTA A 20 MONICA 34 37 0 23 MONICA 10 K 3 SANTA RIVER 60 . Y JEFFERSON 144 2 W

V F

B - OLYMPIC 145 LV W

2 2 -1 D. Y. F MONTEBELLO 3 2 8 K K 3 PALMS V 56 39 13 19 . 5 0 D VELASCO V

L V B 8

K 53 K 1 AVE. 3 F -

V 1 2 5

CULVER 2 0 MAR VISTA - 32 0

3 COMMERCE JOINTLY CITY FWY.

B 4 K L NON V 2 V E D 4 IC . - - N 1 10 2 E LA BREA 3 OW NED OW NED DW P 44 V 3 VERNON 0 VENICE 45 4 K MARINA SLAUSON AVE. V BELL GARDENS 95 DEL REY 90 18 INGLEW OOD LAGUNA BELL 2 -13 8 K V BELL (SCE)

. HUNTINGTON V

GENERATING STATION, NUCLEAR N HARBOR

K AVE. A O V A S ST. PARK

L D R E

R F E

F 58 0 E B

J 41 M

A 3

W ESTCHESTER A L

2 N A

MANCHESTER AVE. FIRESTONE CUDAHY -

GENERATING STATION, THERMAL AIRPORT 2 V 137 14 BLV I D. S GRAMERCY T PLAYA 1 1 1 A CENTURY DEL REY D 225 139 SOUTH E B L GATE 2-138 KV27 POW ER PLANT, HYDRO M LOS ANGELES A R INTERNATIONAL BLVD. W ATTS IMPERIAL HWY. R A AIRPORT O V B DOW NEY HYPERION E R

2 -13 8 K V 105 . LYNW OOD

47 H T

L S CONVERTER STATION IMPERIAL 710 EL SEGUNDO BLVD.

AVE. SCATTERGOOD HAW THORNE

405 ROSECRANS PARAMOUNT

. BLVD. D H

SW ITCHING STATION OR SUBSTATION V

I L G GARDENA COMPTON AVE.

SEPULVEDA H S 143 B 605 L A LAW NDALE A N

D MANHATTAN 2-138 KV

A BEACH V BELLFLOW ER

RECEIVING STATION E MAIN

. IA GARFIELD . ARTES FWY ARTESIA BLVD. REDONDO BEACH 91 FWY.

P A 2-138 KV ORIA ST. C CT

D VI HERMOSA N I IE F G

O O H

I AVE.

BEACH T C

DISTRIBUTING STATION C G A 190th ST.

T. N E C S

YL I

O ER B B M

A F LAKEW OOD

L S HALLDALE W I REDONDO Y T 105 . W BLVD. BEACH DEL AMO

H 4 H A

W C - FUTURE DISTRIBUTING STATION G

D 2 Y A N . E 3

TORRANCE O E 0 M L

A HAWTHORNE.

L K

A V SEP ULVEDA B 189 LVD

POLE TOP DISTRIBUTION STATION . LONG WESTERN 106 CARSON L OM I

TA SIGNAL HILL BELLFLOWER

P TERMINAL TOW ER A C IF BLVD. IC ST LOMITA WE W ILMINGTON C CHERRY COAST HWY. PALOS

W IND GENERATION . VERDES ROLLING 123 128 125 ST. R ANAHEIM D ESTATES HILLS ESTATES 120 S 51

E Q 1 19 D LONG BEACH R HARBOR 1 18

E OCEAN

TRANSMISSION LINE, OVERHEAD V ROLLING W ILMINGTON B

LVD

S HILLS .

A 214 P RANCHO PALOS VERDES HARBOR TERMINAL TRANSMISSION LINE, UNDERGROUND PALOS ISLAND HAYNES 121

3 V ST. E R D 89 CHANGE OF OPERATING JURISDICTION E S SAN D OR OW NERSHIP R. PEDRO SOU TH GAFFEY

FUTURE

POWER SYSTEM PLANNING AND DEVELOPMENT OES-LCM67 TRANSMISSION PLANNING GROUP JULY 2010 REV. 16 LADWP’s 2010 Ten-Year Transmission Assessment

Methodology WECC Reference Case. Study cases were developed from the WECC-approved 2010HS3-OP case which models the expected power flows throughout the Western United States during heavy summer conditions with heavy flows from the Pacific Northwest to California and moderate flows elsewhere.

Table 2 summarizes the power flows along major transmission corridors in the reference case that are relevant to this 2010 Assessment. These flows are scheduled above the projected LADWP’s firm transfer levels to represent reasonable stressed system.

Table 2. POWER FLOWS ALONG MAJOR SOUTHERN CALIFORNIA TRANSMISSION CORRIDORS IN THE REFERENCE CASE

Transmission Corridor Rating Power Flow (MW) Loading

Pacific DC Intertie 3100 2779 90% (Path 65) Intermountain DC 2400 1705 71% (Path 27) East-of-the-Colorado River 9300 4889 53% (Path 49) West-of-the-Colorado River 10623 6159 58% (Path 46) Victorville-Lugo 500kV Line 1 2400 1171 49% (Path 61) LADWP-SCE @ Sylmar 1600 -80 5% (Path 41) Adelanto-Toluca 500kV 942 Line 1 Adelanto-Rinaldi 500kV 625 Line 1 Victorville-Rinaldi 500kV TBD 559 Line 1 Victorville-Century1 287kV 202 Line 1 Victorville-Century2 287kV 202 Line 1

7 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

Analysis. A minimum of one study case is developed from the 2010HS3-OP reference case for each study year, 2011 through 2020. Each study case models the LADWP system as it is likely to be configured on the 1-in-10 year peak summer day that year to capture the critical system conditions.

Initially, power flow studies are conducted for each study case with all transmission facilities in-service (N-0) and within normal operating procedures. Subsequently, all single-transmission line or transformer outage (N-1) and all credible double-transmission line outages (N-2) are also studied. The results from these studies identify the transmission lines likely to experience thermal overloading or significant voltage depression under the applicable test condition. The most severe of these scenarios are further studied for post-transient stability and reactive margins.

As a summer-peaking system, LADWP plans its outages at cooler times of the year. Therefore, planned outages as initial conditions are not modeled in this Assessment.

Transient stability is investigated for line outages of critical transmission paths to assess their inter-regional impacts and to ensure system adequacy and security. Control devices such as HVDC controls, SVC controls and all other controls are modeled in the WECC dynamic database. Protective systems such as Under-frequency Load Shedding are also modeled in the WECC dynamic database, whereas relevant remedial action schemes are listed in the switching sequence files which drive the dynamic simulation.

Where study results show that transmission paths are constrained, overloaded, or unstable, recommendations to mitigate or alleviate the problems are provided.

Criteria. Annual transmission assessments are performed in compliance with NERC/WECC Planning Standards (Appendix A) and fulfill WECC’s requirement that each utility independently performs such a reliability assessment and demonstrates compliance with the NERC/WECC standards.

Power Flow. In addition to the NERC and WECC requirements, LADWP has established performance standards for its in-basin electric system as follows:

1. With all transmission system components in service (N-0), the in-basin electric system shall not experience the following:

a. Interruption of load

b. Bus voltage less than 0.99 pu

c. With the worst-case generating unit off-line, operation of a transmission system component at a level in excess of its normal rating.

2. A Single Contingency (N-1) shall not result in any of the following:

a. Interruption of load

b. Bus voltage less than 0.95 pu

c. With the worst-case generating unit off-line, operation of a transmission system component at a level in excess of its emergency rating.

8 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

Transient and Post-Transient Stability. Transient and post-transient performance under the various contingencies described in Appendix G shall meet the following additional requirements:

Transient Stability:

1. All machines in the system shall remain in synchronism as demonstrated by their relative rotor angles

2. Induction motors shall be modeled at 20% of the total load across the WECC region

3. System stability shall be evaluated based on the damping of the relative rotor angles and the damping of the voltage magnitude swings

4. The transient voltage dip should be maintained above 0.80pu at Adelanto and Sylmar

Post-Transient Stability

1. All loads shall be modeled as constant MVA during the first few minutes following an outage or disturbance.

2. All voltages at distribution substations shall be restored to normal values by the transformer tap changers and other voltage control devices.

3. Generator MVAR limits shall be modeled as a single value for each generator since the reactive power capability curve will not be modeled in the program output.

4. No manual operator intervention is allowed to increase the generator MVAR flow.

5. Remedial actions such as generator dropping, load shedding and blocking of automatic generation control (AGC) shall not be considered for single contingencies.

6. Shunt capacitors (132 MVAR) at Adelanto and Marketplace shall be used if the post- transient voltage deviation exceeds 5% at those buses. Although modeled as shunt capacitors the actual devices are automatically controlled Static Var Compensators (SVCs). 7. Other assumptions: • Area Interchange: Disabled • Governor Blocking: Base load flag shall be used per WECC practice • DC Line Transformer Tap Automatic Adjustment: Enabled • Generator Voltage Control set to local except for Palo Verde, and selected Northwest generation • Phase Shifter Control: Disabled • Switched Shunt Devices: Disabled

9 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

Assumptions LADWP Loads. One-in-ten year summer heat waves, as represented in the “April 2010 Retail Electric Sales and Demand Forecast” released on May 6, 2010 are modeled each year in the study.

The one-in-ten system loads modeled in this 2010 Assessment are higher than those applied in the 2009 Assessment which are those forecast in the “January 2010 Retail Electric Sales and Demand Forecast”, a comparison of which is presented in Table 3.

Table 3. COMPARISON OF 1-IN-10 SYSTEM LOADS (MW)

2009 2010 Year Increase/Decrease Assessment Assessment 2011 6275 6262 (13) 2012 6300 6307 7 2013 6331 6377 46 2014 6394 6479 85 2015 6405 6538 133 2016 6432 6597 165 2017 6526 6697 171 2018 6742 6807 65 2019 6833 6917 84 2020 6940 7020 80

Receiving Station loads are scaled according to the “Receiving Station and Distributing Station Load Forecast – 2009 to 2018” distributed February 25, 2010. Loading at receiving station banks are generally developed with the power factors provided in the Receiving Station/Distribution Station Forecast, but with some modification to match available historical peak load data. Table 4 lists the forecasted real power loads at the receiving station level. Appendix B lists the coincidental peak real and reactive power loads at the receiving stations.

10 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

Table 4. RECEIVING STATION (RS) PEAK LOADS (MW)

Service Area Receiving Station 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 Airport 208 209 213 216 219 220 224 228 231 235 Atwater 321 323 331 333 337 339 344 352 358 363 Century 300 303 306 312 316 318 323 333 339 344 Fairfax 409 413 416 421 423 424 428 433 441 447 Hollywood 405 411 415 426 427 432 437 444 452 458 Central Market (River) 370 371 371 375 378 381 383 388 395 401 Olympic 423 423 430 442 445 452 460 467 475 482 Scattergood 27 27 27 27 27 27 28 28 29 29 St. John 226 230 230 233 235 237 241 244 248 251 Velasco 229 230 231 234 235 238 242 246 250 254 Total Central Load 2918 2940 2970 3019 3042 3068 3110 3163 3218 3264 Halldale 49 49 49 49 50 50 52 52 53 54 Harbor 204 205 206 208 209 211 213 216 219 223 Southern Wilmington 165 164 165 168 168 170 171 175 177 180 Total Southern Load 418 418 420 425 427 431 436 443 449 457 Canoga 375 377 380 372 376 378 383 389 396 402 Northridge 529 533 535 557 563 568 579 588 598 606 Rinaldi 301 304 312 319 322 328 334 341 347 352 Tarzana 350 354 358 364 367 370 379 383 390 395 Valley Toluca 415 414 419 418 424 432 437 444 452 458 Valley 321 328 330 337 341 340 348 355 361 366 Van Nuys 432 436 443 455 461 465 474 483 491 498 Total Valley Load 2723 2746 2777 2822 2854 2881 2934 2983 3035 3077 Total Receiving Station Load 6059 6104 6137 6167 6226 6380 6480 6589 6702 6798 Diversity Factor 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 1.05 Total Coincidental Receiving 5770 5813 5873 5968 6022 6076 6171 6275 6383 6474 Station Load Owens Valley Load & Transmission 492 494 504 511 516 521 526 532 534 546 Losses 1-in 10 Peak Load Forecastb 6262 6307 6377 6479 6538 6597 6697 6807 6917 7020

b Forecast estimates customer generation of 212 MW in 2011 increase to 311 MW in 2020

11 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

Infrastructure Improvements and Expansion. Table 5 lists the infrastructure improvements, expansion projects, and resource acquisitions captured in this 2010 Ten-Year Transmission Assessment.

Table 5. PLANNED SYSTEM ENHANCEMENTS

System Enhancements In-Service Date Initial Model Year

Southern Transmission System Upgrade December 2010 2011

Harper Lake Solar Project January 2012 2012

Northridge – Tarzana 230 kV Line Upgrade July 2012 2012

Owenyo Solar Phase I Project July 2013 2013

Castaic Power Plant Modernization January 2013 2013

Haynes Generation Station Re-powering Phase 2 February 2013 2013

Scattergood-Olympic 230KV Line 1 June 2014 2014

Beacon Solar Project May 2014 2014

RS-C Bypass March 2014 2014

Owenyo Solar Phase II Project October 2014 2015

Synchronous Condenser Replacement June 2015 2015

Pine Canyon Wind Project September 2015 2015

Barren Ridge-Haskell 230kV Lines (*) December 2014 2015

Barren Ridge-Rinaldi 230kV Line (upgrade) (*) December 2015 2016

Scattergood Generating Unit 3 Re-powering December 2015 2016

(*) The new Barren Ridge-Haskell 230kV Lines and the upgraded Barren Ridge-Rinaldi 230kV Line are part of the Renewable Transmission Expansion Project as illustrated in Appendix J

Renewable energy projects anticipated in the near–term include:

• Wind projects in the Owens Valley (Pine Tree Wind and Pine Canyon Wind Projects) and in Utah (Milford Wind Project)

• Solar projects in the Owens Valley (Beacon Solar and Owenyo Solar Projects) and California High Desert (Harper Lake Solar Project)

Generation. LADWP owns and operates resources capable of producing up to 5203 MW by internal generation and 3291 MW external generation. Table 6 shows how LADWP’s resources are dispatched in this study whereas unit commitments are provided in Appendix C.

12 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

Table 6. LADWP’s GENERATION MIX (MW)

Capacity Resource Type 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 (MW) Pumped Storage 1595 221 77 98 -58 13 2 18 128 300 162 Natural Gas 3677 1832 1774 1732 1732 1682 1682 1732 1732 2127 1802 Wind 285 40 40 40 40 85 85 85 85 85 85 Solar 210 0 0 100 100 200 200 200 200 200 200 Hydroelectric 221 160 160 160 160 50 120 160 160 160 160 Internal Generation 5987 2253 2051 2131 1975 2030 2089 2195 2305 2872 2409

% Total Generation 64% 47% 42% 43% 39% 40% 41% 42% 43% 53% 43%

Hydroelectric 491 410 410 410 410 410 410 410 410 410 410 Wind 306 80 80 80 80 80 80 80 80 80 80

Solar 500 0 250 250 500 500 500 500 500 500 1087 Coal 1681 1681 1681 1681 1681 1681 1681 1681 1681 1204c 1204c Nuclear 387 387 387 387 387 387 387 387 387 387 387 External Generation (*) 3365 2558 2808 2808 3058 3058 3058 3058 3058 2581 3168

% Total Generation 36% 53% 58% 57% 61% 60% 59% 58% 57% 47% 57%

Total Generation 9352 4811 4859 4939 5033 5088 5147 5253 5363 5453 5577 (*) External Generation represents projected firm transfer for each of the ten years

This Assessment shows that sufficient capacity is available to meet the Renewable Portfolio Standard target of 33% provided that 1324 MW of renewable resources are imported using (a) transmission from the retired Navajo coal generation facility and (b) the Pacific DC Intertie and 98 MW of roof top solar goals in 2020d. Appendix C includes the breakdown of renewable energy resources represented in the 2020 Heavy Summer base case. Transmission. LADWP’s extensive transmission system of more than 3,000 circuit miles reaching beyond its neighboring states facilitates access to low cost power purchases and LADWP’s external generation. As Table 7 shows, over 60 percent of LADWP’s power needs are served by heavily leveraging transmission assets. Over the next ten years, additions of approximately 100 circuit-miles of transmission will increase LADWP’s access to renewable energy intrastate.

c Navajo contract will be expired in 2019. It is assumed that the contract will not be renewed, but may still be retained as a long term energy hub.

d The 10 Year Transmission Assessment takes a snap-shot of the system at the hours of the highest stress on the electrical system. This peak snapshot will likely have a lower than average renewable mix because thermal peaking units are required on peak hours. In contrast to thermal peaking units, renewable resources are used any hour they are available, all year long. Because the renewable target is the annual energy consumed, regardless what is seen in a single snap-shot, the actual resource mix could be substantially lower on the most stressed hours without preventing LADWP from meeting its 2020 RPS’s goal.

13 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

Table 7. ELECTRIC SUPPLY-DEMAND BALANCE (MW)

2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 LADWP Receiving Station Load 5770 5813 5873 5968 6022 6076 6171 6275 6383 6474 System Losses 492 494 504 511 516 521 526 532 534 546 Total Power Requirement 6262 6307 6377 6479 6538 6597 6697 6807 6917 7020 Internal Generation 2253 2051 2131 1974 2031 2089 2195 2305 2872 2409 % Power Requirement 36% 33% 33% 30% 31% 32% 33% 34% 42% 34% External Generation & Purchases 4009 4256 4246 4505 4507 4508 4502 4502 4045 4611 % Power Requirement 64% 67% 67% 70% 69% 68% 67% 66% 58% 66%

Table 8 summarizes the power flows along LADWP’s major transmission paths in this 2010 Ten-Year Transmission Assessment.

Table 8. FLOWS ALONG MAJOR TRANSMISSION CORRIDORS IN STUDY CASES (MW)

Transmission Corridor Rating (MW) 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020

Pacific DC Intertie 3100 2779 2779 2779 2779 2779 2779 2779 2779 2779 2779 (Path 65) Intermountain DC 2400 1705 1705 1705 1705 1705 1705 1705 1705 1705 1705 (Path 27) East-of-the-Colorado River 9300 4889 4886 4887 4886 4886 4886 4886 4886 4441 4440 (Path 49) West-of-the-Colorado River 10623 6159 6151 6152 6150 6150 6150 6150 6150 5709 5840 (Path 46) Victorville-Lugo 500kV Line 1 2400 1170 1166 1141 1144 1136 1136 1134 1130 1218 1151 (Path 61) LADWP-SCE @ Sylmar 1600 -80 -169 -163 -143 -136 -133 -135 -130 15 -111 (Path 41) Adelanto-Toluca 500kV Line 1

Adelanto-Rinaldi 500kV

Line 1 TBD 2531 2692 2718 2716 2725 2724 2725 2730 2410 2719

Victorville-Rinaldi 500kV Line 1 Victorville-Century 287kV Lines 1 & 2

14 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

Assessment Results

• (N-0) or No contingencies. LADWP system meets the performance requirements of Category A in all base cases.

• (N-1) Contingencies. All LADWP circuits were studied for (N-1) contingencies. The only instance where performance criteria was not met was the Olive-Northridge 230 kV Line 1.

Olive-Northridge 230 kV Line 1 Overload

Table 9 shows that projects to mitigate overloads Olive-Northridge 230 kV Line 1 need to be completed by 2020.

Table 9. Overloads On Olive-Northridge from (N-1) Contingencies

Single Outage Overloaded Line Loading Study Year

Sylmar – Haskell Canyon 230 kV Line 1 Olive –Northridge 230 kV Line 1 103% 2020

• (N-2) Contingencies. The only instances where performance criteria were not met were (a) Scattergood-Olympic 230kV Line 2 overloads, (b) Northridge-Tarzana 230kv Line 1 overloads and (c) Sylmar-Northridge 230 kV Line 1 overloads. Scattergood-Olympic 230kV Line Overloads

Table 10a shows that overloads on Scattergood-Olympic 230kv Line 2 are remedied by the new Scattergood-Olympic 230 kV Line 1 scheduled to be in service in June 2014. Table 10a. Overloads on Scattergood-Olympic from (N-2) Contingencies

Study Double Outage Overloaded Line Loading Year Rinaldi-Tarzana 230kV Lines 1 & 2 Scattergood-Olympic 230kv Line 2 102% 2013

Rinaldi-Tarzana 230kV Lines 1 & 2 Scattergood-Olympic 230kv Line 2 <90% 2014-20

Tarzana-Olympic 230kV Line 1 & Tarzana-Olympic 138kV Line 1 Scattergood-Olympic 230kv Line 2 120% 2011 Tarzana-Olympic 230kV Line 1 & Tarzana-Olympic 138kV Line 1 Scattergood-Olympic 230kv Line 2 115% 2012

Tarzana-Olympic 230kV Line 1 & Tarzana-Olympic 138kV Line 1 Scattergood-Olympic 230kv Line 2 121% 2013

Tarzana-Olympic 230kV Line 1 & Tarzana-Olympic 138kV Line 1 Scattergood-Olympic 230kv Line 2 <90% 2014-20

15 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

Northridge-Tarzana 230kV Line Overloads

Table 10b shows the Northridge-Tarzana Line 1 (230kV) needs to be reinforced. Ignoring this work would likely overload the line during a double line outage of Rinaldi-Tarzana Lines 1 & 2 (230kV) as early as summer 2011.

Table 10b. Overloads on Northridge-Tarzana from (N-2) Contingencies

Study Double Outage Overloaded Line Loading Year

Rinaldi-Tarzana 230kV Lines 1 & 2 Northridge-Tarzana 230kV Line 1 102% 2011

Rinaldi-Tarzana 230kV Lines 1 & 2 Northridge-Tarzana 230kV Line 1 104% 2012

Rinaldi-Tarzana 230kV Lines 1 & 2 Northridge-Tarzana 230kV Line 1 <90% 2013-20

Sylmar-Northridge 230 kV Line 1 Overloads Table 10c shows that the overload on Sylmar-Northridge 230 kV Line 1 are remedied by the new Scattergood-Olympic 230 kV Line 1 scheduled to be in service in June 2014.

Table 10c. Overloads on Sylmar-Northridge from (N-2) Contingencies

Study Double Outage Overloaded Line Loading Year

Rinaldi-Tarzana 230kV Lines 1 & 2 Sylmar-Northridge 230 kV Line 1 101% 2013

Rinaldi-Tarzana 230kV Lines 1 & 2 Sylmar-Northridge 230 kV Line 1 <90% 2014-20

• Extreme Events — Multiple Circuit Outages

In general, each annual Assessment can examine different extreme events. There is no NERC or WECC requirement to plan corrective action for such extreme events. The extreme events are selected by their degree of credibility and their expected effect on the BES.

In this Assessment, the two extreme events studied were the simultaneous loss of three lines which share the same tower.

Table 11 shows that the loss of a triple-circuit tower which consists of Toluca-Hollywood 230kV lines 1 & 3 and Toluca-Hollywood 138kV Line 2 would not result in any overloads or any voltage violations. However, the loss of a triple-circuit tower which carries Rinaldi-Tarzana 230kV Lines 1 and 2 and Northridge-Tarzana 230kV Line 1 would result in local under-voltage conditions at RS-U (Tarzana) and RS-T (Canoga). These under-voltage conditions can be mitigated by direct load-tripping at RS-T.

16 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

Table 11. OUTCOME OF MULTIPLE CONTINGENCIES

Multiple Contingency Impacted Elements Study Year

Loss of Toluca – Hollywood 230kV Lines 1 & 3 None and Toluca-Hollywood 138kV Line 1

Loss of Rinaldi – Tarzana 230kV Lines 1 & 2 Local under-voltage @ RS-T and RS-U and Northridge-Tarzana 230kV Line 1 2015

Loss of Rinaldi – Tarzana 230kV Lines 1 & 2 and Northridge-Tarzana 230kV Line 1 with None direct load-tripping at RS T

17 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

Light Winter Scenarios. Heavy summer studies test the ability of LADWP’s transmission system to handle disturbances when equipment are most vulnerable to thermal overloads and the system is susceptible to under-voltage due to the heavy electricity demand. Light winter studies test the ability of the transmission system to handle over-voltage concerns because the network is intact but only modestly loaded. Operationally, LADWP imports electricity from the east and Intermountain and exports to the Pacific Northwest through the Pacific DC Intertie during the winter, but imports electricity from the east, Intermountain, and the Pacific Northwest during the summer. By investigating both summer and winter conditions, this 2010 Assessment provides a comprehensive test of LADWP’s transmission facilities to ensure these assets operate within their ratings and within their thermal, voltage, and stability limits.

Light winter scenarios for Winter 2011 and Winter 2015 were developed from the WECC- approved 2010-11 LW1A operating case which models the anticipated operating conditions with heavy power flows into the Pacific Northwest. The light winter studies were conducted in a manner identical to the approach used with the heavy summer studies.

Table 12 summarizes the power flows along major transmission corridors in these study cases that are relevant to this 2010 Assessment.

Table 12. POWER FLOWS ALONG MAJOR SOUTHERN CALIFORNIA TRANSMISSION CORRIDORS IN LIGHT WINTER STUDY CASES

Rating Transmission Corridor 2011 2015 (MW)

Pacific DC Intertie, south to north 1850 MW 1849 MW 3100 (Path 65) 60% 60% Intermountain DC 1746 MW 1746 MW 2400 (Path 27) 73% 73% East-of-the-Colorado River 3905 MW 3904 MW 9300 (Path 49) 42% 42% West-of-the-Colorado River 4693 MW 4692 MW 10623 (Path 46) 44% 44% Victorville-Lugo 500kV Line 1 645 MW 601 MW 2400 (Path 61) 27% 25% LADWP-SCE @ Sylmar 370 MW 276 MW 1600 (Path 41) 23% 17%

Adelanto-Toluca 500kV Line 1 Adelanto-Rinaldi 500kV Line 1 2904 MW 2907 MW Victorville-Rinaldi 500kV Line 1 TBD

Victorville-Century1 87kV Line 1 Victorville-Century2 87kV Line 1

18 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

Table 13 aggregates the receiving station bank loads according to their district assignments.

Table 13. DISTRICT LOADS IN LIGHT WINTER STUDY CASES (MW)

Service Area 2011 2015

Central 1141 1183 Southern 160 166 Valley 1041 1079

Total Receiving Station Load 2342 2428

Table 14 confirms the expectation that off-peak demand is served primarily from out-of-basin fossil resources acquired through ownership and long-term purchase agreements.

Table 14. GENERATION MIX IN LIGHT WINTER STUDY CASES (MW)

Resource Type Capacity 2011 2015 Pumped Storage 1595 (425) (382) Natural Gas 3677 1135 1085 Wind 285 92 183 Solar 210 0 0 Hydroelectric 221 50 50 Internal Generation 5987 852 936 % Total Generation 64% 25% 27% Hydroelectric 491 340 340 Wind 306 120 120 Solar 500 0 0 Coal 1681 1681 1681 Nuclear 387 387 387 External Generation 3365 2528 2528 % Total Generation 36% 75% 73% Total Generation 9352 3380 3464

For the winter conditions studied in 2011 and 2015, LADWP’s transmission facilities are expected to operate within their ratings and within their thermal and voltage limits for (N-0), (N-1), and (N-2) contingencies. Stability. The 2011, 2015, and 2020 heavy summer cases and the 2015 light winter study cases described in this 2010 Assessment were tested for transient and post-transient performance under (N-1) and (N-2) contingencies described in Appendix G. There were no violations and no stability limits in these studies. Typical plots from these studies are provided in Appendix I.

19 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

Recommendations

#1. Resolve potential overloads on Northridge-Tarzana 230kV Line 1 due to loss of Rinaldi-Tarzana 230kV Lines 1 & 2 for 2011 only.

• Implement a Load Shedding Program in RS-U (Tarzana) when Rinaldi-Tarzana 230kV Lines 1 & 2 are lost. The problem is resolved upon completion of the upgrade to increase the capacity of Northridge-Tarzana 230kV Line 1 prior to Summer 2012.

It is estimated that a load shed of 40 MW should be sufficient to mitigate overloading Northridge-Tarzana 230kV Line 1 in the event of this double contingency outage.

#2. Resolve potential overloads on Scattergood-Olympic 230kV Line 2 during a loss of Tarzana-Olympic 230kV & 138 kV Lines in Summer 2011, Summer 2012 and Summer 2013.

• Implement a selective load-shedding program at RS-K (Olympic) to relieve the overload. The problem is resolved upon completion of the new Scattergood-Olympic 230 kV Line 1 in June 2014.

It is estimated that a load shed of 60 MW should be sufficient to mitigate overloading Scattergood-Olympic 230kV Line 2 in the event of this double contingency outage.

#3. Resolve potential overloads on Scattergood-Olympic 230kV Line 2 during a loss of Rinaldi-Tarzana 230kV Lines 1 & 2 in Summer 2013 only.

• Implement a selective load-shedding program at RS-U (Tarzana) to relieve the overload. The problem is resolved upon completion of the new Scattergood-Olympic 230 kV Line 1 in June 2014.

It is estimated that a load shed of 40 MW should be sufficient to mitigate overloading Scattergood-Olympic 230kV Line 2 in the event of this double contingency outage.

#4. Resolve potential overloads on the Sylmar-Northridge 230 kV Line 1 during a loss of the Rinaldi-Tarzana 230kV Lines 1 & 2 in Summer 2013 only.

• Implement a selective load-shedding program at RS-U (Tarzana) to relieve the overload. The problem is resolved upon completion of the new Scattergood-Olympic 230 kV Line 1 in June 2014.

It is estimated that a load shed of 40 MW should be sufficient to mitigate overloading Northridge-Tarzana 230kV Line 1 in the event of this double contingency outage.

#5. Implementation of corrective action is not required by TPL-004 but this Assessment provides a recommendation to the Transmission Operator to implement a direct load shedding scheme at RS-T (Canoga) from 2014 onward. e

e Recommendation 5 in the 2010 Assessment is the same as Recommendation 5 in the 2009 Assessment. The 2009 Assessment evaluated only model year 2014 for this event, and the 2010 Assessment evaluated only model year 2015 for this event; the recommendation from the 2009 Assessment is still valid, so the recommendation indicating the earliest need to act (2014) is kept in the 2010 Assessment.

20 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

#6. Resolve potential overloads on the Olive-Northridge 230 kV Line 1 during a loss of the Sylmar-Haskell Canyon 230 kV Line 1 in Summer 2020.

Two projects are needed:

• Relocate the 230/115 kV Banks from Olive Switching Station to Haskell Canyon Switching Station.

Summary of load shed requirements at RS-U for loss of Rinaldi-Tarzana 230kV Lines 1 & 2

2011: 40MW (covers #1) 2012: no load shed needed 2013: 40MW (covers #3 and #4).

Implementation Plan for these Recommendations

#1: Design work has already commenced to increase the capacity of the Northridge- Tarzana 230kV Line 1. The work is budgeted and the expected in-service date is prior to Summer 2012. The Load Shedding Program in RS-U (Tarzana) is an interim solution that will work until the in-service date.

#2, #3 and #4: The Scattergood-Olympic 230kV Line 1 is budgeted and has an expected in-service date of June 2014. This project is too far out for the current budget cycle. It will appear in the 2011-2012 budget year. The Load Shedding Programs at RS-U (Tarzana) and RS-K (Olympic) are interim solutions that will work until the in-service date.

#5: Load-shedding programs are not capital budget item, and require minimal lead time, so implementation is done by Grid Operations.

#6: This project is too far out for the current budget cycle. It is expected to appear in the 2017-2018 budget year.

Comparison with Recommendations in the 2009 Ten-Year Transmission Assessment

Changes to previous recommendations

Note: recommendations are renumbered chronologically in each Assessment

Recommendation 1 stayed the same for both the 2009 and 2010 Assessment.f

Recommendation 3 in the 2010 Assessment is very similar Recommendation in the 2009 Assessment, but was delayed two years, and load shed was replaced by generation

f The upgrade of the Northridge-Tarzana 230kV Line 1 was modeled in the 2010 Assessment so no overload was reported after Summer 2011.

21 November 1, 2010 LADWP’s 2010 Ten-Year Transmission Assessment

dispatchg. The overload did not appear in 2011 because of lower load forecast in 2011 and a delay of the RS-C bypass from July 2012 to March 2014. Like the 2009 Assessment, the new Scattergood-Olympic 230kV Line #1 fixes the problem, but the new in-service date is July 2014 instead of July 2012.

Recommendation 2 in the 2010 Assessment is very similar to Recommendation 3 in the 2009 Assessment, but the overload persists two years longer, and load shed was replaced by generation dispatch. The overload persists because the in-service date of the new Scattergood-Olympic 230kV Line #1 is delayed two years to July 2014.

Recommendation 4 (in the 2009 Assessment) does not appear in the 2010 Assessment because the potential overload was relieved by a lower coincidental peak load at the Olympic Receiving Station. h

Recommendation 5 in the 2010 Assessment is the same as Recommendation 5 in the 2009 Assessment. The 2009 Assessment evaluated only model year 2014 for this event, and the 2010 Assessment evaluated only model year 2015 for this event; the recommendation from the 2009 Assessment is still valid, so the recommendation indicating the earliest need to act (2014) is kept it the 2010 Assessment.

New recommendations in the 2010 Assessment

Recommendation 4 (in the 2010 Assessment) : high loading on the same line was found in the 2009 Assessment, however it was just below the criteria to flag as a potential overload. The 2009 Assessment reported 98% while 2010 Assessment reports 101%.

Recommendation 6 (in the 2010 Assessment): this is the first Assessment to study 2020, when the overload occurs.

g Generation dispatch does not provide enough relief, so load shed was utilized. The effectiveness of generation dispatch was marginal in the 2009 Assessment, and the effectiveness of generation dispatch was not sufficient in the 2010 Assessment due to system changes such as delay of the RS-C bypass from July 2012 to March 2014. h This previous recommendation was to relieve a potential overload starting in 2018 of the Olympic 230/138kV transformer F due to the loss of the Olympic 230/138kV transformer E.

22 November 1, 2010

LADWP’s 2010 Ten-Year Transmission Assessment

Appendix A. NERC/WECC Planning Standards

A November 1, 2010

Standard TPL-001-0.1 — System Performance Under Normal Conditions

A. Introduction 1. Title: System Performance Under Normal (No Contingency) Conditions (Category A) 2. Number: TPL-001-0.1 3. Purpose: System simulations and associated assessments are needed periodically to ensure that reliable systems are developed that meet specified performance requirements with sufficient lead time, and continue to be modified or upgraded as necessary to meet present and future system needs. 4. Applicability: 4.1. Planning Authority 4.2. Transmission Planner 5. Effective Date: May 13, 2009 B. Requirements R1. The Planning Authority and Transmission Planner shall each demonstrate through a valid assessment that its portion of the interconnected transmission system is planned such that, with all transmission facilities in service and with normal (pre-contingency) operating procedures in effect, the Network can be operated to supply projected customer demands and projected Firm (non- recallable reserved) Transmission Services at all Demand levels over the range of forecast system demands, under the conditions defined in Category A of Table I. To be considered valid, the Planning Authority and Transmission Planner assessments shall: R1.1. Be made annually. R1.2. Be conducted for near-term (years one through five) and longer-term (years six through ten) planning horizons. R1.3. Be supported by a current or past study and/or system simulation testing that addresses each of the following categories, showing system performance following Category A of Table 1 (no contingencies). The specific elements selected (from each of the following categories) shall be acceptable to the associated Regional Reliability Organization(s). R1.3.1. Cover critical system conditions and study years as deemed appropriate by the entity performing the study. R1.3.2. Be conducted annually unless changes to system conditions do not warrant such analyses. R1.3.3. Be conducted beyond the five-year horizon only as needed to address identified marginal conditions that may have longer lead-time solutions. R1.3.4. Have established normal (pre-contingency) operating procedures in place. R1.3.5. Have all projected firm transfers modeled.

Adopted by NERC Board of Trustees: October 29, 2008 Page 1 of 5 Effective Date: May 13, 2009 Standard TPL-001-0.1 — System Performance Under Normal Conditions

R1.3.6. Be performed for selected demand levels over the range of forecast system demands. R1.3.7. Demonstrate that system performance meets Table 1 for Category A (no contingencies). R1.3.8. Include existing and planned facilities. R1.3.9. Include Reactive Power resources to ensure that adequate reactive resources are available to meet system performance. R1.4. Address any planned upgrades needed to meet the performance requirements of Category A. R2. When system simulations indicate an inability of the systems to respond as prescribed in Reliability Standard TPL-001-0_R1, the Planning Authority and Transmission Planner shall each: R2.1. Provide a written summary of its plans to achieve the required system performance as described above throughout the planning horizon. R2.1.1. Including a schedule for implementation. R2.1.2. Including a discussion of expected required in-service dates of facilities. R2.1.3. Consider lead times necessary to implement plans. R2.2. Review, in subsequent annual assessments, (where sufficient lead time exists), the continuing need for identified system facilities. Detailed implementation plans are not needed. R3. The Planning Authority and Transmission Planner shall each document the results of these reliability assessments and corrective plans and shall annually provide these to its respective NERC Regional Reliability Organization(s), as required by the Regional Reliability Organization. C. Measures M1. The Planning Authority and Transmission Planner shall have a valid assessment and corrective plans as specified in Reliability Standard TPL-001-0_R1 and TPL-001- 0_R2. M2. The Planning Authority and Transmission Planner shall have evidence it reported documentation of results of its Reliability Assessments and corrective plans per Reliability Standard TPL-001-0_R3. D. Compliance 1. Compliance Monitoring Process 1.1. Compliance Monitoring Responsibility Compliance Monitor: Regional Reliability Organization. Each Compliance Monitor shall report compliance and violations to NERC via the NERC Compliance Reporting Process. 1.2. Compliance Monitoring Period and Reset Time Frame

Adopted by NERC Board of Trustees: October 29, 2008 Page 2 of 5 Effective Date: May 13, 2009 Standard TPL-001-0.1 — System Performance Under Normal Conditions

Annually 1.3. Data Retention None specified. 1.4. Additional Compliance Information

2. Levels of Non-Compliance 2.1. Level 1: Not applicable. 2.2. Level 2: A valid assessment and corrective plan for the longer-term planning horizon is not available. 2.3. Level 3: Not applicable. 2.4. Level 4: A valid assessment and corrective plan for the near-term planning horizon is not available. E. Regional Differences 1. None identified.

Version History Version Date Action Change Tracking 0 April 1, 2005 Effective Date New 0 February 8, 2005 BOT Approval Revised 0 June 3, 2005 Fixed reference in M1 to read TPL-001-0 R2.1 Errata and TPL-001-0 R2.2 0 July 24, 2007 Corrected reference in M1. to read TPL-001-0 Errata R1 and TPL-001-0 R2. 0.1 October 29, 2008 BOT adopted errata changes; updated version Errata number to “0.1” 0.1 May 13, 2009 FERC Approved – Updated Effective Date and Revised Footer

Adopted by NERC Board of Trustees: October 29, 2008 Page 3 of 5 Effective Date: May 13, 2009 Standard TPL-001-0.1 — System Performance Under Normal Conditions

Table I. Transmission System Standards – Normal and Emergency Conditions

Contingencies System Limits or Impacts Category System Stable and both Thermal Loss of

and Voltage Demand or Cascading Initiating Event(s) and Contingency Limits within Curtailed Firm Outages Element(s) Applicable Transfers Rating a

A All Facilities in Service Yes No No No Contingencies Single Line Ground (SLG) or 3-Phase (3Ø) B Fault, with Normal Clearing: Yes No b No Event resulting in 1. Generator Yes No b No the loss of a single 2. Transmission Circuit Yes No b No element. 3. Transformer Yes No b No Loss of an Element without a Fault

e Single Pole Block, Normal Clearing : b 4. Single Pole (dc) Line Yes No No e SLG Fault, with Normal Clearing : C Yes Planned/ No 1. Bus Section c Event(s) resulting Controlled in the loss of two 2. Breaker (failure or internal Fault) Yes Planned/ No or more (multiple) Controlledc e elements. SLG or 3Ø Fault, with Normal Clearing , Manual System Adjustments, followed by another SLG or 3Ø Fault, with Normal e Yes Planned/ No Clearing : Controlledc 3. Category B (B1, B2, B3, or B4) contingency, manual system adjustments, followed by another Category B (B1, B2, B3, or B4) contingency e Bipolar Block, with Normal Clearing : Planned/ 4. Bipolar (dc) Line Fault (non 3Ø), with c e Yes Controlled No Normal Clearing :

5. Any two circuits of a multiple circuit Yes Planned/ No f towerline Controlledc e SLG Fault, with Delayed Clearing (stuck breaker or protection system failure): Yes Planned/ No 6. Generator c Controlled

Yes Planned/ No 7. Transformer c Controlled

Yes Planned/ No 8. Transmission Circuit c Controlled

9. Bus Section Yes Planned/ No Controlledc

Adopted by NERC Board of Trustees: October 29, 2008 Page 4 of 5 Effective Date: May 13, 2009 Standard TPL-001-0.1 — System Performance Under Normal Conditions

d e D 3Ø Fault, with Delayed Clearing (stuck breaker or protection system Evaluate for risks and failure): consequences. Extreme event resulting in two or more (multiple) 1. Generator 3. Transformer . May involve substantial loss of elements removed or customer Demand and Cascading out of service. 2. Transmission Circuit 4. Bus Section generation in a widespread area or areas. . Portions or all of the e interconnected systems may 3Ø Fault, with Normal Clearing : or may not achieve a new, 5. Breaker (failure or internal Fault) stable operating point. . Evaluation of these events may require joint studies with 6. Loss of towerline with three or more circuits neighboring systems. 7. All transmission lines on a common right-of way 8. Loss of a substation (one voltage level plus transformers) 9. Loss of a switching station (one voltage level plus transformers) 10. Loss of all generating units at a station 11. Loss of a large Load or major Load center 12. Failure of a fully redundant Special Protection System (or remedial action scheme) to operate when required 13. Operation, partial operation, or misoperation of a fully redundant Special Protection System (or Remedial Action Scheme) in response to an event or abnormal system condition for which it was not intended to operate 14. Impact of severe power swings or oscillations from Disturbances in another Regional Reliability Organization.

a) Applicable rating refers to the applicable Normal and Emergency facility thermal Rating or system voltage limit as determined and consistently applied by the system or facility owner. Applicable Ratings may include Emergency Ratings applicable for short durations as required to permit operating steps necessary to maintain system control. All Ratings must be established consistent with applicable NERC Reliability Standards addressing Facility Ratings. b) Planned or controlled interruption of electric supply to radial customers or some local Network customers, connected to or supplied by the Faulted element or by the affected area, may occur in certain areas without impacting the overall reliability of the interconnected transmission systems. To prepare for the next contingency, system adjustments are permitted, including curtailments of contracted Firm (non-recallable reserved) electric power Transfers. c) Depending on system design and expected system impacts, the controlled interruption of electric supply to customers (load shedding), the planned removal from service of certain generators, and/or the curtailment of contracted Firm (non-recallable reserved) electric power Transfers may be necessary to maintain the overall reliability of the interconnected transmission systems. d) A number of extreme contingencies that are listed under Category D and judged to be critical by the transmission planning entity(ies) will be selected for evaluation. It is not expected that all possible facility outages under each listed contingency of Category D will be evaluated. e) Normal clearing is when the protection system operates as designed and the Fault is cleared in the time normally expected with proper functioning of the installed protection systems. Delayed clearing of a Fault is due to failure of any protection system component such as a relay, circuit breaker, or current transformer, and not because of an intentional design delay. f) System assessments may exclude these events where multiple circuit towers are used over short distances (e.g., station entrance, river crossings) in accordance with Regional exemption criteria.

Adopted by NERC Board of Trustees: October 29, 2008 Page 5 of 5 Effective Date: May 13, 2009 Standard TPL-002-0b — System Performance Following Loss of a Single BES Element

A. Introduction 1. Title: System Performance Following Loss of a Single Bulk Electric System Element (Category B) 2. Number: TPL-002-0b 3. Purpose: System simulations and associated assessments are needed periodically to ensure that reliable systems are developed that meet specified performance requirements with sufficient lead time, and continue to be modified or upgraded as necessary to meet present and future system needs. 4. Applicability: 4.1. Planning Authority 4.2. Transmission Planner 5. Effective Date: Immediately after approval of applicable regulatory authorities. B. Requirements R1. The Planning Authority and Transmission Planner shall each demonstrate through a valid assessment that its portion of the interconnected transmission system is planned such that the Network can be operated to supply projected customer demands and projected Firm (non- recallable reserved) Transmission Services, at all demand levels over the range of forecast system demands, under the contingency conditions as defined in Category B of Table I. To be valid, the Planning Authority and Transmission Planner assessments shall: R1.1. Be made annually. R1.2. Be conducted for near-term (years one through five) and longer-term (years six through ten) planning horizons. R1.3. Be supported by a current or past study and/or system simulation testing that addresses each of the following categories,, showing system performance following Category B of Table 1 (single contingencies). The specific elements selected (from each of the following categories) for inclusion in these studies and simulations shall be acceptable to the associated Regional Reliability Organization(s). R1.3.1. Be performed and evaluated only for those Category B contingencies that would produce the more severe System results or impacts. The rationale for the contingencies selected for evaluation shall be available as supporting information. An explanation of why the remaining simulations would produce less severe system results shall be available as supporting information. R1.3.2. Cover critical system conditions and study years as deemed appropriate by the responsible entity. R1.3.3. Be conducted annually unless changes to system conditions do not warrant such analyses. R1.3.4. Be conducted beyond the five-year horizon only as needed to address identified marginal conditions that may have longer lead-time solutions. R1.3.5. Have all projected firm transfers modeled. R1.3.6. Be performed and evaluated for selected demand levels over the range of forecast system Demands.

Adopted by NERC Board of Trustees: November 5, 2009 Page 1 of 10 Effective Date: TBD Standard TPL-002-0b — System Performance Following Loss of a Single BES Element

R1.3.7. Demonstrate that system performance meets Category B contingencies. R1.3.8. Include existing and planned facilities. R1.3.9. Include Reactive Power resources to ensure that adequate reactive resources are available to meet system performance. R1.3.10. Include the effects of existing and planned protection systems, including any backup or redundant systems. R1.3.11. Include the effects of existing and planned control devices. R1.3.12. Include the planned (including maintenance) outage of any bulk electric equipment (including protection systems or their components) at those demand levels for which planned (including maintenance) outages are performed. R1.4. Address any planned upgrades needed to meet the performance requirements of Category B of Table I. R1.5. Consider all contingencies applicable to Category B. R2. When System simulations indicate an inability of the systems to respond as prescribed in Reliability Standard TPL-002-0_R1, the Planning Authority and Transmission Planner shall each: R2.1. Provide a written summary of its plans to achieve the required system performance as described above throughout the planning horizon: R2.1.1. Including a schedule for implementation. R2.1.2. Including a discussion of expected required in-service dates of facilities. R2.1.3. Consider lead times necessary to implement plans. R2.2. Review, in subsequent annual assessments, (where sufficient lead time exists), the continuing need for identified system facilities. Detailed implementation plans are not needed. R3. The Planning Authority and Transmission Planner shall each document the results of its Reliability Assessments and corrective plans and shall annually provide the results to its respective Regional Reliability Organization(s), as required by the Regional Reliability Organization. C. Measures M1. The Planning Authority and Transmission Planner shall have a valid assessment and corrective plans as specified in Reliability Standard TPL-002-0_R1 and TPL-002-0_R2. M2. The Planning Authority and Transmission Planner shall have evidence it reported documentation of results of its reliability assessments and corrective plans per Reliability Standard TPL-002-0_R3. D. Compliance 1. Compliance Monitoring Process 1.1. Compliance Monitoring Responsibility Compliance Monitor: Regional Reliability Organizations. Each Compliance Monitor shall report compliance and violations to NERC via the NERC Compliance Reporting Process.

Adopted by NERC Board of Trustees: November 5, 2009 Page 2 of 10 Effective Date: TBD Standard TPL-002-0b — System Performance Following Loss of a Single BES Element

1.2. Compliance Monitoring Period and Reset Timeframe Annually.

1.3. Data Retention None specified. 1.4. Additional Compliance Information None. 2. Levels of Non-Compliance 2.1. Level 1: Not applicable. 2.2. Level 2: A valid assessment and corrective plan for the longer-term planning horizon is not available. 2.3. Level 3: Not applicable. 2.4. Level 4: A valid assessment and corrective plan for the near-term planning horizon is not available. E. Regional Differences 1. None identified.

Version History Version Date Action Change Tracking 0 April 1, 2005 Effective Date New 0a October 23, Added Appendix 1 – Interpretation of TPL- Revised 2008 002-0 Requirements R1.3.2 and R1.3.12 and TPL-003-0 Requirements R1.3.2 and R1.3.12 for Ameren and MISO

0b November 5, Added Appendix 2 – Interpretation of Addition 2009 R1.3.10 approved by BOT on November 5, 2009

Adopted by NERC Board of Trustees: November 5, 2009 Page 3 of 10 Effective Date: TBD Standard TPL-002-0b — System Performance Following Loss of a Single BES Element

Table I. Transmission System Standards — Normal and Emergency Conditions

Contingencies System Limits or Impacts Category System Stable and both Thermal and Loss of Demand

Voltage or Cascading Initiating Event(s) and Contingency Limits within Curtailed Firm Outages Element(s) Applicable Transfers Rating a

A All Facilities in Service Yes No No No Contingencies Single Line Ground (SLG) or 3-Phase (3Ø) Fault, B with Normal Clearing: Yes No b No Event resulting in 1. Generator Yes No b No the loss of a single 2. Transmission Circuit Yes No b No element. 3. Transformer Yes No b No Loss of an Element without a Fault.

e Single Pole Block, Normal Clearing : b 4. Single Pole (dc) Line Yes No No e SLG Fault, with Normal Clearing : C Yes Planned/ No 1. Bus Section c Event(s) resulting in Controlled the loss of two or 2. Breaker (failure or internal Fault) Yes Planned/ No more (multiple) Controlledc e elements. SLG or 3Ø Fault, with Normal Clearing , Manual System Adjustments, followed by another SLG or e 3Ø Fault, with Normal Clearing : Yes Planned/ No 3. Category B (B1, B2, B3, or B4) Controlledc contingency, manual system adjustments, followed by another Category B (B1, B2, B3, or B4) contingency e Bipolar Block, with Normal Clearing : Planned/ 4. Bipolar (dc) Line Fault (non 3Ø), with c e Yes Controlled No Normal Clearing :

Yes Planned/ No 7. Transformer c Controlled

Yes Planned/ No 8. Transmission Circuit c Controlled

9. Bus Section Yes Planned/ No Controlledc

Adopted by NERC Board of Trustees: November 5, 2009 Page 4 of 10 Effective Date: TBD Standard TPL-002-0a — System Performance Following Loss of a Single BES Element

d e D 3Ø Fault, with Delayed Clearing (stuck breaker or protection system Evaluate for risks and failure): consequences. Extreme event resulting in two or more (multiple) 1. Generator 3. Transformer . May involve substantial loss of elements removed or customer Demand and Cascading out of service 2. Transmission Circuit 4. Bus Section generation in a widespread area or areas. e 3Ø Fault, with Normal Clearing : . Portions or all of the interconnected systems may 5. Breaker (failure or internal Fault) or may not achieve a new, stable operating point. 6. Loss of towerline with three or more circuits . Evaluation of these events may 7. All transmission lines on a common right-of way require joint studies with neighboring systems. 8. Loss of a substation (one voltage level plus transformers) 9. Loss of a switching station (one voltage level plus transformers) 10. Loss of all generating units at a station 11. Loss of a large Load or major Load center 12. Failure of a fully redundant Special Protection System (or remedial action scheme) to operate when required 13. Operation, partial operation, or misoperation of a fully redundant Special Protection System (or Remedial Action Scheme) in response to an event or abnormal system condition for which it was not intended to operate 14. Impact of severe power swings or oscillations from Disturbances in another Regional Reliability Organization.

a) Applicable rating refers to the applicable Normal and Emergency facility thermal Rating or system voltage limit as determined and consistently applied by the system or facility owner. Applicable Ratings may include Emergency Ratings applicable for short durations as required to permit operating steps necessary to maintain system control. All Ratings must be established consistent with applicable NERC Reliability Standards addressing Facility Ratings. b) Planned or controlled interruption of electric supply to radial customers or some local Network customers, connected to or supplied by the Faulted element or by the affected area, may occur in certain areas without impacting the overall reliability of the interconnected transmission systems. To prepare for the next contingency, system adjustments are permitted, including curtailments of contracted Firm (non-recallable reserved) electric power Transfers. c) Depending on system design and expected system impacts, the controlled interruption of electric supply to customers (load shedding), the planned removal from service of certain generators, and/or the curtailment of contracted Firm (non- recallable reserved) electric power Transfers may be necessary to maintain the overall reliability of the interconnected transmission systems. d) A number of extreme contingencies that are listed under Category D and judged to be critical by the transmission planning entity(ies) will be selected for evaluation. It is not expected that all possible facility outages under each listed contingency of Category D will be evaluated. e) Normal clearing is when the protection system operates as designed and the Fault is cleared in the time normally expected with proper functioning of the installed protection systems. Delayed clearing of a Fault is due to failure of any protection system component such as a relay, circuit breaker, or current transformer, and not because of an intentional design delay. f) System assessments may exclude these events where multiple circuit towers are used over short distances (e.g., station entrance, river crossings) in accordance with Regional exemption criteria.

Adopted by NERC Board of Trustees: February 8, 2005 Page 5 of 10 Effective Date: TBD Standard TPL-002-0a — System Performance Following Loss of a Single BES Element

Appendix 1 Interpretation of TPL-002-0 Requirements R1.3.2 and R1.3.12 and TPL-003-0 Requirements R1.3.2 and R1.3.12 for Ameren and MISO NERC received two requests for interpretation of identical requirements (Requirements R1.3.2 and R1.3.12) in TPL-002-0 and TPL-003-0 from the Midwest ISO and Ameren. These requirements state:

TPL-002-0: [To be valid, the Planning Authority and Transmission Planner assessments shall:] R1.3 Be supported by a current or past study and/or system simulation testing that addresses each of the following categories, showing system performance following Category B of Table 1 (single contingencies). The specific elements selected (from each of the following categories) for inclusion in these studies and simulations shall be acceptable to the associated Regional Reliability Organization(s). R1.3.2 Cover critical system conditions and study years as deemed appropriate by the responsible entity. R1.3.12 Include the planned (including maintenance) outage of any bulk electric equipment (including protection systems or their components) at those demand levels for which planned (including maintenance) outages are performed.

TPL-003-0: [To be valid, the Planning Authority and Transmission Planner assessments shall:] R1.3 Be supported by a current or past study and/or system simulation testing that addresses each of the following categories, showing system performance following Category C of Table 1 (multiple contingencies). The specific elements selected (from each of the following categories) for inclusion in these studies and simulations shall be acceptable to the associated Regional Reliability Organization(s). R1.3.2 Cover critical system conditions and study years as deemed appropriate by the responsible entity. R1.3.12 Include the planned (including maintenance) outage of any bulk electric equipment (including protection systems or their components) at those demand levels for which planned (including maintenance) outages are performed.

Requirement R1.3.2

Request for Interpretation of TPL-002-0 and TPL-003-0 Requirement R1.3.2 Received from Ameren on July 25, 2007: Ameren specifically requests clarification on the phrase, ‘critical system conditions’ in R1.3.2. Ameren asks if compliance with R1.3.2 requires multiple contingent generating unit Outages as part of possible generation dispatch scenarios describing critical system conditions for which the system shall be planned and modeled in accordance with the contingency definitions included in Table 1.

Adopted by NERC Board of Trustees: February 8, 2005 Page 6 of 10 Effective Date: TBD Standard TPL-002-0a — System Performance Following Loss of a Single BES Element

Request for Interpretation of TPL-002-0 and TPL-003-0 Requirement R1.3.2 Received from MISO on August 9, 2007: MISO asks if the TPL standards require that any specific dispatch be applied, other than one that is representative of supply of firm demand and transmission service commitments, in the modeling of system contingencies specified in Table 1 in the TPL standards. MISO then asks if a variety of possible dispatch patterns should be included in planning analyses including a probabilistically based dispatch that is representative of generation deficiency scenarios, would it be an appropriate application of the TPL standard to apply the transmission contingency conditions in Category B of Table 1 to these possible dispatch pattern. The following interpretation of TPL-002-0 and TPL-003-0 Requirement R1.3.2 was developed by the NERC Planning Committee on March 13, 2008: The selection of a credible generation dispatch for the modeling of critical system conditions is within the discretion of the Planning Authority. The Planning Authority was renamed “Planning Coordinator” (PC) in the Functional Model dated February 13, 2007. (TPL -002 and -003 use the former “Planning Authority” name, and the Functional Model terminology was a change in name only and did not affect responsibilities.)  Under the Functional Model, the Planning Coordinator “Provides and informs Resource Planners, Transmission Planners, and adjacent Planning Coordinators of the methodologies and tools for the simulation of the transmission system” while the Transmission Planner “Receives from the Planning Coordinator methodologies and tools for the analysis and development of transmission expansion plans.” A PC’s selection of “critical system conditions” and its associated generation dispatch falls within the purview of “methodology.” Furthermore, consistent with this interpretation, a Planning Coordinator would formulate critical system conditions that may involve a range of critical generator unit outages as part of the possible generator dispatch scenarios. Both TPL-002-0 and TPL-003-0 have a similar measure M1: M1. The Planning Authority and Transmission Planner shall have a valid assessment and corrective plans as specified in Reliability Standard TPL-002-0_R1 [or TPL-003-0_R1] and TPL-002-0_R2 [or TPL-003-0_R2].” The Regional Reliability Organization (RRO) is named as the Compliance Monitor in both standards. Pursuant to Federal Energy Regulatory Commission (FERC) Order 693, FERC eliminated the RRO as the appropriate Compliance Monitor for standards and replaced it with the Regional Entity (RE). See paragraph 157 of Order 693. Although the referenced TPL standards still include the reference to the RRO, to be consistent with Order 693, the RRO is replaced by the RE as the Compliance Monitor for this interpretation. As the Compliance Monitor, the RE determines what a “valid assessment” means when evaluating studies based upon specific sub-requirements in R1.3 selected by the Planning Coordinator and the Transmission Planner. If a PC has Transmission Planners in more than one region, the REs must coordinate among themselves on compliance matters.

Adopted by NERC Board of Trustees: February 8, 2005 Page 7 of 10 Effective Date: TBD Standard TPL-002-0a — System Performance Following Loss of a Single BES Element

Requirement R1.3.12

Request for Interpretation of TPL-002-0 and TPL-003-0 Requirement R1.3.12 Received from Ameren on July 25, 2007: Ameren also asks how the inclusion of planned outages should be interpreted with respect to the contingency definitions specified in Table 1 for Categories B and C. Specifically, Ameren asks if R1.3.12 requires that the system be planned to be operated during those conditions associated with planned outages consistent with the performance requirements described in Table 1 plus any unidentified outage. Request for Interpretation of TPL-002-0 and TPL-003-0 Requirement R1.3.12 Received from MISO on August 9, 2007: MISO asks if the term “planned outages” means only already known/scheduled planned outages that may continue into the planning horizon, or does it include potential planned outages not yet scheduled that may occur at those demand levels for which planned (including maintenance) outages are performed? If the requirement does include not yet scheduled but potential planned outages that could occur in the planning horizon, is the following a proper interpretation of this provision? The system is adequately planned and in accordance with the standard if, in order for a system operator to potentially schedule such a planned outage on the future planned system, planning studies show that a system adjustment (load shed, re-dispatch of generating units in the interconnection, or system reconfiguration) would be required concurrent with taking such a planned outage in order to prepare for a Category B contingency (single element forced out of service)? In other words, should the system in effect be planned to be operated as for a Category C3 n-2 event, even though the first event is a planned base condition? If the requirement is intended to mean only known and scheduled planned outages that will occur or may continue into the planning horizon, is this interpretation consistent with the original interpretation by NERC of the standard as provided by NERC in response to industry questions in the Phase I development of this standard1? The following interpretation of TPL-002-0 and TPL-003-0 Requirement R1.3.12 was developed by the NERC Planning Committee on March 13, 2008: This provision was not previously interpreted by NERC since its approval by FERC and other regulatory authorities. TPL-002-0 and TPL-003-0 explicitly provide that the inclusion of planned (including maintenance) outages of any bulk electric equipment at demand levels for which the planned outages are required. For studies that include planned outages, compliance with the contingency assessment for TPL- 002-0 and TPL-003-0 as outlined in Table 1 would include any necessary system adjustments which might be required to accommodate planned outages since a planned outage is not a “contingency” as defined in the NERC Glossary of Terms Used in Standards.

Adopted by NERC Board of Trustees: February 8, 2005 Page 8 of 10 Effective Date: TBD Standard TPL-002-0a — System Performance Following Loss of a Single BES Element

Appendix 2

Requirement Number and Text of Requirement

R1.3. Be supported by a current or past study and/or system simulation testing that addresses each of the following categories, showing system performance following Category B of Table 1 (single contingencies). The specific elements selected (from each of the following categories) for inclusion in these studies and simulations shall be acceptable to the associated Regional Reliability Organization(s). R1.3.10. Include the effects of existing and planned protection systems, including any backup or redundant systems.

Background Information for Interpretation

Requirement R1.3 and sub-requirement R1.3.10 of standard TPL-002-0a contain three key obligations: 1. That the assessment is supported by “study and/or system simulation testing that addresses each the following categories, showing system performance following Category B of Table 1 (single contingencies).” 2. “…these studies and simulations shall be acceptable to the associated Regional Reliability Organization(s).” 3. “Include the effects of existing and planned protection systems, including any backup or redundant systems.” Category B of Table 1 (single Contingencies) specifies: Single Line Ground (SLG) or 3-Phase (3Ø) Fault, with Normal Clearing: 1. Generator 2. Transmission Circuit 3. Transformer Loss of an Element without a Fault. Single Pole Block, Normal Clearinge: 4. Single Pole (dc) Line Note e specifies: e) Normal Clearing is when the protection system operates as designed and the Fault is cleared in the time normally expected with proper functioning of the installed protection systems. Delayed clearing of a Fault is due to failure of any protection system component such as a relay, circuit breaker, or current transformer, and not because of an intentional design delay. The NERC Glossary of Terms defines Normal Clearing as “A protection system operates as designed and the fault is cleared in the time normally expected with proper functioning of the installed protection systems.”

Conclusion

TPL-002-0a requires that System studies or simulations be made to assess the impact of single Contingency operation with Normal Clearing. TPL-002-0a R1.3.10 does require that all elements expected to be removed from service through normal operations of the Protection Systems be removed in simulations. This standard does not require an assessment of the Transmission System performance due to a Protection System failure or Protection System misoperation. Protection System failure or Protection System misoperation is addressed in TPL-003-0 — System Performance following Loss of Two or More Bulk

Adopted by NERC Board of Trustees: February 8, 2005 Page 9 of 10 Effective Date: TBD Standard TPL-002-0a — System Performance Following Loss of a Single BES Element

Electric System Elements (Category C) and TPL-004-0 — System Performance Following Extreme Events Resulting in the Loss of Two or More Bulk Electric System Elements (Category D). TPL-002-0a R1.3.10 does not require simulating anything other than Normal Clearing when assessing the impact of a Single Line Ground (SLG) or 3-Phase (3Ø) Fault on the performance of the Transmission System. In regards to PacifiCorp’s comments on the material impact associated with this interpretation, the interpretation team has the following comment: Requirement R2.1 requires “a written summary of plans to achieve the required system performance,” including a schedule for implementation and an expected in-service date that considers lead times necessary to implement the plan. Failure to provide such summary may lead to noncompliance that could result in penalties and sanctions.

Adopted by NERC Board of Trustees: February 8, 2005 Page 10 of 10 Effective Date: TBD Standard TPL-003-0a — System Performance Following Loss of Two or More BES Elements

A. Introduction 1. Title: System Performance Following Loss of Two or More Bulk Electric System Elements (Category C) 2. Number: TPL-003-0a 3. Purpose: System simulations and associated assessments are needed periodically to ensure that reliable systems are developed that meet specified performance requirements, with sufficient lead time and continue to be modified or upgraded as necessary to meet present and future System needs. 4. Applicability: 4.1. Planning Authority 4.2. Transmission Planner 5. Effective Date: April 23, 2010 B. Requirements R1. The Planning Authority and Transmission Planner shall each demonstrate through a valid assessment that its portion of the interconnected transmission systems is planned such that the network can be operated to supply projected customer demands and projected Firm (non- recallable reserved) Transmission Services, at all demand Levels over the range of forecast system demands, under the contingency conditions as defined in Category C of Table I (attached). The controlled interruption of customer Demand, the planned removal of generators, or the Curtailment of firm (non-recallable reserved) power transfers may be necessary to meet this standard. To be valid, the Planning Authority and Transmission Planner assessments shall: R1.1. Be made annually. R1.2. Be conducted for near-term (years one through five) and longer-term (years six through ten) planning horizons. R1.3. Be supported by a current or past study and/or system simulation testing that addresses each of the following categories, showing system performance following Category C of Table 1 (multiple contingencies). The specific elements selected (from each of the following categories) for inclusion in these studies and simulations shall be acceptable to the associated Regional Reliability Organization(s). R1.3.1. Be performed and evaluated only for those Category C contingencies that would produce the more severe system results or impacts. The rationale for the contingencies selected for evaluation shall be available as supporting information. An explanation of why the remaining simulations would produce less severe system results shall be available as supporting information. R1.3.2. Cover critical system conditions and study years as deemed appropriate by the responsible entity. R1.3.3. Be conducted annually unless changes to system conditions do not warrant such analyses. R1.3.4. Be conducted beyond the five-year horizon only as needed to address identified marginal conditions that may have longer lead-time solutions. R1.3.5. Have all projected firm transfers modeled.

Adopted by NERC Board of Trustees: October 23, 2008 Page 1 of 8 Effective Date: April 23, 2010 Standard TPL-003-0a — System Performance Following Loss of Two or More BES Elements

R1.3.6. Be performed and evaluated for selected demand levels over the range of forecast system demands. R1.3.7. Demonstrate that System performance meets Table 1 for Category C contingencies. R1.3.8. Include existing and planned facilities. R1.3.9. Include Reactive Power resources to ensure that adequate reactive resources are available to meet System performance. R1.3.10. Include the effects of existing and planned protection systems, including any backup or redundant systems. R1.3.11. Include the effects of existing and planned control devices. R1.3.12. Include the planned (including maintenance) outage of any bulk electric equipment (including protection systems or their components) at those Demand levels for which planned (including maintenance) outages are performed. R1.4. Address any planned upgrades needed to meet the performance requirements of Category C. R1.5. Consider all contingencies applicable to Category C. R2. When system simulations indicate an inability of the systems to respond as prescribed in Reliability Standard TPL-003-0_R1, the Planning Authority and Transmission Planner shall each: R2.1. Provide a written summary of its plans to achieve the required system performance as described above throughout the planning horizon: R2.1.1. Including a schedule for implementation. R2.1.2. Including a discussion of expected required in-service dates of facilities. R2.1.3. Consider lead times necessary to implement plans. R2.2. Review, in subsequent annual assessments, (where sufficient lead time exists), the continuing need for identified system facilities. Detailed implementation plans are not needed. R3. The Planning Authority and Transmission Planner shall each document the results of these Reliability Assessments and corrective plans and shall annually provide these to its respective NERC Regional Reliability Organization(s), as required by the Regional Reliability Organization. C. Measures M1. The Planning Authority and Transmission Planner shall have a valid assessment and corrective plans as specified in Reliability Standard TPL-003-0_R1 and TPL-003-0_R2. M2. The Planning Authority and Transmission Planner shall have evidence it reported documentation of results of its reliability assessments and corrective plans per Reliability Standard TPL-003-0_R3.

Adopted by NERC Board of Trustees: October 23, 2008 Page 2 of 8 Effective Date: April 23, 2010 Standard TPL-003-0a — System Performance Following Loss of Two or More BES Elements

D. Compliance 1. Compliance Monitoring Process 1.1. Compliance Monitoring Responsibility Compliance Monitor: Regional Reliability Organizations.

1.2. Compliance Monitoring Period and Reset Timeframe Annually. 1.3. Data Retention None specified. 1.4. Additional Compliance Information None. 2. Levels of Non-Compliance 2.1. Level 1: Not applicable. 2.2. Level 2: A valid assessment and corrective plan for the longer-term planning horizon is not available. 2.3. Level 3: Not applicable. 2.4. Level 4: A valid assessment and corrective plan for the near-term planning horizon is not available. E. Regional Differences 1. None identified.

Version History Version Date Action Change Tracking 0 April 1, 2005 Effective Date New 0 April 1, 2005 Add parenthesis to item “e” on page 8. Errata 0a October 23, Added Appendix 1 – Interpretation of TPL- Revised 2008 002-0 Requirements R1.3.2 and R1.3.12 and TPL-003-0 Requirements R1.3.2 and R1.3.12 for Ameren and MISO 0a April 23, 2010 FERC approval of interpretation of TPL- Interpretation 003-0 R1.3.12

Adopted by NERC Board of Trustees: October 23, 2008 Page 3 of 8 Effective Date: April 23, 2010 Standard TPL-003-0a — System Performance Following Loss of Two or More BES Elements

Table I. Transmission System Standards – Normal and Emergency Conditions

Contingencies System Limits or Impacts Category System Stable and both Thermal and Loss of Demand

Voltage or Cascading c Initiating Event(s) and Contingency Limits within Curtailed Firm Outages Element(s) Applicable Transfers Rating a

5. Any two circuits of a multiple circuit f Yes Planned/ No towerline Controlledc e SLG Fault, with Delayed Clearing (stuck breaker or protection system failure): Yes Planned/ No 6. Generator c Controlled

Yes Planned/ No 7. Transformer c Controlled

Yes Planned/ No 8. Transmission Circuit c Controlled

9. Bus Section Yes Planned/ No Controlledc

Adopted by NERC Board of Trustees: October 23, 2008 Page 4 of 8 Effective Date: April 23, 2010 Standard TPL-003-0a — System Performance Following Loss of Two or More BES Elements

d e D 3Ø Fault, with Delayed Clearing (stuck breaker or protection system Evaluate for risks and failure): consequences. Extreme event resulting in . two or more (multiple) 1. Generator 3. Transformer May involve substantial loss of elements removed or customer Demand and Cascading out of service 2. Transmission Circuit 4. Bus Section generation in a widespread area or areas. . Portions or all of the e interconnected systems may 3Ø Fault, with Normal Clearing : or may not achieve a new, 5. Breaker (failure or internal Fault) stable operating point. . Evaluation of these events may require joint studies with 6. Loss of towerline with three or more circuits neighboring systems. 7. All transmission lines on a common right-of way 8. Loss of a substation (one voltage level plus transformers) 9. Loss of a switching station (one voltage level plus transformers) 10. Loss of all generating units at a station 11. Loss of a large Load or major Load center 12. Failure of a fully redundant Special Protection System (or remedial action scheme) to operate when required 13. Operation, partial operation, or misoperation of a fully redundant Special Protection System (or Remedial Action Scheme) in response to an event or abnormal system condition for which it was not intended to operate 14. Impact of severe power swings or oscillations from Disturbances in another Regional Reliability Organization.

a) Applicable rating refers to the applicable Normal and Emergency facility thermal Rating or system voltage limit as determined and consistently applied by the system or facility owner. Applicable Ratings may include Emergency Ratings applicable for short durations as required to permit operating steps necessary to maintain system control. All Ratings must be established consistent with applicable NERC Reliability Standards addressing Facility Ratings. b) Planned or controlled interruption of electric supply to radial customers or some local Network customers, connected to or supplied by the Faulted element or by the affected area, may occur in certain areas without impacting the overall reliability of the interconnected transmission systems. To prepare for the next contingency, system adjustments are permitted, including curtailments of contracted Firm (non-recallable reserved) electric power Transfers. c) Depending on system design and expected system impacts, the controlled interruption of electric supply to customers (load shedding), the planned removal from service of certain generators, and/or the curtailment of contracted Firm (non- recallable reserved) electric power transfers may be necessary to maintain the overall reliability of the interconnected transmission systems. d) A number of extreme contingencies that are listed under Category D and judged to be critical by the transmission planning entity(ies) will be selected for evaluation. It is not expected that all possible facility outages under each listed contingency of Category D will be evaluated. e) Normal clearing is when the protection system operates as designed and the Fault is cleared in the time normally expected with proper functioning of the installed protection systems. Delayed clearing of a Fault is due to failure of any protection system component such as a relay, circuit breaker, or current transformer, and not because of an intentional design delay. f) System assessments may exclude these events where multiple circuit towers are used over short distances (e.g., station entrance, river crossings) in accordance with Regional exemption criteria.

Adopted by NERC Board of Trustees: October 23, 2008 Page 5 of 8 Effective Date: April 23, 2010 Standard TPL-003-0a — System Performance Following Loss of Two or More BES Elements

Requirement R1.3.2

Adopted by NERC Board of Trustees: October 23, 2008 Page 6 of 8 Effective Date: April 23, 2010 Standard TPL-003-0a — System Performance Following Loss of Two or More BES Elements

Request for Interpretation of TPL-002-0 and TPL-003-0 Requirement R1.3.2 Received from MISO on August 9, 2007: MISO asks if the TPL standards require that any specific dispatch be applied, other than one that is representative of supply of firm demand and transmission service commitments, in the modeling of system contingencies specified in Table 1 in the TPL standards. MISO then asks if a variety of possible dispatch patterns should be included in planning analyses including a probabilistically based dispatch that is representative of generation deficiency scenarios, would it be an appropriate application of the TPL standard to apply the transmission contingency conditions in Category B of Table 1 to these possible dispatch pattern. The following interpretation of TPL-002-0 and TPL-003-0 Requirement R1.3.2 was developed by the NERC Planning Committee on March 13, 2008: The selection of a credible generation dispatch for the modeling of critical system conditions is within the discretion of the Planning Authority. The Planning Authority was renamed “Planning Coordinator” (PC) in the Functional Model dated February 13, 2007. (TPL -002 and -003 use the former “Planning Authority” name, and the Functional Model terminology was a change in name only and did not affect responsibilities.) − Under the Functional Model, the Planning Coordinator “Provides and informs Resource Planners, Transmission Planners, and adjacent Planning Coordinators of the methodologies and tools for the simulation of the transmission system” while the Transmission Planner “Receives from the Planning Coordinator methodologies and tools for the analysis and development of transmission expansion plans.” A PC’s selection of “critical system conditions” and its associated generation dispatch falls within the purview of “methodology.” Furthermore, consistent with this interpretation, a Planning Coordinator would formulate critical system conditions that may involve a range of critical generator unit outages as part of the possible generator dispatch scenarios. Both TPL-002-0 and TPL-003-0 have a similar measure M1: M1. The Planning Authority and Transmission Planner shall have a valid assessment and corrective plans as specified in Reliability Standard TPL-002-0_R1 [or TPL-003-0_R1] and TPL-002-0_R2 [or TPL-003-0_R2].” The Regional Reliability Organization (RRO) is named as the Compliance Monitor in both standards. Pursuant to Federal Energy Regulatory Commission (FERC) Order 693, FERC eliminated the RRO as the appropriate Compliance Monitor for standards and replaced it with the Regional Entity (RE). See paragraph 157 of Order 693. Although the referenced TPL standards still include the reference to the RRO, to be consistent with Order 693, the RRO is replaced by the RE as the Compliance Monitor for this interpretation. As the Compliance Monitor, the RE determines what a “valid assessment” means when evaluating studies based upon specific sub-requirements in R1.3 selected by the Planning Coordinator and the Transmission Planner. If a PC has Transmission Planners in more than one region, the REs must coordinate among themselves on compliance matters.

Adopted by NERC Board of Trustees: October 23, 2008 Page 7 of 8 Effective Date: April 23, 2010 Standard TPL-003-0a — System Performance Following Loss of Two or More BES Elements

Requirement R1.3.12

Adopted by NERC Board of Trustees: October 23, 2008 Page 8 of 8 Effective Date: April 23, 2010 Standard TPL-004-0 — System Performance Following Extreme BES Events

A. Introduction 1. Title: System Performance Following Extreme Events Resulting in the Loss of Two or More Bulk Electric System Elements (Category D) 2. Number: TPL-004-0 3. Purpose: System simulations and associated assessments are needed periodically to ensure that reliable systems are developed that meet specified performance requirements, with sufficient lead time and continue to be modified or upgraded as necessary to meet present and future System needs. 4. Applicability: 4.1. Planning Authority 4.2. Transmission Planner 5. Effective Date: April 1, 2005 B. Requirements R1. The Planning Authority and Transmission Planner shall each demonstrate through a valid assessment that its portion of the interconnected transmission system is evaluated for the risks and consequences of a number of each of the extreme contingencies that are listed under Category D of Table I. To be valid, the Planning Authority’s and Transmission Planner’s assessment shall: R1.1. Be made annually. R1.2. Be conducted for near-term (years one through five). R1.3. Be supported by a current or past study and/or system simulation testing that addresses each of the following categories, showing system performance following Category D contingencies of Table I. The specific elements selected (from within each of the following categories) for inclusion in these studies and simulations shall be acceptable to the associated Regional Reliability Organization(s). R1.3.1. Be performed and evaluated only for those Category D contingencies that would produce the more severe system results or impacts. The rationale for the contingencies selected for evaluation shall be available as supporting information. An explanation of why the remaining simulations would produce less severe system results shall be available as supporting information. R1.3.2. Cover critical system conditions and study years as deemed appropriate by the responsible entity. R1.3.3. Be conducted annually unless changes to system conditions do not warrant such analyses. R1.3.4. Have all projected firm transfers modeled. R1.3.5. Include existing and planned facilities. R1.3.6. Include Reactive Power resources to ensure that adequate reactive resources are available to meet system performance.

Adopted by NERC Board of Trustees: February 8, 2005 1 of 5 Effective Date: April 1, 2005

Standard TPL-004-0 — System Performance Following Extreme BES Events

R1.3.7. Include the effects of existing and planned protection systems, including any backup or redundant systems. R1.3.8. Include the effects of existing and planned control devices. R1.3.9. Include the planned (including maintenance) outage of any bulk electric equipment (including protection systems or their components) at those demand levels for which planned (including maintenance) outages are performed. R1.4. Consider all contingencies applicable to Category D. R2. The Planning Authority and Transmission Planner shall each document the results of its reliability assessments and shall annually provide the results to its entities’ respective NERC Regional Reliability Organization(s), as required by the Regional Reliability Organization. C. Measures M1. The Planning Authority and Transmission Planner shall have a valid assessment for its system responses as specified in Reliability Standard TPL-004-0_R1. M2. The Planning Authority and Transmission Planner shall provide evidence to its Compliance Monitor that it reported documentation of results of its reliability assessments per Reliability Standard TPL-004-0_R1. D. Compliance 1. Compliance Monitoring Process 1.1. Compliance Monitoring Responsibility Compliance Monitor: Regional Reliability Organization. Each Compliance Monitor shall report compliance and violations to NERC via the NERC Compliance Reporting Process. 1.2. Compliance Monitoring Period and Reset Timeframe Annually. 1.3. Data Retention None specified. 1.4. Additional Compliance Information None. 2. Levels of Non-Compliance 2.1. Level 1: A valid assessment, as defined above, for the near-term planning horizon is not available. 2.2. Level 2: Not applicable. 2.3. Level 3: Not applicable. 2.4. Level 4: Not applicable.

B. Regional Differences 1. None identified.

Adopted by NERC Board of Trustees: February 8, 2005 2 of 5 Effective Date: April 1, 2005

Standard TPL-004-0 — System Performance Following Extreme BES Events

Version History Version Date Action Change Tracking 0 April 1, 2005 Effective Date New

Adopted by NERC Board of Trustees: February 8, 2005 3 of 5 Effective Date: April 1, 2005

Standard TPL-004-0 — System Performance Following Extreme BES Events

Table I. Transmission System Standards – Normal and Emergency Conditions

Contingencies System Limits or Impacts Category System Stable and both Thermal and Loss of Demand

Voltage or Cascading Initiating Event(s) and Contingency Limits within Curtailed Firm Outages Element(s) Applicable Transfers Rating a

Yes Planned/ No 7. Transformer c Controlled

Yes Planned/ No 8. Transmission Circuit c Controlled

9. Bus Section Yes Planned/ No Controlledc

Adopted by NERC Board of Trustees: February 8, 2005 4 of 5 Effective Date: April 1, 2005

Standard TPL-004-0 — System Performance Following Extreme BES Events

require joint studies with 6. Loss of towerline with three or more circuits neighboring systems. 7. All transmission lines on a common right-of way 8. Loss of a substation (one voltage level plus transformers) 9. Loss of a switching station (one voltage level plus transformers) 10. Loss of all generating units at a station 11. Loss of a large Load or major Load center 12. Failure of a fully redundant Special Protection System (or remedial action scheme) to operate when required 13. Operation, partial operation, or misoperation of a fully redundant Special Protection System (or Remedial Action Scheme) in response to an event or abnormal system condition for which it was not intended to operate 14. Impact of severe power swings or oscillations from Disturbances in another Regional Reliability Organization.

a) Applicable rating refers to the applicable Normal and Emergency facility thermal Rating or System Voltage Limit as determined and consistently applied by the system or facility owner. Applicable Ratings may include Emergency Ratings applicable for short durations as required to permit operating steps necessary to maintain system control. All Ratings must be established consistent with applicable NERC Reliability Standards addressing Facility Ratings. b) Planned or controlled interruption of electric supply to radial customers or some local network customers, connected to or supplied by the Faulted element or by the affected area, may occur in certain areas without impacting the overall reliability of the interconnected transmission systems. To prepare for the next contingency, system adjustments are permitted, including curtailments of contracted Firm (non-recallable reserved) electric power Transfers. c) Depending on system design and expected system impacts, the controlled interruption of electric supply to customers (load shedding), the planned removal from service of certain generators, and/or the curtailment of contracted Firm (non- recallable reserved) electric power Transfers may be necessary to maintain the overall reliability of the interconnected transmission systems. d) A number of extreme contingencies that are listed under Category D and judged to be critical by the transmission planning entity(ies) will be selected for evaluation. It is not expected that all possible facility outages under each listed contingency of Category D will be evaluated. e) Normal clearing is when the protection system operates as designed and the Fault is cleared in the time normally expected with proper functioning of the installed protection systems. Delayed clearing of a Fault is due to failure of any protection system component such as a relay, circuit breaker, or current transformer, and not because of an intentional design delay. f) System assessments may exclude these events where multiple circuit towers are used over short distances (e.g., station entrance, river crossings) in accordance with Regional exemption criteria.

Adopted by NERC Board of Trustees: February 8, 2005 5 of 5 Effective Date: April 1, 2005

LADWP’s 2010 Ten-Year Transmission Assessment

Appendix B. Receiving Station Loads

B November 1, 2010

Appendix B. RECEIVING STATION LOADS

SERVICE RECEIVING STATION AREA 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 MW Mvars MW Mvars MW Mvars MW Mvars MW Mvars MW Mvars MW Mvars MW Mvars MW Mvars MW Mvars RS-N AIRPORT 198 61 199 61 203 62 206 63 209 64 210 64 213 65 217 67 220 67 224 69

RS-G ATWATER 306 68 308 69 315 70 317 71 321 72 323 72 328 73 335 75 341 76 346 77

RS-B CENTURY 286 71 289 71 291 72 297 73 301 74 303 75 308 76 317 78 323 80 328 81

RS-D FAIRFAX 390 96 393 97 396 98 401 99 403 99 404 100 408 101 412 102 420 104 426 105

RS-H HOLLYWOOD 386 73 391 74 395 75 406 77 407 77 411 78 416 79 423 80 431 82 436 83

CENTRAL RS-P MARKET (RIVER) 352 54 353 54 353 54 357 55 360 56 363 56 365 56 370 57 376 58 382 59

RS-K OLYMPIC 403 117 403 117 410 118 421 122 424 123 431 125 438 127 445 129 452 131 459 133

RS-L SCATTERGOOD 26 12 26 12 26 12 26 12 26 12 26 12 27 13 27 13 28 13 28 13

RS-A ST JOHN 215 49 219 50 219 50 222 51 224 51 226 52 230 53 232 53 236 54 239 55

RS-F VELASCO 218 48 219 48 220 48 223 49 224 49 227 50 231 51 234 52 238 52 242 53

Total Central Load 2779 649 2800 653 2828 661 2875 672 2897 677 2922 683 2962 692 3012 704 3065 717 3108 727

RS-HAL HALLDALE 47 17 47 17 47 17 47 17 48 18 48 18 50 18 50 18 51 19 51 19

RS-Q HARBOR 194 59 195 59 196 59 198 60 199 60 201 61 203 61 206 62 209 63 212 64 SOUTHERN RS-C WILMINGTON 157 20 156 20 157 20 160 20 160 20 162 20 163 20 167 21 169 21 171 21

Total Southern Load 398 96 398 96 400 96 405 97 407 98 411 99 415 100 422 101 428 103 435 105

RS-T CANOGA 357 66 359 66 362 66 354 65 358 66 360 66 365 67 371 68 377 69 383 70

RS-V CHATSWORTH

RS-J NORTHRIDGE 504 95 508 95 510 96 531 100 536 101 541 101 551 103 560 105 570 107 577 108

RS-RIN RINALDI 287 70 290 71 297 73 304 75 307 75 312 77 318 78 325 80 331 81 335 82

VALLEY RS-U TARZANA 333 64 337 65 341 66 347 67 350 67 352 68 361 70 365 70 371 72 376 73

RS-E TOLUCA 395 82 394 82 399 83 398 83 404 84 411 86 416 87 423 88 431 90 436 91

RS-M VALLEY 306 88 312 90 314 90 321 92 325 93 324 93 331 95 338 97 344 99 349 100

RS-S VAN NUYS 411 55 415 56 422 57 433 58 439 59 443 60 451 61 460 62 468 63 474 64

Total Valley Load 2593 520 2615 525 2645 531 2688 539 2718 545 2744 550 2794 561 2841 570 2890 580 2931 588

TOTAL RECEIVING STATION LOAD 5770 1265 5813 1274 5873 1288 5968 1308 6022 1320 6076 1332 6172 1353 6275 1376 6383 1400 6474 1420

LADWP’s 2010 Ten-Year Transmission Assessment

Appendix C. Generation Schedule for LADWP-Owned Facilities (MW)

C November 1, 2010

Appendix C. Generation Schedule for LADWP-Owned Facilities (MW)

NET MAX. UNIT BASECASE YEAR BUS NO. GENERATING UNIT ID kV CAPABILITY * (MW) 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 26004 CASTAI1G 1 18 240 221 77 99 (58) 13 2 18 128 100 162 26005 CASTAI2G 2 18 265 200 26006 CASTAI3G 3 18 240 26007 CASTAI4G 4 18 265 26008 CASTAI5G 5 18 265 26009 CASTAI6G 6 18 265 26011 CASTAI7G 7 11.5 55 PUMPED STORAGE 1595 221 77 99 (58) 13 2 18 128 300 162 26032 OWENS UP 1 11.5 37.5 37 37 37 37 - 35 37 37 37 37 26034 OWENSCON 1 11.5 37.5 36 36 36 36 - - 36 36 36 36 26033 OWENSMID 1 11.5 37.5 37 37 37 37 - 35 37 37 37 37 26058 PP 1 G 1 7.5 76 40 40 40 40 40 40 40 40 40 40 26060 PP 2 G 2 7.5 32 10 10 10 10 10 10 10 10 10 10 HYDRO 221 160 160 160 160 50 120 160 160 160 160 26110 HARB1G 1 13.8 82 81 81 81 81 81 81 81 81 81 81 26111 HARB2G 2 13.8 82 81 81 81 81 81 81 81 81 81 81 26023 HARB5G 5 13.8 65 65 65 65 65 65 65 65 65 65 60 26143 HARBCT10 10 13.8 47.4 26144 HARBCT11 11 13.8 47.4 26145 HARBCT12 12 13.8 47.4 26146 HARBCT13 13 13.8 47.4 26147 HARBCT14 14 13.8 47.4 26026 HAYNES1G 1 18 222 100 50 50 50 50 50 50 50 150 150 26027 HAYNES2G 2 18 222 100 50 50 50 50 50 150 150 26030 HAYNES5G 5 18 292 26031 HAYNES6G 6 18 243 26151 HAYNES8G 8 18 250 200 200 200 200 200 200 200 200 200 100 26152 HAYNES9G 9 18 162.5 150 150 150 150 150 150 150 150 150 130 26153 HAYNS10G 10 18 162.5 150 150 150 150 150 150 150 150 150 130 26154 HYN1112G 11 13.8 131.8 26154 HYN1112G 12 13.8 131.8 26155 HYN1314G 13 13.8 131.8 26155 HYN1314G 14 13.8 131.8 26156 HYN1516G 15 13.8 131.8 26156 HYN1516G 16 13.8 131.8 26112 SCATT1G 1 18 183 26112 SCATT1G (Re-power) 1 18 131 26106 SCATT2G 2 18 184 100 150 100 100 100 100 100 100 100 150 26067 SCATT3G 3 24 450 428 420 428 428 428 26157 SCATT4GT 4 13.8 210 128 128 128 200 100 26158 SCATT5ST 5 13.8 100 100 100 100 100 90 26159 SCATT6GT 6 13.8 100 100 100 100 100 90 26160 SCATT7GT 7 13.8 100 100 100 100 100 90 26142 VALLEY5G 5 13.8 43 26148 VALLEY6G 6 18 159 113 113 113 113 113 113 113 113 150 150 26149 VALLEY7G 7 18 159 113 113 113 113 113 113 113 113 150 150 26150 VALLEY8G 8 18 215 151 151 151 151 151 151 151 151 200 100 NATURAL GAS 3677 1832 1774 1732 1732 1682 1682 1732 1732 2127 1802 Adelanto Solar ** 4.8 10 RE 26960 RE-BR1 1 0.2 140 137 SM 26930 SODMTGEN 1 0.26 366 300 BCSP 26940 BCSPGEN 1 0.4 150.3 150 HLSP 27201 HLSP1 1 13.8 125 125 125 125 125 125 125 125 125 125 27202 HLSP2 1 13.8 125 125 125 125 125 125 125 125 125 125 BSL 26907 BCON18G 1 18 250 250 250 250 250 250 250 250 Owenyo Solar 26944 OWENYO_S 1 0.21 200 100 100 200 200 200 200 200 200 SOLAR 1366 0 250 350 600 700 700 700 700 700 1287 Pine Tree 27001 PTWTG 1 0.57 135 40 40 40 40 40 40 40 40 40 40 Pine Canyon 27002 PCWTG 1 0.57 150 45 45 45 45 45 45 Milford Wind Corridor 27117 WTGCP CP 0.69 145 20 20 20 20 20 20 20 20 20 20 27119 WTGGE GE 0.57 58.5 20 20 20 20 20 20 20 20 20 20 27123 WTGGE2 1 0.57 102 40 40 40 40 40 40 40 40 40 40 WIND 591 120 120 120 120 165 165 165 165 165 165

LADWP's SHARE (MW) HOOVER 491 410 410 410 410 410 410 410 410 410 410 HYDRO 491 410 410 410 410 410 410 410 410 410 410 15981 NAVAJO 1 26 159 159 159 159 159 159 159 159 159 0 0 15982 NAVAJO 2 26 159 159 159 159 159 159 159 159 159 0 0 15983 NAVAJO 3 26 159 159 159 159 159 159 159 159 159 0 0 26039 INTERMT1G 26 602 602 602 602 602 602 602 602 602 602 602 26040 INTERMT2G 26 602 602 602 602 602 602 602 602 602 602 602 COAL 1681 1681 1681 1681 1681 1681 1681 1681 1681 1204 1204 14931 PALOVRD1 24 129 129 129 129 129 129 129 129 129 129 129 14932 PALOVRD2 24 129 129 129 129 129 129 129 129 129 129 129 14933 PALOVRD3 24 129 129 129 129 129 129 129 129 129 129 129 NUCLEAR 387 387 387 387 387 387 387 387 387 387 387

TOTAL LADWP GENERATION 10008 4811 4859 4939 5033 5088 5147 5253 5363 5453 4990

* Source: GENERATION RATINGS & CAPABILITES OF POWER SOURCES - DECEMBER 2008 (NERC FAC-008-1) ** Not represented in the basecase Appendix C. Generation Schedule for LADWP-Owned Facilities (MW) LIGHT WINTER

BASECASE YEAR NET MAX. UNIT BUS NO. GENERATING UNIT ID kV CAPABILITY * (MW) 2011 2015

26004 CASTAI1G 1 18 240 (225) (182) 26005 CASTAI2G 2 18 265 (200) (200) 26006 CASTAI3G 3 18 240 26007 CASTAI4G 4 18 265 26008 CASTAI5G 5 18 265 26009 CASTAI6G 6 18 265 26011 CASTAI7G 7 11.5 55 PUMPED STORAGE 1595 (425) (382) 26032 OWENS UP 1 11.5 37.5 26034 OWENSCON 1 11.5 37.5 26033 OWENSMID 1 11.5 37.5 26058 PP 1 G 1 7.5 76 40 40 26060 PP 2 G 2 7.5 32 10 10 HYDRO 221 50 50 26110 HARB1G 1 13.8 82 26111 HARB2G 2 13.8 82 26023 HARB5G 5 13.8 65 26143 HARBCT10 10 13.8 47.4 26144 HARBCT11 11 13.8 47.4 26145 HARBCT12 12 13.8 47.4 26146 HARBCT13 13 13.8 47.4 26147 HARBCT14 14 13.8 47.4 26026 HAYNES1G 1 18 222 50 50 26027 HAYNES2G 2 18 222 26030 HAYNES5G 5 18 292 26031 HAYNES6G 6 18 243 26151 HAYNES8G 8 18 250 200 200 26152 HAYNES9G 9 18 162.5 150 150 26153 HAYNS10G 10 18 162.5 150 150 26154 HYN1112G 11 13.8 131.8 26154 HYN1112G 12 13.8 131.8 26155 HYN1314G 13 13.8 131.8 26155 HYN1314G 14 13.8 131.8 26156 HYN1516G 15 13.8 131.8 26156 HYN1516G 16 13.8 131.8 26112 SCATT1G 1 18 183 26106 SCATT2G 2 18 184 85 85 26067 SCATT3G 3 24 450 26157 SCATT4GT 4 13.8 175 26158 SCATT5ST 5 13.8 135 26159 SCATT6GT 6 13.8 100 26160 SCATT7GT 7 13.8 100 26142 VALLEY5G 5 13.8 43 26148 VALLEY6G 6 18 159 150 125 26149 VALLEY7G 7 18 159 150 125 26150 VALLEY8G 8 18 215 200 200 NATURAL GAS 3729 1135 1085 Harper Lake 27201 HLSP1 1 13.8 125 27202 HLSP2 1 13.8 125 Beacon 26907 BCON18G 1 18 250 Owenyo Solar 26944 OWENYO_S 1 0.21 200 SOLAR 700 0 0 Pine Tree 27001 PTWTG 1 0.57 135 92 92 Pine Canyon 27002 PCWTG 1 0.57 150 91 Milford Wind Corridor 27117 WTGCP CP 0.69 100 40 40 27119 WTGGE GE 0.57 100 40 40 27123 WTGGE2 1 0.57 100 40 40 WIND 585 212 303

LADWP's SHARE (MW) HOOVER 491 340 340 HYDRO 491 340 340 15981 NAVAJO 1 26 159 159 159 15982 NAVAJO 2 26 159 159 159 15983 NAVAJO 3 26 159 159 159 26039 INTERMT1G 26 602 602 602 26040 INTERMT2G 26 602 602 602 COAL 1681 1681 1681 14931 PALOVRD1 24 129 129 129 14932 PALOVRD2 24 129 129 129 14933 PALOVRD3 24 129 129 129 NUCLEAR 387 387 387

TOTAL LADWP GENERATION 9388 3380 3464

* Source: GENERATION RATINGS & CAPABILITES OF POWER SOURCES - DECEMBER 2008 (NERC FAC-008-1) RENEWABLE ENERGY RESOURCES REPRESENTED IN THE HEAVY SUMMER 2020 BASECASE

MAXIMUM INSTALLED GENERATION TECHNOLOGY PLANT UNIT ENERGY (Gwh) CAPACITY (MW) DISPATCH (MW)

BIOMASS Atmos Energy Landfill Gas Biogas Digester 0 0 288 Hyperion Digester Gas Biomass Landfill Gas 16 0 147 Lopez Microturbine Biomass Landfill Gas 1.5 0 2 SCS Penrose Biomass Landfill Gas 6.1 0 45 Shell Energy Landfill Gas Landfill Gas 0 0 350 Toyon Power Plant Landfill Gas 3.6 0 12 WM Bradley Biogas or biomethane 6036 SMALL HYDRO Aqueduct & Owens Valley Aqueduct & Owens Valley 54 50 287 MWD Sepulveda 8.5 0 42 Owens Gorge 110 110 261 Water System Hydro 4 0 22 SOLAR LADWP-OWNED LADWP-Built Solar DWP_Owens Lake Demo 0.5 0.5 1 Roof Top 120 120* 194 Sunshares LA 110.5 110* 164 Feed-In-Tariff Feed-In-Tariff 150 150* 236 Owenyo Owenyo Solar Phase I 100 100 198 Owenyo Owenyo Solar Phase II 100 100 198 External & Purchases BSP 250 250 477 BCSP 150 150 347 HL1 125 125 299 HL2 125 125 299 RE-BR1 139 139 265 SMSP 350 350 836 WIND LA-Owned Pine Tree 135 40 382 Pine Canyon 150 45 425 Utah/Wyoming PPM Wyoming 82.2 12 233 Milford Phase I 203.5 40 434 Milford Phase II 102 40 217 Pacific Northwest Linden 50 20 145 Pebble Springs 68.7 10 193 Willow Creek 72 11 197 Windy Point 82.2 12 694 Additional Purchase n/a 40 705

* Netting with RS loads TOTAL = 8,631 2020 Forecasted Total Sale = 26,151 % Renewables = 33%

LADWP’s 2010 Ten-Year Transmission Assessment

Appendix D. Transmission Line Capacities

D November 1, 2010

Appendix D. Transmission Line Capacities

CONTINUOUS RATING EMERGENCY RATING LINE AMP MVA LIMITING COMPONENT AMP MVA LIMITING COMPONENT 69kV LINES Burbank, Toluca -Valley Line 1 850 102 OH Line 977 117 OH Line Burbank, Toluca -Valley Line 2 765 91 OH Line 879 105 OH Line Burbank, Toluca -Valley Line 3 765 91 OH Line 879 105 OH Line Burbank, Toluca - Capon Line 1 686 82 OH Line 789 94 OH Line Burbank, Toluca - Capon Line 2 769 92 OH Line 884 106 OH Line Burbank, Toluca - Capon Line 3 765 91 OH Line 879 105 OH Line RS - E 230 - 69KV Bank E (MUNI) - 403 Xfmr E - 403 Xfmr E RS - E 230 - 69KV Bank F (MUNI) - 403 Xfmr F - 403 Xfmr F 115kV LINES Power Plant 1 - Power Plant 2 Tie Line 443 88 OH Line 600 120 Circuit breaker Power Plant 1 - Olive Line 1 - 80 Xfmr H - 90 Xfmr H Power Plant 2 - Olive Line 1 443 88 OH Line 600 120 Disc Sw & CB 138kV LINES Century - Gramercy Line 1 763 182 OH Line 1200 287 Wave Trap Century - Gramercy Line 2 763 182 OH Line 1200 287 Wave Trap Century - Wilmington Line 1 763 182 OH Line 800 191 Wave Trap Century - Wilmington Line 2 763 182 OH Line 800 191 Wave Trap Fairfax - Airport Line 1 1049 251 UG Cable 1163 278 UG Cable Fairfax - Airport Line 2 1049 251 UG Cable 1163 278 UG Cable Fairfax - Gramercy Line 1 763 182 OH Line 800 191 Reactor Fairfax - Gramercy Line 1 Rating with L-2 in svc 664 159 UG Cable 736 176 UG Cable Fairfax - Gramercy Line 2 763 182 OH Line 800 191 Reactor Fairfax - Gramercy Line 2 Rating with L-1 in svc 664 159 UG Cable 736 176 UG Cable Fairfax - Olympic Ca A 800 191 Reactor 800 191 Reactor Fairfax - Olympic Ca A rating with Ca B in-svc 664 159 UG Cable 736 176 UG Cable Fairfax - Olympic Ca B 800 191 Reactor 800 191 Reactor Fairfax - Olympic Ca B rating with Ca A in-svc 664 159 UG Cable 736 176 UG Cable Harbor - Wilmington Ca A / up to 2014 - 90 Xfmr Bank - 99 Xfmr Bank (4-hr rating) Harbor - Wilmington Ca B / up to 2014 - 90 Xfmr Bank - 99 Xfmr Bank (4-hr rating) Harbor - Wilmington Ca A / after 2014 800 191 Disc Sw 800 191 Disc Sw Harbor - Wilmington Ca A / after 2014 800 191 Disc Sw 800 191 Disc Sw Harbor - Wilmington Ca D 800 191 Disc Sw 800 191 Disc Sw Harbor - Wilmington Ca E 800 191 Disc Sw 800 191 Disc Sw Hollywood - Fairfax Ca A 800 191 Reactor 800 191 Reactor Hollywood - Fairfax Ca A Rating with Ca B in-svc 776 185 UG Cable 800 191 Reactor Hollywood - Fairfax Cable B 800 191 Reactor 800 191 Reactor Hollywood - Fairfax Ca B Rating in Ca A in-svc 776 185 UG Cable 800 191 UG Cable Scattergood - Airport Line 1 979 234 OH Line 1163 278 UG Cable Scattergood - Airport Line 2 979 234 OH Line 1163 278 UG Cable Tarzana - Olympic Line 1 837 200 UG Cable 837 200 UG Cable Tarzana - Olympic Line 1 Rating with 2 circuits in svc - 290 Xfmr E - 328 Xfmr E

Revised 10/25/10 CONTINUOUS RATING EMERGENCY RATING LINE AMP MVA LIMITING COMPONENT AMP MVA LIMITING COMPONENT Toluca - Hollywood Line 2 763 182 OH Line 800 191 Disc Sw Toluca - Hollywood Line 2 Rating with 2 cables in-svc 1200 287 Disc Sw 1200 287 Disc Sw Wilmington - Gramercy Line 1 / up to 2014 763 182 OH Line 932 223 UG Cable Wilmington - Gramercy Line 1 / up to 2014 763 182 OH Line 932 223 UG Cable Harbor-Tap 1 Line 1 763 182 OH Line 800 191 Disc Sw Harbor-Tap 2 Line 2 763 182 OH Line 800 191 Disc Sw 230kV LINES Atwater - Air Way Line 1 1778 708 OH Line 2000 797 Wave Trap Atwater - Air Way Line 2 1778 708 OH Line 2000 797 CB & Disc Sw @ RS-Air Way Atwater - St John Line 1 1360 541 OH Line 1400 558 Disc Sw Atwater - Velasco Line 1 1360 541 OH Line 1600 637 CB Barren Ridge - Rinaldi Line 1 1152 459 OH Line 1635 651 OH Line Castaic - Northridge Line 1 1797 716 Ground Clearance 1797 716 Ground Clearance Castaic - Olive Line 1 1600 637 Disc Sw 1600 637 Disc Sw Castaic - Sylmar Line 1 1855 739 OH Line 2000 797 Disc Sw Haynes - Atwater Line 1 1600 637 CB 1600 637 CB Haynes - River Line 1 1600 637 CB 1600 637 CB Haynes - St John Line 1 1600 637 CB 1600 637 CB Haynes - Velasco Line 1 1600 637 CB 1600 637 CB Intermountain - Gonder Line 1 502 200 System Studies 502 200 System Studies Inyo - Cottonwood Line 1 1152 459 OH Line 1635 651 OH Line Inyo - Rinaldi 1152 459 OH Line 1635 651 OH Line Laguna Bell - Velasco Line 1 861 343 OH Line - 475 Xfmr Bank G Mead - McCullough Line 1 899 358 OH Line 1486 591 OH Line Mead - McCullough Line 2 899 358 OH Line 1486 591 OH Line Northridge - Tarzana Line 3 1437 572 OH Line 2000 797 Disc Sw Olive-Northridge Line 1 1600 637 Ground Clearance 1600 637 Ground Clearance Pine Tree-Barren Ridge Line 1 2008 800 Ground Clearance Rinaldi - Airway Line 1 1152 459 OH Line 1635 651 OH Line Rinaldi - Airway Line 2 1152 459 OH Line 1635 651 OH Line Rinaldi - Tarzana Line 1 1152 459 OH Line 1635 651 OH Line Rinaldi - Tarzana Line 2 1152 459 OH Line 1635 651 OH Line River - Market Cable A - 160 Xfmr A - 200 Xfmr A River - Market Cable B - 160 Xfmr B - 200 Xfmr B River - Market Cable C - 160 Xfmr C - 200 Xfmr C River - Market Cable D - 170 Xfmr D - 220 Xfmr D River - Velasco Line 1 1360 542 OH Line 1600 637 CB Scattergood - Olympic Line 2 876 349 UG Cable 876 349 UG Cable St John - River Line 1 1778 708 OH Line 2000 797 Wave Trap Sylmar - Northridge Line 1 1778 708 OH Line 2518 1003 OH Line Sylmar - Rinaldi Line 1 1778 708 OH Line 2518 1003 OH Line Sylmar - Rinaldi Line 3 1782 710 OH Line 2582 1029 OH Line Sylmar - Rinaldi Line 4 1911 761 OH Line 2767 1102 OH Line Tarzana - Canoga Cable A - 160 Xfmr A - 176 Xfmr A (4-hr rating)

Revised 10/25/10 CONTINUOUS RATING EMERGENCY RATING LINE AMP MVA LIMITING COMPONENT AMP MVA LIMITING COMPONENT Tarzana - Canoga Cable B - 160 Xfmr B - 176 Xfmr B (4-hr rating) Tarzana - Canoga Cable C - 160 Xfmr C - 176 Xfmr C (4-hr rating) Tarzana - Olympic Line 3 958 382 UG Cable 1094 436 UG Cable Toluca - Atwater Line 1 1778 708 OH Line 2000 797 OH Line Toluca - Hollywood Line 1 876 349 UG Cable 1002 399 UG Cable Toluca - Hollywood Line 3 - 400 Xfmr F 1152 459 UG Cable Toluca - Van Nuys Cable A - 170 Xfmr A 469 187 Disc Sw & CB Toluca - Van Nuys Cable B - 160 Xfmr Bank - 176 Xfmr Bank Toluca - Van Nuys Cable C - 160 Xfmr Bank - 176 Xfmr Bank Toluca - Van Nuys Cable D - 160 Xfmr Bank - 176 Xfmr Bank Valley - Rinaldi Line 1 1243 495 OH Line 1805 720 OH Line Valley - Rinaldi Line 2 1243 495 OH Line 1805 720 OH Line Valley - Toluca Line 1 1243 495 OH Line 1805 720 OH Line Valley - Toluca Line 2 1243 495 OH Line 1805 720 OH Line Velasco - Century Line 1 1600 637 CB 1600 637 CB Velasco - Century Line 2 1600 637 CB 1600 637 CB 287kV LINES Mead - Victorville Line 1 - 420 Xfmr - 520 Xfmr Victorville - Century Line 1 - 420 Xfmr F or G - 510 Xfmr F or G Victorville - Century Line 2 - 420 Xfmr F or G - 510 Xfmr F or G Victorville Sw Sta - Bank K TIE - 465 Xfmr K - 573 Xfmr K 345kV LINES Intermountain - Mona Line 1 1004 600 System Studies 2000 1195 CB & Disc Sw @ Mona Intermountain - Mona Line 2 1004 600 System Studies 2000 1195 CB & Disc Sw @ Mona 500kV LINES Adelanto - Rinaldi Line 1 - 1593 Disc Sw & CB - 1593 Disc Sw & CB Adelanto - Toluca Line 1 2000 1819 Disc Sw & CB 2000 1819 Disc Sw & CB Crystal - McCullough Line 1 2600 2252 Series Cap 3000 2598 Wave Trap Eldorado - McCullough Line 1 3000 2728 Disc Sw & CB 3000 2728 Disc Sw & CB Lugo - Victorville Line 1 2771 2400 System Studies 3000 2728 Wave Trap Marketplace - Adelanto Line 1 1800 1636 Series Cap 2430 2210 Series Cap (1/2-hr rating) Marketplace - McCullough Line 1 4013 3475 OH Line 4200 3637 Disc Sw & CB McCullough - Victorville Line 1 1600 1455 Series Cap 2400 2182 Series Cap McCullough - Victorville Line 2 1600 1455 Series Cap 2400 2182 Series Cap Mohave - Eldorado Line 1 1386 2000 Stability 1386 1200 Stability Mohave - Eldorado Line 1 3000 2728 VAR Comp 3000 2728 VAR Comp Navajo - Crystal Line 1 2200 2001 Series Cap 2750 2501 Series Cap (1/2-hr rating) Navajo - Moenkopi Line 1 1630 1412 Series Cap - - Victorville - Adelanto Line 1 3000 2728 Wave Trap 3000 2728 Wave Trap Victorville - Adelanto Line 2 3000 2728 Wave Trap 3000 2728 Wave Trap Victorville - Rinaldi Line 1 1839 1593 SF6 Switchgear 2300 1992 SF6 Switchgear

Revised 10/25/10

LADWP’s 2010 Ten-Year Transmission Assessment

Appendix E. One-Line Diagrams

E November 1, 2010

INTERMOUNTAIN OWENS UP 1 2 26129 37 MEAD S 1.072 1 19012

4 900 258 HOOVER

900 258 1.006 CELILO 1.048 N1 100 BIGEDDY3 BIGEDDY1 BIG EDDY 15 198 41343 41341 40111 37 4 100 18 MEAD PP1 PP2 N2 1.041 1.039 1.076 30 26051 OWENSMID 37 1.017 1 2 1 N3 100 26130 5 1.025 24 208

1.048 1.025 1.071 110 17 131 131 40 2 10 4 INTERMT N4 24

584 26 526 14 53 57 MEAD 805 66 866 31 26043 1.000 74 9 1.050 MCCULLGH 19038 OWENSCON 26046 MEAD N 1.054 26131 36 1.004 19011 1.070 1 78 48 0.996 23 9 MWC345 99 1.048 CASTAIC 0 475 27135 53 1115 1705 841 1.000 1.000 3 136 1.000 1.000 1.056 27 POLE 2 PP 1 PP 2 b 1.000 1.000 1 POLE 1 99 125 63 1 2 3 4 5 6 26057 26059 110 17 1 1.015 1.013 INYO 3 1.000 NAVAJO 24729 14003 39 1 1.065 19 13 19 13 MCCULLGH CRYSTAL 1.090 805 202 61 14 26048 26123 1 158 2 1.053 1.051 195 26 4 1 24 5 805 COTTONWD 68 1 26136 750 1024 1 195

1.000 805 1.043 98 62 1 1.000 MOHAVE195 24 4 68 ELDORDO

1.000 1.000 40 0 24097 20 23 20 0 26 4 158 2 24042 OLIVE 1 1.058 1.000 GE CP 1.000 1.053 536 1.000 1.000 1.000 26052 1.000 b 1 1.015 IPP DC 79 135 99 CASTAIC Milford Wind Corridor 26010 PT230 0 117 736 1.025 27031 1.000 67 1.018 648 482 38 147 16 ADELANTO 458 16 2 98 21 84

118 23 40 26003 1 40 638 342 12 12 1.045 79 SYLMAR2 RINALDI Pine Tree 1 1652 26099 26061 850 1.022 1.022 655 194 346 0 20 1247 713 b MARKETPL 789 278 RINALDI BARRENRD 26044 26132 1.053 SYLMARLA 54 26062

1.000 1.019 26094 1.029 559 SYLMAR1 1.024 278 10 26097 1.030 54 VICTORVL

0.987 292 1.000 RINALDI2 1.030 26115 26105 39 622 1.029 625 1.047 106 VALLEY 23 1171

1.030 292 1.000 1244 719 113 367 22 35 42 22 29 2 26103 2 7 367 75 SYLMAR S 39 55 1.019 VALLEY 75 277 32 LUGO 113 24147 6 155 26102 24086 292 55 1.014 1.000 1.046 0.989 32 39 294 1.000 5 202 5 155 0 b 5 294 833 202 32 942 435 5 1.000 319 5 0.0 801.9 58 151 124 VICTORVL 8 ATWATER 33 56 GLENDAL 26104 b 319 26081 26013 1.006 1.041 387 291 33 1.008 193 42 34 196 18 303 34 20 387 228 NRTHRDGE 467 42 20 26086 55

1.010 1.000 171 467 61 TOLUCA 55 26078 1.000 TOLUCA 163 1-IN-10 PEAK DEMAND 1.013 26079 9 233 28 1.019 LADWP RIVER Gen 2181 MW 26063

207 8 1.000101 3 199 7 HOLYWD_E HOLYWD_F 1.003 STJOHN Gen 403 VAR 26082 26182 178 26068 Load 5751 MW 1.003 1.009 TOLUCA 1.009 3 Load 1261 VAR 26077 TARZANA 1.000 1.012 1.000 Int -2332 MW 26093 HOLYWDLD Loss 392 MW 1.010 26085 Pres 1454 MW 1.005 14 10 Qres 2159 MVR 154 48 119 3 1.000 60 2 60 2 VELASCO TARZANA HOLYWD2 26092 HOLYWD1 26080 MAJOR LADWP PATHS 1.010 26083 26084 1.003 OLYMPC 1.008 26087 1.008 VA-LA 2529MW

1.013 119 6 PDCI ( 2779MW) CNTURYLD 60 5 64 60 5 85 26072 IPPDC ( 1705MW) 14 1.004 204 0 85 57 41 64 1.000 14 35 1.000 0 204 FAIRFAX 57 41 26076 35 1.000 1.007 1.000 OLYMPCLD

26088 AIRPORT 55 1 GRAMERC1 CNTURY CNTURY2 1.007 26089 55 26014 26069 26071 1.009 1.010 1.009 1.012 20 198 88 SCATERGD 19 14 26066 0 33 23 1.000 1.016 19 4 198 0 CNTURY1 GRAMERC2 14

1.000 26070 26015 52 255 33 1.010 88 1.012 4 428 38 4 23 3 30 163 23 10 52 1.000 4 27 2 TAP 1 5 26095 1.008 1.000 10 100 SCATERGD 23 1 26065 2 5 17 1.012 TAP 2 64 1.000 100 26096 23 HALLDALE 1.008 17 2

64 108 3

1 26016 1.000 117 1.008 23 WLMNTN 9 26073 1.007 5 117 100 11 2 15 9 10 1.000 13 6 12 163 13

14 65 200 13 5 22 8 1.000 1.000 190 HARBOR 15 26091 1.006 150 19 9 1.000

2 13 214 150 81 10 81 16 19 2 1 6 1.000 1.000 81 2 81 1 1 6 13

1.000 HAYNES HARB WLMNTNLD 26025 26019 26075 1.012 1.019 1.019

General Electric International, Inc. PSLF Program Sat Oct 16 11:23:10 2010 2010hs10_lml.sav

WESTERN ELECTRICITY COORDINATING COUNCIL MW/MVAR 2010 HS3B APPROVED OPERATING CASE 2010hs10_lml.drw 02/22/10 - 2010 DWP 1-in-10 Summer Peak Rating = 1 INTERMOUNTAIN OWENS UP 1 2 26129 37 MEAD S 1.072 1 19012

4 900 258 HOOVER

900 258 1.006 CELILO 1.048 N1 100 BIGEDDY3 BIGEDDY1 BIG EDDY 15 198 41343 41341 40111 37 4 100 18 MEAD PP1 PP2 N2 1.041 1.039 1.076 30 26051 OWENSMID 37 1.017 1 2 1 N3 100 26130 5 1.025 24 208

1.048 1.025 1.071 110 17 131 131 40 2 10 4 INTERMT N4 24

584 27 525 14 53 57 MEAD 805 66 866 32 26043 1.000 74 9 1.050 MCCULLGH 19038 OWENSCON 26046 MEAD N 1.054 26131 36 1.004 19011 1.070 1 78 48 0.996 23 9 MWC345 98 1.048 CASTAIC 0 475 27135 53 1115 1705 841 1.000 1.000 3 136 1.000 1.000 1.056 27 POLE 2 PP 1 PP 2 b 1.000 1.000 2 POLE 1 98 125 63 1 2 3 4 5 6 26057 26059 110 17 1 1.014 1.013 INYO 3 1.000 NAVAJO 24729 14003 39 1 1.065 19 13 19 13 MCCULLGH CRYSTAL 1.090 805 221 63 14 26048 26123 1 158 2 1.053 1.051 196 26 4 1 24 4 805 COTTONWD 68 1 26136 750 1024 1 195

1.000 805 1.043 97 63 1 1.000 MOHAVE195 24 4 68 ELDORDO

1.000 1.000 40 0 24097 20 23 20 0 26 3 158 2 24042 OLIVE 1 1.058 1.000 GE CP 1.000 1.053 536 1.000 1.000 1.000 26052 1.000 b 1 1.014 IPP DC 79 135 99 CASTAIC Milford Wind Corridor 26010 PT230 0 116 736 1.024 27031 1.000 67 1.018 648 482 38 8 3 153 16 ADELANTO 85 458

123 23 104 21 40 26003 1 40 638 342 12 12 1.045 79 SYLMAR2 RINALDI Pine Tree 1 1652 26099 26061 850 1.022 1.021 655 194 345 0 20 1247 714 b MARKETPL 788 278 RINALDI BARRENRD 26044 26132 1.053 SYLMARLA 54 26062

1.000 1.019 26094 1.029 559 SYLMAR1 1.024 278 11 26097 1.030 54 VICTORVL

0.986 295 1.000 1.030 RINALDI2 26105 39 26115 1.046 622 1.029 624 107 VALLEY 24 1170

1.030 295 1.000 1244 719 113 367 22 35 44 22 29 2 26103 5 7 367 76 SYLMAR S 39 55 1.018 VALLEY 76 278 33 LUGO 113 24147 6 154 26102 24086 295 55 1.013 1.000 1.046 0.988 31 39 295 1.000 5 202 7 154 0 b 6 295 832 202 31 943 434 7 1.000 321 6 0.0 801.2 59 151 126 VICTORVL 8 ATWATER 33 57 GLENDAL 26104 b 321 26081 26013 1.006 1.040 388 292 33 1.008 200 43 34 197 18 303 34 20 388 229 NRTHRDGE 468 43 19 26086 55

1.009 1.000 170 468 60 TOLUCA 55 26078 1.000 TOLUCA 164 1-IN-10 PEAK DEMAND 1.012 26079 8 233 27 1.018 LADWP RIVER Gen 2200 MW 26063

207 8 1.000102 3 199 8 HOLYWD_E HOLYWD_F 1.003 STJOHN Gen 416 VAR 26082 26182 179 26068 Load 5771 MW 1.003 1.008 TOLUCA 1.008 3 Load 1265 VAR 26077 TARZANA 1.000 1.011 1.000 Int -2333 MW 26093 HOLYWDLD Loss 393 MW 1.009 26085 Pres 1434 MW 1.005 16 10 Qres 2144 MVR 157 49 121 2 1.000 60 2 60 2 VELASCO TARZANA HOLYWD2 26092 HOLYWD1 26080 MAJOR LADWP PATHS 1.009 26083 26084 1.003 OLYMPC 1.007 26087 1.007 VA-LA 2530MW

1.013 121 5 PDCI ( 2779MW) CNTURYLD 60 5 63 60 5 87 26072 IPPDC ( 1705MW) 14 1.004 205 0 87 57 42 63 1.000 14 35 1.000 0 205 FAIRFAX 56 42 26076 35 1.000 1.006 1.000 OLYMPCLD

26088 AIRPORT 54 1 GRAMERC1 CNTURY CNTURY2 1.006 26089 55 26014 26069 26071 1.008 1.010 1.009 1.012 20 198 89 SCATERGD 18 14 26066 1 34 23 1.000 1.015 18 4 198 1 CNTURY1 GRAMERC2 14

1.000 26070 26015 53 255 34 1.010 89 1.012 4 428 35 4 23 3 33 163 23 10 53 1.000 4 27 2 TAP 1 5 26095 1.008 1.000 10 100 SCATERGD 23 1 26065 2 5 18 1.012 TAP 2 65 1.000 100 26096 23 HALLDALE 1.008 18 2

65 108 4

1 26016 1.000 117 1.008 23 WLMNTN 9 26073 1.007 5 117 100 11 2 15 9 10 1.000 13 6 12 163 13

14 65 200 14 5 22 8 1.000 1.000 190 HARBOR 15 26091 1.005 150 19 9 1.000

2 13 214 150 81 10 81 17 19 2 1 6 1.000 1.000 81 2 81 1 1 6 13

1.000 HAYNES HARB WLMNTNLD 26025 26019 26075 1.011 1.019 1.018

General Electric International, Inc. PSLF Program Sat Oct 16 11:26:37 2010 2010hs11_lml.sav

WESTERN ELECTRICITY COORDINATING COUNCIL MW/MVAR 2010 HS3B APPROVED OPERATING CASE 2010hs11_lml.drw 02/22/10 - 2011 DWP 1-in-10 Summer Peak Rating = 1 INTERMOUNTAIN OWENS UP 1 2 26129 37 MEAD S 1.072 1 19012

4 900 258 HOOVER

900 258 1.005 CELILO 1.048 N1 100 BIGEDDY3 BIGEDDY1 BIG EDDY 15 198 41343 41341 40111 37 4 100 18 MEAD PP1 PP2 N2 1.041 1.039 1.076 30 26051 OWENSMID 37 1.015 1 2 1 N3 100 26130 4 1.025 24 208

1.048 1.025 1.071 110 18 137 137 40 3 10 6 INTERMT N4 24

578 36 521 22 52 57 MEAD 809 65 871 34 26043 1.000 74 9 1.050 MCCULLGH 19038 OWENSCON 26046 MEAD N 1.053 26131 36 1.002 19011 1.070 1 78 48 0.995 25 8 MWC345 97 1.048 CASTAIC 0 475 27135 50 1096 1705 841 1.000 1.000 4 134 1.000 1.000 1.056 30 POLE 2 PP 1 PP 2 b 1.000 1.000 23 POLE 1 97 125 60 1 2 3 4 5 6 26057 26059 110 17 1 1.018 1.016 INYO 4 1.000 NAVAJO 24729 14003 39 1 19 13 19 13 77 38 1.065 MCCULLGH CRYSTAL 1.089 805 14 26048 26123 1 160 4 1.051 1.049 199 26 6 0 24 7 805 COTTONWD 66 1 26136 740 1017 4 199

1.000 805 1.045 82 69 1 1.000 ELDORDO MOHAVE198 24 6 66

1.000 1.000 40 0 24042 24097 23 20 20 0 OLIVE 26 6 160 4 4 1.050 1.055 26052 1.000 GE CP 1.000 557 1.000 1.000 1.000 1.000 b 1 199 1.023 IPP DC 76 95 CASTAIC Milford Wind Corridor 107 26010 PT230 4 766 1.033 27031 1.000 72 1.022 684 610 MARKETPL 503 38 116 15 ADELANTO 84 22 75 8 66 22 86 311 26044 40 40 26003 1 674 484 1.051 15 15 1.044 77 291 SYLMAR2 RINALDI Pine Tree 1 1652 26099 26061 850 1.034 HLTAP 1.031 27204 195 731 1.037 0 25 250 109 1242 716 b 104 807 HLAKE 301 RINALDI BARRENRD 26132 27205 SYLMARLA 32 26062 1.037

1.000 1.023 26094 1.035 606 SYLMAR1 1.036 301 25 26097 1.073 32 VICTORVL 125 53 125 53 0.958 287 1.000 RINALDI2 1.073 26115 26105 1 1 113 Harper Lake 672 1.035 675 1.045 58 VALLEY 14 1165

1.073 287 1.000 1243 724 113 359 47 75 142 47 95 95 26103 13 7 359 76 SYLMAR S 113 44 1.024 VALLEY 76 290 31 LUGO 113 24147 6 158 26102 24086 287 44 1.019 1.000 1.043 0.960 33 113 296 1.000 5 211 28 158 0 b 3 296 830 211 33 988 473 28 1.000 319 3 0.0 755.8 77 151 108 VICTORVL 8 ATWATER 50 45 GLENDAL 26104 b 319 26081 26013 1.010 1.039 409 305 50 1.012 160 47 53 210 0 318 54 34 409 245 NRTHRDGE 490 47 35 26086 40

1.019 1.000 216 490 55 TOLUCA 40 26078 1.000 TOLUCA 178 1-IN-10 PEAK DEMAND 1.016 26079 18 268 38 1.020 LADWP RIVER Gen 1998 MW

99 3 26063

203 8 1.000 195 8 HOLYWD_E HOLYWD_F 1.006 STJOHN Gen 294 VAR 26082 26182 188 26068 Load 5814 MW 1.006 1.012 TOLUCA 1.012 4 Load 1274 VAR 26077 TARZANA 1.000 1.015 1.000 Int -2333 MW 26093 HOLYWDLD Loss 398 MW 1.018 26085 0 3 Pres 1686 MW 1.009 Qres 2535 MVR 156 30 117 3 1.000 52 2 52 2 VELASCO TARZANA HOLYWD2 26092 HOLYWD1 26080 MAJOR LADWP PATHS 1.017 26083 26084 1.006 OLYMPC 1.011 26087 1.011 VA-LA 2692MW

1.019 117 0 PDCI ( 2779MW) CNTURYLD 52 4 53 52 4 71 26072 IPPDC ( 1705MW) 7 1.006 197 2 71 74 40 53 1.000 7 29 1.000 2 197 FAIRFAX 73 40 26076 29 1.000 1.010 1.000 OLYMPCLD

26088 AIRPORT 46 2 GRAMERC1 CNTURY CNTURY2 1.013 26089 46 26014 26069 26071 1.012 1.012 1.010 1.012 22 207 81 SCATERGD 46 9 26066 3 35 24 1.000 1.020 46 3 207 3 CNTURY1 GRAMERC2 9

1.000 26070 26015 52 239 35 1.012 81 1.012 3 420 60 3 24 3 12 171 23 12 52 1.000 3 33 2 TAP 1 6 26095 1.009 1.000 12 50 SCATERGD 23 1 26065 2 6 13 1.015 TAP 2 65 1.000 50 26096 24 HALLDALE 1.009 13 2

65 83 1

1 26016 1.000 146 1.009 24 WLMNTN 8 26073 1.008 5 146 150 11 2 13 8 10 1.000 13 6 12 140 9

14 65 200 12 5 18 8 1.000 1.000 166 HARBOR 12 26091 1.007 150 15 9 1.000

2 12 185 150 81 10 81 14 15 2 1 6 1.000 1.000 81 2 81 1 1 6 12

1.000 HAYNES HARB WLMNTNLD 26025 26019 26075 1.013 1.020 1.019

General Electric International, Inc. PSLF Program Sat Oct 16 11:19:25 2010 2010hs12_lml2.sav

WESTERN ELECTRICITY COORDINATING COUNCIL MW/MVAR 2010 HS3B APPROVED OPERATING CASE 2010hs12_lml2.drw 02/22/10 - 2012 DWP 1-in-10 Summer Peak Rating = 1 INTERMOUNTAIN OWENS UP 1 2 26129 37 MEAD S 1.067 1 19012

14 900 258 HOOVER

900 258 1.003 CELILO 1.048 N1 100 BIGEDDY3 BIGEDDY1 BIG EDDY 15 198 41343 41341 40111 37 14 100 18 MEAD PP1 PP2 N2 1.041 1.039 1.076 30 26051 OWENSMID 37 1.014 1 2 1 N3 100 26130 16 1.025 25 208

1.048 1.025 1.066 110 19 138 138 40 1 10 2 INTERMT N4 25

579 35 522 21 49 53 MEAD 809 63 870 30 26043 1.000 74 31 1.050 MCCULLGH 19038 OWENSCON 26046 MEAD N 1.051 26131 36 1.001 19011 1.063 1 78 48 0.994 25 24 MWC345 97 1.048 CASTAIC 0 475 27135 48 1094 1705 841 1.000 1.000 5 134 1.000 1.000 1.056 30 POLE 2 PP 1 PP 2 INYO b 1.000 1.000 41 POLE 1 24729 97 124 57 1 2 3 4 5 6 26057 26059 110 54 1.053 1 1.012 1.011 OWENYOTP 5 1.000 NAVAJO 26946 14003 39 1 19 13 19 13 99 70 138 1.000 MCCULLGH CRYSTAL 1.089 26048 805 14 100 26123 1 48 1.049 1.047 202

26 2 24 3 1 1 235 26 66 805 Owenyo Solar 741 1017 1 14 6 202

1.000 805 COTTONWD 67 76 1 1.000 26136 ELDORDO MOHAVE201 24 2 0.990 66 1.000 1.000 40 0 24042 24097 20 23 20 0 OLIVE 26 2 6 1.048 1.053 26052 1.000 GE CP 1.000 556 1.000 1.000 1.000 1.000 234 1 198 1.007 IPP DC 76 93 CASTAIC 5 Milford Wind Corridor 98 26010 b PT230 6 765 1.018 27031 1.000 74 0.979 684 609 MARKETPL 502 36 123 26 ADELANTO 92 29 67 8 73 26 102 311 26044 40 40 26003 1 674 484 1.049 14 14 1.037 61 273 SYLMAR2 RINALDI Pine Tree 1 1652 26099 26061 850 1.014 HLTAP 1.013 27204 262 731 1.032 0 38 250 109 1244 716 b 88 776 HLAKE 301 RINALDI BARRENRD 26132 27205 SYLMARLA 52 26062 1.032

1.000 0.978 26094 1.020 606 SYLMAR1 1.016 301 21 26097 1.030 52 VICTORVL 125 53 125 53 0.979 289 1.000 RINALDI2 1.030 26105 1 1 54 26115 Harper Lake 670 1.020 673 1.039 101 VALLEY 33 1141

6 3

1.030 289 1.000 1242 722 113 352 4 71 64 46 43 4 26103 85 7 352 112 SYLMAR S 54 70 1.011 VALLEY 112 301 35 LUGO 113 24147 6 159 26102 24086 289 70 1.006 1.000 1.041 0.982 35 54 308 1.000 5 217 18 159 0 b 5 308 820 217 35 1005 473 18 1.000 330 5 0.0 790.0 58 151 138 VICTORVL 8 ATWATER 39 72 GLENDAL 26104 b 330 26081 26013 0.999 1.033 415 314 39 1.000 172 41 27 218 10 327 26 14 415 254 NRTHRDGE 498 41 12 26086 50

1.001 1.000 219 498 41 TOLUCA 50 26078 1.000 TOLUCA 184 1-IN-10 PEAK DEMAND 1.004 26079 2 273 10 1.009 LADWP RIVER Gen 1978 MW 26063

213 11 1.000104 4 205 10 HOLYWD_E HOLYWD_F 0.997 STJOHN Gen 623 VAR 26082 26182 193 26068 Load 5873 MW 0.997 1.000 TOLUCA 1.000 13 Load 1288 VAR 26077 TARZANA 1.000 1.003 1.000 Int -2333 MW 26093 HOLYWDLD Loss 419 MW 1.001 26085 Pres 1806 MW 0.996 5 10 Qres 2268 MVR 167 60 124 4 1.000 62 3 62 3 VELASCO TARZANA HOLYWD2 26092 HOLYWD1 26080 MAJOR LADWP PATHS 1.002 26083 26084 0.997 OLYMPC 1.000 26087 1.000 VA-LA 2718MW

1.006 124 8 PDCI ( 2779MW) CNTURYLD 62 7 64 62 7 77 26072 IPPDC ( 1705MW) 13 0.998 207 1 77 70 46 64 1.000 13 31 1.000 1 207 FAIRFAX 69 46 26076 30 1.000 1.000 1.000 OLYMPCLD

26088 AIRPORT 54 1 GRAMERC1 CNTURY CNTURY2 0.999 26089 55 26014 26069 26071 1.002 1.004 1.003 1.004 19 212 89 SCATERGD 18 8 26066 2 34 24 1.000 1.010 18 6 212 2 CNTURY1 GRAMERC2 8

1.000 26070 26015 53 249 34 1.004 89 1.004 6 428 12 6 24 3 57 169 23 11 53 50

1.000 1 2 3 6 24 28 TAP 1 1.000 26095 1.002 50 1.000 11 SCATERGD 23 24 2

26065 2 3 1.000 1.006 TAP 2 66 26096 22 HALLDALE 1.002 5 1 26016 66 82 13 120 1.002 22 WLMNTN 14 26073 1.001 6 120 100 11 2 24 14 10

1.000 200 1.000 29 8

13 1.000 12 140 22 150 9 14 65 25 19 5 1.000 1.000 150 10 167 25

HARBOR 24 1.000 26091 1.000 11

1.000 12

2 16 186 13 81 81 26 2 4 3 1.000 14 1.000 81 2 81 15 1 4 3 16 1.000

1.000 16 HARB WLMNTNLD HAYNES 26019 26075 26025 1.016 1.016 1.008

General Electric International, Inc. PSLF Program Fri Oct 15 15:39:08 2010 2010hs13_lml.sav

WESTERN ELECTRICITY COORDINATING COUNCIL MW/MVAR 2010 HS3B APPROVED OPERATING CASE 2010hs13_lml.drw 02/22/10 - 2013 DWP 1-in-10 Summer Peak Rating = 1 INTERMOUNTAIN OWENS UP 1 2 26129 37 MEAD S 1.043 1 19012 258 8 900 HOOVER

900 258 1.004 CELILO 1.048 N1 100 BIGEDDY3 BIGEDDY1 BIG EDDY 15 198 41343 41341 40111 37 8 100 18 MEAD PP1 PP2 N2 1.041 1.039 1.076 30 26051 OWENSMID 37 1.014 1 2 1 N3 100 26130 10 1.025 25 208

1.048 1.025 1.043 110 19 138 138 40 2 10 4 INTERMT N4 25

581 31 523 18 50 55 MEAD 807 58 868 20 26043 1.000 74 18 1.050 MCCULLGH 19038 OWENSCON 26046 MEAD N 1.052 26131 36 1.002 19011 1.040 1 78 48 0.994 25 15 MWC345 97 1.048 CASTAIC 0 475 27135 49 1093 1705 841 1.000 1.000 4 134 1.000 1.000 1.056 30 POLE 2 PP 1 PP 2 INYO b 1.000 1.000 35 POLE 1 24729 97 124 58 1 2 3 4 5 6 26057 26059 110 33 1.034 1 1.015 1.013 OWENYOTP 4 1.000 NAVAJO 26946 14003 39 1 19 13 19 13 57 65 160 1.000 MCCULLGH CRYSTAL 1.089 26048 805 14 100 26123 1 22 1.050 1.048 201

26 4 24 5 1 1 257 22 66 805 Owenyo 743 1016 1 12 Solar 5 201

1.000 805 COTTONWD 72 74 1 1.000 26136 ELDORDO MOHAVE200 24 4 0.996 66 1.000 1.000 40 0 24042 24097 20 23 20 0 OLIVE 26 4 5 1.049 1.054 26052 1.000 GE CP 1.000 556 1.000 1.000 1.000 1.000 255 1 198 1.015 76 94 CASTAIC 24 Milford Wind Corridor

IPP DC 99 26010 b PT230 5 765 1.021 27031 1.000 72 51 1.030 684 608 MARKETPL

164 20 264 29 237.6 502 37 7 1 12 Pine Tree ADELANTO 74 9 74 9 74 9 97 310 26044

118 23 40 40 26003 HSKLLCYN 1 674 484 1.050 26135 20 20 1.039 SYLMAR2 1.021 138 1 1652 66 278 26099 193 8 850 1.018 51 1 88 1 HLTAP 193 4 4 27204 250 250 RINALDI 1 731 1.034 0 26061 48 72 250 109 1245 715 b 92 1.018 Beacon HLAKE 782 RINALDI BARRENRD BCON230 Solar 299 26062 26132 26905 27205 SYLMARLA 1.032 1.033 1.033 48 1.024 602 26094 1.000 SYLMAR1 1.020 10 26097 1.030 299 VICTORVL 125 53 125 53 0.983 339 48 RINALDI2 1.030 1.000 26105 1 1 36 26115 669 Harper Lake 666 1.024 1.041 VALLEY 21 1143

0 4

1.030 339 1243 720 92 113 352 4 62 35 40 24 2 26103 1.000 65 7 352 106 SYLMAR S 36 64 1.014 VALLEY 106 304 33 LUGO 113 24147 6 162 26102 24086 339 64 1.008 1.000 1.042 0.985 36 36 320 1.000 5 219 5 162 0 b 4 320 822 219 36 1008 414 5 1.000 339 4 0.0 795.3 50 151 135 VICTORVL 8 ATWATER 42 66 GLENDAL 26104 b 339 26081 26013 1.002 1.035 380 323 42 1.003 260 31 34 226 32 336 34 18 380 263 NRTHRDGE 500 31 17 26086 49

1.007 1.000 220 500 40 TOLUCA 49 26078 1.000 TOLUCA 190 1-IN-10 PEAK DEMAND 1.007 26079 2 281 14 1.012 LADWP RIVER Gen 1822 MW 26063

217 10 1.000106 4 208 9 HOLYWD_E HOLYWD_F 0.999 STJOHN Gen 497 VAR 26082 26182 198 26068 Load 5967 MW 0.999 1.003 TOLUCA 1.003 13 Load 1308 VAR 26077 TARZANA 1.000 1.006 1.000 Int -2333 MW 26093 HOLYWDLD Loss 418 MW 1.007 26085 Pres 1983 MW 0.999 7 14 Qres 2483 MVR 181 86 132 10 1.000 62 6 62 6 VELASCO TARZANA HOLYWD2 26092 HOLYWD1 26080 MAJOR LADWP PATHS 1.009 26083 26084 1.000 OLYMPC 1.006 26087 1.006 VA-LA 2716MW

1.016 131 14 PDCI ( 2779MW) CNTURYLD 62 10 69 62 10 80 26072 IPPDC ( 1705MW) 17 1.001 215 3 80 69 55 69 1.000 17 38 1.000 3 215 FAIRFAX 69 55 26076 38 1.000 1.005 1.000

OLYMPCLD

1 4

54 1 CNTURY2

26088 AIRPORT 5 GRAMERCY CNTURY 1.007 26089 26014 26069 26071 1.008 1.006 1.008 1.008 214 34 89 SCATERGD 16 6 26066 4 11 30 1.000 1.018 125 16 34 89 214 29 4 CNTURY1 11 30 6

1.000 26070 56 125 1.008 428 29 9 3 24 168 56 50 1.000 11 11 9 21 1

41 1.000 8 TAP 1 8 1.000 26095 50 SCATERGD 1.008 21 2

26065 23 11 1.000 1.012 25 2 TAP 2 8 HALLDALE 26096 11 5 1 26016 1.008 25 81 10 119 1.008 11 WLMNTN 26073 16 1.006 6 119 100 11 2 15 16

1.000 1.000 200 26 8

13 140 1.000

1.000 19 150 9 14 10 23 1.000 1.000 1.000 150 10 167 23

21 1.000 81 12 2 13 11 1.000 1.000

1.000 12 65 81 187 13 1 13 13 5 1.000

1.000 22 1.000 14 HARBOR 26091 15 1.006

1.000 16 HAYNES 26025 1.010

General Electric International, Inc. PSLF Program Fri Oct 15 15:42:49 2010 2010hs14_lml-r.sav

WESTERN ELECTRICITY COORDINATING COUNCIL MW/MVAR 2010 HS3B APPROVED OPERATING CASE 2010hs14_lml-r.drw 02/22/10 - 2014 DWP 1-in-10 Summer Peak Rating = 1 INTERMOUNTAIN OWENS UP 1 2 26129 MEAD S 1.010 1 19012 258 900 HOOVER

900 258 1.004 CELILO 1.048 N1 100 BIGEDDY3 BIGEDDY1 BIG EDDY 15 198 41343 41341 40111 100 18 MEAD PP1 PP2 N2 1.041 1.039 1.076 0 30 26051 OWENSMID 1.014 1 2 1 1 N3 100 26130 1.025 25 208

1.048 1.025 1.010 110 19 139 139 40 1 10 3 INTERMT N4 25

581 31 523 18 49 54 MEAD 807 59 868 21 26043 1.050 MCCULLGH 1.000 19038 OWENSCON 0 26046 MEAD N 1.052 26131 1.001 19011

1.010 2 1 78 48 0.994 25 MWC345 97 CASTAIC 1.048 27135 49 1093 1705 841

1.000 1.000 1.000 0 475 1.056 4 134 30

0 2 1.000 POLE 2 PP 1 PP 2 INYO 1.000 1.000 37 POLE 1 24729 97 124 58 1 2 3 4 5 6 26057 26059 1.009 b 1 1.014 1.012 OWENYOTP 4 1.000 NAVAJO b 26946 14003 39 1 19 13 19 13

13 63 49 MCCULLGH CRYSTAL 1.089 1.000 Owenyo 805 14 200 26048 26123 1 2 1 1.049 1.048 201

26 4 24 4 Solar 1 247 0 66 805 744 1016 1 15 5 201

1.000 805 COTTONWD 71 74 1 1.000 26136 ELDORDO MOHAVE201 24 3 0.997 66

1.000 1.000 40 0 24042 24097 20 23 20 0 26 3 244 OLIVE 5 1.049 1.054 26052 1.000 25 GE CP 1.000 556 1.000 1.000 1.000 1.000 1 198 1.012 PT230 76 94 CASTAIC Milford Wind Corridor Pine Tree 27031 IPP DC 98 765 26010 1.024 6 1.021 1.000 72 40 684 607 MARKETPL

210 27 259 19 1 237.6 502 37 16 84 ADELANTO

44 12 44 12 44 12 99 310 HSKLLCYN 26044

146 26 81 26003 45 674 26135 1 58 1.038 485 1.049 1.020 SYLMAR2 147 Pine Canyon 1 1652 64 277 26099 206 10 850 1.017 94 5 HLTAP 120 5 206 7 7 27204 250 250 RINALDI 1 731 1.033 0 26061 104 132 250 109 1245 715 b 91 1.017 Beacon HLAKE 781 RINALDI BARRENRD BCON230 Solar 298 26062 26132 26905 27205 SYLMARLA 1.031 1.033 1.033 49 1.023 599 26094 1.000 SYLMAR1 1.019 12 26097 1.030 298 VICTORVL 125 53 125 53 0.982 354 49 RINALDI2 1.030 1.000 26105 1 1 43 26115 666 Harper Lake 663 1.023 1.040 VALLEY 23 1136

8 7

1.030 354 1243 721 93 113 350 3 59 55 38 37 3 26103 1.000 75 null 7 350 110 SYLMAR S 43 67 1.013 VALLEY 110 310 36 LUGO 113 24147 6 164 26102 24086 354 67 1.007 1.000 1.042 0.984 38 43 335 1.000 5 222 5 164 0 b 5 335 822 222 38 1016 414 5 1.000 352 5 0.0 794.7 59 151 142 VICTORVL 8 ATWATER 45 68 GLENDAL 26104 b 352 26081 26013 1.000 1.034 382 339 45 1.001 276 35 37 242 36 353 36 19 382 281 NRTHRDGE 504 35 18 26086 50

1.005 1.000 241 504 40 TOLUCA 50 26078 1.000 TOLUCA 203 1-IN-10 PEAK DEMAND 1.005 26079 2 306 14 1.010 LADWP RIVER Gen 1733 MW 26063

217 10 1.000106 4 209 10 HOLYWD_E HOLYWD_F 0.997 STJOHN Gen 491 VAR 26082 26182 209 26068 Load 6022 MW 0.997 1.001 TOLUCA 1.001 14 Load 1320 VAR 26077 TARZANA 1.000 1.004 1.000 Int -2333 MW 26093 HOLYWDLD Loss 420 MW 1.006 26085 Pres 1734 MW 0.997 3 16 Qres 2257 MVR 189 87 135 9 1.000 62 6 62 6 VELASCO TARZANA HOLYWD2 26092 HOLYWD1 26080 MAJOR LADWP PATHS 1.008 26083 26084 0.998 OLYMPC 1.004 26087 1.004 VA-LA 2725MW

1.014 135 14 PDCI ( 2779MW) CNTURYLD 62 10 71 62 10 77 26072 IPPDC ( 1705MW) 18 0.999 216 3 77 74 56 71 1.000 18 38 1.000 3 216 FAIRFAX 73 56 26076 38 1.000 1.003 1.000

OLYMPCLD

1 2

52 1 CNTURY2

26088 AIRPORT 5 GRAMERCY CNTURY 1.006 26089 26014 26069 26071 1.006 1.007 1.005 1.006 SCATERGD 217 35 87 26066 18 6 1.016 4 11 30 1.000 122 18 35 87 217 27 4 CNTURY1 11 30 6

1.000 26070 56 122 1.006 428 27 10 3 30 174 56 50 1.000 11 11 10 26 1

42 1.000 7 TAP 1 7 26095 1.000 1.007 2 SCATERGD 24 26065 24 11 1.000 1.010 11 2 TAP 2 7 HALLDALE 26096 5 1 26016 1.007 24 68 10 123 1.007 11 WLMNTN 26073 18 1.005 6 123 100 11 2 17 18

1.000 1.000 200 31 8

13 128 1.000

1.000 19 150 9 14 10 27 1.000 1.000 1.000 150 10 156 27

20 1.000 81 12 2 14 11 1.000 1.000

1.000 12 65 81 174 13 1 14 14 5 1.000

1.000 21 1.000 14 HARBOR 26091 15 1.005

1.000 16 HAYNES 26025 1.008

General Electric International, Inc. PSLF Program Fri Oct 15 16:20:56 2010 2010hs15_lml-r.sav

WESTERN ELECTRICITY COORDINATING COUNCIL MW/MVAR 2010 HS3B APPROVED OPERATING CASE 2010hs15_lml-r.drw 02/22/10 - 2015 DWP 1-in-10 Summer Peak Rating = 1 INTERMOUNTAIN OWENS UP 1 2 26129 35 MEAD S 1.041 1 19012 900 14 258 HOOVER 900 258 1.004 CELILO 1.048 N1 100 BIGEDDY3 BIGEDDY1 BIG EDDY 15 198 41343 41341 40111 35 14 100 18 MEAD PP1 PP2 N2 1.041 1.039 1.076 30 26051 OWENSMID 35 1.014 1 2 1 N3 100 26130 15 1.025 25 208

1.048 1.025 1.040 110 19 139 139 40 1 10 2 INTERMT N4 25

581 33 523 19 49 54 MEAD 808 60 869 25 26043 1.000 70 30 1.050 MCCULLGH 19038 OWENSCON 26046 MEAD N 1.052 26131 1.001 19011

1.037 1 78 48 0.994 25 MWC345 97 CASTAIC 1.048 27135 49 1093 1705 841

1.000 1.000 1.000 475 0 4 134 1.000 1.056 30 POLE 2 PP 1 PP 2 INYO 1.000 1.000 38 POLE 1 70 30 24729 97 124 58 1 2 3 4 5 6 26057 26059 1.031 b 1 1.013 1.012 OWENYOTP 4 1.000 NAVAJO b 26946 14003 39 1 19 13 19 13

2 68 121 MCCULLGH CRYSTAL 1.089 1.000 Owenyo 805 14 200 26048 26123 1 20 1 1.049 1.048 202

26 3 24 3 Solar 1 317 17 66 805 744 1016 1 16 201 6 805 COTTONWD 1.000 70 75 1 1.000 26136 ELDORDO MOHAVE201 24 3 0.988 66

1.000 1.000 40 0 24042 24097 20 23 20 0 26 2 314 OLIVE 6 1.049 1.053 26052 1.000 5 GE CP 1.000 556 1.000 1.000 1.000 1.000 1 198 1.010 PT230 76 94 CASTAIC Milford Wind Corridor Pine Tree 27031 IPP DC 97 765 26010 1.017 6 1.019 1.000 72 40 684 607 MARKETPL

216 22 265 15 1 236.1 501 37 12 84 ADELANTO

49 14 49 14 49 14 100 310 HSKLLCYN 26044

148 24 77 26003 45 674 26135 1 58 1.038 484 1.049 1.017 SYLMAR2 177 Pine Canyon 1 1652 63 275 26099 221 15 850 1.016 HLTAP 105 14 150 9 221 17 17 27204 250 250 RINALDI 1 731 1.033 0 26061 129 160 250 109 1245 715 b 90 1.016 Beacon HLAKE 779 RINALDI BARRENRD BCON230 Solar 297 26062 26132 26905 27205 SYLMARLA 1.024 1.026 1.033 50 1.022 596 26094 1.000 SYLMAR1 1.018 14 26097 1.030 297 VICTORVL 125 53 125 53 0.981 356 50 RINALDI2 1.030 1.000 26105 1 1 41 26115 663 Harper Lake 660 1.022 1.040 VALLEY 25 1136

1.030 356 1243 721 96 113 350 37 58 58 37 39 39 26103 1.000 82 7 350 112 SYLMAR S 41 69 1.012 VALLEY 112 312 37 LUGO 113 24147 6 163 26102 24086 356 69 1.006 1.000 1.042 0.983 38 41 342 1.000 5 223 6 163 0 b 5 342 821 223 38 1019 414 6 1.000 359 5 0.0 792.9 60 151 146 VICTORVL 8 ATWATER 46 71 GLENDAL 26104 b 359 26081 26013 0.998 1.033 383 345 46 1.000 280 33 36 247 46 359 36 19 383 287 NRTHRDGE 505 33 17 26086 51

1.004 1.000 242 505 38 TOLUCA 51 26078 1.000 TOLUCA 207 1-IN-10 PEAK DEMAND 1.004 26079 4 311 13 1.009 LADWP RIVER Gen 1801 MW 26063

219 10 1.000107 4 210 9 HOLYWD_E HOLYWD_F 0.996 STJOHN Gen 549 VAR 26082 26182 212 26068 Load 6076 MW 0.996 1.000 TOLUCA 1.000 15 Load 1332 VAR 26077 TARZANA 1.000 1.003 1.000 Int -2333 MW 26093 HOLYWDLD Loss 433 MW 1.005 26085 Pres 1901 MW 0.996 4 18 Qres 2404 MVR 190 101 136 13 1.000 61 8 61 8 VELASCO TARZANA HOLYWD2 26092 HOLYWD1 26080 MAJOR LADWP PATHS 1.008 26083 26084 0.997 OLYMPC 1.004 26087 1.004 VA-LA 2725MW

1.015 136 17 PDCI ( 2779MW) CNTURYLD 61 11 71 61 11 78 26072 IPPDC ( 1705MW) 20 0.998 219 3 78 74 61 71 1.000 20 39 1.000 3 219 FAIRFAX 73 61 26076 39 1.000 1.004 1.000

OLYMPCLD

2 1

51 2 CNTURY2

26088 AIRPORT 5 GRAMERCY CNTURY 1.006 26089 26014 26069 26071 1.007 1.006 1.004 1.005 SCATERGD 218 36 87 26066 19 6 1.018 6 11 31 1.000 128 125 19 36 87 4 9 218 15 6 11 31 CNTURY1 1.000 6

100 1.000 26070 57 5 8 125 1.005 100 1.000 15 10 6 8 178 57 50

1.000 27 1 100 12 12 10 7 48 1.000 8 7 TAP 1 7 1.000 26095 1.000 1.006 2 SCATERGD 24 26065 24 12 1.000 1.011 10 2 TAP 2 7 HALLDALE 26096 5 1 26016 1.006 24 67 11 125 1.006 10 WLMNTN 26073 20 1.004 6 125 100 11 2 16 20

1.000 1.000 200 32 8

13 128 1.000

1.000 20 150 9 14 10 29 1.000 1.000 1.000 150 10 156 29

22 1.000 81 12 2 15 11 1.000 1.000

1.000 12 65 81 174 13 1 15 15 5 1.000

1.000 23 1.000 14 HARBOR 26091 15 1.004

1.000 16 HAYNES 26025 1.007

General Electric International, Inc. PSLF Program Fri Oct 15 16:48:37 2010 2010hs16_lml-r.sav

WESTERN ELECTRICITY COORDINATING COUNCIL MW/MVAR 2010 HS3B APPROVED OPERATING CASE 2010hs16_lml-r.drw 02/22/10 - 2016 DWP 1-in-10 Summer Peak Rating = 1 INTERMOUNTAIN OWENS UP 1 2 26129 37 MEAD S 1.043 1 19012 900 8 258 HOOVER 900 258 1.003 CELILO 1.048 N1 100 BIGEDDY3 BIGEDDY1 BIG EDDY 15 198 41343 41341 40111 37 8 100 18 MEAD PP1 PP2 N2 1.041 1.039 1.076 30 26051 OWENSMID 37 1.013 1 2 1 N3 100 26130 9 1.025 25 208

1.048 1.025 1.043 110 19 139 139 40 1 10 1 INTERMT N4 25

579 35 521 21 49 53 MEAD 809 64 870 32 26043 1.000 74 18 1.050 MCCULLGH 19038 OWENSCON 26046 MEAD N 1.051 26131 36 1.001 19011 1.040 1 78 48 0.994 26 15 MWC345 97 1.048 CASTAIC 0 475 27135 48 1093 1705 841 1.000 1.000 5 134 1.000 1.000 1.056 30 POLE 2 PP 1 PP 2 INYO b 1.000 1.000 42 POLE 1 24729 97 124 57 1 2 3 4 5 6 26057 26059 110 32 1.034 1 1.012 1.010 OWENYOTP 5 1.000 NAVAJO b 26946 14003 39 1 19 13 19 13

18 76 159 MCCULLGH CRYSTAL 1.089 1.000 Owenyo 805 14 200 26048 26123 1 22 1 1.049 1.047 202

26 2 24 3 Solar 2 354 47 66 805 744 1016 1 39 202 6 805 COTTONWD 1.000 67 76 1 1.000 26136 ELDORDO MOHAVE202 24 2 0.981 66

1.000 1.000 40 0 24042 24097 20 23 20 0 26 2 350 OLIVE 6 1.048 1.053 26052 1.000 12 GE CP 1.000 556 1.000 1.000 1.000 1.000 1 198 1.007 PT230 76 93 CASTAIC Milford Wind Corridor Pine Tree 27031 IPP DC 96 765 26010 1.009 6 1.015 1.000 73 40 684 607 MARKETPL

225 17 275 12 1 234.0 501 36 6 84 ADELANTO

46 17 46 17 46 17 103 311 HSKLLCYN 26044

156 23 70 26003 45 674 26135 1 58 1.037 484 1.049 1.013 SYLMAR2 185 Pine Canyon 1 1652 60 272 26099 231 23 850 1.013 HLTAP 120 23 163 17 231 28 28 27204 250 250 RINALDI 1 731 1.032 0 26061 129 160 250 109 1244 717 b 87 1.013 Beacon HLAKE 775 RINALDI BARRENRD BCON230 Solar 296 26062 26132 26905 27205 SYLMARLA 1.015 1.017 1.032 53 1.020 596 26094 1.000 SYLMAR1 1.015 19 26097 1.030 296 VICTORVL 125 53 125 53 0.979 360 53 RINALDI2 1.030 1.000 26105 1 1 40 26115 662 Harper Lake 659 1.020 1.039 VALLEY 31 1134

1.030 360 1242 722 101 113 349 38 59 66 38 44 44 26103 1.000 94 7 349 118 SYLMAR S 40 73 1.009 VALLEY 118 312 37 LUGO 113 24147 6 167 26102 24086 360 73 1.003 1.000 1.041 0.981 40 40 346 1.000 5 223 10 167 0 b 5 346 819 223 40 1021 418 10 1.000 359 5 0.0 789.1 66 151 152 VICTORVL 8 ATWATER 46 75 GLENDAL 26104 b 359 26081 26013 0.997 1.032 390 342 46 0.999 291 36 33 244 52 356 33 17 390 283 NRTHRDGE 506 36 15 26086 53

1.000 1.000 226 506 33 TOLUCA 53 26078 1.000 TOLUCA 203 1-IN-10 PEAK DEMAND 1.002 26079 7 300 8 1.007 LADWP RIVER Gen 1907 MW 26063

222 12 1.000109 5 213 11 HOLYWD_E HOLYWD_F 0.995 STJOHN Gen 633 VAR 26082 26182 209 26068 Load 6171 MW 0.995 0.997 TOLUCA 0.997 18 Load 1353 VAR 26077 TARZANA 1.000 1.000 1.000 Int -2333 MW 26093 HOLYWDLD Loss 445 MW 1.002 26085 Pres 2062 MW 0.993 11 18 Qres 2464 MVR 197 110 139 14 1.000 62 8 62 8 VELASCO TARZANA HOLYWD2 26092 HOLYWD1 26080 MAJOR LADWP PATHS 1.005 26083 26084 0.996 OLYMPC 1.002 26087 1.002 VA-LA 2725MW

1.013 139 19 PDCI ( 2779MW) CNTURYLD 62 11 71 62 11 85 26072 IPPDC ( 1705MW) 20 0.997 221 3 85 69 64 71 1.000 20 39 1.000 3 221 FAIRFAX 69 64 26076 39 1.000 1.001 1.000

OLYMPCLD

1 3

53 1 CNTURY2

26088 AIRPORT 5 GRAMERCY CNTURY 1.004 26089 26014 26069 26071 1.004 1.005 1.003 1.004 SCATERGD 218 37 90 26066 18 6 1.016 7 11 30 1.000 128 123 18 37 90 4 14 218 7 7 11 30 CNTURY1 1.000 6

100 1.000 26070 59 5 13 123 1.004 100 1.000 7 11 6 13 181 59 50

1.000 26 1 100 12 12 11 7 50 1.000 13 6 TAP 1 6 1.000 26095 50 1.000 1.005 2 SCATERGD 23 26 26065 25 12 1.000 1.009 10 1 TAP 2 6 HALLDALE 26096 5 1 26016 1.005 23 78 16 126 1.004 10 WLMNTN 26073 22 1.003 6 126 100 11 2 19 22

1.000 1.000 200 31 8

13 140 1.000

1.000 25 150 9 14 10 28 1.000 1.000 1.000 150 10 168 28

27 1.000 81 12 2 16 11 1.000 1.000

1.000 12 65 81 189 13 1 16 16 5 1.000

1.000 28 1.000 14 HARBOR 26091 15 1.003

1.000 16 HAYNES 26025 1.007

General Electric International, Inc. PSLF Program Fri Oct 15 16:56:52 2010 2010hs17_lml-r.sav

WESTERN ELECTRICITY COORDINATING COUNCIL MW/MVAR 2010 HS3B APPROVED OPERATING CASE 2010hs17_lml-r.drw 02/22/10 - 2017 DWP 1-in-10 Summer Peak Rating = 1 INTERMOUNTAIN OWENS UP 1 2 26129 37 MEAD S 1.043 1 19012 900 8 258 HOOVER 900 258 1.003 CELILO 1.048 N1 100 BIGEDDY3 BIGEDDY1 BIG EDDY 15 198 41343 41341 40111 37 8 100 18 MEAD PP1 PP2 N2 1.041 1.039 1.076 30 26051 OWENSMID 37 1.013 1 2 1 N3 100 26130 9 1.025 25 208

1.048 1.025 1.043 110 20 140 140 40 0 10 1 INTERMT N4 25

578 37 520 23 48 52 MEAD 810 67 872 38 26043 1.000 74 18 1.050 MCCULLGH 19038 OWENSCON 26046 MEAD N 1.051 26131 36 1.001 19011 1.040 1 78 48 0.994 26 15 MWC345 96 CASTAIC 1.048 27135 48 1092 1705 841

1.000 1.000 1.000 475 0 5 133 1.000 1.056 30 POLE 2 PP 1 PP 2 INYO 1.000 1.000 45 POLE 1 24729 96 124 57 1 2 3 4 5 6 26057 26059 110 32 1.034 b 1 1.011 1.010 OWENYOTP 5 1.000 NAVAJO b 26946 14003 39 1 159 1.000 19 13 19 13 MCCULLGH CRYSTAL 1.089 805 128 82 Owenyo 14 200 26048 26123 1 22 1 1.048 1.047 203

26 2 24 2 Solar 2 354 48 66 805 744 1016 1 40 202 6 805 COTTONWD 1.000 64 77 1 1.000 26136 ELDORDO MOHAVE202 24 1 0.981 66

1.000 1.000 40 0 24042 24097 20 23 20 0 26 1 350 OLIVE 6 1.048 1.052 26052 1.000 13 GE CP 1.000 555 1.000 1.000 1.000 1.000 1 198 1.004 PT230 76 92 CASTAIC Milford Wind Corridor Pine Tree 27031 IPP DC 95 764 26010 1.007 7 1.013 1.000 74 40 684 607 MARKETPL

244 17 293 13 1 233.7 501 36 5 84 ADELANTO

17 16 17 16 17 16 105 311 HSKLLCYN 26044

179 25 68 26003 45 673 26135 1 56 1.036 484 1.048 1.011 SYLMAR2 185 Pine Canyon 1 1652 57 269 26099 231 22 850 1.011 HLTAP 156 24 195 18 231 27 27 27204 250 250 RINALDI 1 731 1.031 0 26061 129 160 250 109 1243 718 b 84 1.011 Beacon HLAKE 772 RINALDI BARRENRD BCON230 Solar 294 26062 26132 26905 27205 SYLMARLA 1.013 1.016 1.031 55 1.018 592 26094 1.000 SYLMAR1 1.013 24 26097 1.030 294 VICTORVL 125 53 125 53 0.977 372 55 RINALDI2 1.030 1.000 26105 1 1 41 26115 658 Harper Lake 655 1.018 1.038 VALLEY 35 1130

1.030 372 1242 723 105 113 348 36 57 72 36 48 48 26103 1.000 107 7 348 124 SYLMAR S 41 78 1.007 VALLEY 124 317 40 LUGO 113 24147 6 171 26102 24086 372 78 1.001 1.000 1.040 0.979 43 41 361 1.000 5 226 12 171 0 b 6 361 817 226 43 1028 413 12 1.000 370 6 0.0 785.9 70 151 160 VICTORVL 8 ATWATER 49 80 GLENDAL 26104 b 370 26081 26013 0.994 1.030 390 353 49 0.996 316 39 33 254 56 368 33 17 390 296 NRTHRDGE 510 39 15 26086 56

0.997 1.000 232 510 31 TOLUCA 56 26078 1.000 TOLUCA 211 1-IN-10 PEAK DEMAND 0.999 26079 9 311 6 1.005 LADWP RIVER Gen 2017 MW 26063

224 13 1.000110 6 216 12 HOLYWD_E HOLYWD_F 0.993 STJOHN Gen 704 VAR 26082 26182 216 26068 Load 6276 MW 0.992 0.994 TOLUCA 0.995 20 Load 1376 VAR 26077 TARZANA 1.000 0.997 1.000 Int -2333 MW 26093 HOLYWDLD Loss 450 MW 0.999 26085 Pres 1953 MW 0.990 14 19 Qres 2384 MVR 210 116 144 15 1.000 62 8 62 8 VELASCO TARZANA HOLYWD2 OLYMPC 26092 HOLYWD1 26080 MAJOR LADWP PATHS 1.002 26083 26084 0.993 26087 0.999 1.011 0.999 VA-LA 2729MW

144 19 PDCI ( 2779MW) CNTURYLD 62 12 72 62 12 90 26072 IPPDC ( 1705MW) 0.995 224 3 20 90 68 70 1.000 72 20 224 40 1.000 3 68 FAIRFAX 69 1.000 26076 39 0.999 1.000

OLYMPCLD

1 2

52 1 CNTURY2

26088 AIRPORT 5 GRAMERCY CNTURY 1.001 26089 26014 26069 26071 SCATERGD 1.002 1.000 1.002 26066 1.003 221 1.015 38 91 20 6 128 120 8 12 31 1.000 4 18 20 1 38 91 221 1.000 8 CNTURY1 12 31 6

120 1.000 26070 100 60 5 17 1 1.002

1.000 11 100 189 60 50 6 17 13 13 11 28 1

53 1.000 1.000 5 TAP 1 5 100 26095 50 7 17 1.000 1.003 28 2 1.000 23 25 13 1.000 9 1 TAP 2 5 HALLDALE 26096 5 26016 1.003 23 77 19 1.002 9 WLMNTN 129 26073 1 1.001 6 25 11 100 129 1.000 200 2 22 25 33 8 1.000 13 140 1.000

1.000 28 150 SCATERGD 9 14 10 30 26065 1.000 1.000

1.007 1.000 150 10 169 30

30 1.000 81 12 2 17 11 1.000 1.000

1.000 12 65 81 190 13 1 17 18 5 1.000

1.000 32 1.000 14 HARBOR 26091 15 1.001

1.000 16 HAYNES 26025 1.006

General Electric International, Inc. PSLF Program Sat Oct 16 07:28:19 2010 2010hs18_lml-r.sav

WESTERN ELECTRICITY COORDINATING COUNCIL MW/MVAR 2010 HS3B APPROVED OPERATING CASE 2010hs18_lml-r.drw 02/22/10 - 2018 DWP 1-in-10 Summer Peak Rating = 1 INTERMOUNTAIN OWENS UP 1 2 26129 37 MEAD S 1.043 1 19012 900 8 258 HOOVER 900 258 1.006 CELILO 1.048 N1 100 BIGEDDY3 BIGEDDY1 BIG EDDY 15 198 41343 41341 40111 37 8 100 18 MEAD PP1 PP2 N2 1.041 1.039 1.076 30 26051 OWENSMID 37 1.017 1 2 1 N3 100 26130 9 1.025 23 208

1.048 1.025 1.043 110 16 127 127 40 1 10 2 INTERMT N4 23

580 34 522 20 52 56 MEAD 808 62 870 28 26043 1.000 74 18 1.050 MCCULLGH 19038 OWENSCON 26046 MEAD N 1.055 26131 36 1.004 19011 1.040 1 78 48 0.997 22 15 MWC345 97 1.048 CASTAIC 0 475 27135 54 1057 1705 841 1.000 1.000 3 143 1.000 1.000 1.056 26 POLE 2 PP 1 PP 2 INYO b 1.000 1.000 2 POLE 1 24729 97 123 64 1 2 3 4 5 6 26057 26059 110 33 1.034 1 1.012 1.011 OWENYOTP 3 1.000 NAVAJO b 26946 14003 39 1 159 1.000 19 13 19 13 MCCULLGH CRYSTAL 1.092 646 100 64 Owenyo 200 69 14 200 26048 26123 1 22 1 1.054 1.052 166

26 3 24 3 Solar 1 355 45 66 646 578 836 1 38 165 0 646 COTTONWD 1.000 57 65 1 1.000 26136 ELDORDO MOHAVE165 24 2 0.982 66

1.000 1.000 40 0 24042 24097 20 23 20 0 26 2 350 OLIVE 0 1.054 1.058 26052 1.000 10 GE CP 1.000 515 1.000 1.000 1.000 1.000 1 224 1.009 PT230 76 97 CASTAIC Milford Wind Corridor Pine Tree 27031 IPP DC 83 705 26010 1.011 1 1.021 1.000 71 40 607 643 MARKETPL

266 22 316 16 1 234.6 461 33 8 84 ADELANTO

29 24 29 24 29 24 95 284 HSKLLCYN 26044

211 34 73 26003 45 597 26135 1 58 1.042 413 1.054 1.017 SYLMAR2 185 Pine Canyon 1 1652 69 283 26099 231 24 850 1.015 HLTAP 221 15 247 13 231 29 29 27204 250 250 RINALDI 1 660 1.038 0 26061 129 160 250 109 1245 716 b 83 1.015 Beacon HLAKE 778 RINALDI BARRENRD BCON230 Solar 252 26062 26132 26905 27205 SYLMARLA 1.018 1.020 1.038 65 1.024 506 26094 1.000 SYLMAR1 1.017 24 26097 1.030 252 VICTORVL 125 53 125 53 0.980 357 65 RINALDI2 1.030 1.000 26105 1 1 37 26115 569 Harper Lake 567 1.023 1.044 VALLEY 35 1218

1.030 357 1242 722 127 150 408 5 6 63 5 42 42 26103 1.000 44 7 408 109 SYLMAR S 37 73 1.010 VALLEY 109 286 36 LUGO 150 24147 6 173 26102 24086 357 73 1.004 1.000 1.045 0.982 44 37 324 1.000 5 204 0 173 0 b 9 324 828 204 44 926 379 0 1.000 392 9 0.0 790.7 73 200 154 VICTORVL 8 ATWATER 45 76 GLENDAL 26104 b 392 26081 26013 0.997 1.037 368 326 45 0.999 328 45 39 228 48 340 39 25 368 265 NRTHRDGE 460 45 24 26086 70

1.001 1.000 164 460 50 TOLUCA 70 26078 1.000 TOLUCA 186 1-IN-10 PEAK DEMAND 1.002 26079 0 252 22 1.011 LADWP RIVER Gen 2582 MW 26063

225 15 1.000110 7 216 14 HOLYWD_E HOLYWD_F 0.994 STJOHN Gen 716 VAR 26082 26182 200 26068 Load 6383 MW 0.994 0.998 TOLUCA 0.998 13 Load 1398 VAR 26077 TARZANA 1.000 1.001 1.000 Int -1856 MW 26093 HOLYWDLD Loss 431 MW 1.002 26085 Pres 1636 MW 0.993 39 24 Qres 2538 MVR 173 100 135 10 1.000 59 7 59 7 VELASCO TARZANA HOLYWD2 OLYMPC 26092 HOLYWD1 26080 MAJOR LADWP PATHS 1.004 26083 26084 0.995 26087 1.001 1.013 1.001 VA-LA 2410MW

135 15 PDCI ( 2779MW) CNTURYLD 59 10 74 59 10 115 26072 IPPDC ( 1705MW) 0.997 233 3 25 115 68 47 1.000 74 25 233 47 1.000 3 68 FAIRFAX 46 1.000 26076 46 1.000 1.000

OLYMPCLD

0 1

51 0 CNTURY2

26088 AIRPORT 5 GRAMERCY CNTURY 1.003 26089 26014 26069 26071 SCATERGD 1.003 1.003 1.006 26066 1.005 200 1.016 40 92 27 16 200 147 7 11 28 1.000 4 19 27 9 40 92 200 1.000 7 CNTURY1 11 28 16

147 1.000 26070 100 62 5 14 9 1.006

1.000 9 100 205 62 150 6 14 14 14 9 30 1

53 1.000 1.000 7 TAP 1 7 100 26095 150 7 14 1.000 1.005 30 2 1.000 23 25 14 1.000 10 1 TAP 2 7 HALLDALE 26096 5 26016 1.005 23 124 13 1.004 10 WLMNTN 137 26073 1 1.003 6 23 11 100 137 1.000 200 2 20 23 33 8 1.000 13 186 1.000

SCATERGD 1.000 24 150 26065 9 14 10 29 1.009 1.000 1.000 1.000 150 10 217 29

26 1.000 81 12 2 16 11 1.000 1.000

1.000 12 65 81 246 13 1 16 16 5 1.000

1.000 28 1.000 14 HARBOR 26091 15 1.003

1.000 16 HAYNES 26025 1.007

General Electric International, Inc. PSLF Program Sat Oct 16 07:39:51 2010 2010hs19_lml-r.sav

WESTERN ELECTRICITY COORDINATING COUNCIL MW/MVAR 2010 HS3B APPROVED OPERATING CASE 2010hs19_lml-r.drw 02/22/10 - 2019 DWP 1-in-10 Summer Peak Rating = 1 INTERMOUNTAIN OWENS UP 1 2 26129 37 MEAD S 1.043 1 19012 900 8 258 HOOVER 900 258 1.002 CELILO 1.048 N1 100 BIGEDDY3 BIGEDDY1 BIG EDDY 15 198 41343 41341 40111 37 8 100 18 MEAD PP1 PP2 N2 1.041 1.039 1.076 30 26051 OWENSMID 37 1.012 1 2 1 N3 100 26130 10 1.025 26 208

1.048 1.025 1.043 110 21 141 141 40 2 10 3 INTERMT N4 26

580 34 522 20 46 51 MEAD 808 62 870 27 26043 1.000 74 18 MCCULLGH 19038 OWENSCON 1.050 MEAD N 1.050 26131 36 1.000 19011 1.040 1 78 48 26046 0.993 14 15 83

1.048 MWC345 CASTAIC 0 475 48 1050 1705 841

1.000 1.000 27135 1.000 7 156 16 POLE 2 PP 1 PP 2 INYO b 1.000 1.000 1.056 65 POLE 1 24729 1.000 83 121 57

26057 110 33 1 2 4 5 6 7 26059 1.034 1 3 1.007 1.005 OWENYOTP 7 1.000 NAVAJO 26946 BCSPTAP 14003 39 1 159 1.000 Owenyo 19 13 19 13 26942 MCCULLGH CRYSTAL 1.090 646

162 104 26048 1 200 1.000 26123 22 1 Solar 1.047 1.047 176 15 2 25 1 25 2 355 19 81 646 150 569 823 1 12 1 176 0 6 646 OLIVE COTTONWD Boulder 1.000 4 86 1 26052 26136 City ELDORDO 176 0.994 0.988 81 MOHAVE

1.000 20 0 40 0 24042 24097 1.000 1.000 351 20 23 HASKELL1 6 1.047 1.051 1.064 34 GE CP 1.000 555 1.000 1.000 1.000 HASKELL2 1 310 PT230 94 90 CASTAIC Milford Wind Corridor 27031 IPP DC 49 765 26010 Pine Tree 0.987 6 1.004 1.000 1.000 40 682 840 77

1 MARKETPL 501 34 25 2 279 19 8 85

25 1 1.000 ADELANTO

10 21 10 21 10 21 112 213 26044 HSKLLCYN BARRENRD

190 24 32 26003 45 671 1.047 26135 1 37 26132 1.032 1.000 0.990 50 HLTAP 208 SYLMAR2 222 Pine Canyon 1 1652 27204 26099 277 50 850 1.029 13 SODATAP 1.004 250 155 40 200 33 277 61 61 26934 RINALDI RE-BR1 86 1 1.030 137 135 BCON230 Beacon 747 499 26061 1 250 109

1244 716 26905 Solar 1.004 10 22 69 57 RINALDI SODAMTN 291 69 RE-BR1 HLAKE 290 26062 1 27205 26933 SYLMARLA 26962 1.030 62 1.012 0.996 DES-SAPP Desert 583 1.029 26094 1.000 SYLMAR1 1.006 26909 Sapphire 39 26097 1.030 290

0 125 53 125 53 300 0 b VICTORVL 0.970 62 RINALDI2

1.030 761 1.000 1 1 1 26115 26105 409 648 Harper Lake Soda Mtn 645 1.012 1.034 33 VALLEY 51 1155 1.030

1243 722 121 150 360 31 49 95 31 64 64 26103 1.000 141 7 360 137 SYLMAR S 409 92 1.001 VALLEY 137 321 43 LUGO 150 24147 33 6 176 26102 24086 92 0.994 1.000 1.038 0.972 47 409 370 1.000 5 229 33 22 176 0 b 8 370 812 229 277 47 1031 446 22 1.000 386 8 0.0 774.7 78 1 100 177 VICTORVL 8 ATWATER 51 91 GLENDAL 26104 b 386 26081 26013 0.988 1.027 416 360 51 0.990 329 44 29 260 70 375 28 15 416 302 NRTHRDGE 511 44 12 26086 62

0.988 1.000 223 511 25 TOLUCA 62 26078 1.000 TOLUCA 216 1-IN-10 PEAK DEMAND 0.992 26079 15 310 1 0.999 LADWP RIVER Gen 2121 MW 26063

231 17 1.000113 7 222 16 HOLYWD_E HOLYWD_F 0.987 STJOHN Gen 910 VAR 26082 26182 223 26068 Load 6474 MW 0.987 0.987 TOLUCA 0.987 25 Load 1420 VAR 26077 TARZANA 1.000 0.990 1.000 Int -1856 MW 26093 HOLYWDLD Loss 465 MW 0.991 26085 Pres 1909 MW 0.983 24 25 Qres 2280 MVR 239 139 154 19 1.000 64 9 64 9 VELASCO TARZANA HOLYWD2 OLYMPC 26092 HOLYWD1 26080 MAJOR LADWP PATHS 0.995 26083 26084 0.988 26087 0.993 1.006 0.993 VA-LA 2719MW

154 24 PDCI ( 2779MW) CNTURYLD 64 13 70 64 13 102 26072 IPPDC ( 1705MW) 0.989 224 3 23 102 76 62 1.000 70 23 224 41 1.000 3 76 FAIRFAX 62 1.000 26076 41 0.992 1.000

OLYMPCLD

0 3

53 0 CNTURY2

26088 AIRPORT 5 GRAMERCY CNTURY 0.995 26089 26014 26069 26071 SCATERGD 0.996 0.995 0.997 26066 0.997 224 1.010 42 96 26 6 100 106 11 14 31 1.000 4 30 26 24 42 96 224 1.000 11 CNTURY1 14 31 6

106 1.000 26070 90 66 5 30 24 0.997

1.000 13 90 159 66 150 6 30 16 16 13 37 1

59 1.000 1.000 3 TAP 1 3 90 26095 150 7 30 1.000 0.998 37 2 1.000 21 26 16 1.000 6 1 TAP 2 3 HALLDALE 26096 5 26016 0.998 21 88 26 0.997 6 WLMNTN 139 26073 1 0.997 6 30 11 150 139 1.000 100 2 34 30 35 8 1.000 13 154 1.000

SCATERGD 1.000 35 130 26065 9 14 10 36 1.002 1.000 1.000 1.000 130 10 184 36

38 1.000 81 12 2 21 11 1.000 1.000

1.000 12 60 81 209 13 1 21 22 5 1.000

1.000 40 1.000 14 HARBOR 26091 15 0.997

1.000 16 HAYNES 26025 1.003

General Electric International, Inc. PSLF Program Fri Oct 29 13:35:05 2010 2010hs20_lml-rc-fix4-33%.sav

WESTERN ELECTRICITY COORDINATING COUNCIL MW/MVAR 2010 HS3B APPROVED OPERATING CASE 2010hs20_lml-rc-fix4-33% 02/22/10 - 2020 DWP 1-in-10 Summer Peak Rating = 1 OWENS VALLEY INTERMOUNTAIN OWENS UP 1 MEAD S 26129 1 2 HOOVER 19012 1.051 1.029 CELILO 1.048 85 950 218 950 218 N1 169 BIGEDDY3 BIGEDDY1 BIG EDDY 7 41343 41341 40111 85 2 PP1 PP2 N2 MEAD 1.046 1.048 1.101 0 7 26051 OWENSMID 1.040 1 2 1 1 1.025 N3 85 26130 1.025 7 169 1.050 1.048 85 2 120 120 40 2 10 4 N4 INTERMT 7

389 91 351 75 53 56 426 86 684 35

26043 1.000 MCCULLGH MEAD 1.050 26046 0 MEAD N 19038 OWENSCON 1.023 19011 26131 2 1 1.023 1.069

0 115 34 MWC345 90 27

1.050 1.048 2 27135 275 1.000 1.000 1746 869 23 172 31

CASTAIC 0 696 PP 1 PP 2 1.000 1.052 1.000 107 POLE 1 POLE 2 1.000 90 34 32 26057 26059 1.000 1 2 3 4 5 6 INYO b 1 37 1.015 1.013 23 1.000 24729 NAVAJO

0 5 CRYSTAL

38 17 39 1 14003 1.050 38 17 MCCULLGH 14 26123 1.096 225 22 200 19 26048 805 1 1.065 1.064 1

26 4 48 8 165 24 4 66 COTTONWD 1069 1124 805 1 26136 29 165

1.000 95 18 1.044 805 1.000 165 1 24 4 66 ELDORDO MOHAVE 1.000 1.000 40 0 40 27 40 0 26 3 48 25 BARRENRD 29 24042 24097 0 33 1.000 GE CP 1.000 1.064 1.061 1.000 1.000 1.000 1.000 OLIVE 26132 1 1.051 431

26052 b IPP DC 76 CASTAIC Milford Wind Farm 210 26010 1.014 32 40

1.000 182 1.013 66 5

115 586 413 45 92 92 104 4 208 7 0 ADELANTO 112

1 18 320 622 70 SYLMARLA 6 26003 576 SYLMAR2 26094 Pine Tree PT230 1.051 470 26099 1.016 RINALDI 27031 56 26061 1 1690 1.014 1.053 876 1.020 594 139 332 1000 0 b 10 MARKETPL 550 413 401 RINALDI 26044 1.065 18 26062 1.000 1.022 807 SYLMAR1 401 90 645 26097 0.959 18

1.000 94 1.053 584 890 VICTORVL 0.959 LUGO 45 RINALDI2 VALLEY 93 26105 24086 884 26115 1.050 26103 VALLEY 1.053 0.959 106 1.026

584 1.000 1.023

1000 552 105 7 105 7 267

160 6 26102 SYLMAR S 45 150 1.022 12 267 12 234 18 24147 214 7 5 62 584 1751.000 1.055 10 10 45 150 1.000 6 5 12 214 5 62 0 b 175 10 173 26 10 1006 12 1.000 857 25 34 200 VICTORVL

0.0 890.1 69 26 8 8 26104 GLENDAL ATWATER 34 26081 1.055 b 241 51 26013 1.026 1.026 33 22 200 59 241 53 59 14 33 23 426 68 10 42 15

1.000 142 18 NRTHRDGE 426 26086 11 TOLUCA 42 1.016 1.000 26078 TOLUCA 10 1-IN-10 PEAK DEMAND 1.027 26079 26 LADWP 1.031 RIVER Gen 831 MW 67 12

137 23 1.000 131 22 26063 STJOHN Gen 108 VAR HOLYWD_E HOLYWD_F 1.028 26082 26182 26068 Load 2343 MW 29 1.027 1.026 TOLUCA 1.026 Load 360 VAR 26077 22 TARZANA 1.000 1.029 1.000 Int 114 MW 26093 HOLYWDLD Loss 267 MW 1.020 26085 25 Pres 2183 MW 1.027 37

29 42 Qres 1885 MVR 29 136

1.000 89 16 89 16 TARZANA HOLYWD1 45 VELASCO 26092 HOLYWD2 26083 37 26080 MAJOR LADWP PATHS 1.030 89 26084 1.029 OLYMPC 1.044 1.044 45 VA-LA 2904MW

26087 29 43 23 1.039 37 PDCI (-1850MW)

89 23 IPPDC ( 1746MW) 45 8 CNTURYLD 112 26072 13 45 1.032

1.000 1.000 8 FAIRFAX 112 26076 1.000 13 1.044 CNTURY 1.000 12 26069 78 11 1.038

132 14 132 14 CNTURY2 OLYMPCLD 79 43 GRAMERC1 26071 26088 28 13 172 1.040 1.037 26014 1.040 43 SCATERGD 26 6 105 1.000 CNTURY1 26066 6 32 26070 1.043 1.040 105 172 6

AIRPORT GRAMERC2 32 1.000 253 26089 26015 55 1.044 1.040 3 15 9

9 17 26 6 55

1.000 253 1 0 9 15 TAP 1 26095 9 1.039 17 SCATERGD 1.000 1 TAP 2 0 26065 WLMNTN 50 HALLDALE 26096 1 1.042 1.039 26073 27 26016 39 1.000 1.038 1.039 4

1 63 109 5 1 39 9 2

9 1.000 13 4

85 91 11 10 127 2 27 5

13 1.025 1.000

1.000 1.000 5 13 12

1.025 138 6 1.025 14 5 5 1.000 1.025 1.000 200 HARBOR 157 30 8 26091 2 1.025 1.038 150 27 9 1.025 1 0 10 1.000 150 10 0 27 b 1.025 2 10 1.000

HARB WLMNTNLD HAYNES 26019 26075 26025 1.043 1.042 1.033

General Electric International, Inc. PSLF Program Sat Oct 16 09:58:11 2010 2011lw11-lml.sav

WESTERN ELECTRICITY COORDINATING COUNCIL MW/MVAR 2010-11 LW1A APPROVED OPERATING CASE 2011lw11-lml.drw 08/02/2010 - 2011 DWP LIGHT WINTER Rating = 1 INTERMOUNTAIN OWENS UP 1 2 26129 MEAD S 1.029 1 19012

950 216 HOOVER 216 950 1.029 CELILO 1.048 N1 85 BIGEDDY3 BIGEDDY1 BIG EDDY 7 169 41343 41341 40111 85 2 MEAD PP1 PP2 N2 1.040 1.042 1.095 0 7 26051 OWENSMID 1.040 1 2 1 1 N3 85 26130 1.025 7 169

1.048 1.025 1.029 85 2 122 122 40 3 10 7 INTERMT N4 7

388 88 351 72 54 57 MEAD 426 83 683 31 26043 1.050 MCCULLGH 1.000 19038 OWENSCON 0 26046 MEAD N 1.070 26131 1.024 19011

1.029 2 1 76 39 1.023 27 MWC345 90 CASTAIC 1.048 27135 30 266 1746 869

1.000 1.000 1.000 0 696 1.052 23 171 32

0 2 1.000 POLE 2 PP 1 PP 2 INYO 1.000 1.000 106 POLE 1 24729 90 33 36 1 2 3 4 5 6 26057 26059 1.029 b 1 1.018 1.016 OWENYOTP 23 1.000 NAVAJO 14003

0 9 b 26946 48 1.024 38 17 38 17 MCCULLGH CRYSTAL 1.096 805 2 182 Owenyo 200 4 14 26048 26123 1 8 1 1.066 1.064 163 26 6 0 24 7 48 Solar 805

0 31 65 1071 1114 1 6 28 163

1.000 805 COTTONWD 99 16 1 1.000 26136 ELDORDO MOHAVE163 24 6 65 1.000 1.000 1.020 24042 24097 40 27 40 0 26 6 48 OLIVE 28 1.065 1.061 26052 1.000 21 GE CP 1.000 439 1.000 1.000 1.000 1.000 1 179 1.023 PT230 76 41 CASTAIC Milford Wind Corridor Pine Tree 27031 IPP DC 182 634 26010 1.021 32 1.019 1 6 1.000 69 51 20 92 605 252 MARKETPL

1 237.6 421 43 39 181 ADELANTO

25 15 106 463 HSKLLCYN 26044

120 7 120 7 120 7 46 26003 91 595 26135 1 58 1.053 518 1.066 1.022 SYLMAR2 60 Pine Canyon 1 1690 62 327 26099 84 1 876 1.020 33 1 84 4 HLTAP 101 0 4 27204 RINALDI 1 514 1.056 0 26061 0 0 1000 545 b 25 1.025 Beacon HLAKE 417 RINALDI BARRENRD BCON230 Solar 398 26062 26132 26905 27205 SYLMARLA 1.024 1.033 1.056 14 1.026 802 26094 1.000 SYLMAR1 1.022 77 26097 0.959 398 VICTORVL 1.059 510 14 RINALDI2 0.959 1.000 26105 1 1 48 26115 114 882 Harper Lake 877 1.031 1.053 17 VALLEY 81 617

0.959 510 1000 548 98 125 231 114 173 22 17 26103 1.000 59 null 7 231 33 SYLMAR S 48 4 1.027 VALLEY 33 234 21 LUGO 125 24147 6 63 26102 24086 510 4 1.026 1.000 1.054 1.060 10 48 188 1.000 5 176 3 63 0 b 14 188 1011 176 10 859 96 3 1.000 27 14 0.0 899.2 38 200 63 VICTORVL 8 ATWATER 35 0 GLENDAL 26104 b 27 26081 26013 1.030 1.058 192 43 35 1.030 86 57 18 51 90 45 18 11 192 59 NRTHRDGE 427 57 12 26086 40 5 1.025 1.000 136 427 14 7 TOLUCA 40 26078 1.000 TOLUCA 13 1-IN-10 PEAK DEMAND 1.031 26079 26 1.035 LADWP RIVER Gen 824 MW

67 15 26063

137 29 1.000 132 28 HOLYWD_E HOLYWD_F 1.032 STJOHN Gen 31 VAR 26082 26182 32 26068 Load 2390 MW 1.031 1.031 TOLUCA 1.031 21 Load 368 VAR 26077 TARZANA 1.000 1.034 1.000 Int 114 MW 26093 HOLYWDLD Loss 264 MW 1.030 26085 Pres 2190 MW 1.032 25 41 Qres 2072 MVR 34 57 22 195 1.000 88 23 88 23 VELASCO TARZANA HOLYWD2 26092 HOLYWD1 26080 MAJOR LADWP PATHS 1.043 26083 26084 1.033 OLYMPC 1.055 26087 1.055 VA-LA 2894MW 1.056 34 58 PDCI (-1849MW) CNTURYLD 88 30 52 88 30 46 26072 IPPDC ( 1746MW) 39 1.037 118 4 46 13 25 52 1.000 39 48 1.000 4 118 FAIRFAX 13 25 26076 48 1.000 1.056 1.000

OLYMPCLD

6 7

77 16 CNTURY2 1 26088 AIRPORT 7 GRAMERCY CNTURY 1.052 26089 26014 26069 26071 1.057 1.046 1.043 1.044 SCATERGD 173 26066 135 27 105 4 1.059 12 7 40 1.000 130 135 27 105 173 15 12 7 40 4 CNTURY1

1.000 26070 55 130 1.044 15 8 3 259 55 50 1.000 18 18 8 32 1

31 1.000 9 TAP 1 9 26095 23 1.000 1.045 2 SCATERGD 13 26065 9 18 1.000 1.056 23 1 TAP 2 9 HALLDALE 26096 13 5 1 26016 1.045 109 1 1.045 94 WLMNTN 5 26073 6 94 1.042 85 11 2 27 5

1.000 1.000 200 26 8

13 127 1.025

1.000 1 150 9 14 10 23 1.025 1.000 1.000 150 10 139 23

0 1.025 2 12 11 1.000 1.000

1.000 12 1 5 158 13 1.000

1.000 4 1.000 14 HARBOR 26091 15 1.043

1.000 16 HAYNES 26025 1.035

General Electric International, Inc. PSLF Program Sat Oct 16 10:14:06 2010 2011lw15-lml.sav

WESTERN ELECTRICITY COORDINATING COUNCIL MW/MVAR 2010-11 LW1A APPROVED OPERATING CASE 2011lw15-lml.drw 08/02/2010 - 2015 DWP LIGHT WINTER Rating = 1

LADWP’s 2010 Ten-Year Transmission Assessment

Appendix F. List of Contingencies Studied

F November 1, 2010

Appendix F. LIST OF CONTINGENCIES STUDIED

CONTINGENCY NO. FROM TO CKT

(N-1) CONTINGENCY 500kV Lines 1 26003 ADELANTO 500 26115 RINALDI2 500 1 2 26003 ADELANTO 500 26079 TOLUCA 500 1 3 27204 HLTAP 500 26003 ADELANTO 500 1 4 26044 MARKETPL 500 26003 ADELANTO 500 1 5 26044 MARKETPL 500 27204 HLTAP 500 1 6 26044 MARKETPL 500 26048 MCCULLGH 500 1 7 26048 MCCULLGH 500 26105 VICTORVL 500 1 8 26105 VICTORVL 500 26003 ADELANTO 500 1 9 26105 VICTORVL 500 24086 LUGO 500 1 10 26105 VICTORVL 500 26062 RINALDI 500 1 287kV Lines 11 26051 MEAD 287 26104 VICTORVL 287 1 12 26104 VICTORVL 287 26070 CNTURY1 287 1 13 26104 VICTORVL 287 26071 CNTURY2 287 1 230kV Lines 14 26081 ATWATER 230 26068 STJOHN 230 1 15 26081 ATWATER 230 26080 VELASCO 230 1 16 26132 BARRENRD 230 26905 BCON230 230 1 17 26132 BARRENRD 230 26010 CASTAIC 230 1 18 26132 BARRENRD 230 26136 COTTONWD 230 1 with RAS 19 26132 BARRENRD 230 26135 HSKLLCYN 230 2 20 26132 BARRENRD 230 26135 HSKLLCYN 230 3 21 26132 BARRENRD 230 26061 RINALDI 230 1 with RAS 22 26010 CASTAIC 230 26035 HSKLLCYN 230 1 23 26010 CASTAIC 230 26086 NRTHRDGE 230 1 24 26010 CASTAIC 230 26052 OLIVE 230 1 25 26010 CASTAIC 230 26094 SYLMARLA 230 1 26 26013 GLENDAL 230 26081 ATWATER 230 1 27 26025 HAYNES 230 26081 ATWATER 230 1 28 26025 HAYNES 230 26063 RIVER 230 1 29 26025 HAYNES 230 26068 STJOHN 230 1 30 26025 HAYNES 230 26080 VELASCO 230 1 31 27031 PT230 230 26132 BARRENRD 230 1 32 26135 HSKLLCYN 230 26052 OLIVE 230 1 33 26086 NRTHRDGE 230 26093 TARZANA 230 1 34 26052 OLIVE 230 26086 NRTHRDGE 230 1 35 26061 RINALDI 230 26013 GLENDAL 230 1 36 26061 RINALDI 230 26135 HSKLLCYN 230 1 37 26061 RINALDI 230 26093 TARZANA 230 1 CONTINGENCY NO. FROM TO CKT

38 26066 SCATERGD 230 26087 OLYMPCLD 230 2 39 26068 STJOHN 230 26063 RIVER 230 1 40 26094 SYLMARLA 230 26135 HSKLLCYN 230 1 41 26094 SYLMARLA 230 26086 NRTHRDGE 230 1 42 26094 SYLMARLA 230 26061 RINALDI 230 1 43 26093 TARZANA 230 26087 OLYMPC 230 1 44 26078 TOLUCA 230 26081 ATWATER 230 1 45 26078 TOLUCA 230 26082 HOLYWD_E 230 1 46 26078 TOLUCA 230 26182 HOLYWD_F 230 1 47 26103 VALLEY 230 26061 RINALDI 230 1 48 26103 VALLEY 230 26078 TOLUCA 230 1 49 26080 VELASCO 230 26072 CNTURYLD 230 1 50 26946 OWENYOTP 230 26136 COTTONWD 230 1 with RAS 51 26946 OWENYOTP 230 24729 INYO 230 1 with RAS 138kV Lines 52 26069 CNTURY 138 26014 GRAMERC1 138 1 53 26069 CNTURY 138 26014 GRAMERCY 138 1 54 26069 CNTURY 138 26073 WLMNTN 138 1 55 26076 FAIRFAX 138 26089 AIRPORT 138 1 56 26076 FAIRFAX 138 26014 GRAMERC1 138 1 57 26076 FAIRFAX 138 26088 OLYMPCLD 138 1 58 26091 HARBOR 138 26095 TAP1 138 1 59 26091 HARBOR 138 26096 TAP2 138 1 60 26091 HARBOR 138 26073 WLMNTN 138 E 61 26019 HARB 138 26075 WLMNTNLD 138 A 62 26083 HOLYWD 138 26076 FAIRFAX 138 1 63 26083 HOLYWD 138 26085 HOLYWDLD 138 1 64 26065 SCATERGD 138 26089 AIRPORT 138 1 65 26095 TAP1 138 26016 HALLDALE 138 1 66 26096 TAP2 138 26016 HALLDALE 138 1 67 26095 TAP1 138 26014 GRAMERC1 138 1 68 26096 TAP2 138 26015 GRAMERC2 138 1 69 26095 TAP1 138 26014 GRAMERCY 138 1 70 26096 TAP2 138 26015 GRAMERCY 138 1 71 26092 TARZANA 138 26088 OLYMPCLD 138 1 72 26077 TOLUCA 138 26085 HOLYWDLD 138 2 73 26073 WLMNTN 138 26095 TAP1 138 1 74 26073 WLMNTN 138 26096 TAP2 138 1 75 26075 WLMNTNLD 138 26073 WLMNTN 138 1 76 26075 WLMNTNLD 138 26019 HARB 138 1 Auto-Transformers 77 26070 CNTURY1 287 26069 CNTURY 138 G 78 26071 CNTURY2 230 26069 CNTURY 138 F 79 26072 CNTURYLD 287 26069 CNTURY 138 1 80 26087 OLYMPC 230 26088 OLYMPCLD 138 1 81 26066 SCATERGD 230 26065 SCATERGD 138 1 82 26105 VICTORVL 500 26104 VICTORVL 287 1 CONTINGENCY NO. FROM TO CKT

(N-2) CONTINGENCY

26003 ADELANTO 500 26115 RINALDI2 500 1 1 26105 VICTORVL 500 26062 RINALDI 500 1 26048 MCCULLGH 500 26105 VICTORVL 500 1 2 26048 MCCULLGH 500 26105 VICTORVL 500 2 26105 VICTORVL 500 26003 ADELANTO 500 1 3 26105 VICTORVL 500 26003 ADELANTO 500 2 26104 VICTORVL 287 26070 CNTURY1 287 1 4 26104 VICTORVL 287 26071 CNTURY2 287 1 26010 CASTAIC 230 26135 HSKLLCYN 230 1 5 26010 CASTAIC 230 26135 HSKLLCYN 230 2 26013 GLENDAL 230 26081 ATWATER 230 1 6 26013 GLENDAL 230 26081 ATWATER 230 2 26061 RINALDI 230 26113 GLENDAL 230 1 7 26061 RINALDI 230 26113 GLENDAL 230 2 26061 RINALDI 230 26093 TARZANA 230 1 8 26061 RINALDI 230 26093 TARZANA 230 2 26093 TARZANA 230 26087 OLYMPC 230 1 9 26092 TARZANA 138 26088 OLYMPCLD 138 1 26103 VALLEY 230 26061 RINALDI 230 1 10 26103 VALLEY 230 26061 RINALDI 230 2 26103 VALLEY 230 26078 TOLUCA 230 1 11 26103 VALLEY 230 26078 TOLUCA 230 2 26080 VELASCO 230 26072 CNTURYLD 230 1 12 26080 VELASCO 230 26072 CNTURYLD 230 2 26069 CNTURY 138 26014 GRAMERC1 138 1 13 26069 CNTURY 138 26015 GRAMERC2 138 1 26069 CNTURY 138 26014 GRAMERCY 138 1 14 26069 CNTURY 138 26014 GRAMERCY 138 2 26069 CNTURY 138 26073 WLMNTN 138 1 15 26069 CNTURY 138 26073 WLMNTN 138 2 26076 FAIRFAX 138 26089 AIRPORT 138 1 16 26076 FAIRFAX 138 26089 AIRPORT 138 2 26076 FAIRFAX 138 26014 GRAMERC1 138 1 17 26076 FAIRFAX 138 26015 GRAMERC2 138 1 26076 FAIRFAX 138 26014 GRAMERCY 138 1 18 26076 FAIRFAX 138 26014 GRAMERCY 138 2 26095 TAP 1 138 26014 GRAMERC1 138 1 19 26096 TAP 2 138 26015 GRAMERC2 138 1 26095 TAP 1 138 26014 GRAMERCY 138 1 20 26096 TAP 2 138 26014 GRAMERCY 138 1

LADWP’s 2010 Ten-Year Transmission Assessment

Appendix G. Switching Sequences for Transient and Post- Transient

G November 1, 2010

SWITCHING SEQUENCES

CONTINGENCY SEQUENCE

Adelanto-Rinaldi 500kV Line 1 Adelanto - Toluca 500 kV Line 2 Adelanto - Victorville 500 kV Line 3 Lugo-Victorville 500 kV Line 4 Victorville-Rinaldi 500 kV Line 5 McCullgh-Victorville 500 kV Line 6 Mead – Victorville 287 kV Line 7 Cottonwood-Barren Ridge 230 kV with Remedial Action Scheme (RAS) 8 Rinaldi – Barren Ridge 230 kV 9 IPP DC Bipole 10 Palo Verde-g2-OL-MA-RAS 12 Adelanto-Rinaldi and Victorville-Rinadi 500kV Lines 13 McCullgh-Victorville 500 kV Lines 1 & 2 14 Rinaldi - Tarzana 230 kV Lines 1 & 2 15 Rinaldi-Glendale 230 kV Lines 1&2 16 Rinaldi-Valley 230 kV Lines 1 & 2 17 Toluca-Valley 230 kV Lines 1&2 18 Glendale-Atwater 230 kV Lines 1&2 19 Tarzana – Olympic 230kV and 138kV Lines 20 Velasco-Century 230kV Lines 1&2 21 Century - Wilmington 138kV Lines 1 & 2 22 Gramercy – Fairfax 138kV Lines 1 & 2 23 Gramercy Tap1 & Tap2 138 kV Lines 24 Airport – Fairfax 138kV Lines 1 & 2 25 Toluca – Hollywood Lines 1, 2 and 3 26 Rinaldi – Tarzana Lines 1 & 2 and Northridge – Tarzana Line 1 27 Rinaldi – Tarzana Lines 1 & 2 and Northridge – Tarzana Line 1 with RAS 28

Adelanto-Rinaldi 500kV Line 1

RUN * 3 phase 4 cycle fault at Adelanto * Loss of Adelanto-Rinaldi 500kV line * * CC cards for post-transient only * * Fault bus at RINALDI 500 busses FB 0.0 "RINALDI2" 500. * * Temporary block all DC * DDC 0.0 "INT MT1R" 206. "ADELAN1I" 202. DDC 0.0 "CELILO1 " 500. "SYLMAR1 " 230. DDC 0.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Clear fault at Rinaldi CFB 4.0 "RINALDI2" 500. * * Trip Adelanto - Rinaldi 500kV line * DL 4.0 "ADELANTO" 500. "RINALDI2" 500. "1 " * * Restart all DC * SDC 4.0 "INT MT1R" 206. "ADELAN1I" 202. SDC 4.0 "CELILO1 " 500. "SYLMAR1 " 230. SDC 4.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Readjust Northwest SVC's CC MSV 0.0 "KEEL-SVC" 230.0 "1 " 350. -300. CC MSV 0.0 "MV-SVC " 230.0 "1 " 350. -300. * * Add SVC's at Marketplace and Adelanto * CC MBS 120.0 "ADELSVC " 500. "sv" "A" 0.0 1.320 CC MBS 120.0 "MKTPSVC " 500. "sv" "A" 0.0 1.320 *

Adelanto - Toluca 500 kV Line 2

RUN * 3 phase 4 cycle fault at Adelanto * Loss of Adelanto-Toluca Line * CC cards for post-transient only * * Fault bus at Adelanto FB 0.0 "ADELANTO" 500. * * Temporary block all DC * DDC 0.0 "INT MT1R" 206. "ADELAN1I" 202. DDC 0.0 "CELILO1 " 500. "SYLMAR1 " 230. DDC 0.0 "CELILO2 " 500. "SYLMAR2 " 230. * Clear fault at Adelanto CFB 4.0 "ADELANTO" 500. * * Trip Adelanto - Toluca 500kV line * DL 4.0 "ADELANTO" 500. "TOLUCA " 500. "1 " * * Restart all DC * SDC 4.0 "INT MT1R" 206. "ADELAN1I" 202. SDC 4.0 "CELILO1 " 500. "SYLMAR1 " 230. SDC 4.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Readjust Northwest SVC's * CC MSV 0.0 "KEEL-SVC" 230.0 "1 " 350. -300. * CC MSV 0.0 "MV-SVC " 230.0 "1 " 350. -300. * * Add SVC's at Marketplace and Adelanto * CC MBS 120.0 "ADELSVC " 500. "sv" "A" 0.0 1.320 CC MBS 120.0 "MKTPSVC " 500. "sv" "A" 0.0 1.320 *

Adelanto - Victorville 500 kV Line 3

RUN * 3 phase 4 cycle fault at Victorville * Loss of Adelanto-Victorville one line * CC cards for post-transient only * * Fault bus at Victorville FB 0.0 "VICTORVL" 500. * * Temporary block all DC * DDC 0.0 "INT MT1R" 206. "ADELAN1I" 202. DDC 0.0 "CELILO1 " 500. "SYLMAR1 " 230. DDC 0.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Clear fault at Victorville CFB 4.0 "VICTORVL" 500. * * Trip Adelanto - Victorville line 1 * DL 4.0 "ADELANTO" 500. "VICTORVL" 500. "1 " * * Restart all DC * SDC 4.0 "INT MT1R" 206. "ADELAN1I" 202. SDC 0.0 "CELILO1 " 500. "SYLMAR1 " 230. SDC 0.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Readjust Northwest SVC's CC MSV 0.0 "KEEL-SVC" 230.0 "1 " 350. -300. CC MSV 0.0 "MV-SVC " 230.0 "1 " 350. -300. * Add SVC's at Marketplace and Adelanto * * CC MBS 120.0 "ADELSVC " 500. "sv" "A" 0.0 1.320 * CC MBS 120.0 "MKTPSVC " 500. "sv" "A" 0.0 1.320 *

Lugo-Victorville 500 kV Line 4

RUN * 3 phase 4 cycle fault at Lugo * Loss of Lugo-Victorville Line * CC cards for post-transient only * * Fault bus at Lugo FB 0.0 "LUGO " 500. * * Temporary block all DC * DDC 0.0 "INT MT1R" 206. "ADELAN1I" 202. DDC 0.0 "CELILO1 " 500. "SYLMAR1 " 230. DDC 0.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Clear fault at Lugo CFB 4.0 "LUGO " 500. * * Trip Lugo - Victorville line * DL 4.0 "LUGO " 500. "VICTORVL " 500. "1 " * * Restart all DC * SDC 4.0 "INT MT1R" 206. "ADELAN1I" 202. SDC 0.0 "CELILO1 " 500. "SYLMAR1 " 230. SDC 0.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Readjust Northwest SVC's CC MSV 0.0 "KEEL-SVC" 230.0 "1 " 350. -300. CC MSV 0.0 "MV-SVC " 230.0 "1 " 350. -300. * * Add SVC's at Marketplace and Adelanto * CC MBS 120.0 "ADELSVC " 500. "sv" "A" 0.0 1.320 CC MBS 120.0 "MKTPSVC " 500. "sv" "A" 0.0 1.320 *

Victorville-Rinaldi 500 kV Line 5

RUN * 3 phase 4 cycle fault at Adelanto * Loss of Victorville-Rinadi 500 kV Line * CC cards for post-transient only * * Fault bus at RINALDI 500 busses FB 0.0 "RINALDI " 500. * * Temporary block all DC * DDC 0.0 "INT MT1R" 206. "ADELAN1I" 202. DDC 0.0 "CELILO1 " 500. "SYLMAR1 " 230. DDC 0.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Clear fault at Rinaldi CFB 4.0 "RINALDI " 500. * * Trip Adelanto - Rinaldi 500 kV Line * DL 4.0 "VICTORVL" 500. "RINALDI " 500. "1 " * * Restart all DC * SDC 4.0 "INT MT1R" 206. "ADELAN1I" 202. SDC 4.0 "CELILO1 " 500. "SYLMAR1 " 230. SDC 4.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Readjust Northwest SVC's CC MSV 0.0 "KEEL-SVC" 230.0 "1 " 350. -300. CC MSV 0.0 "MV-SVC " 230.0 "1 " 350. -300. * * * Add SVC's at Marketplace and Adelanto * CC MBS 120.0 "ADELSVC " 500. "sv" "A" 0.0 1.320 CC MBS 120.0 "MKTPSVC " 500. "sv" "A" 0.0 1.320 *

McCullgh-Victorville 500 kV Line 6

RUN * 3 phase 4 cycle fault at Victorville * Loss of McCullgh-Victorville one line * CC cards for post-transient only * * Fault bus at Victorville FB 0.0 "VICTORVL" 500. * * Temporary block all DC * DDC 0.0 "INT MT1R" 206. "ADELAN1I" 202. DDC 0.0 "CELILO1 " 500. "SYLMAR1 " 230. DDC 0.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Clear fault at Victorville CFB 4.0 "VICTORVL" 500. * * Trip McCullough - Victorville lines * DL 4.0 "MCCULLGH" 500. "VICTORVL" 500. "1 " * * Restart all DC * SDC 4.0 "INT MT1R" 206. "ADELAN1I" 202. SDC 4.0 "CELILO1 " 500. "SYLMAR1 " 230. SDC 4.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Readjust Northwest SVC's CC MSV 0.0 "KEEL-SVC" 230.0 "1 " 350. -300. CC MSV 0.0 "MV-SVC " 230.0 "1 " 350. -300. * * Add SVC's at Marketplace and Adelanto * CC MBS 120.0 "ADELSVC " 500. "sv" "A" 0.0 1.320 CC MBS 120.0 "MKTPSVC " 500. "sv" "A" 0.0 1.320 * Mead-Victorville 287 kV Line 7

RUN * 3 phase 4 cycle fault at Mead * Loss of Mead-Victorville one line * CC cards for post-transient only * * Fault bus at Mead FB 0.0 "MEAD" 287. * * Clear fault at Mead CFB 4.0 "MEAD" 287. * * Trip Mead - Victorville lines * DL 4.0 "MEAD" 287. "VICTORVL" 287. "1 " *

* Readjust Northwest SVC's CC MSV 0.0 "KEEL-SVC" 230.0 "1 " 350. -300. CC MSV 0.0 "MV-SVC " 230.0 "1 " 350. -300. * * Add SVC's at Marketplace and Adelanto * CC MBS 120.0 "ADELSVC " 500. "sv" "A" 0.0 1.320 CC MBS 120.0 "MKTPSVC " 500. "sv" "A" 0.0 1.320 *

Cottonwood-Barren Ridge 230 kV Line with RAS 8

RUN * Cottonwood - Barren Ridge 230kV Line Out * W/ RAS * 3-phase 4 cycle fault at Barren Ridge * * CC DRP 110 * * Fault bus at Barren Ridge 230 FB 0.0 "BARRENRD" 230. * * * Clear fault bus Barren Ridge CFB 4.0 "BARRENRD" 230. * * Trip Cottonwood - Barren Ridge DL 4.0 "COTTONWD" 230. "BARRENRD" 230. "1 " * * Trip OG Units * TG 8.0 "OWENS UP " 11.5 "1 " TG 8.0 "OWENSMID " 11.5 "1 " TG 8.0 "OWENSCON " 11.5. "1 " * * * Open Inyo tie * DL 12.0 "INYO " 115. "INYO PS " 115. "1 " * Barren Ridge - Rinaldi 230 kV Line 9

RUN * Barren Ridge-Rinaldi 230kV Line Out * * 3-phase 4 cycle fault at Barren Ridge * * * Fault bus at Barren Ridge 230 FB 0.0 "BARRENRD" 230. * * * * Clear fault bus at BARRENRD CFB 4.0 "BARRENRD" 230. * * Trip Barren Ridge - Rinaldi DL 4.0 "RINALDI" 230. "BARRENRD" 230. "1 " *

IPP DC Bipole 10

RUN * Loss of IPP Bipole with North-to-South flow * * CC cards for post-transient only * CC DRP 1900 * * Readjust Northwest SVC's * CC MSV 0.0 "KEEL-SVC" 19.60 "1 " 350. -300. CC MSV 0.0 "MV-SVC " 19.60 "1 " 350. -300. * * Readjust SCE SVC's * MSV 0.0 "DEVRSVC1" 500.0 "1 " 400. -249. * * Delete Intermountain and Adelanto buses * DDC 0.0 "INT MT1R" 206. "ADELAN1I" 202. * * Drop filter bank capacitors at Intermountain * MBS 4.0 "INTERMT " 345. "b " "D" * * Drop filter bank capacitors at Adelanto * MBS 4.0 "ADELANTO" 500. "b " "D" * * Trip both units at Intermountain * TG 10.2 "INTERM1G " 26.0 "1 " TG 10.2 "INTERM2G " 26.0 "2 " * * Trip all wind turbines * TG 10.2 "WTGGE " 0.57 "1 " TG 10.2 "WTGCP " 0.69 "1 " TG 10.2 "WTGGE2 " 0.57 "1 " * MBS 10.2 "MWC1_35 " 34.5 "b " "D" MBS 10.2 "MWC2_35 " 34.5 "b " "D" * * * Add SVC's at Marketplace and Adelanto * CC MBS 120.0 "ADELSVC " 500. "sv" "A" 0.0 1.320 CC MBS 120.0 "MKTPSVC " 500. "sv" "A" 0.0 1.320 * Loss of Two Palo Verde Units 11

RUN * Loss of 2 Palo Verde generators * * CC cards for post-transient only * * Set Generator MW Dropping CC DRP 2641 * * Readjust Northwest SVC's * CC MSV 0.0 "KEEL-SVC" 19.60 "1 " 350. -300. CC MSV 0.0 "MV-SVC " 19.60 "1 " 350. -300. * CC RG 0.0 "DALLES 3" 13.8 "1 " 180. -270. * * Trip Palo Verde units #1 and #3 * TG 0.0 "PALOVRD1" 24. "**" TG 0.0 "PALOVRD2" 24. "**" * * * This routine will call the FACRI (Fort Rock and Malin MSC) * in In-Run EPCL (facri.p) * Disregard timing * * Insert Fort Rock series caps CC RC 12.6 "CAPTJACK" 500. "GRIZZLY " 500. "1 " 4 CC RC 12.6 "GRIZZLY " 500. "MALIN " 500. "2 " 4 CC RC 12.6 "PONDROSA" 500. "SUMMER L" 500. "1 " 4 * * Switch on Shunt caps at malin as part of FACRI CC MBS 13.4 "MALIN " 500. "c1" "R" CC MBS 13.4 "MALIN " 500. "c2" "R" *CC MBS 13.4 "MALIN " 500. "r3" "D" *CC MBS 13.4 "MALIN " 500. "r4" "D" CC MSV 13.4 "MALIN " 500. "s " 0.0 0.0 * * Load shed in the Arizona Area (2-PV RAS) * * Total Load Drop = 120 * 120.0 + J3.89 * MBL 60.0 "AGUAFAPS" 69. "AP" "M" -15.0 -2.72 MBL 60.0 "PAPAGOBT" 69. "SR" "M" -30.0 -3.80 MBL 60.0 "SANTAN " 69. "SR" "M" -30.0 -0.10 MBL 60.0 "CORBELRS" 69. "SR" "M" -15.0 -0.80 MBL 60.0 "ORME RS" 69. "SR" "M" -15.0 -0.22 MBL 60.0 "THUNDRST" 69. "SR" "M" -15.0 -0.05 * * * Remove reactors at Olinda * CC MLS 17.5 "OLINDA" 500. "MAXWELL" 500. "1 " 1 "D" "f " CC MLS 17.5 "CAPTJACK" 500. "OLINDA" 500. "1 " 4 "D" "t " * * Switch on Olinda Shunt cap * CC MBS 17.5 "OLINDA " 500. "c1" "R" * * Switch on Table Mountain Shunt cap * 2 x 217 caps (91 Mvar reactor modeled separately) CC MBS 90. "TABLE MT" 500. "c1" "R" CC MBS 90. "TABLE MT" 500. "c2" "R" * * Adelanto-Rinaldi and Victorville-Rinadi 500kV Lines 12

RUN * 3 phase 4 cycle fault at Adelanto * Loss of Adelanto-Rinaldi and Victorville-Rinadi 500kV lines * CC cards for post-transient only * * Fault bus at RINALDI 500 busses FB 0.0 "RINALDI " 500. FB 0.0 "RINALDI2" 500. * * * Temporary block all DC * DDC 0.0 "INT MT1R" 206. "ADELAN1I" 202. DDC 0.0 "CELILO1 " 500. "SYLMAR1 " 230. DDC 0.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Clear fault at Rinaldi CFB 4.0 "RINALDI " 500. CFB 4.0 "RINALDI2" 500. * * Trip Adelanto - Rinaldi & Victorville-Rinaldi 500kV lines * DL 4.0 "ADELANTO" 500. "RINALDI2" 500. "1 " DL 4.0 "VICTORVL" 500. "RINALDI " 500. "1 " * * Restart all DC * SDC 4.0 "INT MT1R" 206. "ADELAN1I" 202. SDC 4.0 "CELILO1 " 500. "SYLMAR1 " 230. SDC 4.0 "CELILO2 " 500. "SYLMAR2 " 230. * * * * Readjust Northwest SVC's CC MSV 0.0 "KEEL-SVC" 230.0 "1 " 350. -300. CC MSV 0.0 "MV-SVC " 230.0 "1 " 350. -300. * * * Add SVC's at Marketplace and Adelanto * CC MBS 120.0 "ADELSVC " 500. "sv" "A" 0.0 1.320 CC MBS 120.0 "MKTPSVC " 500. "sv" "A" 0.0 1.320

McCullgh-Victorville 500 kV Lines 1 & 2 13

RUN * 3 phase 4 cycle fault at Victorville * Loss of McCullgh-Victorville two lines * CC cards for post-transient only * * Fault bus at Victorville FB 0.0 "VICTORVL" 500. * * * Temporary block all DC * DDC 0.0 "INT MT1R" 206. "ADELAN1I" 202. DDC 0.0 "CELILO1 " 500. "SYLMAR1 " 230. DDC 0.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Flash series capacitors in following 500 kV Lines * FC 0.0 "MARKETPL" 500. "ADELANTO" 500. "1 " 1 FC 0.0 "MOHAVE " 500. "LUGO " 500. "1 " 1 FC 0.0 "ELDORDO" 500. "LUGO " 500. "1 " 3 FC 0.0 "MCCULLGH" 500. "VICTORVL" 500. "1 " 3 FC 0.0 "MCCULLGH" 500. "VICTORVL" 500. "2 " 1 * * Clear fault at Victorville CFB 4.0 "VICTORVL" 500. * * Trip McCullough - Victorville lines * DL 4.0 "MCCULLGH" 500. "VICTORVL" 500. "1 " DL 4.0 "MCCULLGH" 500. "VICTORVL" 500. "2 " * * Restart all DC * SDC 4.0 "INT MT1R" 206. "ADELAN1I" 202. SDC 4.0 "CELILO1 " 500. "SYLMAR1 " 230. SDC 4.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Reinsert series capacitors in following 500 kV Lines * RC 4.0 "MARKETPL" 500. "ADELANTO" 500. "1 " 1 RC 8.0 "MOHAVE " 500. "LUGO " 500. "1 " 1 RC 8.0 "ELDORDO" 500. "LUGO " 500. "1 " 3 RC 8.0 "MCCULLGH" 500. "VICTORVL" 500. "1 " 1 RC 8.0 "MCCULLGH" 500. "VICTORVL" 500. "1 " 3 RC 8.0 "MCCULLGH" 500. "VICTORVL" 500. "2 " 1 RC 8.0 "MCCULLGH" 500. "VICTORVL" 500. "2 " 3 * * Readjust Northwest SVC's CC MSV 0.0 "KEEL-SVC" 230.0 "1 " 350. -300. CC MSV 0.0 "MV-SVC " 230.0 "1 " 350. -300. * * Add SVC's at Marketplace and Adelanto * CC MBS 120.0 "ADELSVC " 500. "sv" "A" 0.0 1.320 CC MBS 120.0 "MKTPSVC " 500. "sv" "A" 0.0 1.320 * * Rinaldi - Tarzana 230 kV Lines 1 & 2 14

RUN * Loss of Rinaldi-Tarzana two lines * Fault bus at Rinaldi 230 FB 0.0 "RINALDI" 230. * * Temporary block all DC * DDC 0.0 "INT MT1R" 206. "ADELAN1I" 202. DDC 0.0 "CELILO1 " 500. "SYLMAR1 " 230. DDC 0.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Clear fault at Adelanto CFB 4.0 "RINALDI" 230. * * Restart all DC * SDC 4.0 "INT MT1R" 206. "ADELAN1I" 202. SDC 4.0 "CELILO1 " 500. "SYLMAR1 " 230. SDC 4.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Trip Rinaldi - Tarzana lines * DL 0.0 "RINALDI " 230. "TARZANA " 230. "1 " DL 0.0 "RINALDI " 230. "TARZANA " 230. "2 "

Rinaldi-Glendale 230 kV Lines 1&2 15

RUN * Loss of Rinaldi-Glendale two lines * Fault bus at Rinaldi 230 FB 0.0 "RINALDI" 230. * * Temporary block all DC * DDC 0.0 "INT MT1R" 206. "ADELAN1I" 202. DDC 0.0 "CELILO1 " 500. "SYLMAR1 " 230. DDC 0.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Clear fault at Adelanto CFB 4.0 "RINALDI" 230. * * Restart all DC * SDC 4.0 "INT MT1R" 206. "ADELAN1I" 202. SDC 4.0 "CELILO1 " 500. "SYLMAR1 " 230. SDC 4.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Trip Rinaldi - Tarzana lines * DL 0.0 "RINALDI " 230. "GLENDAL " 230. "1 " DL 0.0 "RINALDI " 230. "GLENDAL " 230. "2 " *

Rinaldi-Valley 230 kV Lines 1 & 2 16

RUN * Loss of Rinaldi-Valley two lines * * Fault bus at Rinaldi 230 FB 0.0 "RINALDI " 230. * * Temporary block all DC * DDC 0.0 "INT MT1R" 206. "ADELAN1I" 202. DDC 0.0 "CELILO1 " 500. "SYLMAR1 " 230. DDC 0.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Clear fault at RINALDI CFB 4.0 "RINALDI " 230. * * Restart all DC * SDC 4.0 "INT MT1R" 206. "ADELAN1I" 202. SDC 4.0 "CELILO1 " 500. "SYLMAR1 " 230. SDC 4.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Trip Rinaldi - Valley lines * DL 0.0 "RINALDI " 230. "VALLEY " 230. "1 " DL 0.0 "RINALDI " 230. "VALLEY " 230. "2 "

Toluca-Valley 230 kV Lines 1&2 17

RUN * Loss of Valley-Toluca two lines * * Fault bus at Toluca 230 FB 0.0 "TOLUCA " 230. * * * Temporary block all DC * DDC 0.0 "INT MT1R" 206. "ADELAN1I" 202. DDC 0.0 "CELILO1 " 500. "SYLMAR1 " 230. DDC 0.0 "CELILO2 " 500. "SYLMAR2 " 230. * * * Clear fault at Toluca CFB 4.0 "TOLUCA " 230. * * Restart all DC * SDC 4.0 "INT MT1R" 206. "ADELAN1I" 202. SDC 4.0 "CELILO1 " 500. "SYLMAR1 " 230. SDC 4.0 "CELILO2 " 500. "SYLMAR2 " 230. * * Trip Rinaldi - Tarzana lines * DL 0.0 "TOLUCA " 230. "VALLEY " 230. "1 " DL 0.0 "TOLUCA " 230. "VALLEY " 230. "2 " *

Glendale-Atwater 230 kV Lines 1&2 18

RUN * Loss of Glendale-Atwater two lines * * Fault bus at Glendale 230 FB 0.0 "GLENDAL " 230. * * Clear fault at Glendale 230 CFB 4.0 "GLENDAL" 230. * * Trip Rinaldi - Tarzana lines * DL 0.0 "ATWATER " 230. "GLENDAL " 230. "1 " DL 0.0 "ATWATER " 230. "GLENDAL " 230. "2 " * Tarzana-Olympic 230 kV and 138k V Lines 19

RUN * Loss of Tarzana-Olympic two lines * * Fault bus at TARZANA 230 FB 0.0 "TARZANA" 230. * * * Clear fault at TARZANA 230 CFB 4.0 "TARZANA" 230. * * Trip Tarzana-Olympic lines * DL 0.0 "TARZANA" 230. "OLYMPC " 230. "1 " DL 0.0 "TARZANA" 138. "OLYMPLD " 138. "1 " * Velasco-Century 230kV Lines 1&2 20

RUN * Loss of Velasco-Century two lines * * Fault bus at Velasco 230 FB 0.0 "VELASCO " 230. * * Clear fault at Glendale 230 CFB 4.0 "VELASCO " 230. * * Trip Rinaldi - Tarzana lines * DL 0.0 "VELASCO " 230. "CNTURYLD" 230. "1 " DL 0.0 "VELASCO " 230. "CNTURYLD" 230. "2 " Century - Wilmington 138kV Lines 1 & 2 21

RUN * Loss of CNTURY - WILMINGTON two lines * * Fault bus at CNTURY 138 FB 0.0 "CNTURY " 138. * * Clear fault at Glendale 230 CFB 4.0 "CNTURY " 138. * * Trip Rinaldi - Tarzana lines * DL 0.0 "CNTURY " 138. "WILMNTN " 138. "1 " DL 0.0 "CNTURY " 138. "WILMNTN " 138. "2 " * Gramercy-Fairfax 138kV Lines 1 &2 22

RUN * Loss of GRAMERCY - FAIRFAX two lines * * Fault bus at GRAMERCY 138 FB 0.0 "GRAMERCY" 138. * * Clear fault at GRAMERCY 230 CFB 4.0 "GRAMERCY" 138. * * Trip Gramercy - Fairfax lines * DL 0.0 "GRAMERCY" 138. "FAIRFAX" 138. "1 " DL 0.0 "GRAMERCY" 138. "FAIRFAX" 138. "2 " *

Century-Gramercy 138kV Lines 1 &2 23

RUN * Loss of CNTURY - GRAMERCY two lines * CC cards for post-transient only * * Fault bus at CNTURY 138 FB 0.0 "CNTURY " 138. * * Clear fault at CNTURY 230 CFB 4.0 "CNTURY " 138. * * Trip Century - Gramercy lines * DL 0.0 "CNTURY " 138. "GRAMERCY" 138. "1 " DL 0.0 "CNTURY " 138. "GRAMERCY" 138. "2 " *

Gramercy – Tap1 & Tap2 138 kV Lines 24

RUN * Loss of GRAMERCY - TAP two lines * CC cards for post-transient only * * Fault bus at GRAMERCY 138 FB 0.0 "GRAMERCY" 138. * * Clear fault at GRAMERCY 230 CFB 4.0 "GRAMERCY" 138. * * Trip Gramercy – Tap lines * DL 0.0 "GRAMERCY" 138. "TAP1 " 138. "1 " DL 0.0 "GRAMERCY" 138. "TAP2 " 138. "2 " * Airport – Fairfax 138 kV Lines 25

RUN * Loss of AIRPORT - FAIRFAX two lines * Fault bus at AIRPORT 138 * FB 0.0 "AIRPORT" 138. * * * Clear fault at AIRPORT 230 CFB 4.0 "AIRPORT" 138. * * Trip Airport - Fairfax lines * DL 0.0 "AIRPORT" 138. "FAIRFAX" 138. "1 " DL 0.0 "AIRPORT" 138. "FAIRFAX" 138. "2 " * Toluca– Hollywood Lines 1, 2, and 3 26

RUN * Loss of Toluca - Holywood triple towers * CC cards for post-transient only * * * Trip Toluca - Holywood lines * DL 0.0 "TOLUCA " 230. "HOLYWD_E" 230. "1 " DL 0.0 "TOLUCA " 230. "HOLYWD_F" 230. "3 " DL 0.0 "TOLUCA " 138. "HOLYWDLD" 230. "2 " * Rinaldi–Tarzana Lines 1 & 2 and Northridge-Tarzana Line 1 27

RUN * Loss of Northridge-Tarzana tripple tower * CC cards for post-transient only * * Trip Rinaldi/Northridge - Tarzana lines * DL 0.0 "RINALDI " 230. "TARZANA " 230. "1 " DL 0.0 "RINALDI " 230. "TARZANA " 230. "2 " DL 0.0 "NRTHRDGE" 230. "TARZANA " 230. "1 " * Rinaldi–Tarzana Lines 1 & 2 and Northridge-Tarzana Line with load shed 28

RUN * Loss of Northridge-Tarzana tripple tower w/ load shed @ CAN * CC cards for post-transient only * * Trip Rinaldi/Northridge - Tarzana lines * DL 0.0 "RINALDI " 230. "TARZANA " 230. "1 " DL 0.0 "RINALDI " 230. "TARZANA " 230. "2 " DL 0.0 "NRTHRDGE" 230. "TARZANA " 230. "1 " * * * Drop Canoga Load * MBL 0.0 "CAN A M " 34.5 "A" "D" MBL 0.0 "CAN B M " 34.5 "B" "D" MBL 0.0 "CAN C M " 34.5 "C" "D" * * Add SVC's at Marketplace and Adelanto * CC MBS 120.0 "ADELSVC " 500. "sv" "A" 0.0 1.320 CC MBS 120.0 "MKTPSVC " 500. "sv" "A" 0.0 1.320 * LADWP’s 2010 Ten-Year Transmission Assessment

Appendix H. Power Flow Results

H November 1, 2010

230kV Lines 287kV Lines 500kV Lines CONT. NO. 5201AWTR20200VLSO201 withRAS 1 1 230 230 1 COTTONWD 1 26136 230 1 CASTAIC 230 26010 230 230 BCON230 VELASCO 26905 230 BARRENRD 26080 1 26132 STJOHN 230 BARRENRD 26068 287 1 230 26132 BARRENRD 18 287 230 26132 CNTURY2 ATWATER 17 26071 26081 CNTURY1 1 ATWATER 1 16 26070 287 26081 500 287 15 287 VICTORVL VICTORVL 14 26104 RINALDI 26104 VICTORVL 26104 26062 MEAD 287 13 500 26051 12 VICTORVL 11 26105 10 60 ITRL50206LG 0 1 500 1 500 LUGO 1 ADELANTO 1 500 24086 1 500 500 26003 500 VICTORVL 500 1 1 MCCULLGH VICTORVL 26105 26105 500 500 500 HLTAP VICTORVL 26048 26105 500 ADELANTO ADELANTO MCCULLGH 27204 9 26048 500 26003 MARKETPL 26003 8 500 26044 500 MARKETPL 7 26044 MARKETPL 6 1 26044 HLTAP 500 5 27204 4 RINALDI2 3 26115 500 ADELANTO 26003 1 2 60 DLNO500 ADELANTO 26003 CIRCUIT 67 OUA500 TOLUCA 26079 2010 Ten-YearPlanContin 1 VALLEY -RINALDI230kVLine2 VALLEY -RINALDI230kVLine1 VALLEY-TOLUCA 230kVLine2 VALLEY-TOLUCA 230kVLine1 RINALDI -TARZANA230kVLine2 RINALDI -TARZANA230kVLine1 (N-1) CONTINGENCY (N-0) CONTINGENCY HEAVY SUMMER IMPACTED ELEMENT g ency AnalysesResults

2010hs11_lml

2010hs12_lml2

2010hs13_lml

9%9%9%9%9%97% 97% 93% 93% 94% 94% 92% 92% 92% 92% 90% 90% 2010hs14_lml-r BASECASE 2010hs15_lml-r

2010hs16_lml-r

9%95% 95% 92% 92% 2010hs17_lml-r

2010hs18_lml-r

2010hs19_lml-r 91% 91% 2010hs20_lml-rc-fix4-33% CONT. NO. 6208TLC 3 68 OYDF201TOLUCA-HOLYWD_E230kVLine1 1 230 1 RINALDI 230 1 26061 1 HOLYWD_F 230 OLIVE-NRTHRDGE230kVLine1 230 26182 1 230 HOLYWD_E 26082 230 230 1 ATWATER 26081 OLYMPCLD 230 VALLEY 230 OLYMPC 26103 RINALDI-TARZANA230kVLine2 1 230 TOLUCA 1 26087 26078 1 RINALDI 230 230 TOLUCA 47 230 26061 26078 230 NRTHRDGE TOLUCA 46 26086 26078 230 HSKLLCYN TARZANA RIVER 45 26135 26093 230 1 26063 SYLMARLA 44 26094 230 230 230 SYLMARLA 1 43 26094 1 SYLMARLA 230 TARZANA 42 26094 230 1 26093 STJOHN HSKLLCYN 41 26068 230 26135 230 GLENDAL 40 1 NRTHRDGE 1 26013 230 39 26086 230 230 1 230 RINALDI 230 26061 230 38 1 RINALDI TARZANA 1 26061 BARRENRD 26093 OLIVE 230 RINALDI 1 37 26132 26052 230 26061 230 OLIVE 230 VELASCO 36 230 230 26052 26080 1 NRTHRDGE STJOHN 35 26086 26068 230 HSKLLCYN 230 RIVER 1 34 26135 26063 PT230 230 1 230 ATWATER 33 1 27031 26081 HAYNES 230 230 32 230 ATWATER 26025 HAYNES 230 26081 31 SYLMARLA 1 26025 HAYNES 26094 30 1 230 withRAS OLIVE 230 26025 HAYNES 26052 230 230 29 NRTHRDGE 1 26025 GLENDAL 26086 230 28 230 HSKLLCYN 26013 CASTAIC 26035 230 3 27 26010 CASTAIC 230 RINALDI 230 2 26 26010 26061 CASTAIC 230 HSKLLCYN 25 26010 26135 230 CASTAIC HSKLLCYN 24 26010 26135 230 BARRENRD 23 26132 230 BARRENRD 22 26132 BARRENRD 21 26132 20 19 66 2 26066 SCATERGD 230 ICI IMPACTEDELEMENT CIRCUIT 26087 230 AIRPORT-SCATERGD 138kVLine2 AIRPORT-SCATERGD 138kVLine1

2010hs11_lml 1 4 94% 95% 94% 95% 91% 2010hs12_lml2 92% 2010hs13_lml

2010hs14_lml-r BASECASE 2010hs15_lml-r

2010hs16_lml-r

2010hs17_lml-r

2010hs18_lml-r

2010hs19_lml-r

2010hs20_lml-rc-fix4-33% 138kV Lines CONT. NO. 4203WMT 3 69 A2181 138 1 138 TAP2 2 26096 TAP1 138 1 1 26095 138 HOLYWDLD 138 138 26085 138 GRAMERCY OLYMPCLD 1 WLMNTN 138 26015 26088 26073 138 WLMNTN SCATERGD-AIRPORT138kVLine2 138 138 26073 1 1 GRAMERC2 TOLUCA 74 26015 138 26077 138 1 TARZANA 73 GRAMERCY 138 26092 1 138 HALLDALE 26014 TAP2 72 26016 138 26096 HALLDALE 1 TAP1 138 71 26016 GRAMERC1 138 26095 138 1 26014 TAP2 70 1 138 26096 138 TAP1 138 138 69 AIRPORT 26095 HOLYWDLD 26089 TAP2 68 26085 E 1 26096 FAIRFAX 138 TAP1 67 138 138 26076 138 26095 A SCATERGD 66 138 138 WLMNTN 26065 HOLYWD 65 26073 WLMNTNLD TAP2 26083 1 1 26075 HOLYWD 64 26096 138 TAP1138 26083 138 1 HARB 138 63 26095 1 138 OLYMPCLD 26019 138 HARBOR 62 138 26088 1 138 GRAMERC1 26091 HARBOR 138 61 26014 138 AIRPORT 26091 1 HARBOR 60 26089 138 WLMNTN 26091 138 1 FAIRFAX VALLEY-TOLUCA230kVLine2 withRAS 26073 59 138 GRAMERCY 26076 138 FAIRFAX 1 26014 58 138 GRAMERC1 26076 230 FAIRFAX 26014 57 138 26076 withRAS CNTURY 56 138 26069 1 1 CNTURY 1 55 INYO 26069 230 230 24729 230 CNTURY 54 COTTONWD 26069 CNTURYLD 26136 53 230 TOLUCA 26072 26078 OWENYOTP 52 230 26946 230 230 OWENYOTP 26946 VELASCO 51 26080 VALLEY 50 26103 49 48 ICI IMPACTEDELEMENT CIRCUIT

2010hs11_lml 6 9%96% 93% 96% 2010hs12_lml2

2010hs13_lml

2010hs14_lml-r BASECASE 2010hs15_lml-r

2010hs16_lml-r

2010hs17_lml-r

2010hs18_lml-r

2010hs19_lml-r 90% 2010hs20_lml-rc-fix4-33% Auto-Transformers CONT. NO. 12 11 10 1206SAEG 3 66 CTRD181SCATERGD-OLYMPC230kVLine2 OLYMPC-OLYMPCLD230/138kVxfmrF 1 287 1 1 VICTORVL 138 26104 138 1 SCATERGD F OLYMPCLD 500 138 26065 26088 138 G 230 VICTORVL CNTURY 230 138 26105 26069 CNTURY SCATERGD 1 26069 26066 287 CNTURY OLYMPC 82 138 26069 230 26087 1 CNTURYLD 81 287 26072 138 CNTURY2 80 HARB 26071 26019 CNTURY1 79 WLMNTN 26070 26073 138 78 138 WLMNTNLD 77 26075 WLMNTNLD 26075 76 75 9 8 7 6 5 4 3 2 1 68 EAC 3 67 NUYD202 2 1 230 1 230 230 CNTURYLD 2 230 CNTURYLD 1 26072 230 TOLUCA 230 26072 230 TOLUCA 26078 230 RINALDI 230 1 26078 1 VELASCO RINALDI 230 26061 138 VELASCO 230 26080 230 26061 OLYMPCLD VALLEY 26080 230 OLYMPC VALLEY 26088 26103 VALLEY 138 26087 26103 VALLEY 230 26103 TARZANA 26103 TARZANA 26092 26093 66 IAD 3 69 AZN 3 NRTHRDGE-TARZANA230kVLine1 1 2 230 1 230 TARZANA 230 2 GLENDAL 26093 1 230 GLENDAL 230 26113 2 230 230 26113 ATWATER 1 230 230 ATWATER RINALDI 26081 1 230 HSKLLCYN RINALDI 230 26081 26061 1 287 HSKLLCYN RINALDI 230 26135 26061 287 230 2 GLENDAL 26135 CNTURY2 26061 230 1 500 GLENDAL CNTURY1 26013 26071 2 500 CASTAIC ADELANTO 287 26013 26070 1 1 CASTAIC 500 ADELANTO 287 26010 26003 VICTORVL 500 500 500 26010 26003 1 VICTORVL VICTORVL 500 26104 VICTORVL 500 26105 VICTORVL RINALDI 26104 500 26105 VICTORVL 26105 RINALDI2 26062 500 MCCULLGH 500 26105 26115 MCCULLGH 26048 500 VICTORVL 26048 ADELANTO 26105 26003 66 IAD 3 69 AZN 3 SCATERGD-OLYMPC230kVLine2 2 230 TARZANA 26093 230 RINALDI 26061 ICI IMPACTEDELEMENT CIRCUIT

SYLMAR-NRTHRDGE 230kVLine1 SCATERGD-OLYMPC 230kVLine2 (N-2) CONTINGENCY 0%96% 100% 2%15 121% 115% 120% 104% 1%15 118% 115% 118% 3 99% 93% 2010hs11_lml

2010hs12_lml2 101% 102%

2010hs13_lml

2010hs14_lml-r BASECASE 2010hs15_lml-r

2010hs16_lml-r 0 2 5 93% 95% 92% 90% 2010hs17_lml-r 2 98% 92% 2010hs18_lml-r

2010hs19_lml-r 90% 2010hs20_lml-rc-fix4-33% CONT. NO. 20 19 18 17 16 15 14 13 69 A 3 61 RMRY181 138 1 GRAMERCY 1 138 GRAMERCY 138 1 26014 138 GRAMERC2 138 26014 138 2 GRAMERC1 26015 138 138 1 26014 TAP2 GRAMERCY 138 1 138 TAP1 26096 GRAMERCY 138 1 26014 2 TAP2 138 26095 GRAMERC2 138 26014 138 1 TAP1 138 26096 GRAMERC1 26015 2 138 FAIRFAX 138 26095 AIRPORT 26014 138 1 FAIRFAX 138 26076 AIRPORT 26089 138 FAIRFAX 138 26076 WLMNTN 26089 2 FAIRFAX 138 26076 WLMNTN 26073 138 1 FAIRFAX 138 26076 GRAMERCY 1 26073 138 FAIRFAX 138 26076 GRAMERCY 138 1 26014 CNTURY 138 26076 GRAMERC2 138 26014 CNTURY 138 26069 GRAMERC1 26015 CNTURY 138 26069 26014 CNTURY 138 26069 CNTURY 26069 CNTURY 26069 26069 ICI IMPACTEDELEMENT CIRCUIT SCATERGD-OLYMPC 230kVLine2

2010hs11_lml 94% 2010hs12_lml2

2010hs13_lml

2010hs14_lml-r BASECASE 2010hs15_lml-r

2010hs16_lml-r

2010hs17_lml-r

2010hs18_lml-r

2010hs19_lml-r

2010hs20_lml-rc-fix4-33% 230kV Lines 287kV Lines 500kV Lines CONT. NO. 7201RNLI20203TRAA201 230 1 1 230 TARZANA 1 230 26093 HSKLLCYN 230 26135 230 GLENDAL 1 1 NRTHRDGE 26013 230 26086 230 230 1 230 RINALDI 230 230 1 26061 TARZANA RINALDI 1 BARRENRD 26093 26061 230 1 OLIVE RINALDI 26132 230 37 26052 26061 230 230 OLIVE VELASCO 36 230 230 26052 1 26080 NRTHRDGE STJOHN 35 26086 230 26068 1 230 HSKLLCYN RIVER 34 26135 1 26063 230 PT230 1 230 ATWATER 33 27031 26081 230 230 HAYNES 230 32 ATWATER 26025 230 HAYNES 26081 1 SYLMARLA 31 26025 26094 1 HAYNES OLIVE 230 230 30 26025 26052 HAYNES 230 1 230 NRTHRDGE 29 26025 26086 GLENDAL 230 230 HSKLLCYN 28 26013 3 26035 CASTAIC 230 27 26010 2 230 CASTAIC RINALDI 230 26 26010 26061 230 CASTAIC HSKLLCYN 1 25 1 26010 26135 230 CASTAIC HSKLLCYN 24 230 26010 230 1 26135 230 BARRENRD COTTONWD 23 1 26132 230 26136 230 1 BARRENRD 22 CASTAIC 230 26132 26010 230 230 BARRENRD BCON230 21 26132 VELASCO 26905 230 BARRENRD 1 20 26080 STJOHN 26132 230 BARRENRD 1 19 287 26068 230 26132 BARRENRD 287 18 230 CNTURY2 26132 ATWATER 26071 17 CNTURY1 1 26081 1 ATWATER 26070 16 287 26081 500 287 15 287 VICTORVL VICTORVL 14 RINALDI 26104 26104 VICTORVL 26104 26062 MEAD 287 13 500 26051 12 VICTORVL 11 26105 10 60 ITRL50206LG 0 1 500 1 500 1 LUGO 1 500 ADELANTO 1 24086 500 500 500 26003 VICTORVL 500 1 1 MCCULLGH VICTORVL 26105 500 26105 500 500 HLTAP 1 26048 VICTORVL 500 26105 ADELANTO ADELANTO 500 27204 MCCULLGH 1 9 500 26048 26003 26003 MARKETPL 500 8 500 500 26044 TOLUCA MARKETPL 7 26044 RINALDI2 26079 MARKETPL 6 500 26044 26115 HLTAP 5 500 27204 ADELANTO 4 26003 ADELANTO 3 26003 2 1 2010 Ten-YearPlanContin CIRCUIT (N-1) CONTINGENCY (N-0) CONTINGENCY LIGHT WINTER g ency AnalysesResults IMPACTED ELEMENT

2011lw11-lml.sav BASECASE

2011lw15-lml-r.sav Auto-Transformers 138kV Lines CONT. NO. 2215VCOV 0 60 ITRL271 287 1 1 VICTORVL 138 1 26104 138 F SCATERGD 138 OLYMPCLD 500 26065 138 26088 G 230 VICTORVL CNTURY 138 230 26105 26069 CNTURY SCATERGD 1 26069 26066 CNTURY 287 OLYMPC 1 138 82 26069 230 1 26087 CNTURYLD 1 138 81 287 138 26072 CNTURY2 138 HARB 80 26071 26019 CNTURY1 WLMNTN 79 2 TAP2 26070 26073 138 26096 78 138 TAP1 1 1 138 WLMNTNLD 26095 77 138 HOLYWDLD 26075 138 138 26085 WLMNTNLD 138 26075 GRAMERCY OLYMPCLD 1 WLMNTN 138 76 26015 26088 26073 138 WLMNTN 75 138 138 1 1 26073 GRAMERC2 TOLUCA 74 26015 138 1 138 26077 TARZANA 73 GRAMERCY 1 138 138 26092 HALLDALE 26014 TAP2 72 26016 138 1 26096 HALLDALE TAP1138 71 26016 GRAMERC1 138 138 1 26095 26014 1 TAP2 70 138 138 26096 138 TAP1138 AIRPORT 69 HOLYWDLD 26095 26089 E TAP2 1 26085 68 FAIRFAX 26096 138 138 TAP1 138 26076 67 138 A 26095 SCATERGD 66 138 138 WLMNTN 26065 HOLYWD 26073 65 WLMNTNLD 1 1 TAP2 26083 26075 HOLYWD 26096 64 138 138 TAP1138 1 26083 1 HARB 138 26095 63 138 OLYMPCLD 138 26019 1 138 HARBOR 26088 62 138 GRAMERC1 26091 138 HARBOR 26014 138 61 AIRPORT 1 26091 HARBOR 26089 138 60 WLMNTN 1 138 26091 FAIRFAX 26073 138 59 GRAMERCY 138 26076 1 FAIRFAX 26014 138 58 GRAMERC1 26076 230 FAIRFAX 26014 138 57 26076 CNTURY 138 56 1 1 26069 1 CNTURY 55 INYO 230 1 230 26069 230 24729 CNTURY 54 COTTONWD 230 26069 CNTURYLD 26136 230 53 TOLUCA 1 26072 26078 OWENYOTP 52 230 RINALDI 1 230 230 26946 26061 1 230 OWENYOTP 230 HOLYWD_F 26946 1 230 26182 230 VELASCO 51 HOLYWD_E 26080 230 26082 1 230 VALLEY ATWATER 50 26103 26081 230 230 VALLEY 49 OLYMPC 26103 1 1 230 TOLUCA 26087 48 1 26078 230 RINALDI 230 TOLUCA 230 47 26061 230 26078 NRTHRDGE TOLUCA 46 26086 230 26078 2 HSKLLCYN TARZANA RIVER 45 26135 230 230 26093 26063 SYLMARLA 44 230 26094 OLYMPCLD 230 SYLMARLA 43 26087 26094 SYLMARLA 42 26094 230 STJOHN 41 26068 SCATERGD 40 26066 39 38 CIRCUIT IMPACTED ELEMENT

2011lw11-lml.sav BASECASE

2011lw15-lml-r.sav CONT. NO. 20 19 18 17 16 15 14 13 12 11 10 9 8 7 6 5 4 3 2 1 69 A 3 61 RMRY181 1 138 GRAMERCY 1 138 GRAMERCY 1 138 26014 138 GRAMERC2 138 26014 138 2 GRAMERC1 26015 138 1 138 26014 TAP2 GRAMERCY 138 1 138 26096 TAP1 GRAMERCY 1 138 26014 26095 2 TAP2 138 GRAMERC2 138 26014 26096 1 138 TAP1 138 GRAMERC1 26015 26095 2 138 FAIRFAX 138 AIRPORT 26014 26076 1 138 FAIRFAX 138 AIRPORT 26089 26076 138 FAIRFAX 138 WLMNTN 2 26089 26076 FAIRFAX 138 WLMNTN 26073 1 138 26076 FAIRFAX 138 GRAMERCY 1 26073 138 26076 FAIRFAX 138 GRAMERCY 1 138 26014 26076 CNTURY 138 GRAMERC2 138 26014 26069 2 CNTURY 138 GRAMERC1 2 26015 26069 1 230 CNTURY 138 1 26014 230 26069 230 CNTURYLD CNTURY 138 2 230 26069 CNTURYLD 26072 CNTURY TOLUCA 230 1 230 26069 26072 CNTURY TOLUCA 26078 230 230 26069 230 VELASCO RINALDI 26078 26080 1 230 VELASCO 1 RINALDI 26061 26080 138 2 230 VALLEY 230 26061 26103 OLYMPCLD 1 230 230 VALLEY 26103 OLYMPC 26088 2 230 VALLEY TARZANA 138 26103 26087 1 230 VALLEY TARZANA 230 26093 26103 230 TARZANA 230 GLENDAL 2 26093 26092 TARZANA 230 GLENDAL 1 230 26113 26093 RINALDI 230 230 2 26113 26061 ATWATER RINALDI 230 1 230 26061 ATWATER 26081 RINALDI 230 230 1 HSKLLCYN 26061 26081 RINALDI 230 1 287 HSKLLCYN 26135 26061 GLENDAL 230 287 26135 26013 2 CNTURY2 GLENDAL 230 26013 1 500 CNTURY1 26071 CASTAIC 287 26010 500 ADELANTO 2 26070 CASTAIC 287 26010 ADELANTO 1 500 26003 VICTORVL 1 500 26104 500 26003 VICTORVL 500 VICTORVL 1 500 26104 VICTORVL VICTORVL 26105 500 26105 RINALDI 500 VICTORVL 26105 26105 500 26062 MCCULLGH RINALDI2 500 26048 MCCULLGH 26115 26048 500 VICTORVL 26105 ADELANTO 26003 CIRCUIT (N-2) CONTINGENCY

IMPACTED ELEMENT

2011lw11-lml.sav BASECASE

2011lw15-lml-r.sav LADWP’s 2010 Ten-Year Transmission Assessment

Appendix I. Transient and Post-Transient Stability Results

I November 1, 2010

2010 Ten Year Plan Transient & Post Transient Results 2011 Heavy Summer

Possible Violations Post-Transient CONT. NO. OUTAGE STABLE MORC1 MORC2 FREQ DIP ΔV>5% ΔV>10%

(N-1) CONTINGENCY

1 Adelanto-Rinaldi 500kV line Yes None None None None

2 Adelanto-Toluca 500kV line Yes None None None None

3 Adelanto-Victorville 500kV line Yes None None None None

4 Lugo-Victorville 500kV Line Yes None None None None

5 Victorville-Rinaldi 500kV Line Yes None None None None

6 Mccullgh-Victorville 500kV Line Yes None None None None

7 Mead-Victorville 287kV Line Yes None None None None

8 Cottonwd-Barren Ridge 230 kV with Remedial Action Scheme (RAS) Yes None None None None

9 Rinaldi-Barren Ridge 230 kV Line Yes None None None None

(N-2) CONTINGENCY

10 IPP DC Bipole Yes None None None None

11 Palo Verde-g2-OL-MA-RAS Yes None None None None

12 Adelanto-Rinaldi and Victorville-Rinaldi 500 kV Lines Yes None None None None

13 McCullgh-Victorville 500 kV Lines 1 & 2 Yes None None None None

14 Rinaldi-Tarzana 230 kV Lines 1 & 2 Yes None None None None

15 Rinaldi-Glendale 230 kV Lines 1 & 2 Yes None None None None

16 Rinaldi-Valley 230 kV Lines 1 & 2 Yes None None None None

17 Toluca- Valley 230 kV Lines 1 & 2 Yes None None None None

18 Glendale-Atwater 230 kV Lines 1 & 2 Yes None None None None

19 Tarzana-Olympic 230 kV and 138 kV Lines Yes None None None None

20 Velasco-Century 230 kV Lines 1 & 2 Yes None None None None

21 Century-Wilmington 138 kV Lines 1 & 2 Yes None None None None

22 Gramercy-Fairfax 138 kV Lines 1& 2 Yes None None None None

23 Century-Gramercy dlo Yes None None None None

24 Gramercy Tap 1 & Tap 2 138 kV Lines Yes None None None None

25 Airport-Fairfax 138 kV Lines 1 & 2 Yes None None None None

MULTIPLE CONTINGENCIES

26 Toluca-Hollywood Lines 1,2 & 3 Yes None None None None

27 Rinaldi-Tarzana Lines 1 & 2 and Northridge-Tarzana Line 1 No Yes Yes Yes Yes

28 Rinaldi-Tarzana Lines 1 & 2 and Northridge-Tarzana Line 1 with RAS Yes None None None None 2010 Ten Year Plan Transient & Post Transient Results 2015 Heavy Summer