FEASIBILITY STUDY REPORT

Transcription

1 FEASIBILITY STUDY REPORT HL20S PV Prepared for: El Paso Electric Company Prepared by: Engineers, LLC 249 Eastern Avenue Augusta, ME (207) July 2012

2 FOREWORD This report was prepared for the project Interconnection Customer, by System Planning at El Paso Electric Company. Any correspondence concerning this document, including technical and commercial questions should be referred to: Dennis Malone Director System Planning Department El Paso Electric Company 100 North Stanton El Paso, Texas Phone: (915) Fax: (915) Or David Gutierrez Principal Engineer El Paso Electric Company 100 North Stanton El Paso, Texas Phone: (915) Fax: (915)

3 Table of Contents EXECUTIVE SUMMARY INTRODUCTION PERFORMANCE CRITERIA STUDY METHODOLOGY ASSUMPTIONS PROCEDURE Development and Description of Cases HL20S Generation Modeling CONTINGENCY LIST STEADY STATE POWER FLOW ANALYSIS PRE-PROJECT POWER FLOW EVALUATION Pre-Project N-0 Flow Violations Pre-Project N-1 Flow Violations POST-PROJECT POWER FLOW EVALUATION Post-Project N-0 Power Flow Analysis Post-Project N-1 Power Flow Analysis POWER FLOW ANALYSIS CONCLUSION STEADY STATE VOLTAGE ANALYSIS POWER FACTOR ANALYSIS SHORT CIRCUIT ANALYSIS SHORT CIRCUIT ANALYSIS MODELING SHORT CIRCUIT ANALYSIS PROCEDURE SHORT CIRCUIT ANALYSIS RESULTS SHORT CIRCUIT ANALYSIS CONCLUSIONS COST ESTIMATES DISCLAIMER CONCLUSIONS... 23

4 List of Figures Figure 2-1: HL20S Interconnection One Line Diagram... 6 Figure 5-1: 2015 peak case POI one line diagram for N-0 condition Figure 5-2: 2015 peak case POI one line diagram for N-1 condition Figure 5-3: 2015 peak case POI one line diagram for N-1 condition Figure 7-1: HL20S POI and HL20S 115 kv Station One line List of Tables Table 1-1: EPE and New Mexico Performance Criteria... 4 Table 3-1: Pre-Project 2015 N-1 Flow Violations... 7 Table 3-2: 2015 peak N-1 post-project power flow analysis results... 8 Table 6-1: Generator Short Circuit Modeling Data Table 6-2: 2014 HL20S Short Circuit Summary Results Table 7-1: EPE Interconnection Facilities Costs for HL20S POI Table 7-2: Network System Upgrades Costs for HL20S 115 kv Substation Appendices Appendix A Statement of Work Appendix B Power Flow Contingency List Appendix C Project Schedule

5 Executive Summary The study objective was to determine the impact that the proposed HL20S project would have on the El Paso Electric Company (EPE) and Southern New Mexico transmission systems. HL20S is a 20 MW PV plant with the Point of Interconnection ¼ mile south of Holloman 115 kv Station on the Holloman - Largo - Amrad 115 kv line. The proposed Commercial Operation date is December 31, Two interconnection projects in the EPE study queue have executed Interconnection Agreements (IA) with EPE and were included in this Study. The two (2) interconnection projects included in this Feasibility Study (FS) are: 1. DS92S: 92 MW solar powered project interconnected on the Diablo-Santa Teresa 115 kv line 5.7 miles from Diablo 115 kv station. 2. AA100W: 100 MW wind powered project interconnected on the Amrad-Artesia 345 kv, 65 miles east of Amrad 345 kv substation. The generation from the DS92S project was modeled as being delivered to all entities in the Western Electricity Coordinating Council (WECC), the generation from the AA100W and HL20S projects was modeled as being delivered to all WECC entities except EPE and New Mexico. This Study Area was limited to the WECC Area 11 - EPE (TX) and Area 10 - PNM (NM). Steady State Results The power flow analysis was conducted for 2014 off peak and 2015 peak load conditions. The Arroyo Phase Shifter was modeled as being out of service in 2014, and in service in The power flow analysis results showed that the addition of 20 MW of the HL20S project will not have an adverse impact on the EPE and Southern New Mexico transmission systems. The only required Network Upgrades are those for the interconnection of the HL20S project. Short Circuit Results A short circuit analysis was performed to determine if the addition of the HL20S project to the EPE transmission system would not cause any of EPE s transmission system s existing substation circuit breakers to exceed their interrupting capability ratings. 1

6 Cost Estimates Good faith cost estimates are presented. The cost estimates are in 2012 dollars (no escalation applied) and are based upon typical construction costs for previously performed similar construction. These costs include all estimated applicable labor and overheads associated with the engineering, design, and construction of these new EPE facilities. These estimates did not include the Generator Interconnection Costs 1 for any other Interconnection Customer owned equipment or associated design and engineering except for the Point of Interconnection (POI) facilities. The estimated total cost for the required upgrades is $4.12 Million. This breaks down to $0.14 Million for the EPE Interconnection Costs 2 at the POI and $3.98 Million for Network Upgrade Costs 3. Generator Interconnection Costs have not been estimated as part of this study. The estimated time frame for Engineering, Procurement, and Construction of Network Upgrades is approximately 24 months upon notice to proceed with construction from the Interconnection Customers. Conclusion The system impact study shows that the proposed HL20S project with proposed Network Upgrades in place will NOT have an adverse impact on the EPE and Southern New Mexico transmission systems. 1 Generator Interconnection Costs: cost of facilities paid for by Interconnection Customer and owned and operated by the Interconnection Customer from the generator facilities to the Change of Ownership Point, which is typically on the first dead-end at the Point of Interconnection substation. Not subject to transmission credits. 2 EPE Interconnection Costs: cost of facilities paid for by Interconnection Customer but owned and operated by EPE from the Change of Ownership Point to the Point of Interconnection. Not subject to transmission credits. 3 Network Upgrades Costs: cost of facilities from the Point of Interconnection outward, paid for by the interconnector but owned and operated by EPE. Subject to transmission credits 2

7 1. Introduction The Interconnection Customer proposed interconnection of 20 MW of generation to the EPE 115 kv transmission system. EPE requires that a FS be performed for generation facilities desiring to connect to the El Paso Electric Transmission System. The proposed Commercial Operation dates for the HL20S project is as December 31, Performance Criteria The Study was performed according to Western Electricity Coordinating Council (WECC), North American Electric Reliability Corporation (NERC), and EPE standards. The EPE local reliability standards can be found in Section 4 of EPE s FERC Form No The steady state analysis was performed by using the GE PSLF Version 18 program. Transformer tap and phase-shifting transformer angle movement, as well as static VAR device switching, were allowed for the steady state pre-contingency analysis. All regulating equipment such as transformer controls and switched shunts were fixed at pre-contingency positions when the contingency analysis was performed. All facility loadings, as well as voltages 69 kv and greater, were monitored within the El Paso, New Mexico and Arizona control areas. Pre-contingency flows on lines and transformers were required to remain at or below the normal rating, while post-contingency flows on lines and transformers were required to remain at or below the emergency rating. Flows above 100% of an element s rating, either pre- or post-contingency, were considered violations. Post-project voltage criteria violations that either exacerbate or improve an existing pre-project violation were not considered an adverse impact to the system. The performance criteria utilized in qualifying violations in the study area are shown in Table

8 Table 1-1: EPE and New Mexico Performance Criteria Area Conditions Loading Limits EPEC PNM Tri- State Normal Contingency Normal ALIS Contingency N-1 Contingency N-2 Normal ALIS Contingency N-1 Contingency N-2 Normal Rating Emergency Rating Voltage (p.u.) Voltage Drop * Taiban Mesa and Guadalupe 345 kv bus voltage must be between 0.95 and 1.10 p.u. under normal and contingency conditions. ** For PNM buses in southern New Mexico the allowable N-1 voltage drop is 7%. *** Provided operator action can be utilized to adjust voltages back down to 1.05 Application kV and above Artesia 345 kv Arroyo 345 kv PST source side Alamo, Sierra Blanca and Van Horn 69kV % 60 kv to 115 kv % Artesia 345kV % Arroyo 345kV PST source side Alamo, Sierra Blanca and Van Horn 69kV % Hidalgo, Luna, or other 345 kv buses Normal Rating kv and above* Emergency Rating Emergency Rating *** 6 %** 46 kv to 115 kv *** 6 %** 230 kv and above *** 10 % 46 kv and above* Normal Rating All buses Emergency Rating Emergency Rating % % % Tri-State buses in the PNM Service Area (list provided by Tri-State) Tri-State buses in southern and northeastern New Mexico (list provided by Tri-State) All buses 4

9 2. Study Methodology 2.1 Assumptions The following assumptions are consistent for all study scenarios unless otherwise noted. This study assumed that all system expansion projects as planned by area utilities by the year under analysis are completed, and that any system improvements required by the interconnections senior to the HL20S project are implemented. This study did not analyze any transmission service from the interconnection point to any specific point on the grid for the interconnections senior to the HL20S project. 2.2 Procedure The analyses in this study included only Steady State Analysis as stated in the Statement of Work in Appendix A. A description of the procedures used to complete the analyses is presented below Development and Description of Cases 100% peak summer load 2014 and 2015 WECC power flow cases were used and modified, as listed below, to establish 2014 off peak and 2015 peak benchmark cases without the proposed HL20S project. The HL20S generation was modeled as being dispatched to all WECC entities except EPE and New Mexico. When in service, the Arroyo Phase Shifter was modeled to provide MW N-S flow during the peak load conditions. At all times, the Eddy County DC tie operational flow was set at 0 MW. 5

10 Benchmark Cases 2014 and 2015: The 2014 and 2015 benchmark cases included the following existing third party generation: (i) (ii) 92 MW of generation (DS92S) interconnected on the Diablo-Santa Teresa 115 kv line 5.7 miles from Diablo 115 kv station and scheduled to the WECC grid. 100 MW of generation (AA100W) interconnected on the Amrad- Artesia 345 kv, 65 miles east of Amrad 345 kv substation, and scheduled to all WECC entities except EPE and New Mexico and 2015 post-project cases were created from the benchmark cases described above HL20S Generation Modeling The HL20S generation was modeled to generate 20 MW at 34.5 kv (with power factor capability of +/- 0.99), stepped up to the 115 kv transmission voltage, and interconnect to the EPE transmission system about ¼ mile south of Holloman 115 kv Station on the Holloman - Largo 115 kv line, as illustrated in Figure 2-1. Figure 2-1: HL20S Interconnection One Line Diagram 0.25 miles miles Holloman G 20 MW HL20S Largo 2.3 Contingency List All outages (69 kv and above with EPE) were modeled in the subsystem files. The list of contingencies used in this study can be found in Appendix B. Based on engineering judgment, these contingencies were selected to represent a good cross section of potential contingencies that would stress the EPE and PNM s southern New Mexico systems. This study was only performed for N-0 and N-1 conditions. 6

11 3. Steady State Power Flow Analysis 3.1 Pre-Project Power Flow Evaluation Peak and off peak base cases were evaluated for overloaded facilities under both normal and contingency conditions prior to the addition of the HL20S project Pre-Project N-0 Flow Violations Power flow study analysis results showed no overloaded transmission facilities were present in the El Paso Electric (EPE) and Public Service Company of New Mexico (PNM) areas under non-contingency system conditions prior to the addition of the HL20S project Pre-Project N-1 Flow Violations Power flow contingency analysis results show that one overload exists in the EPE area prior to the addition of the HL20S project, as shown in Table 3-1. Table 3-1: Pre-Project 2015 N-1 Flow Violations From Bus kv To Bus kv Ckt ID Area Rating (MVA) JORNADA 115 ARROYO Contingency NEWMAN-AFTON 345 kv Peak Condition % of Emergency Rating Post-Project Power Flow Evaluation This section provides a high-level understanding of the HL20S project impact on the loading of transmission lines and transformers in the Study Area. The analysis was performed under both normal and contingency conditions Post-Project N-0 Power Flow Analysis Power flow study results for the EPE and PNM areas showed that the addition of the HL20S project to the existing system would not cause any power flow violations under non-contingency system conditions Post-Project N-1 Power Flow Analysis Power flow study results for the EPE and PNM areas showed that the addition the HL20S project to the existing system would not have an adverse impact on the El Paso and New Mexico transmission systems in both scenarios, as shown in Table

12 From Bus kv To Bus kv Table 3-2: 2015 peak N-1 post-project power flow analysis results Ckt ID Area Rating (MVA) Contingency W/O Project % of Rating With Project % of Rating Delta % of Rating JORNADA 115 ARROYO NEWMAN-AFTON 345 kv Power Flow Analysis Conclusion The analysis showed that the addition of the HL20S project to the system would not have an adverse impact on the EPE or New Mexico transmission systems. 8

13 4. Steady State Voltage Analysis Bus voltages within the Study Area were compared under both normal and contingency conditions, with and without the HL20S project in service. The Performance Criterion, shown in Table 1-1, was considered when analyzing bus voltages for violations. The voltage analysis results showed that after the addition of the HL20S project the Study area transmission network voltages stayed within criteria limits or did not significantly change from the pre-project voltage levels. 9

14 5. Power Factor Analysis Power factor at the POI was observed under both normal and contingency conditions. The HL20S project was required to be capable of maintaining +/ power factor at the POI. The power factor analysis results showed that the HL20S project will be capable of maintaining +/ power factor at the POI. The one line diagrams demonstrating the MW/VAR flow at the POI are shown in in Figures 5-1 through

15 Figure 5-1: 2015 peak case POI one line diagram for N-0 condition 11

16 Figure 5-2: 2015 peak case POI one line diagram for N-1 condition Loss of POI Holloman 115 kv line 12

17 Figure 5-3: 2015 peak case POI one line diagram for N-1 condition Loss of POI Largo 115 kv line 13

18 6. Short Circuit Analysis A short circuit analysis was performed to determine if the addition of the HL20S project to the EPE transmission system would cause any of EPE s transmission system s existing substation circuit breakers to exceed their interrupting capability ratings. 6.1 Short Circuit Analysis Modeling Two cases were developed to perform this analysis showing the integration of the HL20S project. As mentioned, any planned or proposed third party generation listed in EPE s study queue ahead of the HL20S project were also modeled in the two cases. The generator data used in the study is shown in Table 5-1. This analysis evaluated the impact of the HL20S project by comparing the pre- and post- HL20S project fault current levels. Table 6-1: Generator Short Circuit Modeling Data Project Total Output (MW) AA100W 100 DS92S 92 East El Paso Cluster Generation Unit 1 Unit ID Pmax (MW) Interconnection Customer Qmax (MVAR) Qmin (MVAR) Z subtransient Rating (MVA) GSU Voltage (kv) P j /34.5 P j G j /13.8 G j / G j /13.8 HL20S 20 G /7.2/ 13.8 * - Denotes that subtransient impedance values were not available so default values found in ASPEN were used. Z subtransient j j j j j0.9 14

19 6.2 Short Circuit Analysis Procedure The initial short circuit analysis was performed with all other third-party generation projects ahead of the HL20S project in the study queue in service and the HL20S project out of service. This identified the base case fault duties of the circuit breakers. The short circuit analysis was performed again with HL20S project in service on a year to year basis. Three phase, two phase, and single-phase line-to-ground faults were simulated at selected buses in the EPE system. ASPEN One Liner and Batch Short Circuit Module were used to perform the short circuit analysis. The short circuit fault analyses were performed with the following settings: Transmission line G+jB ignored Shunts with positive sequence impedance ignored Transformer line shunts ignored The pre-fault voltage was calculated using a Flat bus voltage of 1.05 p.u. The difference between the fault current values in the two cases demonstrates the post-project fault contribution of the HL20S project to the pre-project fault current levels in the EPE system. The resulting fault currents in the post-project scenario were compared to the smallest breaker interruption ratings at each of the substations to determine whether or not the HL20S project caused any breaker to be over-duty. 6.3 Short Circuit Analysis Results The short circuit analysis results for the EPE monitored buses are shown below in Table

20 Table 6-2: 2014 HL20S Short Circuit Summary Results Bus Fault On: Lowest Breaker Rating (ka) AMRAD 115 kv 40 ALMOPGT 115 kv (Tri-State Bus) HL20S_TAP 115 kv 40 HL20S 34.5 kv 40 HOLLOMAN 115 kv 31 LARGO 115 kv 25 Fault Pre Current (Amps) Pre X/R Post Current (Amps) Post X/R Delta (Amperes) 3LG LG LG LG LG LG LG N/A N/A LG N/A N/A LG N/A N/A LG N/A N/A LG N/A N/A LG N/A N/A LG LG LG LG LG LG

21 6.4 Short Circuit Analysis Conclusions The results of this short circuit study show that the addition of the HL20S project will not significantly increase the fault currents. Therefore, the HL20S project will not have an adverse impact on the breaker interrupting capability of the breakers on the EPE transmission system. East Cluster System Impact Study 17

22 7. Cost Estimates Good faith cost estimates have been determined. The cost estimates are in 2012 dollars (no escalation applied) and are based upon typical construction costs for previously performed similar construction. These estimated costs include all applicable labor and overheads associated with the engineering, design, and construction of these new facilities. These estimates did not include the cost for any other Interconnection Customer owned equipment or associated design and engineering except for those located at the POI. The estimated total cost for the required upgrades is $4.12 Million. This breaks down to $0.14 Million for the EPE Interconnection Cost 4 and $3.98 Million for Network Upgrades Cost 5. The Generator Interconnection Cost 6 estimates are not included. The estimated time frame for Engineering, Procurement, and Construction of Network Upgrades is approximately 24 months upon notice to proceed with construction from the Interconnection Customers. The estimated time frame for Engineering, Procurement, and Construction is 24 months for new POI Substations or expansion at existing substations. Appendix C shows the project schedule. Any sequencing in project schedule will delay the overall completion date. A time frame for permitting the project assumed best case scenario. Should the NEPA process be delayed on any section, this will also delay the final completion date. Tables and one-line diagrams in this section of the report show the HL20S interconnection project, its POI, associated EPE Interconnection facility, Network Upgrades, and estimated costs. 4 EPE Interconnection Cost: Cost of faculties paid for by interconnector but owned and operated by EPE from the Change of Ownership Point to the Point of Interconnection. Not subject to transmission credits. 5 Network Upgrades Cost: Cost of facilities from the Point of Interconnection outward, paid for by the interconnector but owned and operated by EPE. Subject to transmission credits. 6 Generator Interconnection Cost: Cost of facilities paid for by interconnector and owned and operated by the interconnector from the generator faculties to the Change of Ownership Point, which is typically at the Point of Interconnection substation first dead-end. Not subject to transmission credits. 18

23 Table 7-1: EPE Interconnection Facilities Costs for HL20S POI Element Description Cost Est. Millions HL20S POI EPE Interconnection Facilities located at MO420G POI in phase 1 total of 105 MW (2014): $0.14 One 115 kv 2000 A disconnect switch w/ grounding One set of CCVT s and Structures Three Lightning arresters and Structures One Set of 115 kv 3-Phase Metering Units and structures Relaying, communication, and testing Estimated Time Frame for Engineering, Procurement, Construction, and Commissioning 24 Months 19

24 Figure 7-1: HL20S POI and HL20S 115 kv Station One line HL20S Substation HL20S 20 MW 115 kv M 115 kv To Holloman 0.25 miles 14.6 miles To Largo Existing Holloman-Largo 115 kv line Color Code Network Upgrades Existing Facilities EPE Interconnection Facilities Located at POI Interconnection Customer Equipment 20

25 Table 7-2: Network System Upgrades Costs for HL20S 115 kv Substation Element Description Cost Est. Millions HL20S 115 kv Substation Build a new 115 kv three breaker in a Breaker and a Half Scheme Substation. The new equipment required includes: $3.98 Three 115 kv 3000 A circuit breakers Six 115 kv 2000 A disconnect switches Two 115 kv 2000 A line disconnect switches w/ grounding Six sets of CCVT s and Structures Six Lightning arresters and Structures Three sets of Transmission Line Dead-end Assemblies for Substation Dead-end One lot 115 kv bus, insulators, and structural supports One lot Transmission line relaying, SCADA, communication, and testing One lot ground grid, misc. grounding, concrete, conduit, cable trench, and fencing Relay Setting Changes at Amrad, Largo, and Holloman Estimated Time Frame for Engineering, Procurement, Construction, and Commissioning 24 Months 21

26 General Cost Assumptions 1. The cost estimates provided are good faith scoping estimates. 2. Estimates do not include land or permitting. 3. Interconnection Customer to secure POI site and transfer ownership to EPE. 4. Permitting time frames are included. Actual time frames will vary due to local and Federal requirements. 5. Estimates are in 2012 Dollars. 6. Where applicable, the Interconnection Customers are responsible for funding and construction of all transmission facilities from the proposed generator substation to the Points of Interconnection. 7. The Interconnection Customer will supply enough transmission conductor from their last structure outside the POI substation for Termination into the POI substation bus. 8. Interconnection Customers are responsible for Engineering, Procurement, and Construction for all and any FACTs and other transmission compensation devices at their generation site or along their long interconnecting transmission lines to just outside the POI sites. 22

27 8. Disclaimer If any of the project data provided by Interconnection Customer and used in this study varies significantly from the actual data once the HL20S project equipment is installed, the results from this study will need to be verified with the actual data at the Project Interconnection Customer's expense. Additionally, any change in the generation in EPE s Interconnection Queue that is senior to the HL20S project may require a reevaluation of this Study. 9. Conclusions This HL20S project Feasibility Study, consisting of a Steady State and Short Circuit Analysis, for a net 20 MW of generation interconnecting on the EPE transmission systems, has demonstrated that the HL20S project will NOT have an adverse impact on the EPE and Southern New Mexico transmission systems. The estimated cost for integrating the HL20S project onto the EPE and Southern New Mexico transmission systems is $4.12 Million. The good faith estimate of the time frame to Engineer, Procure, and Construct all facilities is 24 months. 23

28 Appendix A Statement of Work Appendix A

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33 Appendix B Power Flow Contingency List Appendix B

34 CONTINGENCY LIST Transmission Lines 1. ALA_ to ORO_GRAN Circuit 1 2. AMRAD to LARGO Circuit 1 3. AMRAD to ARTESIA Circuit 1 4. ANTHONY to BORDER Circuit 1 5. ANTHONY to MONTOYA Circuit 1 6. ANTHONY to NEWMAN Circuit 1 7. ANTHONY to SALOPEK Circuit 1 8. ASCARATE to COPPER Circuit 1 9. ASCARATE to RIVERENA Circuit AUSTIN_N to MARLOW Circuit AUSTIN_N to MARLOW Circuit BUTERFLD to FT._BLIS Circuit CALIENTE to LANE # Circuit CALIENTE to VISTA # Circuit CALIENTE to AMRAD Circuit CHAPARAL to ORO_GRAN Circuit COPPER to LANE # Circuit COPPER to PENDALE Circuit COYOTE to CALIENTE Circuit COYOTE to RGC_DC Circuit CROMO to RIO_GRAN Circuit DIABLO to RIO_GRAN Circuit DIABLO to RIO_GRAN Circuit DIABLO to INSURG Circuit DYER to AUSTIN_N Circuit DYER to SHEARMAN Circuit 27. BIGGS to GR Circuit FT._BLIS to AUSTIN_N Circuit GR to VISTA # Circuit HATCH to JORNADA Circuit HOLLOMAN to HL20S_TAP Circuit HL20S_TAP to LARGO Circuit HORIZON to MONTWOOD Circuit JORNADA to ARROYO Circuit LANE # to WRANGLER Circuit LAS_CRUC to ARROYO Circuit LAS_CRUC to SALOPEK Circuit LUNA to DIABLO Circuit LUNA to HIDALGO Circuit LUNA to AFTON Circuit MAR to LARGO Circuit MARLOW to TROWBRIG Circuit MESA # to AUSTIN_N Circuit MESA # to RIO_GRAN Circuit MILAGRO to NEWMAN Circuit MILAGRO to NEWMAN Circuit MILAGRO to LEO Circuit NEWMAN to BUTERFLD Circuit NEWMAN to CHAPARAL Circuit NEWMAN to CROMO Circuit NEWMAN to SHEARMAN Circuit NEWMAN to ARROYO Circuit NEWMAN to AFTON Circuit NE to NEWMAN Circuit PELICANO to HORIZON Circuit PELICANO to MONTWOOD Circuit RIPLEY to THORN Circuit MONTWOOD to CALIENTE Circuit MONTWOOD to COYOTE Circuit ORO_GRAN to AMRAD Circuit RIO_GRAN to RIPLEY Circuit SALOPEK to ARROYO Circuit SANTA_T to DIABLO Circuit SANTA_T to MONTOYA Circuit SANTA_T to NW Circuit SCOTSDALE to VISTA # Circuit PENDALE to LANE # Circuit SOL to LANE # Circuit SOL to VISTA # Circuit SPARKS to HORIZON Circuit SUNSET_N to RIO_GRAN Circuit TALAVERA to ANTHONY Circuit THORN to MONTOYA Circuit NW to DIABLO Circuit WHITE_SA to ALA_ Circuit WRANGLER to SPARKS Circuit WRANGLER to SPARKS Circuit AEP to AZTECAS Circuit AEP to REA Circuit CHAMIZAL to COLEGIO Circuit CHAMIZAL to RIVERENA Circuit CHAVENA to AZTECAS Circuit COLEGIO to CHAVENA Circuit COLEGIO to FTS Circuit FTS to TEC Circuit INSURG to CHAMIZAL Circuit INSURG to CHAVENA Circuit REA to AZTECAS Circuit REA to INSURG Circuit CALIENTE to PICANTE Circuit NEWMAN to PIPELINE Circuit LEO to DYER Circuit 1

35 CONTINGENCY LIST Transmission Lines 93. PICANTE to NEWMAN Circuit PICANTE to BIGGS Circuit PICANTE to GR Circuit ANTHONY to NW Circuit ARROYO to COX Circuit APOLLOSS to APOLLO Circuit HATCH to LEASBURG Circuit LE to APOLLOSS Circuit LE to JORNADA Circuit SUNSET_N to DURAZNO Circuit DURAZNO to ASCARATE Circuit NW to MONTOYA Circuit COX to APOLLOSS Circuit APOLLO to JORNADA Circuit LEASBURG to JORNADA Circuit NE to CROMO Circuit ANTHONY to COX Circuit COX to TALAVERA Circuit ASCARATE to COPPER Circuit JORNADA to AIRPOR Circuit AFTON to AIRPOR Circuit SOL to VISTA # Circuit NEWMAN to PICANTE Circuit PIPELINE to BIGGS Circuit HIDALGO to GREENLEE Circuit LUNA to LEF Circuit DONA_ANA to LAS_CRUC Circuit AMRAD to ALAMOGCP Circuit HOLLOMAN to ALAMOGCP Circuit AIRPOR_T to AIRPOR Circuit CABALLOT to UVAS Circuit UVAS to MIMBRES Circuit ORO_GRAN to JARILLA Circuit WSTAP to WHITE_SA Circuit ASCARATE to TROWBRIG Circuit EPE to COYOTE Circuit EPE to MONTWOOD Circuit CALIENTE to EPE Circuit CALIENTE to EPE Circuit CALIENTE to VISTA # Circuit CALIENTE to SE Circuit CALIENTE to SE Circuit CALIENTE to PICANTE Circuit MACHO_SPRNGS to LUNA Circuit MACHO_SPRNGS345.0 to SPRINGR Circuit LE to ARROYO Circuit SE to LANE # Circuit Line SE to LANE # Circuit RIPLEY to THORN Circuit PICANTE to AMRAD Circuit WESTMESA to ARR PS Circuit NW to ROADRUNRTAP Circuit ROADRUNRTAP to DIABLO Circuit ROADRUNRTAP to ROADRUNER Circuit ART320W to ARTESIA Circuit Line CALIENTE to CORONA Circuit AMRAD to AA100W Circuit AA100W to ARTESIA Circuit CORONA to AMRAD Circuit CORONA to AMRAD Circuit CORONA to PICANTE Circuit CORONA to NEWMAN Circuit WESTMESA to WA300POI Circuit WA300POI to ARR PS Circuit WA300POI to WA300_C Circuit WA300_C to WA300_C Circuit IRONSTREET-PRAGER 46 kv (PI) 160. IRONSTREET-PERSON 46 kv (PH) 161. PERSON-TOME 46 kv (PB) 162. PERSON-TOME 46 kv (BN) 163. PERSON-PY47 46 kv (EL) 164. POWERPLANT-ZIA 46 kv (ZS) 165. POWERPLANT-ZIA 46 kv (ZM) 166. PRAGER-KELEHER 46 kv (PY) 167. SANDIA-IDEAL 46 kv (ID) 168. ALGODONE-PACHMANN 115 kv (AL) 169. ALGODONE-NORTON/ZIA1 115 kv (ANZ) 170. ALGODONE-AW CAP 115 kv 171. AW CAP-WILLARD 115 kv 172. AMBROSIA-BLUEWATER 115 (MB) 173. AMBROSIA-GULF PGT 115 kv (MA) 174. AMBROSIA-YAHTAHEY 115 kv (AY) 175. BA-ZIA 115 kv (RS) 176. BA-REEVES kv (AB) 177. BA-REEVES kv (RB) 178. BA-STA 115 kv (RL) 179. BA-PACHMANN 115 kv (CB) 180. BELEN-WILLARD 115 kv (WL) 181. BELEN-TOME 115 kv (TJ) 182. BELEN-WEST MESA kv (WB) 183. BELEN-SOCORRO 115 kv (SOC) 184. CORRALES-IRVING 115 kv (IC) 185. CORRALES-PACHMANN 115 kv (CY)

36 CONTINGENCY LIST Transmission Lines 186. EMBUDO-SANDIA kv (SE) 187. EMBUDO-NORTH(TL)/EB86 (EB) 115 kv 188. EMBUDO-REEVES kv (RE) 189. EMBUDO-REEVES kv (ER) 190. IRVING-WEST MESA kv (WR) 191. IRVING-REEVES kv (IR) 192. KIRTLAND-PERSON 115 kv (PS) 193. KIRTLAND-SANDIA kv (KS) 194. NORTH-PRAGER 115 kv (PN) 195. NORTH-MISSION 115 kv (MN) 196. NORTH-REEVES kv (RN) 197. NORTON-ETA 115 kv (NL) 198. NORTON-ZIA kv (NS) 199. NORTON-HERNANDEZ 115 kv (NH) 200. OJO-HERNANDEZ 115 kv (HO) 201. PACHMANN-WEST MESA kv (CE) 202. PERSON-SP83/HW kv (SP) 203. PERSON-WEST MESA kv (PM) 204. PERSON-TOME 115 kv (AT) 205. PERSON-WEST MESA kv (PW) 206. PRAGER-WEST MESA kv (WP) 207. REEVES 2-MISSION 115 kv (NR) 208. REEVES 2-WEST MESA kv (NW) 209. SANDIA 1-HW43/EB kv (EB) 210. SANDIA 2-SP kv (SP) 211. VALENCIA-ZIA 115 kv (SL) 212. VALENCIA-STORRIE LAKE 115 kv (VS) 213. WEST MESA 115 kv BUS TIE WEST MESA 1-GULF PGT 115 kv (KM) 215. WEST MESA 115 kv BUS TIE WEST MESA 3-BLUEWATER 115 kv (BW) 217. YAHTAHEY-PEGS 115 kv (GYTH&WTG) 218. ZIA 115 kv BUS TIE 219. ETA-STA 115 kv (SA) 220. ETA-WTA 115 kv (TE) 221. ETA-TA kv (LA) 222. STA-WTA 115 kv (SW) 223. TA3-TA kv (SW) 224. TA3-WTA 115 kv (WT) 225. SPRINGER-TAOS 115 kv 226. SPRINGER-STORRIE LAKE 115 kv 227. TAOS-HERNANDEZ 115 kv 228. GLADSTONE-CLAPHAM 115 kv 229. RIO PUERCO - CORRALES BLUFFS (RR) 115 kv 230. AMBROSIA-WEST MESA 230 kv (WA) 231. AMBROSIA-PEGS 230 kv 232. AMBROSIA-BISTI 230 kv (BI) 233. BA-RIO PUERCO 345 kv 234. WEST MESA-RIO PUERCO 345 kv 235. BA-GAUDALUPE 345 kv (BB) 236. B-A-RIO PUERCO 345 kv 237. SAN JUAN-RIO PUERCO 345 kv 238. BA-NORTON 345 kv (NB) 239. BISTI-PILLAR 230 kv (BP) 240. FOUR CORNERS-WEST MESA 345 kv (FW) 241. GALLEGOS-PILLAR 230 kv (GC) 242. OJO-SAN JUAN 345 kv (OJ) 243. OJO-TAOS 345 kv (OT) 244. PILLAR-FOUR CORNERS 230 kv (AF) 245. SANDIA-WEST MESA 345 kv (WS) 246. SAN JUAN-SHIPROCK 345 kv (SR) 247. SAN JUAN-MCKINLEY 345 kv # SAN JUAN-MCKINLEY 345 kv # SAN JUAN-SANJN PS 345 kv (SH) 250. TAIBAN-BLACKWATER 345 kv (TB) 251. WALSENBURG - GLADSTON 230 kv 252. LORDSBURG-MD 69 kv 253. SILVER CITY-TURQUOISE 69 kv 254. SILVER CITY-MD 69 kv 255. ALMAMOGORDO-AMRAD 115 kv 256. ALAMOGORDO-DONA ANA 115 kv 257. ALAMOGORDO-HOLLOMAN 115 kv 258. AMRAD-LARGO/HOLLOMAN 115 kv 259. AMRAD-OROGRANDE 115 kv 260. HIDALGO-LORDSBURG 115 kv 261. HIDALGO-TURQUOISE 115 kv 262. LUNA-MIMBRES 115 kv 263. LUNA-MD 115 kv 264. MD-TURQUOISE 115 kv 265. MIMBRES-PICACHO 115 kv 266. MIMBRES-ELEPHANT BUTTE 115 kv 267. PICACHO-DONA ANA 115 kv 268. PICACHO-ELEPHANT BUTTE 115 kv 269. LUNA-LEF kv

37 270. AMRAD 345/115 kv Circuit ARROYO 345/115 kv Circuit ARROYO 345/115 kv Circuit CALIENTE 345/115 kv Circuit CALIENTE 345/115 kv Circuit DIABLO 345/115 kv Circuit DIABLO 345/115 kv Circuit DIABLO 345/115 kv Circuit NEWMAN 345/115 kv Circuit PICANTE 345/115 kv Circuit AFTON 345/115 kv Circuit HIDALGO 345/115 kv Circuit HIDALGO 345/115 kv Circuit LUNA 345/115 kv Circuit ZIA 115/46 kv TRANSFORMER # ZIA 115/46 kv TRANSFORMER # PERSON 115/46 kv TRANSFORMER 287. PRAGER 115/46 kv TRANSFORMER 288. SANDIA 115/46 kv TRANSFORMER # TOME 115/46 kv TRANSFORMER 290. ZIA 115/46 kv TRANSFORMER # ZIA 115/46 kv TRANSFORMER #1 & SPRINGER-GLADSTONE 115 kv 293. TAOS 345/115 kf TRANSFORMER # TAOS 345/115 kf TRANSFORMER # AMBROSIA 230/115 kv TRANSFORMER 296. BA 345/115 TRANSFORMER 297. OJO 345/115 kv TRANSFORMER 298. SANDIA 345/115 kv TRANSFORMER 299. WESTMESA 345/115 kv TRANSFORMER # WESTMESA 345/115 kv TRANSFORMER # WESTMESA 230/115 kv TRANSFORMER # WESTMESA 230/115 kv TRANSFORMER # NORTON 345/115 kv TRANSFORMER 304. MCKINLEY-YAHTAHEY 345/115 kv TRANSFORMER 305. SAN JUAN-HOGBACK 230/115 kv TRANSFORMER CONTINGENCY LIST Transformers

38 CONTINGENCY LIST Generators 306. AMRAD_A 13.2 Unit ID NEWMANG Unit ID NEWMN4S Unit ID NEWMN5G Unit ID NEWMN5G Unit ID NEWMN5S Unit ID NEWMN6G Unit ID NEWMN6G Unit ID NEWMN6S Unit ID RIOGD_G Unit ID RIOGD_G Unit ID RIOGD_G Unit ID ST_DIST_PV 24.9 Unit ID APT_DIST_PV 24.9 Unit ID CHAP_DIST_PV 13.8 Unit ID HAT_DIST_PV 24.9 Unit ID ART320W_G Unit ID ART320W_G Unit ID MOCC_G Unit ID MOCC_G Unit ID MOCC_G Unit ID MOCC_G Unit ID MO420G ALL UNITS"

39 Appendix C Project Schedule East Cluster System Impact Study Appendix C

40 ID Task Name Duration Start Finish 1 HL20S POI Switching Station 588 days Sun 7/1/12 Wed 10/1/14 3rd Quarter 2nd Quarter 1st Quarter 4th Quarter May Sep Jan May Sep Jan May Sep Jan 2 Preliiminary Engineering 4 wks Wed 8/1/12 Tue 8/28/12 3 Permitting 26 wks Wed 8/29/12 Tue 2/26/13 4 Engineering and Procurement 52 wks Wed 2/27/13 Tue 2/25/14 5 Construction 26 wks Wed 2/26/14 Tue 8/26/ Holloman-Largo-Amrad Relay Work 437 days Mon 1/28/13 Wed 10/1/14 8 Engineering and Procurement 16 wks Mon 7/15/13 Fri 11/1/13 9 Construction 5 wks Wed 7/23/14 Tue 8/26/14 Task Rolled Up Milestone Inactive Summary Task Progress Rolled Up Progress Manual Task Critical Task Split Duration-only Project: HL20S Project Schedule.mpp Date: Tue 7/17/12 Critical Task Progress Milestone External Tasks Project Summary Manual Summary Rollup Manual Summary Summary Group By Summary Start-only Rolled Up Task Inactive Task Finish-only Rolled Up Critical Task Inactive Milestone Deadline Page 1