FEASIBILITY STUDY REPORT - El Paso Electric

FEASIBILITY STUDY REPORT

HL20S PV

Prepared for:

El Paso Electric Company

Prepared by:

TRC Engineers, LLC

249 Eastern Avenue

Augusta, ME 04330

(207) 621-7000

July 2012

HL20S Feasibility Study TRC July 17, 2012

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 79901 Phone: (915) 543-5757 Fax: (915) 521-4763

Or

David Gutierrez Principal Engineer

El Paso Electric Company 100 North Stanton

El Paso, Texas 79901 Phone: (915) 543-4083 Fax: (915) 521-4763


Table of Contents

EXECUTIVE SUMMARY ......................................................................................................................................... 1

1. INTRODUCTION .............................................................................................................................................. 3

1.1 PERFORMANCE CRITERIA ................................................................................................................................. 3

2. STUDY METHODOLOGY .............................................................................................................................. 5

2.1 ASSUMPTIONS .................................................................................................................................................. 5 2.2 PROCEDURE ..................................................................................................................................................... 5

2.2.1 Development and Description of Cases ................................................................................................. 5 2.2.2 HL20S Generation Modeling ................................................................................................................. 6

2.3 CONTINGENCY LIST ......................................................................................................................................... 6

3. STEADY STATE POWER FLOW ANALYSIS ............................................................................................. 7

3.1 PRE-PROJECT POWER FLOW EVALUATION ....................................................................................................... 7 3.1.1 Pre-Project N-0 Flow Violations ........................................................................................................... 7 3.1.2 Pre-Project N-1 Flow Violations ........................................................................................................... 7

3.2 POST-PROJECT POWER FLOW EVALUATION ..................................................................................................... 7 3.2.1 Post-Project N-0 Power Flow Analysis ................................................................................................. 7 3.2.2 Post-Project N-1 Power Flow Analysis ................................................................................................. 7

3.3 POWER FLOW ANALYSIS CONCLUSION ............................................................................................................ 8

4. STEADY STATE VOLTAGE ANALYSIS ..................................................................................................... 9

5. POWER FACTOR ANALYSIS ...................................................................................................................... 10

6. SHORT CIRCUIT ANALYSIS ...................................................................................................................... 14

6.1 SHORT CIRCUIT ANALYSIS MODELING .......................................................................................................... 14 6.2 SHORT CIRCUIT ANALYSIS PROCEDURE ......................................................................................................... 15 6.3 SHORT CIRCUIT ANALYSIS RESULTS .............................................................................................................. 15 6.4 SHORT CIRCUIT ANALYSIS CONCLUSIONS ..................................................................................................... 17

7. COST ESTIMATES ........................................................................................................................................ 18

8. DISCLAIMER .................................................................................................................................................. 23

9. CONCLUSIONS .............................................................................................................................................. 23


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 ........................................... 11 Figure 5-2: 2015 peak case POI one line diagram for N-1 condition ........................................... 12 Figure 5-3: 2015 peak case POI one line diagram for N-1 condition ........................................... 13 Figure 7-1: HL20S POI and HL20S 115 kV Station One line ..................................................... 20

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 ...................................................................... 14 Table 6-2: 2014 HL20S Short Circuit Summary Results ............................................................. 16 Table 7-1: EPE Interconnection Facilities Costs for HL20S POI................................................. 19 Table 7-2: Network System Upgrades Costs for HL20S 115 kV Substation ............................... 21

Appendices

Appendix A HL20S Feasibility Study Statement of Work Appendix B Power Flow Contingency List Appendix C Project Schedule

HL20S Feasibility Study TRC July 17, 2012 1

HL20S Feasibility Study

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, 2014.

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 2015. 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.

HL20S Feasibility Study TRC July 17, 2012 2

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 Costs1 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 Costs2 at the POI and $3.98 Million for Network Upgrade Costs3. 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


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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, 2014.

1.1 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. 715. 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 1-1.


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Table 1-1: EPE and New Mexico Performance Criteria

* 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

Area Conditions Loading Limits

Voltage (p.u.) Voltage Drop

Application

EPEC

Normal Normal Rating

0.95 - 1.05 69kV and above 0.95 - 1.10 Artesia 345 kV 0.95 - 1.08 Arroyo 345 kV PST source side

0.90 - 1.05 Alamo, Sierra Blanca and Van Horn 69kV

Contingency Emergency Rating

0.925 - 1.05 7% 60 kV to 115 kV 0.95 - 1.07 7% Artesia 345kV 0.95 - 1.08 7% Arroyo 345kV PST source side

0.90 - 1.05 Alamo, Sierra Blanca and Van Horn 69kV

0.95 - 1.05 7% Hidalgo, Luna, or other 345 kV buses

PNM

Normal ALIS Normal Rating 0.95-1.05 46 kV and above*

Contingency N-1

Emergency Rating

0.925-1.08*** 6 %** 46 kV to 115 kV 0.90 – 1.08*** 6 %** 230 kV and above

Contingency N-2

Emergency Rating 0.90-1.08*** 10 % 46 kV and above*

Tri- State

Normal ALIS Normal Rating 0.95-1.05 All buses

Contingency N-1

Emergency Rating

0.90 – 1.10 6 %

Tri-State buses in the PNM Service Area (list provided by

Tri-State)

0.90-1.10 7 % Tri-State buses in southern and northeastern New Mexico (list

provided by Tri-State) Contingency

N-2 Emergency

Rating 0.90-1.10 10% All buses


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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 HL20S Feasibility Study Statement of Work in Appendix A. A description of the procedures used to complete the analyses is presented below.

2.2.1 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 10-20 MW N-S flow during the peak load conditions. At all times, the Eddy County DC tie operational flow was set at 0 MW.


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Benchmark Cases – 2014 and 2015: The 2014 and 2015 benchmark cases included the following existing third party generation: (i) 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.

(ii) 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.

2014 and 2015 post-project cases were created from the benchmark cases described above.

2.2.2 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

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.

Holloman

HL20S

14.65 miles

0.25 miles

20 MW

Largo

G


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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.

3.1.1 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.

3.1.2 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)

Contingency

Peak Condition

% of Emergency

Rating

JORNADA 115 ARROYO 115 1 11 115.7 NEWMAN-AFTON 345 kV 100.6

3.2 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.

3.2.1 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.

3.2.2 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 3-2.


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Table 3-2: 2015 peak N-1 post-project power flow analysis results

3.3 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.

From Bus kV To Bus kV Ckt ID Area

Rating (MVA)

Contingency

W/O Project % of Rating

With Project % of Rating

Delta % of Rating

JORNADA 115 ARROYO 115 1 11 115.7 NEWMAN-AFTON 345 kV 100.4 98.0 -2.4


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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.


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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 +/- 0.95 power factor at the POI.

The power factor analysis results showed that the HL20S project will be capable of maintaining +/- 0.95 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 5-3.


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


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


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


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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)

Interconnection Customer

GSU

Unit ID

Pmax (MW)

Qmax (MVAR)

Qmin (MVAR) Z subtransient Rating

(MVA) Voltage

(kV) Z

subtransient

AA100W 100 P1 60 20 -20 0 +j 0.02133 100

345/34.5

0.0037 +j0.1667

P2 40 13 -13 0 +j 0.02133

DS92S 92 G1 46 24 -17.2 0.00 +j 0.1200 56 115/13.8 0.0000

+j0.085

G2 46 24 -17.2 0.00 +j 0.1200 56 115/13.8 0.0000 +j0.085

East El Paso

Cluster Generation

Unit 1

105 G1 105 53.9 -53.9 0.005 +j0.162 168 115/13.8 0.0021 +j0.1000

HL20S 20 G1 20 0 0 9999 20 115/7.2/13.8 0+j0.9

* - Denotes that subtransient impedance values were not available so default values found in ASPEN were used.


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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 6-2.


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Table 6-2: 2014 HL20S Short Circuit Summary Results

Bus Fault On:

Lowest Breaker Rating (kA)

Fault Pre

Current (Amps)

Pre X/R Post

Current (Amps)

Post X/R Delta (Amperes)

AMRAD 115 kV 40 3LG 7763.7 10.6812 7763.8 10.6812 0.1

2LG 8252 10.8621 8252.1 10.8622 0.1 1LG 8495.8 10.919 8495.9 10.919 0.1

ALMOPGT 115 kV (Tri-State Bus)

3LG 4290.3 5.88895 4291.2 5.88845 0.9 2LG 3981.2 5.4645 3982 5.46418 0.8 1LG 3052.5 4.45936 3052.8 4.45916 0.3

HL20S_TAP 115 kV 40 3LG N/A N/A 4070.8 5.49953 - 2LG N/A N/A 3805.2 5.09787 - 1LG N/A N/A 3002.7 4.21829 -

HL20S 34.5 kV 40 3LG N/A N/A 10090.7 7.04081 - 2LG N/A N/A 9583 6.35003 - 1LG N/A N/A 7993.1 5.1613 -

HOLLOMAN 115 kV 31 3LG 4068.1 5.49449 4068.1 5.49456 0 2LG 3801.6 5.09482 3801.7 5.0949 0.1 1LG 2997.2 4.2164 2997.2 4.2165 0

LARGO 115 kV 25 3LG 5187.3 6.48488 5187.3 6.48492 0 2LG 4947.7 5.94004 4947.8 5.94008 0.1 1LG 4259.7 5.06078 4259.8 5.06082 0.1

East Cluster System Impact Study TRC July 17, 2012

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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.


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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 Cost4 and $3.98 Million for Network Upgrades Cost5. The Generator Interconnection Cost6 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.


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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):

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

$0.14

Estimated Time Frame for Engineering, Procurement, Construction, and Commissioning

24 Months


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Figure 7-1: HL20S POI and HL20S 115 kV Station One line

115 kV

To Largo

Existing Holloman-Largo

115 kV line conductors

To Holloman

0.25 miles

14.6 miles

115 kV

M

Color Code Network Upgrades Existing Facilities EPE Interconnection Facilities Located at POI Interconnection Customer Equipment

HL20S 20 MW

HL20S Substation


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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:

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

$3.98

Estimated Time Frame for Engineering, Procurement, Construction, and Commissioning

24Months


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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.


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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 re-evaluation 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.


Appendix A

Appendix A HL20S Feasibility Study Statement of Work


Appendix B

Appendix B Power Flow Contingency List

CONTINGENCY LIST Transmission Lines

1. ALA_5 115.0 to ORO_GRAN 115.0 Circuit 1 2. AMRAD 115.0 to LARGO 115.0 Circuit 1 3. AMRAD 345.0 to ARTESIA 345.0 Circuit 1 4. ANTHONY 115.0 to BORDER 115.0 Circuit 1 5. ANTHONY 115.0 to MONTOYA 115.0 Circuit 1 6. ANTHONY 115.0 to NEWMAN 115.0 Circuit 1 7. ANTHONY 115.0 to SALOPEK 115.0 Circuit 1 8. ASCARATE 115.0 to COPPER 115.0 Circuit 1 9. ASCARATE 115.0 to RIVERENA 115.0 Circuit 1 10. AUSTIN_N 115.0 to MARLOW 115.0 Circuit 1 11. AUSTIN_N 115.0 to MARLOW 115.0 Circuit 2 12. BUTERFLD 115.0 to FT._BLIS 115.0 Circuit 1 13. CALIENTE 115.0 to LANE___# 115.0 Circuit 1 14. CALIENTE 115.0 to VISTA__# 115.0 Circuit 1 15. CALIENTE 345.0 to AMRAD 345.0 Circuit 1 16. CHAPARAL 115.0 to ORO_GRAN 115.0 Circuit 1 17. COPPER 115.0 to LANE___# 115.0 Circuit 1 18. COPPER 115.0 to PENDALE 115.0 Circuit 1 19. COYOTE 115.0 to CALIENTE 115.0 Circuit 1 20. COYOTE 115.0 to RGC_DC 115.0 Circuit 1 21. CROMO 115.0 to RIO_GRAN 115.0 Circuit 1 22. DIABLO 115.0 to RIO_GRAN 115.0 Circuit 1 23. DIABLO 115.0 to RIO_GRAN 115.0 Circuit 2 24. DIABLO 115.0 to INSURG 115.0 Circuit 1 25. DYER 115.0 to AUSTIN_N 115.0 Circuit 1 26. DYER 115.0 to SHEARMAN 115.0 Circuit 27. BIGGS 115.0 to GR 115.0 Circuit 1 28. FT._BLIS 115.0 to AUSTIN_N 115.0 Circuit 1 29. GR 115.0 to VISTA__# 115.0 Circuit 1 30. HATCH 115.0 to JORNADA 115.0 Circuit 1 31. HOLLOMAN 115.0 to HL20S_TAP 115.0 Circuit 1 32. HL20S_TAP 115.0 to LARGO 115.0 Circuit 1 33. HORIZON 115.0 to MONTWOOD 115.0 Circuit 1 34. JORNADA 115.0 to ARROYO 115.0 Circuit 1 35. LANE___# 115.0 to WRANGLER 115.0 Circuit 1 36. LAS_CRUC 115.0 to ARROYO 115.0 Circuit 1 37. LAS_CRUC 115.0 to SALOPEK 115.0 Circuit 1 38. LUNA 345.0 to DIABLO 345.0 Circuit 1 39. LUNA 345.0 to HIDALGO 345.0 Circuit 1 40. LUNA 345.0 to AFTON 345.0 Circuit 1 41. MAR 115.0 to LARGO 115.0 Circuit 1 42. MARLOW 115.0 to TROWBRIG 115.0 Circuit 1 43. MESA___# 115.0 to AUSTIN_N 115.0 Circuit 1 44. MESA___# 115.0 to RIO_GRAN 115.0 Circuit 1 45. MILAGRO 115.0 to NEWMAN 115.0 Circuit 1 46. MILAGRO 115.0 to NEWMAN 115.0 Circuit 2

47. MILAGRO 115.0 to LEO 115.0 Circuit 1 48. NEWMAN 115.0 to BUTERFLD 115.0 Circuit 1 49. NEWMAN 115.0 to CHAPARAL 115.0 Circuit 1 50. NEWMAN 115.0 to CROMO 115.0 Circuit 1 51. NEWMAN 115.0 to SHEARMAN 115.0 Circuit 1 52. NEWMAN 345.0 to ARROYO 345.0 Circuit 1 53. NEWMAN 345.0 to AFTON 345.0 Circuit 1 54. NE1 115.0 to NEWMAN 115.0 Circuit 1 55. PELICANO 115.0 to HORIZON 115.0 Circuit 1 56. PELICANO 115.0 to MONTWOOD 115.0 Circuit 1 57. RIPLEY 115.0 to THORN 115.0 Circuit 1 58. MONTWOOD 115.0 to CALIENTE 115.0 Circuit 1 59. MONTWOOD 115.0 to COYOTE 115.0 Circuit 1 60. ORO_GRAN 115.0 to AMRAD 115.0 Circuit 1 61. RIO_GRAN 115.0 to RIPLEY 115.0 Circuit 1 62. SALOPEK 115.0 to ARROYO 115.0 Circuit 1 63. SANTA_T 115.0 to DIABLO 115.0 Circuit 1 64. SANTA_T 115.0 to MONTOYA 115.0 Circuit 1 65. SANTA_T 115.0 to NW2 115.0 Circuit 1 66. SCOTSDALE 115.0 to VISTA__# 115.0 Circuit 1 67. PENDALE 115.0 to LANE___# 115.0 Circuit 1 68. SOL 115.0 to LANE___# 115.0 Circuit 1 69. SOL 115.0 to VISTA__# 115.0 Circuit 1 70. SPARKS 115.0 to HORIZON 115.0 Circuit 1 71. SUNSET_N 115.0 to RIO_GRAN 115.0 Circuit 1 72. TALAVERA 115.0 to ANTHONY 115.0 Circuit 1 73. THORN 115.0 to MONTOYA 115.0 Circuit 1 74. NW2 115.0 to DIABLO 115.0 Circuit 1 75. WHITE_SA 115.0 to ALA_5 115.0 Circuit 1 76. WRANGLER 115.0 to SPARKS 115.0 Circuit 1 77. WRANGLER 115.0 to SPARKS 115.0 Circuit 2 78. AEP 115.0 to AZTECAS 115.0 Circuit 1 79. AEP 115.0 to REA2 115.0 Circuit 1 80. CHAMIZAL 115.0 to COLEGIO 115.0 Circuit 1 81. CHAMIZAL 115.0 to RIVERENA 115.0 Circuit 1 82. CHAVENA 115.0 to AZTECAS 115.0 Circuit 1 83. COLEGIO 115.0 to CHAVENA 115.0 Circuit 1 84. COLEGIO 115.0 to FTS 115.0 Circuit 1 85. FTS 115.0 to TEC 115.0 Circuit 1 86. INSURG 115.0 to CHAMIZAL 115.0 Circuit 1 87. INSURG 115.0 to CHAVENA 115.0 Circuit 1 88. REA2 115.0 to AZTECAS 115.0 Circuit 1 89. REA2 115.0 to INSURG 115.0 Circuit 1 90. CALIENTE 345.0 to PICANTE 345.0 Circuit 1 91. NEWMAN 115.0 to PIPELINE 115.0 Circuit 1 92. LEO 115.0 to DYER 115.0 Circuit 1


93. PICANTE 345.0 to NEWMAN 345.0 Circuit 1 94. PICANTE 115.0 to BIGGS 115.0 Circuit 1 95. PICANTE 115.0 to GR 115.0 Circuit 1 96. ANTHONY 115.0 to NW3 115.0 Circuit 1 97. ARROYO 115.0 to COX 115.0 Circuit 1 98. APOLLOSS 115.0 to APOLLO 115.0 Circuit 1 99. HATCH 115.0 to LEASBURG 115.0 Circuit 1 100. LE1 115.0 to APOLLOSS 115.0 Circuit 1 101. LE1 115.0 to JORNADA 115.0 Circuit 1 102. SUNSET_N 115.0 to DURAZNO 115.0 Circuit 1 103. DURAZNO 115.0 to ASCARATE 115.0 Circuit 1 104. NW3 115.0 to MONTOYA 115.0 Circuit 1 105. COX 115.0 to APOLLOSS 115.0 Circuit 1 106. APOLLO 115.0 to JORNADA 115.0 Circuit 1 107. LEASBURG 115.0 to JORNADA 115.0 Circuit 1 108. NE1 115.0 to CROMO 115.0 Circuit 1 109. ANTHONY 115.0 to COX 115.0 Circuit 1 110. COX 115.0 to TALAVERA 115.0 Circuit 1 111. ASCARATE 115.0 to COPPER 115.0 Circuit 2 112. JORNADA 115.0 to AIRPOR 115.0 Circuit 1 113. AFTON 115.0 to AIRPOR 115.0 Circuit 1 114. SOL 115.0 to VISTA__# 115.0 Circuit 2 115. NEWMAN 115.0 to PICANTE 115.0 Circuit 1 116. PIPELINE 115.0 to BIGGS 115.0 Circuit 1 117. HIDALGO 345.0 to GREENLEE 345.0 Circuit 1 118. LUNA 345.0 to LEF 345.0 Circuit 1 119. DONA_ANA 115.0 to LAS_CRUC 115.0 Circuit 1 120. AMRAD 115.0 to ALAMOGCP 115.0 Circuit 1 121. HOLLOMAN 115.0 to ALAMOGCP 115.0 Circuit 1 122. AIRPOR_T 115.0 to AIRPOR 115.0 Circuit 1 123. CABALLOT 115.0 to UVAS 115.0 Circuit 1 124. UVAS 115.0 to MIMBRES 115.0 Circuit 1 125. ORO_GRAN 115.0 to JARILLA1 115.0 Circuit 1 126. WSTAP 115.0 to WHITE_SA 115.0 Circuit 1 127. ASCARATE 115.0 to TROWBRIG 115.0 Circuit 1 128. EPE1 115.0 to COYOTE 115.0 Circuit 1 129. EPE1 115.0 to MONTWOOD 115.0 Circuit 1 130. CALIENTE 115.0 to EPE1 115.0 Circuit 1 131. CALIENTE 115.0 to EPE1 115.0 Circuit 2 132. CALIENTE 115.0 to VISTA__# 115.0 Circuit 2 133. CALIENTE 115.0 to SE2 115.0 Circuit 1 134. CALIENTE 115.0 to SE2 115.0 Circuit 2 135. CALIENTE 345.0 to PICANTE 345.0 Circuit 2 136. MACHO_SPRNGS 345.0 to LUNA 345.0 Circuit 1 137. MACHO_SPRNGS345.0 to SPRINGR 345.0 Circuit 1 138. LE1 115.0 to ARROYO 115.0 Circuit 1 139. SE2 115.0 to LANE___# 115.0 Circuit 1

140. Line SE2 115.0 to LANE___# 115.0 Circuit 2 141. RIPLEY 115.0 to THORN 115.0 Circuit 2 142. PICANTE 345.0 to AMRAD 345.0 Circuit 1 143. WESTMESA 345.0 to ARR___PS 345.0 Circuit 1 144. NW2 115.0 to ROADRUNRTAP 115.0 Circuit 1 145. ROADRUNRTAP 115.0 to DIABLO 115.0 Circuit 1 146. ROADRUNRTAP 115.0 to ROADRUNER 115.0

Circuit 1 147. ART320W 345.0 to ARTESIA 345.0 Circuit 1 148. Line CALIENTE 345.0 to CORONA 345.0 Circuit 1 149. AMRAD 345.0 to AA100W 345.0 Circuit 1 150. AA100W 345.0 to ARTESIA 345.0 Circuit 1 151. CORONA 345.0 to AMRAD 345.0 Circuit 1 152. CORONA 345.0 to AMRAD 345.0 Circuit 2 153. CORONA 345.0 to PICANTE 345.0 Circuit 1 154. CORONA 345.0 to NEWMAN 345.0 Circuit 1 155. WESTMESA 345.0 to WA300POI 345.0 Circuit 1 156. WA300POI 345.0 to ARR___PS 345.0 Circuit 1 157. WA300POI 345.0 to WA300_C 345.0 Circuit 1 158. WA300_C 345.0 to WA300_C2 345.0 Circuit 1 159. 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 1 115 kV (AB) 177. BA-REEVES 2 115 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 3 115 kV (WB) 183. BELEN-SOCORRO 115 kV (SOC) 184. CORRALES-IRVING 115 kV (IC) 185. CORRALES-PACHMANN 115 kV (CY)


186. EMBUDO-SANDIA 2 115 kV (SE) 187. EMBUDO-NORTH(TL)/EB86 (EB) 115 kV 188. EMBUDO-REEVES 1 115 kV (RE) 189. EMBUDO-REEVES 2 115 kV (ER) 190. IRVING-WEST MESA 1 115 kV (WR) 191. IRVING-REEVES 1 115 kV (IR) 192. KIRTLAND-PERSON 115 kV (PS) 193. KIRTLAND-SANDIA 1 115 kV (KS) 194. NORTH-PRAGER 115 kV (PN) 195. NORTH-MISSION 115 kV (MN) 196. NORTH-REEVES 1 115 kV (RN) 197. NORTON-ETA 115 kV (NL) 198. NORTON-ZIA 2 115 kV (NS) 199. NORTON-HERNANDEZ 115 kV (NH) 200. OJO-HERNANDEZ 115 kV (HO) 201. PACHMANN-WEST MESA 3 115 kV (CE) 202. PERSON-SP83/HW43 115 kV (SP) 203. PERSON-WEST MESA 2 115 kV (PM) 204. PERSON-TOME 115 kV (AT) 205. PERSON-WEST MESA 1 115 kV (PW) 206. PRAGER-WEST MESA 2 115 kV (WP) 207. REEVES 2-MISSION 115 kV (NR) 208. REEVES 2-WEST MESA 2 115 kV (NW) 209. SANDIA 1-HW43/EB68 115 kV (EB) 210. SANDIA 2-SP83 115 kV (SP) 211. VALENCIA-ZIA 115 kV (SL) 212. VALENCIA-STORRIE LAKE 115 kV (VS) 213. WEST MESA 115 kV BUS TIE 1-3 214. WEST MESA 1-GULF PGT 115 kV (KM) 215. WEST MESA 115 kV BUS TIE 1-2 216. 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-TA53 115 kV (LA) 222. STA-WTA 115 kV (SW) 223. TA3-TA53 115 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 #1 248. SAN JUAN-MCKINLEY 345 kV #2 249. 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 345.0 kV

CONTINGENCY LIST Transformers

270. AMRAD 345/115 kV Circuit 1 271. ARROYO 345/115 kV Circuit 1 272. ARROYO 345/115 kV Circuit 2 273. CALIENTE 345/115 kV Circuit 1 274. CALIENTE 345/115 kV Circuit 2 275. DIABLO 345/115 kV Circuit 1 276. DIABLO 345/115 kV Circuit 2 277. DIABLO 345/115 kV Circuit 3 278. NEWMAN 345/115 kV Circuit 1 279. PICANTE 345/115 kV Circuit 1 280. AFTON 345/115 kV Circuit 1 281. HIDALGO 345/115 kV Circuit 1 282. HIDALGO 345/115 kV Circuit 2 283. LUNA 345/115 kV Circuit 1 284. ZIA 115/46 kV TRANSFORMER #1 285. ZIA 115/46 kV TRANSFORMER #2 286. PERSON 115/46 kV TRANSFORMER 287. PRAGER 115/46 kV TRANSFORMER 288. SANDIA 115/46 kV TRANSFORMER #2 289. TOME 115/46 kV TRANSFORMER 290. ZIA 115/46 kV TRANSFORMER #3 291. ZIA 115/46 kV TRANSFORMER #1 & 2 292. SPRINGER-GLADSTONE 115 kV 293. TAOS 345/115 kF TRANSFORMER #3 294. TAOS 345/115 kF TRANSFORMER #4 295. 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 #1 300. WESTMESA 345/115 kV TRANSFORMER #2 301. WESTMESA 230/115 kV TRANSFORMER #1 302. WESTMESA 230/115 kV TRANSFORMER #2 303. NORTON 345/115 kV TRANSFORMER 304. MCKINLEY-YAHTAHEY 345/115 kV

TRANSFORMER 305. SAN JUAN-HOGBACK 230/115 kV

TRANSFORMER

CONTINGENCY LIST Generators

306. AMRAD_A 13.2 Unit ID 1 307. NEWMANG3 13.8 Unit ID 1 308. NEWMN4S1 13.8 Unit ID 1 309. NEWMN5G1 13.8 Unit ID 1 310. NEWMN5G2 13.8 Unit ID 1 311. NEWMN5S1 13.8 Unit ID 1 312. NEWMN6G1 13.8 Unit ID 1 313. NEWMN6G2 13.8 Unit ID 1 314. NEWMN6S1 13.8 Unit ID 1 315. RIOGD_G8 17.5 Unit ID 1 316. RIOGD_G9 13.8 Unit ID 1 317. RIOGD_G10 13.8 Unit ID 1 318. ST_DIST_PV 24.9 Unit ID 1

319. APT_DIST_PV 24.9 Unit ID 1 320. CHAP_DIST_PV 13.8 Unit ID 1 321. HAT_DIST_PV 24.9 Unit ID 1 322. ART320W_G1 34.5 Unit ID 1 323. ART320W_G2 34.5 Unit ID 1 324. MOCC_G1 13.8 Unit ID 1 325. MOCC_G2 13.8 Unit ID 1 326. MOCC_G3 13.8 Unit ID 1 327. MOCC_G4 13.8 Unit ID 1 328. MO420G ALL UNITS"

East Cluster System Impact Study TRC July 17, 2012

Appendix C

Appendix C Project Schedule

ID Task Name Duration Start Finish

1 HL20S POI Switching Station 588 days Sun 7/1/12 Wed 10/1/14

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 8/26/14

6

7 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

May Sep Jan May Sep Jan May Sep Jan3rd Quarter 2nd Quarter 1st Quarter 4th Quarter

Task

Task Progress

Critical Task

Critical Task Progress

Milestone

Summary

Rolled Up Task

Rolled Up Critical Task

Rolled Up Milestone

Rolled Up Progress

Split

External Tasks

Project Summary

Group By Summary

Inactive Task

Inactive Milestone

Inactive Summary

Manual Task

Duration-only

Manual Summary Rollup

Manual Summary

Start-only

Finish-only

Deadline

Page 1

Project: HL20S Project Schedule.mppDate: Tue 7/17/12

FEASIBILITY STUDY REPORT - El Paso Electric

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