TEXAS ECONOMIC STUDY REPORT ICTES INFORMATIONAL ONLY

Transcription

1 TEXAS ECONOMIC STUDY REPORT ICTES INFORMATIONAL ONLY Prepared for: Entergy Service, Inc. (SPO) American Electric Power Service Corporation (AEPSC) GDS Associates, Inc. (GDS), as agent of East Texas Electric Cooperative, Inc. ( ETEC ), Tex-La Electric Cooperative of Texas, Inc. (TEXL), and Northeast Texas Electric Cooperative, Inc. (NTEC) Prepared by: Southwest Power Pool Independent Coordinator of Transmission 201 Worthen Drive Little Rock, Arkansas Rev Issue Date Description of Revision 0 8/01/2012 Final Step 1Study Report

2 TABLE OF CONTENTS 1. EXECUTIVE SUMMARY DESCRIPTION OF PROBLEM ASSUMPTIONS Power-flow Models Model Change Model(s) STUDY PROCESS Power-flow model analysis Economic Study Analysis SOLUTION SETS Quarry Rivtrin 345 kv Solution Set kv Alternative Solution Set Grimes Mt. Zion 138 kv Solution Set Grimes Huntsville 138 kv Solution Set Grimes Ponderosa 230 kv Solution Set POWERFLOW STUDY DATA ECONOMIC STUDY DATA Quarry Rivtrin Economic Study Information Economic Analysis Projects Included in the Economic Study Models Projects include in the B/C calculations APC Breakdown Additional gates Added kv Solution Economic Study Information Economic Study Projects Included in the Economic Study Models Projects Included in the B/C Calculations Grimes Mt. Zion Economic Study Information Economic Study Projects Included in the Economic Study Models

3 7.3.3 Projects Include in the B/C calculations Grimes Huntsville Economic Study Information Economic Study Projects Included in the Economic Study Models Projects Include in the B/C calculations Grimes - Ponderosa Economic Study Information Economic Study Projects Included in the Economic Study Models Projects Include in the B/C calculations Additional gates Added SUMMARY APPENDIX A LIST OF PRIORS APPENDIX B ECONOMIC STUDY ASSUMPTIONS Fuel Price Forecast Summary Wheeling Charges Emission Rates APPENDIX C METRIC CALCULATION How is the APC calculated? Import/Export Cost Calculation APC-d Benefit-to-Cost-Ratio APPENDIX D ENTERGY APPROVED CONSTRUCTION PLAN PROJECTS

4 1. EXECUTIVE SUMMARY This study reviews constraints identified through System Impact Studies (SIS) and Affected Systems Studies (AFS) in the Entergy Texas region. In accordance with Section 14 of Attachment K of the Entergy OATT, this study was commissioned in order to determine upgrades in the area that will increase transfer capability. Those upgrades have also been assessed to determine what, if any, economic benefits in terms of production cost reduction that they may provide. This report identifies constraints, reviews potential solution sets, and provides planning level cost estimates as well as an evaluation of the economic benefits of each solution set. Through this study process, a number of transmission solution sets have been developed. Those solutions sets have been evaluated in order to determine if a) those upgrades will relieve the N-1 overloads that are seen with the inclusion of the selected transmission service requests, and b) what reduction in congestion and production cost these upgrades may have. The results are summarized in the table below. The projects and results are described in more detail in the body of the report. Table 1: Summary of Results Solution Set Cost Estimate Relieves N-1 Overloads? APC B/C Ratio (2015) APC B/C Ratio (2020) Quarry Rivtrin 345 kv $84,590,215 Yes kv Alternative $141,780,842 Yes Grimes Mt. Zion 138 kv $14,966,895 No Grimes Huntsville 138 kv $24,442,906 No Grimes Ponderosa 230 kv $82,279,000 Yes d upon the results of this study, the study participants will have the option of entering into a more detailed study of selected solution set(s) in order to arrive at a more detailed breakdown of the benefits associated with the projects and to arrive at a cost allocation for the selected upgrades. Note that this study is for informational purposes only and does not guarantee the availability of Available Transfer Capability (ATC) or Rollover Rights (ROR). 2. DESCRIPTION OF PROBLEM Several constraints in the Texas Region have been identified from the following Transmission Service Requests: OASIS , OASIS , OASIS , OASIS , SPP OASIS , SPP OASIS , SPP OASIS , SPP OASIS _1004_1007_1231_1265, and SPP OASIS

5 3. ASSUMPTIONS 3.1 Power-flow Models Model A. Entergy s 2010 Series Update 3 Models. a Summer / Winter Peak case b Summer / Winter Peak case c Summer / Winter Peak case B. Includes 2011 Approved Construction Plan (CP) projects and commitments to fund Supplemental Upgrades available at the time of the study. The Case Models were modified with SPP Priority Projects, and SPP Balanced Portfolio Projects. Also, the ETEC Load Forecast was updated in the Case Models Change Model(s) A. Entergy Proposed / Horizon projects were considered to relieve constraints. B. Considered any other additional transmission upgrades to relieve constraints. 4. STUDY PROCESS This study is a High-Level Analysis (Step1), as described below. d upon the outcome of the Step1 analysis, Customers may choose to have their TSRs studied further in the Step 2 analysis. 4.1 Power-flow model analysis A high-level full AC contingency analysis (N-1) will be performed on the base and change models. There will be no TRM included in the analysis. The contingency scan will include NERC Category A and B events. Details on monitored elements and Category A and B events can be found in the Contingency Scan. The thermal and voltage violations thresholds are the same as those specified for the NERC Reliability Standard TPL-001 and -002 contingency evaluations in which facility loadings must be within their normal rating (RATE A) or emergency rating (RATE B), consistent with the applicable rating as determined and consistently applied by SPP, ICT and/or Entergy. The monitored and contingent element list will include all transmission facilities at 115kV or higher. 4.2 Economic Study Analysis Economic modeling, simulations, and results will be developed using GridView (GV), developed by ABB Inc. In general, GV is a database-driven software package that uses a linear programming approach for economic simulation of electric power systems. Its application is for generation and transmission expansion planning, market simulation, and production cost modeling. GV uses a Security Constrained Unit Commitment and 5

6 Economic Dispatch (SCUC&ED) to simulate the most economic generation dispatch while observing system security constraints. The economic analysis will also be conducted in Step 2. Adjusted Production Cost1 (APC)-based Benefit-to-Cost (B/C) ratio metric has been calculated below. The APCbased B/C refers to the reduction in APC due to a project divided by carrying charge rate of the planning cost estimate of the project. Ideal APC-based B/C ratio would be greater than 1. A ratio of 1 or greater would imply that they reduction in APC would be equal to or greater than the annual transmission revenue requirement for the upgrade. 5. SOLUTION SETS This section will detail those solution sets that have been evaluated as part of this study. Planning level cost estimates have been provided for these upgrades, as well as a description of the projects that are included in each solution set. 5.1 Quarry Rivtrin 345 kv Solution Set The main project in this solution set is the Quarry Rivtrin 345 kv project, along with several supporting projects. The Quarry - Rivtrin project consists of tapping the existing Crockett Grimes 345 kv line, installing a new 345 kv switching station at Quarry, and building nine (9) miles of new 345 kv line from Quarry to the existing Rivtrin station. A 345/138 kv transformer would be added at Rivtrin to step down to the 138 kv system. A diagram of that option is displayed below. In addition to the Quarry project, several smaller system reinforcements are needed to address other overloads in the area. All of the required upgrades for this solution set, along with their costs are listed below. 1 Adjusted Production Cost (APC) is a measure of the impact on production cost savings by using LMPs, accounting for purchases and sales of energy between each area. This metric compares adjusted production cost with and without transmission solutions. A negative value means that a reduction in transmission congestion decreased generation production cost. In theory, production cost will decrease when constraints are removed from the system. 6

7 Figure 1 - Quarry - Rivtrin Project Table 2: Quarry Rivtrin Solution Set and Cost Estimates MAJOR ELEMENTS COSTS SCHEDULE % Quarry Rivtrin 345kV Project $79,697,735 3 years Egypt Panorama Line $1,429,120 2 years Panorama Longmire Line $3,363,360 2 years Rivtrin Walker Line $100,000 1 year 4L558TP91 Wyntex 4L558TP85 Line O&M 1 month Upgrade Toledo Bend Leach Line (ISD Summer 2017) Ponderosa Switching Station Mossville Cut in Nelson to Carlyss Line New Moss Bluff Nelson Line Cedar Hill Plantation Line Plantation Conroe Line DTEC Project NONE TOTAL: $84,590,215* (ISD Summer 2013) (ISD Summer 2013) (ISD Summer 2012) (ISD Summer 2013) (ISD Summer 2013) DTEC Project (ISD 2015) * Note: The costs identified above are estimates, but do not include an additional +/- 30% for tax gross up, which may be applicable should the customer elect to proceed with the upgrades. Detailed cost estimates and solutions for the major elements would be provided in the Step 2 study. % The schedule estimates are planning estimates only. 7

8 Table 3: Upgrade Description No. Upgrade Description 1 Tap Grimes Crocket 345kV Line with the Quarry substation, build 345kV line from Quarry to Rivtrin, and install 345/ Autotransformer at Rivtrin. Capacity created by this upgrade is 525MW on the Rivtrin 345/ autotransformer and 1326MW from Quarry to Rivtrin 345kV Line. 2 Upgrade 1.16 miles of transmission line from Egypt to Panorama. 3 Upgrade 2.73 miles of transmission line from Panorama to Longmire. 4 5 Replace line bay buses at Walker. Closed transmission line from 4L558TP91 to Wyntex and open transmission line from 4L558TP85 to Wyntex. 6 Upgrade 2.26 miles of transmission line from Toledo Bend to Leach. 7 Tie together Longmire Fish Creek and Conroe Woodhaven stations at West Conroe Switching Station. Upgrade miles of transmission line from Longmire to Conroe. 8 Cut Nelson to Carlyss line into Mossville substation. 9 Build new Nelson to Moss Bluff 230kV. 10 Upgrade 3.13 miles of transmission line from Cedar Hill to Plantation. 11 Upgrade 2.93 miles of transmission line from Plantation to Conroe. The existing conductor needs to be upgraded to at least 1272 MCM ACSR, which gives a line rating of 316MVA and 1322A. The existing conductor needs to be upgraded to at least 1272 MCM ACSR, which gives a line rating of 316MVA and 1322A. Upgrade the line bay buses at Walker, which gives a line rating on Rivtrin Walker of 140MVA and 585A. The switching scheme reduces the flow on the 4L558TP91 Huntsville line. The existing conductor needs to be upgraded to at least 954 MCM ACSR, which gives a line rating of 265MVA and 1109A. The existing conductor needs to be upgraded to at least ACSR, which gives a line rating of 205MVA and 858A. Capacity created by this upgrade is 0MW. Capacity created by this upgrade is 704MW. The existing conductor needs to be upgraded to at least MCM ACSR, which gives a line rating of 478MVA and 2000A. The existing conductor needs to be upgraded to at least MCM ACSR, which gives a line rating of 478MVA and 2000A. 12 Build new line from Etoile to Chireno, set Leach to Six Mile in-service, convert Tenaha to Martinsville to, and build new line from Chireno to Martinsville. Capacity created by this project is 902MW. 8

9 kv Alternative Solution Set Instead of constructing one bulk project, this alternative examined upgrading the existing system to accommodate the transfers. As such, there are a number of 138 kv line upgrades included in this option. The projects are diagramed below, and a table is included that provides the list of projects and the cost estimates. Figure kv Alternative Solution Table 4: 138 kv Alternative Solution Set and Cost Estimates MAJOR ELEMENTS COSTS SCHEDULE % New 3 rd 345/ Grimes $24,668,806 3 years Upgrade Grimes Bentwater Line $21,629,995 2 years Upgrade Grimes Mt. Zion Wyntex Tap Line $20,132,921 2 years Upgrade Grimes Magnolia Anderson Sota Navasota Line $32,697,280 2 years Upgrade Tubular Dobbin Line $19,724,320 2 years Upgrade Porter Apollo Line $22,927,520 2 years Upgrade Mossville - Nelson Line (ISD Summer 2013) 9

10 MAJOR ELEMENTS COSTS SCHEDULE % New Moss Bluff Nelson 230kV Line Upgrade Toledo Bend Leach Line Ponderosa Switching Station Orange County Upgrade Cedar Hill Plantation Line Upgrade Plantation Conroe Line Jacinto Splendora Project Upgrade Jacinto Splendora Line Upgrade Splendora Apollo Line DTEC Project NONE TOTAL COST: $141,780,842* (ISD Summer 2012) (ISD Summer 2017) (ISD Summer 2013) (ISD Summer 2017) (ISD Summer 2013) (ISD Summer 2013) (ISD Summer 2017) (ISD Summer 2016) (ISD Summer 2016) DTEC Project (ISD 2105) * Note: The costs identified above are estimates, but do not include an additional +/- 30% for tax gross up, which may be applicable should the customer elect to proceed with the upgrades. Detailed cost estimates and solutions for the major elements would be provided in the Step 2 study. % The schedule estimates are planning estimates only. Table 5: Upgrade Description No. Upgrade Description Install 345/ autotransformer at Grimes. Upgrade miles of transmission line from Grimes - Bentwater. Upgrade miles of transmission line from Grimes - Mt. Zion. Upgrade 5.35 miles of transmission line from Mt. Zion - Wyntex Tap. Upgrade miles of transmission line from Grimes to Magnolia Anderson. Upgrade 7.46 miles of transmission line from Magnolia Anderson to Sota. Replace line relays at Navasota. Capacity created by this upgrade is 525MW on the 3 rd Grimes 345/ autotransformer. The existing conductor needs to be upgraded to at least 1272 MCM ACSR, which gives a line rating of 312MVA and 1304A. The existing conductors from Grimes to Mt. Zion and Mt. Zion to Wyntex Tap need to be upgraded to at least MCM ACSR, which gives a line rating of 339 MVA and 1418A. The existing conductors from Grimes to Magnolia Anderson and Magnolia Anderson to Sota need to be upgraded to at least 954 MCM ACSR, which gives a line rating of 265 MVA and 1108A. The existing conductor from Sota to Navasota needs line relays replaced at Navasota, which gives a line rating of 243 MVA and 1017A. 10

11 No. Upgrade Description Upgrade miles of transmission line from Tubular to Dobbin. Upgrade miles of transmission line from Porter to Apollo. Cut Nelson to Carlyss line into Mossville substation. The existing conductor from Tubular to Dobbin needs to be upgraded to at least MCM ACSR, which gives a line rating of 206 MVA and 860A. The existing conductor needs to be upgraded to at least 1272 MCM ACSR, which gives a line rating of 312MVA and 1304A. Capacity created by this upgrade is 0 MW. 8 Build new Nelson to Moss Bluff 230kV. Capacity created by this upgrade is 704 MW Upgrade 2.26 miles of transmission line from Toledo Bend to Leach. Tie together Longmire Fish Creek and Conroe Woodhaven stations at West Conroe Switching Station. Upgrade miles of transmission line from Longmire to Conroe. Cut Sabine Georgetown 230kV line into new substation called Chisholm Road. Add new Hartburg Chisholm Road 230kV line and 2 nd 500/230kV autotransformer at Hartburg. Upgrade 3.13 miles of transmission line from Cedar Hill to Plantation. Upgrade 2.93 miles of transmission line from Plantation to Conroe. The existing conductor needs to be upgraded to at least 954 MCM ACSR, which gives a line rating of 265MVA and 1109A. The existing conductor needs to be upgraded to at least ACSR, which gives a line rating of 205MVA and 858A. Capacity created by the Hartburg Chisholm Road 230kV line is 1042 MW. Capacity created by the 2 nd 500/230kV autotransformer at Hartburg is 800 MW. The existing conductor needs to be upgraded to at least MCM ACSR, which gives a line rating of 478MVA and 2000A. The existing conductor needs to be upgraded to at least MCM ACSR, which gives a line rating of 478MVA and 2000A. 14 Tie Jacinto Splendora line into Cleveland station. Capacity created by this project is 0 MW. 15 Upgrade miles of transmission line from Jacinto to Splendora. The existing conductor needs to be upgraded to at least MCM ACSR, which gives a line rating of 478 MVA. 11

12 No. Upgrade Description Upgrade 2.67 miles of transmission line from Splendora to Apollo. Build new line from Etoile to Chireno, set Leach to Six Mile in-service, convert Tenaha to Martinsville to, and build new line from Chireno to Martinsville. The existing conductor needs to be upgraded to at least MCM ACSR, which gives a line rating of 478 MVA. Capacity created by this project is 902 MW. 5.3 Grimes Mt. Zion 138 kv Solution Set This alternative project was examined to observe what overloads were alleviated in the Western Region. This alternative project was not sufficient in accommodating the transfers for this study. The projects are diagramed below, and a table is included that provides the list of projects and the cost estimates. Figure 3 - Grimes - Mt. Zion 138 kv Upgrade 12

13 Table 6: Grimes Mt. Zion Solution Set and Cost Estimates MAJOR ELEMENTS COSTS SCHEDULE % Upgrade Grimes Mt. Zion Line $14,966,895 2 years TOTAL COST: $14,966,895 * Note: The costs identified above are estimates, but do not include an additional +/- 30% for tax gross up, which may be applicable should the customer elect to proceed with the upgrades. Detailed cost estimates and solutions for the major elements would be provided in the Step 2 study. % The schedule estimates are planning estimates only. Table 7: Upgrade Description No. Upgrade Description 1 Upgrade miles of transmission line from Grimes to Mt. Zion The existing conductor needs to be upgraded to at least MCM ACSR, which gives a line rating of 339 MVA and 1418A. 5.4 Grimes Huntsville 138 kv Solution Set This alternative project was examined to observe what overloads were alleviated in the Western Region. This alternative project was not sufficient in accommodating the transfers for this study. The projects are diagramed below, and a table is included that provides the list of projects and the cost estimates. Figure 4 - Grimes - Huntsville 138 kv upgrade 13

14 Table 8: Grimes Huntsville Solution Set and Cost Estimates MAJOR ELEMENTS COSTS SCHEDULE % Upgrade Grimes Mt. Zion Huntsville Line $24,442,906 2 years TOTAL COST: $24,442,906 * Note: The costs identified above are estimates, but do not include an additional +/- 30% for tax gross up, which may be applicable should the customer elect to proceed with the upgrades. Detailed cost estimates and solutions for the major elements would be provided in the Step 2 study. % The schedule estimates are planning estimates only. Table 9: Upgrade Description No. Upgrade Description 1 Upgrade miles of transmission line from Grimes to Mt. Zion. Upgrade 5.35 miles of transmission line from Mt. Zion to Wyntex Tap. Upgrade 2.25 miles of transmission line from Wyntex Tap to Huntsville. The existing conductors from Grimes to Mt. Zion and Mt. Zion to Wyntex Tap, and Wyntex Tap to Huntsville need to be upgraded to at least MCM ACSR, which gives a line rating of 339 MVA and 1418A. The existing conductor from Wyntex Tap to Huntsville need to be upgraded to at least 1033 MCM ACSR, which gives a line rating of 299MVA and 1252A. 5.5 Grimes Ponderosa 230 kv Solution Set The main project in this solution set is the Grimes - Ponderosa project, along with a few supporting projects. The Grimes - Ponderosa project consists of the following upgrades: tie together Longmire Fish Creek and the Conroe Woodhaven stations at Ponderosa Switching Station, upgrade Longmire Conroe line, build new 230kV substation at Grimes, add 345/230kV autotransformer at Grimes, build new Grimes Ponderosa 230kV line, add new 230/ autotransformer at Ponderosa, and upgrade Ponderosa Conroe line. In addition to the Grimes Ponderosa project, a few smaller system reinforcements are needed to address other overloads in the area. The projects are diagramed below, and a table is included that provides the list of projects and the cost estimates. 14

15 Figure 5 Grimes Ponderosa 230 kv Table 10: Grimes - Ponderosa Solution Set and Cost Estimates MAJOR ELEMENTS COSTS SCHEDULE % Grimes Ponderosa Project $82,179,000 3 years Rivtrin Walker Line $100,000 1 year Mossville Cut in Nelson to Carlyss Line (ISD Summer 2013) Upgrade Toledo Bend Leach Line (ISD Summer 2017) DTEC Project NONE DTEC Project (ISD 2015) TOTAL COST: $82,279,000* * Note: The costs identified above are estimates, but do not include an additional +/- 30% for tax gross up, which may be applicable should the customer elect to proceed with the upgrades. Detailed cost estimates and solutions for the major elements would be provided in the Step 2 study. % The schedule estimates are planning estimates only. 15

16 Table 11: Upgrade Description No. Upgrade Description 1 Tie together Longmire Fish Creek and Conroe Woodhaven stations at Ponderosa Switching Station. Upgrade miles of transmission line from Longmire to Conroe. Build new 230kV substation and 345/230kV autotransformer at Grimes. Build new transmission line from Grimes to Ponderosa 230kV. Add new 230/ autotransformer at Ponderosa. Upgrade 2.6 miles of transmission line from Ponderosa to Conroe. Capacity created by the 345/230kV autotransformer at Grimes, Grimes Ponderosa 230kV line, 230/ autotransformer at Ponderosa, and Ponderosa Conroe line are 700MW, 519MW,750MW, and 193MW, respectively. 2 Upgrade line bay buses at Walker. Upgrade the line bay buses at Walker, which gives a line rating on Rivtrin Walker of 140MVA and 585A Cut Nelson to Carlyss line into Mossville substation. Upgrade 2.26 miles of transmission line from Toledo Bend to Leach. Build new line from Etoile to Chireno, set Leach to Six Mile in-service, convert Tenaha to Martinsville to, and build new line from Chireno to Martinsville. Capacity created by this upgrade is 0 MW. The existing conductor needs to be upgraded to at least 954 MCM ACSR, which gives a line rating of 265MVA and 1109A. Capacity created by this project is 902 MW. 16

17 6. POWERFLOW STUDY DATA Study results are summarized below. The top constraints were listed. Tables 1 6 contain priors and the transactions of this Economic Study with the parameters outlined in Section 4.1 of this report. No transmission solutions were included in these runs. Tables 7-12 contain priors and the transactions of this Economic Study with the parameters outlined in Section 4.1 of this report, along with the Quarry Rivtrin Solution Set. The 138 kv Solution and the Grimes Ponderosa 230 kv Solution yield the same results. As such, specific tables are not provided for those solutions. Tables contain priors and the transactions of this Economic Study with the parameters outlined in Section 4.1 of this report, along with the Grimes Mt. Zion Solution Set. Tables contain priors and the transactions of this Economic Study with the parameters outlined in Section 4.1 of this report, along with the Grimes Huntsville Solution Set. Table Summer () Limiting Element Contingency Element ContMW Mossville Nelson Carlyss Citcon West Table Winter () Limiting Element Contingency Element ContMW NONE NONE Table Summer () Limiting Element Contingency Element ContMW Grimes 345/ ckt 1 Grimes 345/ ckt Grimes 345/ ckt 2 Grimes 345/ ckt Jasper Rayburn Cypress Hartburg 500kV Tubular Dobbin Mossville Nelson Longmire Lewis Creek Carlyss Citcon West

18 Table 4 Winter 2015 () Limiting Element Contingency Element ContMW NONE NONE Table Summer () Limiting Element Contingency Element ContMW Magnolia Anderson Sota Grimes Magnolia Anderson Grimes College Station Grimes College Station Grimes 345/ ckt 1 Grimes 345/ ckt Grimes 345/ ckt 2 Grimes 345/ ckt Grimes Bentwater Grimes Huntsville Grimes Mt. Zion Cypress Hartburg 500kV Dobbin Springbranch Tubular Dobbin Mt. Zion Wyntex Tap Plantation Conroe Conroe2 Conroe1 Plantation Cedar Hill Longmire Lewis Creek Longmire Lewis Creek Cypress Hartburg 500kV Oak Ridge Porter Oak Ridge Porter Oak Ridge Porter Rayburn Jasper Cypress Hartburg 500kV Newton Bulk Leach Leach Toledo Bend Cypress Hartburg 500kV Cypress Hartburg 500kV Helbig McLewis 230kV Cypress Hartburg 500kV Mossville Nelson Cypress 500/ transformer Carlyss Citcon West Cypress 500/230kV transformer

19 Limiting Element Contingency Element ContMW Splendora Jacinto Eastgate Klemp Exposaic China Porter 230kV China Porter 230kV Table Winter () Limiting Element Contingency Element ContMW Grimes 345/ ckt 1 Grimes 345/ ckt Grimes 345/ ckt 2 Grimes 345/ ckt Grimes Bentwater Grimes Frontier 345/ Grimes Mt. Zion Grimes - Conroe Tubular Dobbin Longmire Lewis Creek Rayburn Jasper Cypress Hartburg 500kV Buna Evadale Junction Evadale Junction Evadale Newton Bulk Leach Leach Toledo Bend Rayburn Mill Creek Rayburn Mill Creek Cypress Hartburg 500kV Cypress Hartburg 500kV Mossville Nelson Carlyss Citcon West

20 Table Summer (w/quarry-rivtrin) Limiting Element Contingency Element ContMW NONE NONE Table Winter (w/quarry-rivtrin) Limiting Element Contingency Element ContMW NONE NONE Table Summer (w/quarry-rivtrin) Limiting Element Contingency Element ContMW NONE NONE Table Winter (w/quarry-rivtrin) Limiting Element Contingency Element ContMW NONE NONE Table Summer (w/quarry-rivtrin) Limiting Element Contingency Element ContMW NONE NONE Table Winter (w/quarry-rivtrin) Limiting Element Contingency Element ContMW NONE NONE

21 Table Summer (w/grimes Mt. Zion) Limiting Element Contingency Element ContMW Mossville Nelson Carlyss Citcon West Table Winter (w/grimes Mt. Zion) Limiting Element Contingency Element ContMW NONE NONE Table Summer (w/grimes Mt. Zion) Limiting Element Contingency Element ContMW Grimes 345/ ckt 1 Grimes 345/ ckt Grimes 345/ ckt 2 Grimes 345/ ckt Mt. Zion Wyntex Tap Cypress Hartburg 500kV Jasper Rayburn Cypress Hartburg 500kV Tubular Dobbin Longmire Lewis Creek Mossville Nelson Carlyss Citcon West Table Winter (w/grimes Mt. Zion) Limiting Element Contingency Element ContMW NONE NONE Table Summer (w/grimes Mt. Zion) Limiting Element Contingency Element ContMW 21 Grimes 345/ ckt 1 Grimes 345/ ckt Grimes 345/ ckt 2 Grimes 345/ ckt Grimes Bentwater Grimes - Huntsville Dobbin Springbranch Lewis Creek - Longmire

22 Tubular Dobbin Lewis Creek - Longmire Huntsville Wyntex Tap Cypress Hartburg 500kV Mt. Zion Wyntex Tap Cypress Hartburg 500kV Plantation Conroe Oak Ridge Porter Conroe2 Conroe1 Oak Ridge Porter Plantation Cedar Hill Oak Ridge Porter Rayburn Jasper Cypress Hartburg 500kV Newton Bulk Leach Cypress Hartburg 500kV Leach Toledo Bend Cypress Hartburg 500kV Helbig McLewis 230kV Cypress Hartburg 500kV Mossville Nelson Carlyss Citcon West Cypress 500/ Cypress 500/230kV transformer transformer Splendora Jacinto China Porter 230kV Eastgate Klemp Exposaic China Porter 230kV Table Winter (w/grimes Mt. Zion) Limiting Element Contingency Element ContMW Grimes 345/ ckt 1 Grimes 345/ ckt Grimes 345/ ckt 2 Grimes 345/ ckt Grimes Bentwater Tubular Dobbin Grimes - Huntsville Lewis Creek - Longmire Huntsville Wyntex Tap Grimes Conroe Mt. Zion Wyntex Tap Grimes Conroe Rayburn Jasper Cypress Hartburg 500kV Buna Evadale Junction Rayburn Mill Creek Evadale Evadale Junction Rayburn Mill Creek Newton Bulk Leach Cypress Hartburg 500kV

23 Leach Toledo Bend Mossville Nelson Cypress Hartburg 500kV Carlyss Citcon West Table Summer (w/grimes Huntsville) Limiting Element Contingency Element ContMW Mossville Nelson Carlyss Citcon West Table Winter (w/grimes Huntsville) Limiting Element Contingency Element ContMW NONE NONE Table Summer (w/grimes Huntsville) Limiting Element Contingency Element ContMW Grimes 345/ ckt 1 Grimes 345/ ckt Grimes 345/ ckt 2 Grimes 345/ ckt Jasper Rayburn Cypress Hartburg 500kV Tubular Dobbin Longmire Lewis Creek Mossville Nelson Carlyss Citcon West Table Winter (w/grimes Huntsville) Limiting Element Contingency Element ContMW NONE NONE

24 Table Summer (w/grimes Huntsville) Limiting Element Contingency Element ContMW Grimes 345/ ckt 1 Grimes 345/ ckt Grimes 345/ ckt 2 Grimes 345/ ckt Grimes Bentwater Grimes Huntsville Dobbin Springbranch Lewis Creek - Longmire Tubular Dobbin Lewis Creek - Longmire Plantation Conroe Oak Ridge Porter Conroe2 Conroe1 Oak Ridge Porter Plantation Cedar Hill Oak Ridge Porter Rayburn Jasper Cypress Hartburg 500kV Newton Bulk Leach Cypress Hartburg 500kV Leach Toledo Bend Cypress Hartburg 500kV Helbig McLewis 230kV Cypress Hartburg 500kV Mossville Nelson Carlyss Citcon West Cypress 500/ Cypress 500/230kV transformer transformer Splendora Jacinto China Porter 230kV Eastgate Klemp Exposaic China Porter 230kV Table Winter (w/grimes Huntsville) Limiting Element Contingency Element ContMW 24 Grimes 345/ ckt 1 Grimes 345/ ckt Grimes 345/ ckt 2 Grimes 345/ ckt Grimes Bentwater Grimes - Huntsville Tubular Dobbin Lewis Creek - Longmire Rayburn Jasper Cypress Hartburg 500kV Buna Evadale Junction Rayburn Mill Creek

25 Evadale Evadale Junction Newton Bulk Leach Leach Toledo Bend Mossville Nelson Rayburn Mill Creek Cypress Hartburg 500kV Cypress Hartburg 500kV Carlyss Citcon West

26 7. ECONOMIC STUDY DATA 7.1 Quarry Rivtrin Economic Study Information Economic Analysis Year Upgrade Cost Annualized Cost Change in APC-d Benefit-to-Costof Upgrades APC Ratio 2015 $79,797,735* $13,964,604 $24M $84,590,215* $14,803,288 $22M Projects Included in the Economic Study Models 2015 Reference o Mossville Nelson Line Plan (Summer 2013) o Plantation Conroe Line Upgrade Plan (Summer 2013) o Cedar Hill Plantation Line Upgrade Plan (Summer 2013) o Conroe Switching Station Plan (Summer 2013) o DTEC Project GDS Supplied Project (2015) 2020 Reference o Mossville Nelson Line Plan (Summer 2013) o Plantation Conroe Line Upgrade Plan (Summer 2013) o Cedar Hill Plantation Line Upgrade Plan (Summer 2013) o Conroe Switching Station Plan (Summer 2013) o DTEC Project GDS Supplied Project (2015) o Toledo Bend Leach Line Upgrade Plan (Summer 2017) Projects include in the B/C calculations The tables below breakdown what projects were included in the cost portion of the B/C metric MAJOR ELEMENTS COSTS Quarry Rivtrin 345kV Project $79,697,735 Rivtrin Walker Line $100,000 TOTAL: $79,797,735 26

27 o Annualized Cost To calculate the Annualized Cost, the project cost is multiplied by a Carrying Charge. Annualized Cost = Upgrade Cost * Carrying Charge: ,797,735 * 17.5% = $13,964,604 MAJOR ELEMENTS COSTS Quarry Rivtrin 345kV Project $79,697,735 Rivtrin Walker Line $100,000 Egypt Panorama Line $1,429,120 Panorama Longmire Line $3,363,360 4L558TP91 Wyntex 4L558TP85 O&M Line TOTAL: $84,590,215 o Annualized Cost To calculate the Annualized Cost, the project cost is multiplied by a Carrying Charge. Annualized Cost = Upgrade Cost * Carrying Charge: 84,590,215 * 17.5% = $14,803, APC Breakdown 2015 Production Cost Import Cost Adjusted Production Year Savings (M$) Savings (M$) Cost Savings (M$) Production Cost Import Cost Adjusted Production Year Savings (M$) Savings (M$) Cost Savings (M$)

28 7.1.5 Additional gates Added Mt Zion Wyntex Tap FTLO Grime Quarry 345kV Wyntex Tap Huntsville FTLO Grimes Bentwater Wyntex Tap Huntsville FTLO Grimes Quarry 345kV Mt. Zion Wyntex Tap FTLO Grimes Bentwater Rivtrin Line 558/91 Tap FTLO Rivtrin Goree Rivtrin Goree FTLO Rivtrin Line 558/91 Tap Line 558/91 Tap Huntsville FTLO Rivtrin Goree Grimes Mt Zion FTLO Quarry Rivtrin 345kV Rivtrin Line 558/91 Tap FTLO Grimes Quarry 345kV Rivtrin Goree FTLO Grimes Quarry 345kV kv Solution Economic Study Information Economic Study Year Upgrade Cost Annualized Cost Change in APC-d Benefit-to-Costof Upgrades APC Ratio 2015 $24,668,806 $4,317,041 -$3M $141,780,842 $24,811,647 $22M Projects Included in the Economic Study Models 2015 Reference o Mossville Nelson Line Plan (Summer 2013) o Moss Bluff Nelson 230kV Line Plan (Summer 2012) o Toledo Bend Leach Line Upgrade Plan (Summer 2017) o Conroe Switching Station Plan (Summer 2013) o DTEC Project GDS Supplied Project (2015) 2015 Change Case All 2015 Reference Case Projects plus the following: o 3rd 345/ Grimes Supplemental 2020 Reference o Mossville Nelson Line Plan (Summer 2013) o Moss Bluff Nelson 230kV Line Plan (Summer 2012) o Toledo Bend Leach Line Upgrade Plan (Summer 2017) o Conroe Switching Station Plan (Summer 2013) o DTEC Project No $ (2015) 28

29 o Plantation Conroe Line Upgrade Plan (Summer 2013) o Cedar Hill Plantation Line Upgrade Plan (Summer 2013) o Jacinto Splendora Project Plan (Summer 2017) o Jacinto Splendora Line Plan (Summer 2016) o Splendora Apollo Line Plan (Summer 2016) o Orange County Plan (Summer 2017) 2020 Change Case All 2020 Reference Case Projects plus the following: o 3rd 345/ Grimes Supplemental o Grimes Bentwater Line Supplemental o Grimes Mt Zion Wyntex Tap Line Supplemental o Grimes Magnolia Anderson Sota Navasota Line Supplemental o Tubular Dobbin Line Supplemental o Porter Apollo Line Supplemental Projects Included in the B/C Calculations The tables below breakdown what projects were included in the cost portion of the B/C metric MAJOR ELEMENTS New 3 rd 345/ Grimes COSTS $24,668,806 TOTAL: $24,668,806 o Annualized Cost To calculate the Annualized Cost, the project cost is multiplied by a Carrying Charge. Annualized Cost = Upgrade Cost * Carrying Charge: 24,668,806 * 17.5% = $4,317,041 29

30 2020 MAJOR ELEMENTS COSTS New 3rd 345/ Grimes $24,668,806 Upgrade Grimes Bentwater Line $21,629,995 Upgrade Grimes Mt. Zion Wyntex Tap Line $20,132,921 Upgrade Grimes Magnolia Anderson Sota Navasota Line $32,697,280 Upgrade Tubular Dobbin Line $19,724,320 Upgrade Porter Apollo Line $22,927,520 TOTAL: $141,780,842 o Annualized Cost To calculate the Annualized Cost, the project cost is multiplied by a Carrying Charge. Annualized Cost = Upgrade Cost * Carrying Charge: 141,780,842 * 17.5% = $24,811, Grimes Mt. Zion Economic Study Information Economic Study Year Upgrade Cost Annualized Cost Change APC-d Benefit-to-Costof Upgrades in APC Ratio 2015 $14,966,895 $2,619,206 $0M N/A 2020 $14,966,895 $2,619,206 $1M Projects Included in the Economic Study Models 2015 Reference o Only projects that were included in the base model (i.e. Entergy Approved Construction Plan Projects) 2015 Change Case All 2015 Reference Case Projects plus the following: o Grimes Mt Zion Line Supplemental 2020 Reference o Only projects that were included in the base model (i.e., Entergy Approved Construction Plan Projects) 30

31 2020 Change Case All 2020 Reference Case Projects plus the following: o Grimes Mt Zion Line Supplemental Projects Include in the B/C calculations The tables below breakdown what projects were included in the cost portion of the B/C metric MAJOR ELEMENTS Upgrade Grimes Mt. Zion Line COSTS $14,966,895 TOTAL: $14,966,895 o Annualized Cost To calculate the Annualized Cost, the project cost is multiplied by a Carrying Charge. Annualized Cost = Upgrade Cost * Carrying Charge: 14,966,895 * 17.5% = $4,317, MAJOR ELEMENTS Upgrade Grimes Mt. Zion Line COSTS $14,966,895 TOTAL: $14,966,895 o Annualized Cost To calculate the Annualized Cost, the project cost is multiplied by a Carrying Charge. Annualized Cost = Upgrade Cost * Carrying Charge: 14,966,895 * 17.5% = $4,317,041 31

32 7.4 Grimes Huntsville Economic Study Information Economic Study Year Upgrade Cost Annualized Cost Change APC-d Benefit-to-Costof Upgrades in APC Ratio 2015 $24,442,906 $4,277,509 $6M $24,442,906 $4,277,509 $5M Projects Included in the Economic Study Models 2015 Reference o Only projects that were included in the base model (i.e. Entergy Approved Construction Plan Projects) 2015 Change Case All 2015 Reference Case Projects plus the following: o Grimes Mt Zion Huntsville Line Supplemental 2020 Reference o Only projects that were included in the base model (i.e. Entergy Approved Construction Plan Projects) 2020 Change Case All 2020 Reference Case Projects plus the following: o Grimes Mt Zion - Huntsville Line Supplemental Projects Include in the B/C calculations The tables below breakdown what projects were included in the cost portion of the B/C metric MAJOR ELEMENTS Upgrade Grimes Mt. Zion Huntsville Line COSTS $24,442,906 TOTAL: $24,442,906 32

33 o Annualized Cost To calculate the Annualized Cost, the project cost is multiplied by a Carrying Charge. Annualized Cost = Upgrade Cost * Carrying Charge: 24,442,906 * 17.5% = $4,277, MAJOR ELEMENTS Upgrade Grimes Mt. Zion - Huntsville Line COSTS $24,442,906 TOTAL: $24,442,906 o Annualized Cost To calculate the Annualized Cost, the project cost is multiplied by a Carrying Charge. Annualized Cost = Upgrade Cost * Carrying Charge: 24,442,906 * 17.5% = $4,277, Grimes - Ponderosa Economic Study Information Economic Study Year Upgrade Cost Annualized Cost of Upgrades 2015 $82,279,000 $ 14,398, $82,279,000 $ 14,398,825 Change in APC APC-d Benefit-to-Cost- Ratio $19,000, $18,700, Projects Included in the Economic Study Models 2015 Reference o Only projects that were included in the base model (i.e. Entergy Approved Construction Plan Projects) 33

34 2015 Change Case All 2015 Reference Case Projects plus the following: o Grimes Ponderosa Project Supplemental 2020 Reference o Only projects that were included in the base model (i.e. Entergy Approved Construction Plan Projects) 2020 Change Case All 2020 Reference Case Projects plus the following: o Grimes Ponderosa Project Supplemental Projects Include in the B/C calculations The tables below breakdown what projects were included in the cost portion of the B/C metric MAJOR ELEMENTS COSTS Upgrade Grimes Ponderosa Project $82,279,000 TOTAL: $82,279,000 o Annualized Cost To calculate the Annualized Cost, the project cost is multiplied by a Carrying Charge. Annualized Cost = Upgrade Cost * Carrying Charge: $82,279,000 * 17.5% = $ 14,398, MAJOR ELEMENTS COSTS Upgrade Grimes Ponderosa Project $82,279,000 TOTAL: $82,279,000 o Annualized Cost To calculate the Annualized Cost, the project cost is multiplied by a Carrying Charge. Annualized Cost = Upgrade Cost * Carrying Charge: $82,279,000 * 17.5% = $14,398,825 34

35 7.5.4 Additional gates Added Grimes- Mt Zion FTLO Grimes Ponderosa Grimes - Bentwater FTLO Grimes - Ponderosa Ponderosa - Conroe FTLO China - Porter Ponderosa - Conroe FTLO Longmire - Ponderosa Conroe - Goslin FTLO Conroe - Plantation 8. SUMMARY This report analyzed the effects of several sets of upgrades in the Entergy Texas region in terms of powerflow and economics. d upon the analysis presented here, it can be determined that there is the potential for alleviating overloads, removing constraints to transmission service, and reduction in congestion from several of the packages of upgrades. The Quarry - Rivtrin, 138 kv Solution, and the Grimes Ponderosa solutions all took care of the transmission overloads that are described in Section 6. The other solutions, Grimes Mt. Zion and Grimes Huntsville, provided some relief, but did not address all of the overloads in Section 6. In addition to the powerflow analysis, these upgrades were reviewed to determine if there are any economic benefits to those projects. The Quarry Rivtrin, Grimes Ponderosa, and Grimes Huntsville projects all displayed benefits in excess of their costs. However, with the Grimes Huntsville upgrade, there is still congestion that remains in Western Region that can be alleviated with the Quarry Rivtrin or Grimes Ponderosa projects. d on the analysis, it appears that the Quarry Rivtrin and Grimes Ponderosa projects are similar in terms of cost and performance. This report is intended to be a high-level analysis of these upgrades in order to provide the study participants with information such that they can make a decision on whether to pursue these upgrades further. If the study participants are so inclined, the next step would be to perform a more detailed analysis of a subset of the upgrades presented here in order to arrive at a more detailed breakdown of the benefits associated with the upgrades. Ultimately, any information produced from a more detailed analysis could be used to derive an allocation of costs amongst the participating study members. 35

36 9. APPENDIX A List of Priors OASIS PSE MW Begin End NRG Power Marketing 300 1/1/2013 1/1/ NRG Power Marketing 300 1/1/2013 1/1/ Cargill Power Markets 101 7/1/2012 7/1/ Cargill Power Markets 101 7/1/2012 7/1/ Cargill Power Markets 101 7/1/2012 7/1/ Cargill Power Markets 101 7/1/2013 7/1/ Cargill Power Markets 101 7/1/2013 7/1/ Cargill Power Markets 101 7/1/2013 7/1/ Entergy Services (SPO) 450 6/1/2012 6/1/ Entergy Services (SPO) 620 6/1/2012 6/1/ Entergy Services (SPO) 35 6/1/2012 6/1/ Entergy Services (SPO) 20 6/1/2012 6/1/ (undesignation) Entergy Services (SPO) 1 1/1/2012 1/1/ (undesignation) Entergy Services (SPO) 1 1/1/2012 1/1/ SMEPA 2 1/1/2012 1/1/ AECI 103 1/1/2012 1/1/ TEA 200 7/1/2012 7/1/ Cargill Power Markets /1/ /1/ Cargill Power Markets /1/ /1/ MOWR 20 4/1/2012 4/1/ Cargill Power Markets 98 12/1/ /1/ NRG Power Marketing 600 1/1/2014 1/1/ NextEra Energy 100 1/1/2012 1/1/ Cargill Power Markets /1/ /1/ Horizon Wind 100 7/1/2012 7/1/2017 SPP Tenaska Power Service 6 8/1/2011 6/1/2014 SPP Tenaska Power Service 44 8/1/2011 6/1/

37 10. APPENDIX B Economic Study Assumptions 10.1 Fuel Price Forecast Summary

38

39 2015 &

40 10.2 Wheeling Charges Wheeling charges are per MWh charges for moving energy from one area to another. GridView models this charge as a tariff for a particular interface. Commitment and dispatch are the two types of charges that can be assessed in GridView. A commitment charge is only applied to the initial startup of a unit and a dispatch charges is applied per MWh of an operating unit Emission Rates 40

41 11. APPENDIX C Metric Calculation 11.1 How is the APC calculated? Adjusted Production Cost (APC) is a measure of the impact on production cost savings by using LMPs, accounting for purchases and sales of energy between each area. The APC is calculated by: Entergy Production Cost Imports Exports APC 11.2 Import/Export Cost Calculation Interface for 1 hr (MW) The Average of (Simple LMP of Sending Area + Simple Average LMP of Receiving Area) Hourly Import/Export Cost Sum all 8760 hours of the year to get total Import/Export Cost for each interface Sum all Interface Import/Export Cost to get total Import/Export Cost 11.3 APC-d Benefit-to-Cost-Ratio Change in APC Annualized Transmission Cost* APC B/C Ratio *Annualized Transmission Cost is calculated using a 17.5% Carrying Charge. 41

42 12. APPENDIX D Entergy Approved Construction Plan Projects Construction Plan ID Project Name LE Proposed ISD (Planning) 10CP-EAI-006 Donaghey - Conway South 161 kv Line: Reconductor with 666 ACSS EAI Spring CP-EAI SMEPA (Plum Point): * Dell - Manilla 161kV Line: Upgrade to at least 247MVA EAI Spring CP-EAI SMEPA (Plum Point): * Manilla - Monette 161kV Line: Upgrade to at least 247MVA EAI Spring CP-EAI SMEPA (Plum Point): * Jonesboro North - Paragould South 161kV Line: Upgrade to at least 247MVA EAI Spring CP-EAI SMEPA (Plum Point): * Jonesboro North - Jonesboro 161kV Line: Upgrade to at least 247MVA EAI Spring CP-EAI-008 Beebe 115 kv Substation: Install 21.6 MVAR Capacitor Bank EAI Summer CP-EAI-009 Melbourne - Sage 161 kv Line: Upgrade line to at least 1200 A EAI Summer CP-EAI-010 Warren East 115 kv Substation: Install 10.8 MVAR Capacitor Bank EAI Summer CP-EAI-011 Parkin to Twist 161 kv - Replace line trap at Parkin (increase rating of line segment) EAI Winter CP-EAI Transmission Service (OG&E) Upgrade ANO - Russellville North 161 kv Line to 546 MVA EAI Summer CP-EAI Transmission Service (OG&E) Upgrade Russellville East - Russellville South 161 kv Line to 448 MVA EAI Summer CP-EAI-013 Osage Creek-Grandview New Line Build new 161 kv (At Least 1200 A) line from Grandview EAI Summer 2011 (Planned SPA 161 kv Substation tapped on the Eureka - Table Rock 161 kv Line) to Osage Creek 10CP-EAI Holland Bottoms (Cabot EHV): Construct new 500/161/115 kv substation Phase 1 Projects (2011) Tap the Keo - ISES 500 kv Line EAI Summer 2011 Tap the Cabot - Jacksonville North 115 kv Line Install 500 kv and 115 kv Busses and a 600 MVA 500 kv / 115 kv Autotransformer 10CP-EAI Holland Bottoms (Cabot EHV): Construct new 500/161/115 kv substation Phase 2 Projects(2012) EAI Summer 2012 Install 161 kv Bus and a 600 MVA 500 kv / 161 kv Autotransformer 10CP-EAI Transmission Service (Aquilla) Upgrade Hot Springs - Bismark 115 kv Line to 176 MVA EAI Winter CP-EAI Transmission Service (Aquilla) Upgrade Bismark - Alpine 115 kv Line to 176 MVA EAI Winter CP-EAI Transmission Service (Aquilla) Upgrade Alpine - Amity 115 kv Line to 176 MVA EAI Winter

43 Construction Plan ID Project Name 43 LE Proposed ISD (Planning) 10CP-EAI-017 Holland Bottoms - Hamlet 161 kv Line: Construct new 161 kv Line Convert Hamlet SS to a breaker station (Single Bus Single Breaker Scheme) Move the Quitman line from Gold Creek to Hamlet SS EAI Summer 2012 Move the Gravel Ridge line from Gold Creek to Hamlet SS Construct a line rated at least 1200 A from Hamlet SS to Holland Bottoms 10CP-EAI-019 Jonesboro to Hergett 161 kv Line: Upgrade 161 kv Line to at least 240 MVA EAI Summer CP-EAI-020 Benton North to Benton South: Construct New 115 kv Line Rated at least 170 MVA Install Switching Stations at Benton North and Benton South EAI Winter CP-EAI Westar Transmission Service Monette - Paragould 161kV Line: Upgrade to at least 246 MVA EAI Summer CP-EAI Westar Transmission Service Paragould Substation: Upgrade the switch B6673 from 600A to 2000A EAI Summer CP-EAI Westar Transmission Service Russellville South - Dardanelle Dam (SPA) 161kV Line: Upgrade to 416 MVA EAI Summer CP-EAI-023 Couch to McNeil 115kV Line: Upgrade jumpers at Couch EAI Summer CP-EAI-024 Lake Catherine 4 to Arklahoma 115 kv line: Upgrade risers at Arklahoma EAI Summer CP-EAI-025 Mabelvale to LR Mann Road 115 kv line: Replace switches and risers at Mabelvale and upgrade bus at LR Mann Road EAI Winter CP-EAI-026 Mabelvale to LR Alexander 115 kv line: Replace switches and risers at Mabelvale and upgrade bus at LR Mann Road EAI Winter CP-EAI-027 Russellville North to Russellville East 161 kv line: Replace jumpers at EAI Spring 2011 Russellville East 10CP-EAI-028 Morgan to Mayflower 115 kv line: Replace jumpers and bus at Mayflower EAI Summer CP-EAI-029 Maumelle East SS to Morgan 115 kv line: Replace switch and bus at Maumelle East SS EAI Summer CP-EAI-030 Heber Springs South to Heber Springs Industrial 161 kv line: Replace bus at Heber Springs South EAI Summer CP-EAI-031 West Memphis to Birmingham Steel 500 kv line flowgate: Replace 500 kv breaker, six line traps, and 2 switches at West Memphis 500 kv substation EAI Fall CP-EAI Sheridan South 500 kv FG Upgrade: Mabelvale 500 kv Substation replace 3 breakers, 13 switches, and 2 line traps EAI Spring CP-EAI Sheridan South 500 kv FG Upgrade: Sheridan 500 kv Substation replace 11 switches, and 6 line traps EAI Spring CP-EAI Sheridan South 500 kv FG Upgrade: White Bluff 500 kv Substation replace 5 switches, and 2 line traps EAI Spring CP-EAI Sheridan South 500 kv FG Upgrade: Eldorado 500 kv Substation replace 1 switch and 2 line traps EAI Spring CP-EAI-005 Russellville East to Russellville South 161 kv line: Replace jumpers and risers at Russellville East EAI Spring CP-EAI-009 Basin Springs Substation - Construct new substation EAI Summer CP-EAI-011 Pangburn 161 kv Substation: Relocate Rutherford 116 kv Cap Bank to Pangburn EAI Summer CP-EAI-013 Woodward to Pine Bluff Watson Chapel: Upgrade station equipment at Watson Chapel EAI Summer CP-EGL-002 Addis to Cajun 230 kv line - Upgrade Limiting Section With Double-Bundled ACAR (654 MVA) EGSL Winter CP-EGL-003 Carter and Elton: Upgrade 69 kv capacitor bank at Elton to 14 MVAR, Add 69 kv, 14 MVAR capacitor bank at Carter EGSL Fall CP-EGL-004 Construct New Youngsville 138 kv Distribution Substation EGSL Winter CP-EGL-005 Alchem - Monochem 138 kv Line: Upgrade 138 kv line to 275 MVA EGSL Summer