Generation Interconnection Feasibility Study For XXXXXXXXXXXXXXXXXXXXXX MW generator at new Western Refinary Substation

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1 Generation Interconnection Feasibility Study For XXXXXXXXXXXXXXXXXXXXXX MW generator at new Western Refinary Substation System Planning Section April, 2005

2 TABLE OF CONTENT 1 EXECUTIVE SUMMARY 3 2 COST ESTIMATES Scenario #1: General Electric (GE) 1x1 7FA combined cycle unit rated at approximately 250 MW Scenario #2: GE 1x1 7EA combined cycle unit rated at approximately 131 MW Scenario #3: GE 2x1 7EA combined cycle unit rated at approximately 250 MW 12 3 INTRODUCTION Assumptions Criteria Procedure Benchmark and Base Case Development List of Contingencies for Each Scenario QV Reactive Margin Analysis Short Circuit Generation Modeling 17 4 POWERFLOW and QV ANALYSES Results of power flow analysis Benchmark Case Scenario #1: General Electric (GE) 1x1 7FA combined cycle unit rated at approximately 250 MW Scenario #2: GE 1x1 7EA combined cycle unit rated at approximately 131 MW Scenario #3: GE 2x1 7EA combined cycle unit rated at approximately 250 MW Results of QV Voltage Stability analysis 26 5 SHORT CIRCUIT ANALYSES Short Circuit Study Modeling Results of the Short Circuit Analysis Conclusions 47-1-

3 6 APPENDICES 6.1 Appendix 1: Transmission and Facilities Study: Study Scope 6.2 Appendix 2: EPE FERC Form Appendix 3: Load & Resources 6.5 Appendix 4: Powerflow Maps 6.6 Appendix 5: Contingencies List 6.7 Appendix 6: Power Flow Study Results 6.8 Appendix 7: QV Voltage Stability Study Results -2-

4 1 EXECUTIVE SUMMARY System Planning (EPESP) received a Generator Interconnection Request on February 7, 2005 from XXXXXXXXXXXXXXXXXXXXX (XXX) and performed a Feasibility Study to determine the feasibility of interconnecting the requested new combined cycle generator at or near Western Refinery site in central El Paso. EPESP has performed a study that looks at three proposed generation scenario cases as specified in the Interconnection Study Request. The first case scenario modeled General Electric (GE) 1x1 7FA combined cycle unit rated at approximately 250 MW. The second case modeled GE 1x1 7EA combined cycle unit rated at approximately 131 MW. The third case scenario modeled GE 2x1 7EA combined cycle unit rated at approximately 250 MW. The proposed commercial operation date of the generator is June 1, Prier to this analysis EPE created a Study Scope (Scope) attached to this report in Appendix 1. This Scope discusses the system feasibility studies to be conducted by EPESP for the evaluation of the proposed facilities. EPESP used the Scope and subsequent verbal communications with XXX, XXXXXXXXXXXX (XX) and their consultants Burns & McDonnell as guides to perform the system studies, which included power flow, Q-V reactive margin, and short-circuit analyses. The objective of this Study was to identify potential major impacts associated with the addition of the proposed generation and to provide a good faith estimate of Network Upgrades, a good faith non-binding estimate of costs, and a good faith estimate of construction timing that would be needed to achieve a successful integration. Results of the studies were evaluated against technical constraints as defined in the Criteria section of the Study Scope, and remediation, with associated non-binding good faith estimated costs, are identified in the event the study discloses violations of these technical constraints and criteria with the proposed plant in operation. This analysis included evaluation of the proposed new generation for the Heavy Summer loading condition only. All three scenarios model new generation at the maximum output specified for each respected scenario. The proposed in-service date for the generator is June 1, Therefore, these generating units were analyzed as per the Heavy Summer case of The study assumed that the upgrades identified in the previous generation analyses were included in the preparation of the proposed Base Case. The sensitivity scenario without the proposed earlier Newman 5 combined cycle generator was run in addition to the main analysis. The total amount of MVA generated by the new proposed generators was distributed equally between all Western Electricity Coordinating Council (WECC) utilities, none of the increase in generation was assumed to be delivered to a specific point of interconnection. No actual transactions and/or schedules over any line or -3-

5 path were considered for the purpose of these analyses, only the actual flows on the transmission system. The results of this analysis show that due to the limitations of the existing transmission lines no additional firm power injections can be made at the Project location without major system upgrades. As per study request EPESP evaluated the Network Upgrades required to deliver the full plant MW output to the WECC grid for each of the requested scenarios. Network Upgrades & New Facilities Powerflow studies show that the studied power injections into the EPE system would create a number of overloads in the EPE transmission system. The recommended Network Upgrades to alleviate the overloads would depend on the study scenario and would include the following: Scenario #1: General Electric (GE) 1x1 7FA combined cycle unit rated at approximately 250 MW.. The new generator is taped into an existing El Paso Refinery - Ascarate 115 KV transmission line. Upgrade of section of this line between the point of interconnection of new generation and Ascarate substation by using double bundled 556 ACSR or similar conductor is required. The structural upgrade of the existing towers may also be required Tap into an existing Sunset North Ascarate 115 KV transmission line. The new section of this line between new generator and Ascarate need to be double -4-

6 bundled with 556 ACSR or similar conductor. The structural upgrade of the existing towers may be required 115/69 KV autotransformer at the new XX substation. The proposed autotransformer will be connected to the existing Ascarate-Austin 69 KV transmission line. New Western Refinery substation should be constructed. The acceptable configuration for this substation should include breaker and a half scheme for 115 KV portion of the substation. The ring bus breaker configuration is proposed for the 69 KV portion of this substation. The one line diagram for the new substation can be found below. -5-

7 Scenario #2: GE 1x1 7EA combined cycle unit rated at approximately 131 MW. The new generator is taped into an existing El Paso Refinery - Ascarate 115 KV transmission line. Upgrade of section of this line between the point of interconnection of new generation and Ascarate substation by using double bundled 556 ACSR or similar conductor is required. The structural upgrade of the existing towers may also be required New Western Refinery substation should be constructed. The acceptable configuration for this substation should include breaker and a half scheme for 115 KV portion of the substation. The ring bus breaker configuration is proposed for the 69 KV portion of this substation. The one line diagram for the new substation can be found below. -6-

8 Scenario #3: GE 2x1 7EA combined cycle unit rated at approximately 250 MW From the power flow perspective the scenario #3 is very similar to the Scenario #1 as both scenarios model the same size generation. Therefore the proposed by this study modifications are similar to the modifications proposed for the scenario #1. -7-

9 The new generator is taped into an existing El Paso Refinery - Ascarate 115 KV transmission line. Upgrade of section of this line between the point of interconnection of new generation and Ascarate substation by using double bundled 556 ACSR or similar conductor is required. The structural upgrade of the existing towers may also be required Tap into an existing Sunset North Ascarate 115 KV transmission line. The new section of this line between new Generator and Ascarate need to be double bundled with 556 ACSR or similar conductor. Additional 115/69 KV autotransformer at the new XX substation. The proposed autotransformer will be connected to the existing Ascarate-Austin 69 KV transmission line. New Western Refinery substation should be constructed. The acceptable configuration for this substation should include breaker and a half scheme for 115 KV portion of the substation. The ring bus breaker configuration is proposed for the 69 KV portion of this substation. The one line diagram for the new substation can be found below. -8-

10 Estimated Engineering for All Scenarios According to the EPE Substation Department, an additional investigation of the existing Ascarate 115 KV substation bus is required because of possible overload to the existing bus-bar facilities. This investigation may entail additional expenses for modification of the Ascarate 115 KV bus. The future impact study will provide further clarification of this issue. The costs of possible modifications to Ascarate Substation, if any, are uncertain at this time. The estimated time required to engineer, permit, and construct the Network Upgrade facilities for delivery is similar for all three scenarios and is at least 20 months. According to the study request, the XXX will engineer, permit, construct, and finance the proposed generation station including step up transformers. It must be noted that the purpose of this study was not to determine transmission service paths for the output of the new combined cycle generator but rather to determine the interconnection requirements of the new plant and does not make any warranty as the availability of transmission from the plant. Therefore, in the performance of the study, the proposed generation was distributed equally to all of the WECC utilities. Additionally, the study did not analyze all of the conditions under which the plant may operate, but the conditions as agreed to between EPESP and the XXX, as specified in the Study Scope. Hence, this study gives the parameters in which the system, with proposed generation included, will operate and the required EPE system modifications that will allow the interconnection of the proposed new generation. Further, this study was not meant to investigate all of the modes of operation of the proposed generators. Note that transmission service studies for the output on the new generation will evaluate directional transfers and may show some additional results from this generator interconnection analysis. The primary purpose of this analysis is limited to verifying whether the interconnection of the proposed generation to the EPE transmission system is technically feasible and what upgrades may be required for that interconnection only. Note also that the impact of the proposed interconnection of the proposed generation on neighboring utilities was noted but not evaluated in this analysis. The costs of the upgrades that may be necessary in order to enhance those systems were not determined. Additionally, the costs associated with purchasing of the proposed generators, step up transformer and any other associated equipment are not included in this analysis. The EPE interconnection costs will depend on the type of generation that will be finally chosen by the project, the costs for each proposed scenario evaluated in this analysis is included in the cost section of this analysis. Please note that these costs are good faith estimates and additional site engineering work may require added costs. The results of short circuit, QV and power flow analyses performed by EPESP are largely dependent on the quality of data provided to the EPESP for this study. XXX and XX -9-

11 have stated that the data provided is the best data available and EPESP is not be responsible for any inaccuracies in the results of this analysis resulting from inaccurate data. -10-

12 2 COST ESTIMATES To provide an interconnection and delivery to the grid for the Customer requested generation at the new generation station at the XXXXXXXXXXXXXXin central El Paso Network Upgrades must be made on the EPE transmission system. The sensitivity scenario without the proposed Newman 5 combined cycle generator appear to require substantially lower cost for the upgrades of existing substation breakers at Newman substation. This difference is reflected in Scenario Totals. A good faith best estimate of the total cost for the upgrades for each scenario are as follow: 2.1 Scenario #1: General Electric (GE) 1x1 7FA combined cycle unit rated at approximately 250 MW. Ascarate New Generator 115 kv Transmission line upgrade $700,000 Taping in and out to the Ascarate Sunset North 115 KV line New Ascarate XX portion is double bundled $1,100,000 New Generator to Western 115 kv Transmission line upgrade $1,643,000 Western to Austin 115 kv Transmission line upgrade $1,060,000 New Western Refinery substation $6,197,000 (69 & 115 KV buses; equipment, labor etc.,) Upgrade of the existing EPE breakers as per Short Circuit analysis $1,953,000 (With Newman 5 generation) Estimated TOTAL for scenario 1 (with Newman 5): $12,653,000 Upgrade of the existing EPE breakers as per Short Circuit analysis $189,000 (Without Newman 5 generation) Estimated TOTAL for scenario 1 (without Newman 5) $10,889,

13 2.2 Scenario #2: GE 1x1 7EA combined cycle unit rated at approximately 131 MW. Ascarate New Generator 115 kv Transmission line upgrade $700,000 New generator substation (115 KV only) $1,900,000 Upgrade of the existing EPE breakers as per Short Circuit analysis $1,701,000 (with Newman 5 generation) Estimated TOTAL for scenario 2 (with Newman 5): $4,301,000 Upgrade of the existing EPE breakers as per Short Circuit analysis $63,000 (without Newman 5 generation) Estimated TOTAL for scenario 2 (without Newman 5) $2,663, Scenario #3: GE 2x1 7EA combined cycle unit rated at approximately 250 MW Ascarate New Generator 115 kv Transmission line upgrade $700,000 Taping in and out to the Ascarate Sunset North 115 KV line New Ascarate XX portion is double bundled $1,100,000 New Generator to Western 115 kv Transmission line upgrade $1,643,000 Western to Austin 115 kv Transmission line upgrade $1,060,000 New Western Refinery substation $6,197,000 (69 & 115 KV buses; equipment, labor etc.,) Upgrade of the existing EPE breakers as per Short Circuit analysis $1,701,000 (with Newman 5 generation) Estimated TOTAL for scenario 3 (with Newman 5): $12,401,000 Upgrade of the existing EPE breakers as per Short Circuit analysis $189,000 (without Newman 5 generation) Estimated TOTAL for scenario 3 (without Newman 5) $10,889,

14 The estimated cost shown is an indicative preliminary budgetary cost in 2005 dollars and is 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 EPE facilities. This estimate does not include any costs for any Customer-owned, supplied, and installed equipment or associated design and engineering. This estimate also does not include any costs that may be required for other entities systems. The better cost estimates may be available upon execution of the Facilities Studies that should be done at a later time. -13-

15 3 INTRODUCTION On February 7, 2005, the XXXXXXXXXXXXXXXXXXXXXXXXXXXXXXXX (XXX) submitted to System Planning section of (EPESP) an Interconnection Request for a new power plant to be located at the XXXXXXXX (XX) in central El Paso. The proposed generation would be a joint venture between XX and XXXXXXXXXXXXXXXX (XXX). The EPESP performed a study that looked at all three scenario cases specified in the Interconnection Study Request. The first case scenario model General Electric (GE) 1x1 7FA combined cycle unit rated at approximately 250 MW. The second case model GE 1x1 7EA combined cycle unit rated at approximately 131 MW. The third case scenario model GE 2x1 7EA combined cycle unit rated at approximately 250 MW. This Interconnection Feasibility Study preliminarily evaluated the feasibility of the proposed interconnection to the EPE Transmission System. It consisted of power flow, QV and short circuit analyses. The power flow analysis identified thermal and voltage criteria violations resulting from the interconnection and also identified Network Upgrades required to deliver the full amount of proposed generation to the WECC grid. The QV analysis determined the impact of the proposed generation on the EPE transfer capabilities criteria. The short circuit analysis identified circuit breaker short circuit capability limits exceeded as a result of the Interconnection and delivery of the proposed generation. This analysis included evaluation of the proposed new generation for the Heavy Summer loading condition only. All three scenarios model new generation at the maximum output specified for each respected scenario. The proposed in-service date for the generator is the first of June, Therefore, these generating units were analyzed as per Heavy Summer case of The purpose of this study was not to determine transmission service paths for the new combined cycle generator but rather to determine the interconnection requirements of the new plant. Therefore, in the performance of the study, the proposed generation was distributed equally to all of the WECC utilities. Additionally, the study did not analyze all of the conditions under which the plant may operate, but the conditions as agreed to between EPE departments, as specified in the Study Scope. Hence, this study gives the parameters in which the system, with proposed generation included, will operate and the required EPE system modifications that will allow the interconnection of the proposed new generation. Further, this study was not meant to investigate all of the modes of operation of the proposed generators. The study assumed that the upgrades identified in the previous generation analyses were included in the preparation of the proposed Base Case. The sensitivity scenario without the proposed earlier Newman 5 combined cycle generator was run in addition to the main analysis. -14-

16 Future Transmission Studies will evaluate directional transfers and may show results different from this generator interconnection analysis. The primary purpose of this analysis is limited to verifying whether the interconnection of the proposed generation to the EPE transmission system is technically feasible and what upgrades may be required for that interconnection only. The costs associated with purchasing of the proposed generators and step up transformer are not included in this analysis. The EPE interconnection costs will depend on the type of generation that will be finally chosen by XXX and XX, the costs for each proposed scenario evaluated in this analysis will be included in the cost section of this analysis. Please note that these costs are intended as a good faith best estimates and additional site engineering work may require added costs. 3.1 ASSUMPTIONS The following assumptions are consistent for all study scenarios unless otherwise noted. The cost of the additional generators and associated equipment including step-up transformers etc,. is separate and is not included in this study The costs associated with modifications and/or additions of any of EPE equipment to allow for the interconnection does not include the cost of relaying, communication and SCADA equipment. These costs will be determined with the final engineering design of the interconnection (in the Facilities Study) 3.2 CRITERIA The reliability criteria standards used by EPE in performing this study are readily acceptable WECC and EPE standards and have been included in Appendix 1 (Generation Interconnection and Facilities Study: Study Scope) and in Appendix 2 (EPE FERC Form 715). EPE adheres to NERC/WECC Reliability Criteria, as well as internal Company criteria for planning studies. During system intact conditions, these criteria are used to maintain transmission system bus voltages between 0.95 and 1.05 per-unit of system nominal / normal conditions, and steady state power flows within 1.0 per-unit of all elements thermal (continuous current or MVA) ratings. Operationally, EPE tries to maintain a transmission system voltage profile ranging from 1.02 per-unit or higher at generation buses, to 1.0 per-unit or higher at transmission load buses. Following a single contingency element outage, transmission system steady state bus voltages must remain within per unit to 1.05 per-unit, and power flows within 1.0 per-unit of the elements emergency thermal ratings. Impacts on neighboring utilities were monitored, but not fully addressed in the scope of this study. Should the Customer continue this request and move on to the System Impact Study, all impacts on EPE and neighboring utilities will be identified. It is not expected that neighboring utilities may have an -15-

17 interest in participating in future studies because of negligible impact of the proposed new generation on their systems. 3.3 PROCEDURE As previously mentioned, the system study analyses conducted by EPE included powerflow, Q-V reactive margin, and short-circuit analyses. Detailed discussions for each study have been included in this report and may be quickly referenced through the Table of Contents. The following procedural considerations were employed: Benchmark and Base Case Development The 2008 Heavy Summer base case with and without the proposed generation was developed in order to examine the impact of that additional generation on EPE s transmission system for each scenario. The Benchmark 2008 case was established by integrating the latest available EPE and New Mexico system representations with the existing WECC 2008 base case. Criteria violations, if any, were flagged. Consequently, if criteria violations also existed in the Without Additional Generation power flow cases, no action or modification was taken that would penalize the proposed generating plant. Load and resource information for the 2008 Benchmark base cases are included in Appendix 3. EPE powerflow base case one-line diagrams are located in Appendix List of Contingencies for Each Scenario Powerflow analyses were performed for cases both with and without the proposed new generation. These analyses determined whether any line/transformer loading conditions and/or voltage conditions violated criteria. First the system was modeled with all lines in service. Contingencies were then simulated. The same contingencies were simulated on all scenarios and are identified in Appendix 5. The contingencies selected were based on those most likely to stress the EPE system, and prudent engineering judgment QV Reactive Margin Analysis EPE performed Q-V reactive margin analyses for the 2008 Heavy Summer case in order to verify that the EPE reactive power margin criteria was being met under the worst contingencies. This Q-V analysis was based on WECC methodology, which stipulates increasing EPE area load by 5% above that of the base case, and then observing whether a positive reactive margin occurs under the worst contingency scenario. Prior analyses have shown that the worst single contingencies impacting reactive margin are the Springerville-Luna 345 kv line and the Luna-Diablo 345 kv line. The buses most impacted are the 345 kv buses -16-

18 at Luna, Hidalgo, Arroyo, Caliente, and Newman. Q-V plots were then created identifying the reactive margins available at key 345 kv buses Short Circuit Short circuit studies, with and without the addition of the proposed generation, were performed. These short circuit studies consisted of three-phase and phaseto-ground bus fault simulations at the new substation as well as at those substations with direct transmission line connections into the new substation. The objective of this study was to determine if the substation breakers would safely respond to fault currents for either scenario. This analysis identified those breakers where ratings were exceeded. 3.4 GENERATION MODELING The proposed generator additions were modeled as per XXX/XX supplied data. The new combined cycle unit was interconnected to the new Western Refinery substation just North of the existing Chevron substation. -17-

19 4 POWERFLOW and QV ANALYSES Power flow studies were based on the WECC 2008 heavy summer base case. The studies were performed using the GE PSLF program. Proposed generation was modeled at the new Western Refinery substation. The project generation was distributed evenly among all WECC utilities by raising their load and adjusting the WECC system interchange schedules. Efforts were made to include in the models all transmission projects expected to be inservice for the 2008 heavy summer season. The studies assumed 2008 peak summer demand conditions in the EPE system and in other utility systems. The sensitivity scenario without the proposed earlier Newman 5 combined cycle generator was run in addition to the main analysis. In order to model this sensitivity scenario some generation redispatch was required. Two redispatch scenarios were analyzed. The original (main) scenario had Newman 5 on line at full output (this scenario will be referred as a first redispatch scenario). The second redispatch scenario had Newman 5 turned off (this scenario will be referred as a second redispatch scenario). In determining the modifications required for interconnecting the proposed generators Power flow analyses were performed for all of the scenarios under this study. A base case was first developed for each scenario, showing the system with all lines in service. Voltage and/or loading criteria violations in the base cases were noted. Contingency powerflow analyses were also performed for all of the scenarios under this study. A list of the contingencies analyzed is shown in Appendix 5. For these contingencies, only criteria violations that affect EPE elements (if any) are discussed in detail. Bus voltage deviations between the base case and all contingency conditions (if any) were investigated and discussed both with and without proposed generation. The results of this study indicate that with the existing system, there is no available capacity across the EPE system. Some transmission capability may be available depending on marketing activities, dispatch patterns, demand levels and the status of transmission facilities. This study determined the Network Upgrades that would be required to accept the full power from the proposed generation for the conditions studied. For the study, the project generation was scheduled to be at maximum. The results of this analysis for each individual scenario are included in the next section 4.1 Results of power flow analysis The aforementioned scenarios were used to determine whether modifications to the EPE transmission system were required to allow the proposed new generator to be -18-

20 interconnected to the EPE system. These scenarios considered various options for the proposed generation plant and are based on the no directional sale conditions Benchmark case. Any EPE system modifications required before the addition of the proposed generation can not be attributed to the generation addition and should be considered as a pre existing condition which should be addressed by EPE along. Hence, the analysis of the EPE system prier to the addition of the proposed generation was performed. This analysis modeled both redispatch scenarios mentioned earlier in this section. The results of these evaluations were used for the comparison with corresponding generation scenarios. The results of this analyses revealed several transmission lines that didn t meet an existing EPE reliability criteria and therefore required an upgrade independent on the addition of the proposed generation. These lines include the following transmission lines: Austin-Dyer 69 KV transmission line loaded at 100.5% of its normal rating for all lines in service scenario with Newman 5 generator modeled. This line was planned for the upgrade in 2012 but was rescheduled to be upgraded this year. Newman-Sherman 115 KV transmission line loaded at 100.4% of its normal rating for all lines in service scenario with Newman 5 generator modeled. This line was planned for the upgrade in 2010 or when the Newman 5 generator goes on line. Please note that this overload only occurs when the proposed Newman 5 generator is modeled. Newman-Fort Bliss KV transmission line was found to be loaded at 100% of its normal rating for all lines in service scenario with Newman 5 generator modeled. This line was planned for construction in 2008 and just needs a bigger wire then was originally planned Scenario #1: General Electric (GE) 1x1 7FA combined cycle unit rated at approximately 250 MW. The proposed new generation station thought to be located adjacent to the existing Chevron substation and was logically connected to the existing Western-Chevron 115 KV line. The addition of the new generation overloaded an existing link between new generation and existing Ascarate substation over an acceptable continuous and emergency rating even under all lines in service scenario. The contingency analyses reveal several other critical (above emergency rating) overloads. These overloads are listed below. The overloading of abovementioned transmission link between new generation station and Ascarate 115 KV substation is not included in the listing below because this link was overloaded well over emergency rating for practically all of the contingencies considered. -19-

21 First Redispatch Scenario Contingency Overloaded lines % overload* CHEVRON ASCARATE CHEVSO EPREFGEN % AUSTIN_N CHEVSO % * - % overload over acceptable rating. Acceptable rating is a continuous element rating for the all lines in service scenarios and emergency rating for all contingency scenarios. Second Redispatch Scenario Contingency Overloaded lines % overload* CHEVRON ASCARATE CHEVSO EPREFGEN % AUSTIN_N CHEVSO % * - % overload over acceptable rating. Acceptable rating is a continuous element rating for the all lines in service scenarios and emergency rating for all contingency scenarios. The recommended Network Upgrades to alleviate the overloads and accommodate this generation scenario are listed below Upgrade of an existing 115 KV transmission path between Austin North and Ascarate substations by using double bundled 556 ACSR or similar conductor. The structural upgrade of the existing towers will be required. Tap into an existing Sunset North Ascarate 115 KV transmission line. The new section of this line between EPRefinery and Ascarate need to be double bundled with 556 ACSR or similar conductor. One line diagram for the proposed upgrades for Scenario #1 After the proposed above modifications were placed in service it was noticed that the contingency of an existing 115/69 KV autotransformer at Ascarate substation -20-

22 causes an overload in access of the emergency rating (101% of transformer emergency rating) of a second 115/69 KV autotransformer at Ascarate. To remedy this overload an additional 115/69 KV autotransformer is required. Unfortunately, Ascarate 69 KV substation doesn t have any room for expansion. For this reason the addition of 115/69 KV autotransformer was proposed at the new XX substation. The proposed autotransformer will be connected to the existing Ascarate-Austin 69 KV transmission line According to the EPE Substation Department, additional investigation of the existing Ascarate 115 KV substation bus is required under this scenario. This investigation may entail additional expenses for modification of the Ascarate 115 KV bus. The future impact study will provide a further investigation. In order to accommodate new generation station and the proposed above modifications a new substation should be constructed. The acceptable configuration for this substation should include Breaker And a Half scheme for 115 KV portion of the proposed substation and Ring Bus for 69 KV portion of this substation. The diagram for new substation can be found below Several alternative remediations were considered in this analysis. These solutions included either construction of a new 115 KV transmission line to Copper or construction -21-

23 of a new transmission line to Ascarate. The line to Copper, however, appeared to be a lot more costly then the proposed scenario and would require an acquisition of an expensive right of way. The construction of the new line to Ascarate would require the rebuilding of the Ascarate 115 KV substation, which would be very expensive and hard to schedule. There were no voltage problems associated with this scenario The proposed above system modifications appeared to be the most cost effective and feasible solution available and therefore are the only solution proposed by this analysis Scenario #2: GE 1x1 7EA combined cycle unit rated at approximately 131 MW. Second generation scenario modeled a much smaller 131 MW combine cycle unit and therefore the resulting overloads appear to be less pronounced than in Scenario #1. The addition of the new generation overloaded an existing path between new generation and Ascarate 115 KV substation for the First Redispatch Scenario in excess of normal line rating under the all lines in service scenario. Contingency Overloaded lines % overload* Base Case CHEVRON EPREFGEN % CHEVRON ASCARATE % * - % overload over acceptable rating. Acceptable rating is a continuous element rating for the all lines in service scenarios and emergency rating for all contingency scenarios. The basic recommended Network Upgrades to alleviate the above listed overload and accommodate this generation scenario include the following: Upgrade the section of an existing El Paso Refinery - Ascarate 115 KV transmission path between the future location of new generation station and Ascarate substation by using double bundled 556 ACSR or similar conductor. The structural upgrade of the existing towers may be required. -22-

24 One line diagram for the proposed upgrades for Scenario #2 In order to accommodate new generation station a new 115 KV substation should be constructed. The acceptable configuration for this substation should include breaker and a half scheme. The substation diagram for the new substation can be found on the next page There were no voltage problems associated with this scenario. -23-

25 4.1.4 Scenario #3: GE 2x1 7EA combined cycle unit rated at approximately 250 MW Scenario #3 is similar to the scenario #1 as it models the same amount of generation. Therefore the results are similar to the results of Scenario #1. The addition of the new generation overloaded an existing link between new generation and existing Ascarate substation way over an acceptable continuous and emergency rating even under all lines in service scenario. The proposed new generation station thought to be located adjacent to the existing Chevron substation and was logically connected to the existing Western-Chevron 115 KV line. The addition of the new generation overloaded an existing link between new generation and existing Ascarate substation over an acceptable continuous and emergency rating even under all lines in service scenario. The contingency analyses reveal several other critical (above emergency rating) overloads. These overloads are listed below. The overloading of abovementioned transmission link between new generation station and Ascarate 115 KV substation is not included in the listing below because this link was overloaded well over emergency rating for practically all of the contingencies considered. First Redispatch Scenario Contingency Overloaded lines % overload* CHEVRON ASCARATE CHEVSO EPREFGEN % AUSTIN_N CHEVSO % * - % overload over acceptable rating. Acceptable rating is a continuous element rating for the all lines in service scenarios and emergency rating for all contingency scenarios. Second Redispatch Scenario Contingency Overloaded lines % overload* CHEVRON ASCARATE CHEVSO EPREFGEN % AUSTIN_N CHEVSO % * - % overload over acceptable rating. Acceptable rating is a continuous element rating for the all lines in service scenarios and emergency rating for all contingency scenarios. The recommended Network Upgrades to alleviate the overloads and accommodate this generation scenario are listed below Upgrade of an existing 115 KV transmission path between Austin North and Ascarate substations by using double bundled 556 ACSR or similar conductor. The structural upgrade of the existing towers will be required. -24-

26 Tap into an existing Sunset North Ascarate 115 KV transmission line. The new section of this line between EP Refinery and Ascarate need to be double bundled with 556 ACSR or similar conductor. One line diagram for the proposed upgrades for Scenario #3 After the proposed above modifications were placed in service it was noticed that the contingency of an existing 115/69 KV autotransformer at Ascarate substation causes an overload in access of the emergency rating (101% of transformer emergency rating) of a second 115/69 KV autotransformer at Ascarate. To remedy this overload an additional 115/69 KV autotransformer is required. Unfortunately, Ascarate 69 KV substation doesn t have any room for expansion. For this reason the addition of 115/69 KV autotransformer was proposed at the new XX substation. The proposed autotransformer will be connected to the existing Ascarate-Austin 69 KV transmission line According to the EPE Substation Department, additional investigation of the existing Ascarate 115 KV substation bus is required under this scenario. This investigation may entail additional expenses for modification of the Ascarate 115 KV bus. The future impact study will provide a further investigation. In order to accommodate new generation station and the proposed above modifications a new substation should be constructed. The acceptable configuration for this substation should include Breaker And a Half scheme for 115 KV portion of the proposed substation and Ring Bus for 69 KV portion of this substation. The diagram for new substation can be found below -25-

27 Several alternative remediations were considered in this analysis. These solutions included either construction of a new 115 KV transmission line to Copper or construction of a new transmission line to Ascarate. The line to Copper, however, appeared to be a lot more costly then the proposed scenario and would require an acquisition of an expensive right of way. The construction of the new line to Ascarate would require the rebuilding of the Ascarate 115 KV substation, which would be very expensive and hard to schedule. There were no voltage problems associated with this scenario The proposed above system modifications appeared to be the most cost effective and feasible solution available and therefore are the only solution proposed by this analysis. 4.2 Results of QV Voltage Stability analysis For all scenarios in this analysis, the addition of the proposed generation provided a better voltage support and positive impact on the existing stability limits. The voltage pattern had improved and the critical VAR margins had increased. The sample QV curves reflecting before and after transmission voltage margin scenarios can be found in the Appendix 7 of this analysis. -26-

28 5 SHORT CIRCUIT ANALYSES With the addition of a proposed combined cycle generating station, the available fault current on EPE s system increases. Therefore, as part of this Feasibility Study, a short circuit study was performed to determine if the additional fault current on the EPE system due to the proposed new generator does not exceed the interruption ratings of EPE s existing substation circuit breakers. Note that the individual generator MVA was provided by XX and Burns & McDonald and differed from the generator MW output as modeled in the powerflow part of the Feasibility study. 5.1 Short Circuit Study Modeling The new generation proposed by XXX is sited at a new WR 115 kv substation. The combustion and steam-turbine generator portion of the proposed combined-cycle plant was analyzed for the following: Scenario 1: Connected to the EPE 115 and 69 kv systems through a 132/176/200 MVA, 18/115 kv step-up transformer per generator (1 CT, 1 ST, FA generator scenario). See Page 23 for substation diagram. Scenario 2: Connected to the EPE 115 kv system through a 72/96/120 MVA, 13.8/115 kv step-up transformer per generator (1 CT, 1 ST, EA generator Scenario). See Page 25 for substation diagram. Scenario 3: Connected to the EPE 115 and 69 kv systems through a 72/96/120 MVA, 13.8/115 kv step-up transformer per generator (2 CT, 1 ST, EA generator Scenario). See Page 28 for substation diagram. For Scenario 1, each of two generator step-up transformers has an impedance of 9.0 % on a 132 MVA base. For Scenario 2 and 3, this was studied with each of two generator stepup transformers having an impedance of 9.0 % on a 72 MVA base and each of three generator step-up transformers has an impedance of 9.0 % on a 72 MVA base, respectively. The step-up transformer impedance modeled in the short circuit analysis for both step-up transformers was: -27-

29 Z (step-up) = J per unit (100 MVA base) for Scenario 1 (FA generator step-up transformers) Z (step-up) = J0.125 per unit (100 MVA base) for Scenarios 2 and 3 (EA generator step-up transformers) The R part of the generator step-up transformer impedance was not modeled due to lack of data. This, however, is regarded as of minor consequence given that the R component is much less than the X component and the short-circuit values yielded would have been nearly identical (although slightly lower in amperes) than just modeling the X component as in this study. The New Generators have the following reactance values on the generator MVA base (220 MVA): Scenario 1, Combustion-Turbine (FA Generators): X d = Direct Axis Synchronous Reactance = 2.01 per unit X d = Direct Axis Transient Reactance = 0.22 per unit X d = Direct Axis Sub-transient Reactance = per unit Scenario 2 and 3, Combustion-Turbine (EA Generators): X d = Direct Axis Synchronous Reactance = 2.28 per unit X d = Direct Axis Transient Reactance = per unit X d = Direct Axis Sub-transient Reactance = per unit Scenario 1, Steam-Turbine (FA Generators): X d = Direct Axis Synchronous Reactance = 2.01 per unit X d = Direct Axis Transient Reactance = 0.22 per unit X d = Direct Axis Sub-transient Reactance = per unit Scenarios 2 and 3, Steam-Turbine (EA Generators): X d = Direct Axis Synchronous Reactance = 2.28 per unit X d = Direct Axis Transient Reactance = per unit X d = Direct Axis Sub-transient Reactance = per unit The generator step-up reactance values were converted to a 100 MVA base and the generator reactance values were input on the machine base (220 MVA). Both were used to model the New Generators in the short circuit study. -28-

30 Additional Southern New Mexico Generation: In addition to the new generation connected to the WR 115 kv bus, existing and potential projects in southern New Mexico was also modeled in the short circuit analysis in two ways: (1) without potential generation at the Newman 115 kv bus but with three existing and two generation projects ahead of the WR generation in the EPE interconnection queue. These generation projects included the following: 149 MW of generation at Afton Substation interconnected to the Luna-Afton- Newman 345 kv line (existing). 550 MW of generation interconnected at the Luna 345 kv Substation. 160 MW of generation interconnected near Lordsburg, New Mexico. (existing). 150 MW of generation interconnected at Lordsburg, New Mexico (existing). 130 MW of new generation interconnected at Afton 345 kv Substation and, (2) with potential generation at the Newman 115 kv bus but and in addition three existing and two potential generation projects modeled. These generation projects included the following: 149 MW of generation at Afton Substation interconnected to the Luna-Afton- Newman 345 kv line (existing). 550 MW of generation interconnected at the Luna 345 kv Substation. 160 MW of generation interconnected near Lordsburg, New Mexico. (existing). 150 MW of generation interconnected at Lordsburg, New Mexico (existing). 130 MW of new generation interconnected at Afton 345 kv Substation and, 290 MW of new generation interconnected at Newman 115 kv Substation These additional generators were modeled in the study to provide a worst case scenario in the event that all are interconnected into EPE s system before the proposed new generation is interconnected. Maximum fault currents were then determined at the WR 115 kv (and, when modeled, the WR 69 kv) bus and other EPE substations of interest or importance. Maximum fault currents were then determined at all buses that were one bus beyond the new WR interconnection bus(es). These included the following: Ascarate 115 kv Austin 115 kv Austin 69 kv Chaparal 115 kv Chevron 115 kv Copper 115 kv -29-

31 Cromo 115 kv Diablo 115 kv El Paso Refining/Chevron South 115 kv NEW WR 115 kv NEW WR 69 kv Newman 115 kv Rio Grande 115 kv Rio Grande 69 kv Sunset North 115 kv Vista 115 kv The resulting fault current was then compared to the circuit breaker interruption ratings of the breakers at each of the above mentioned substations. Note that the information used for the short-circuit part of the analysis was updated as of April Results of the Short Circuit Analysis The circuit breakers used in the southern New Mexico system at 345 kv, 115 kv, and 69 kv buses vary between the substations. The following is a list of the existing circuit breakers, along with the interruption rating, at each of the relevant substations: Breaker Breaker Interruption Substation Voltage Number Rating (Amps) Ascarate B 26, B 26, B 26, B 31, B 26, B 21, B 40, B 19, B 29, B 35, B 21,000 Austin 115 A , A , A , A ,

32 Breaker Breaker Interruption Substation Voltage Number Rating (Amps) Austin B 28, B 28, B 28, B 28, B 28, B 28, B 28, B 28, B 28, B 28, B 28, B 28, B 28, B 28, B 28, B 28, B 28, B 28,000 Caliente B 40, B 40, B 40, B 40, B 40, B 40, B 40, B 40, B 40,000 Chaparral B 40, B 40, B 40,000 Chevron B 31, B 31, B 31, B 31,500 Copper B 20, B 20, B 40, B 25,

33 Breaker Breaker Interruption Substation Voltage Number Rating (Amps) Cromo B 40, B 40, B 40, B 40,000 Diablo B 40, B 40, B 40, B 40, B 40, B 31, B 40,000 El Paso Refining B 31, B 31, B 31, B 31,500 Newman , , , N , , , N , , N , , , N , , N , , N , N , , N , N , , N , N ,

34 Breaker Breaker Interruption Substation Voltage Number Rating (Amps) Rio Grande B 40,000* B 23, B 23, B 40, B 40, B 23, B 23, B 40, B 40,000* B 23, B 23, B 40,000 Rio Grande ,000* , , , , , , , B 31, , , B 31, , ,000 Sunset North B 25, B 31, B 20, B 25,000 Vista B 40, B 25, B 40, B 25, B 25, B 25,000 * Currently these breakers have ratings ranging between 19,000-20,000 amperes. They are expected to be replaced with breakers having 40,000 ampere ratings as part of EPE s normal breaker replacement program. -33-

35 The short circuit analysis was first performed with no new generation at WR 115 kv (all other potential generation projects in). This gave the base case fault duties of the circuit breakers. The new generation at WR 115 kv was then modeled. The short circuit study was then reanalyzed (with all other potential generation projects in). The incremental between the three studies gave the impact of the New Generators on the existing circuit breakers in the Southern New Mexico system. A. Scenario 1A. 1x1 7FA combined cycle generator (Without Newman #5) For this short-circuit run, a new combustion-turbine and a new steam-turbine generator in a combined-cycle configuration are connected through a 132/176/200 MVA, 18/115 kv step-up transformer per generator (FA generators) with an impedance of 9.0 % on a 132 MVA base. The generation is located at the WR substation where there are connections from both a new WR 115 kv and 69 kv bus with a 115/69 kv WR autotransformer to the EPE 115 and 69 kv systems. The other proposed projects previously listed are also included in this configuration (no proposed generation at Newman 115 kv bus). The short circuit (fault) currents follow. Three Phase Line to Ground: No New Generation With New Generation at NEW WR115 kv at NEW WR115 kv Substation Faulted Fault Current (Amps) Fault Current (Amps) Ascarate 115 kv 16,091 23,655 Austin 115 kv 16,292 20,957 Austin 69 kv 15,876 18,669 Caliente 115 kv 14,220 15,440 Chaparal 115 kv 14,022 14,508 Chevron 115 kv 15,830 23,583 Copper 115 kv 14,855 19,751 Cromo 115 kv 17,207 18,900 Diablo 115 kv 18,047 19,735 El Paso Refining 115 kv 15,724 21,764 NEW WR 115 kv N/A 24,003 NEW WR 69 kv N/A 23,098 Newman 115 kv 25,541 27,728 Rio Grande 115 kv 19,987 22,482 Rio Grande 69 kv 18,637 19,677 Sunset North 115 kv 12,439 14,104 Vista 115 kv 12,904 14,

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