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2018 Gridliance High Plains Planning Study Final Transmission Plan

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2018 Gridliance High Plains Planning Study Final Transmission Plan April 1, 2019 2018 GridLiance High Plains Planning Study Final Transmission Plan Transmission Planning April 1, 2019 April 1, 2019 Executive Summary GridLiance High Plains LLC (GridLiance) performed its 2018 annual system assessment in compliance with the GridLiance Open Access Transmission Tariff Attachment K requirements. This assessment utilized the GridLiance Reliability Criteria in addition to North American Electric Reliability Corporation (NERC) and Southwest Power Pool, Inc. (SPP) criteria and protocols to address the unique needs and conditions of the GridLiance system. GridLiance identified reliability needs in the Oklahoma Panhandle and East Central Oklahoma regions, evaluated mitigation options, and estimated construction cost and timing. Through the 2018 Local Planning Process (LPP), GridLiance has selected mitigations to the identified reliability needs over the 10-year study horizon. These recommended mitigations are listed in Table 1 below. GridLiance recommends for budgetary approval approximately $14 million of those upgrades in the next 2 years, as shown in Table 2. The remaining recommended mitigations will undergo continued evaluation in the next LPP study. Upgrades Location Recommendation Close Egypt Switch after all necessary system East Central Submit to SPP for coordination & modifications and relay coordination within and Oklahoma recommend for budgetary approval external to the GridLiance system takes place1 Oklahoma Submit to SPP for coordination & Build new Y-Road Switching Station, 3-terminal ring bus Panhandle recommend for budgetary approval Retire Eva Regulator + Install 25-30 MVAR reactive Oklahoma Submit to SPP for coordination & support in Western Panhandle region2 Panhandle recommend for budgetary approval Add station and 25 MVAR reactive support at/near Oklahoma Submit to SPP for coordination & Turpin Panhandle recommend for budgetary approval New approximately 8.5-mi 115 kV line from Red Devil to Oklahoma Enel’s Goodwell Wind, station expansion, and rebuild Y- Continue Evaluation in 2019 LPP Panhandle Road-Goodwell-Red Devil 115 kV lines New approximately 25-mile 115 kV line from Dry Trails Oklahoma to new station tapping Liberal-Texas County Continue Evaluation in 2019 LPP Panhandle Interchange 115 kV line near Hooker, OK New approximately 30-mile 115 kV line from Rose to Oklahoma Continue Evaluation in 2019 LPP Sunflower’s Liberal Panhandle Install voltage support near Powell Corner 115 kV - 14.4 Oklahoma Continue Evaluation in 2019 LPP MVAR reactive support Panhandle Table 1: GridLiance 2018 LPP Recommended Mitigations 1 There are on-going interconnection discussions with other Transmission Owners for this project. Details on other equipment will be added upon execution of agreements. 2 Determination of size and placement of reactive support will be performed in a separate Electromagnetic Transients Program (EMTP) study. 2 April 1, 2019 Project Cost Est. Proposed Upgrades Location Driver (millions) ISD Close Egypt Switch after all necessary system East Central modifications and relay coordination within and MW-Mile TBD 2019 Oklahoma external to the GridLiance system takes place Oklahoma Build new Y-Road Switching Station, 3-terminal ring bus Operational $4.5 2019 Panhandle Retire Eva Regulator + Install 25-30 MVAR reactive Thermal, Oklahoma $4.0 2020 support in Western Panhandle region Voltage Panhandle Add station and 25 MVAR reactive support at/near Oklahoma Voltage $5.0 2020 Turpin Panhandle Table 2: Projects Recommended for Construction 3 April 1, 2019 OVERVIEW GridLiance performed its annual system assessment in compliance with the GridLiance Open Access Transmission Tariff Attachment K requirements. This report outlines the study assumptions, findings, and mitigations resulting from the 2018 GridLiance Local Planning Study. The assessment utilized GridLiance’s Reliability Criteria, in addition to NERC and SPP criteria and protocols, to address the unique needs and conditions of the GridLiance system. As outlined in the Attachment K, GridLiance conducts an annual assessment of the GridLiance facilities’ current and expected operations thereby identifying actions needed to: (1) maintain the reliability of the GridLiance facilities in an economic and environmentally acceptable manner; (2) ensure that the load, transmission, and interconnection needs of GridLiance and GridLiance customers are met and services are provided in a manner that treats similarly situated customers comparably; and (3) meet needs driven by Public Policy requirements established by state or federal laws or regulations. As part of the system assessment, GridLiance has developed a plan to meet anticipated current and future transmission needs of its customers who are receiving generator interconnection services and transmission services on or across GridLiance transmission facilities. The GridLiance facilities under this study include its 115 and 69 kV Oklahoma panhandle facilities, 69 kV facilities in Nixa, Missouri, and the 138 kV East Central Oklahoma facilities that GridLiance expects to acquire this year.3 The geographic regions are depicted respectively in Figure 1, Figure 2, and Figure 3. Figure 1: GridLiance Oklahoma Panhandle Service Area 3 In March 2019, after GridLiance’s LPP analysis was complete, GridLiance’s application to acquire the East Central Oklahoma Facilities from People’s Electric Cooperative was denied by Federal Energy Regulatory Commission (FERC) without prejudice. GridLiance plans to file another application in 2019 requesting approval of the acquisition. 4 April 1, 2019 Figure 2: GridLiance Missouri Service Area Figure 3: GridLiance East Central Oklahoma Service Area 5 April 1, 2019 Modeling Assumptions For this assessment, GridLiance used the most recent SPP 2018 Integrated Transmission Planning Near-Term (ITPNT) Scenario 0 (S0) and Baseline Reliability4 (BR) models as a study starting point. These cases are released every year and contain existing SPP transmission topology and any upgrades or facilities that have been approved for construction. GridLiance made modelling changes to accurately reflect current GridLiance topology and load forecasts as well as recently-announced nearby generation retirements. In addition to correcting existing topology in the SPP models, GridLiance modelled planned construction projects that have been announced since the 2018 ITPNT cases were finalized. These projects include the following: • Panhandle Reliability Project (In-service date (ISD) June 2019)- construct a new 115/69 kV substation and 20 miles of new 115 kV transmission. The new 115/69 kV substation called Panhandle will bisect the Thrash to Cougar 69 kV transmission line one mile west of Thrash. This will create two new breakered 69 kV line sections, Powell Corner to Panhandle and Panhandle to Cougar. The new 115 kV transmission line will connect Powell Corner to Panhandle. • Second Cole 115/69 kV Transformer (ISD December 2019)5- Add second 115/69 kV 39.5 MVA transformer at Cole substation. • Nixa Espy- Downtown 69 kV Reconductor (ISD December 2019)- GridLiance received an NTC to reconductor its existing Espy to Downtown 69 kV line. • James River Reconfiguration (ISD June 2018)- City Utilities announced adding a second 161/69 kV transformer at its James River station and retiring generation units 4 and 5. These updated models were used as base cases for this study. Near-term and long-term case years were studied to account for a variety of system conditions. GridLiance also studied summer high load cases with abnormal weather peak load in compliance with its Reliability Criteria.6 This abnormal weather peak load refers to the forecasted normal peak load for an average year plus 10% which is referenced as summer high load (SHL) in this report. GridLiance studied generation sensitivities dispatching generation at Centrahoma and States Edge. Since load served from the GridLiance facilities is at its highest during summer peak conditions, the following years and cases identified in Table 3 were studied for this assessment. 4 S0 assumes projected usage of long-term firm transmission service between SPP customers, dispatching each entity’s generation to meet their load and obligations. S0 emphasizes high conventional generation commitment and dispatch. Renewable generation is set to match the Model Development Working Group (MDWG) 2017 models. BR assumes expected usage of long-term firm transmission service usage. Renewable resources are dispatched at each facility's latest five-year average for the SPP coincident summer peak, not to exceed each facility's firm service amount. 5 GridLiance is currently coordinating with SPS on project construction timing. 6 GridLiance Reliability Criteria: GridLiance OASIS>> Transmission Planning>> GridLiance Reliability Criteria 6 April 1, 2019 Year Season Scenario 0 & BR Sensitivity Cases Year 1(Current+1) Light load, Summer peak Year 4 Summer peak Year 9 Summer peak Table 3: Steady State Annual Planning Study Models Study Methodology This study assessed the GridLiance system performance using its Reliability Criteria, in addition to the NERC Reliability Standard TPL-001-4 and SPP Planning Criteria. Steady state analysis was conducted under normal operating (P0) conditions and contingency outage events (P1-P7). Local contingencies 69 kV and above defined by GridLiance and contingencies posted by SPP that may impact the GridLiance system were included in the steady state analysis. The transmission system is expected to perform reliably under a variety
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