Q50 Facility Study. By Tucson Electric Power Company Transmission Planning March 7, Proposed Point of Interconnection: Vail Fort Huachuca 138kV

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1 Q50 Facility Study Proposed Point of Interconnection: Vail Fort Huachuca 138kV By Tucson Electric Power Company Transmission Planning March 7, 2018 PREPARED BY:

2 FACILITY STUDY PREPARED FOR: TUCSON ELECTRIC POWER PROJECT CONTACTS: ANA BUSTAMANTE INGRID RAHAIM PHX (03/7/2018) GG PAGE i

3 TABLE OF CONTENTS 1.0 INTRODUCTION COST ESTIMATES DISCLAIMER SCOPE OF WORK INTERCONNECTION GEOTECHNICAL FIELD INVESTIGATIONS AND ENGINEERING BABACOMARI 138KV SWITCHYARD DESIGN VAIL 138KV SUBSTATION DESIGN FORT HUACHUCA 138KV SUBSTATION DESIGN ESTIMATE OF PROBABLE COST AND CONSTRUCTION TIME ESTIMATES ESTIMATE OF COST CONSTRUCTION TIME ESTIMATES REFERENCES ATTACHMENT A EQUIPMENT LAYOUT PLAN BABACOMARI SWITCHYARD ATTACHMENT B SINGLE LINE DIAGRAM BABACOMARI SWITCHYARD ATTACHMENT C BLOCK DIAGRAM AUTOMATION NETWORK, BABACOMARI SWITCHYARD PHX (03/7/2018) GG PAGE ii

4 1.0 INTRODUCTION Tucson Electric Power Co. (TEP) performed this Generator Interconnection Facilities Study (IFS) in response to an interconnection request submitted by Q50, the Interconnection Customer ( IC ), on October 12, 2016 for the interconnection of a 100MW Photovoltaic (PV) solar generator with a proposed interconnection to a new switchyard on the Vail Fort Huachuca 138kV circuit, approximately 26 miles southeast of the Vail 138kV substation. This circuit is part of the TEP balancing authority. The IC has indicated that this project will comprise one or more Qualifying Facility or Facilities and intends to sell the output of the project to TEP. A System Impact Study was performed to determine what effects the addition of the Q50 PV project would have on the TEP transmission system. The system impact study included steady state power flow, transient stability, post-transient stability, and short circuit analysis to determine potential impacts to the TEP transmission system. The study was conducted using the Western Electricity Coordinating Council s (WECC) approved 2021 heavy summer and heavy winter models. TEP retained POWER Engineers to perform the technical analysis portion of this IFS. The IFS Agreement was signed by the IC on November 6, The purpose of this IFS is to provide cost, engineering, procurement and construction time estimates for the facilities needed to safely and reliably interconnect the Q50 solar project to the TEP transmission system, based on the System Impact Study. TEP will require the following system modifications to accommodate the Q50 solar project: Construction of a new switchyard identified as the Babacomari 138kV switchyard including all protection, communication, automation and metering (PCAM) equipment associated with this site. Upgraded line relaying, communication and automation equipment at TEP s Vail 138kV substation. Upgraded line relaying, communication and automation equipment at TEP s Fort Huachuca 138kV substation. The Point of Interconnection (POI) will be the metering point at the new at Babacomari 138kV switchyard where the 0.3 mile 138kV transmission line enters from the IC s PV facility switchyard (located at 31 38'52.8"N, '02.4"W). The new Babacomari 138kV switchyard will be located in Cochise County, AZ. TEP shall perform the following at the IC s expense: Design, specification, procurement and installation of the interconnection facilities specified in this document. Land acquisition of the Babacomari 138kV switchyard site including surveying, geotechnical services, easements and permits. Design, specification, procurement and installation of one (1) Babacomari 138kV switchyard including all protective relaying equipment, primary and back-up metering facilities, fiber and wireless communications facilities, and station service sources. Coordination with the IC on project related issues. PHX (02/15/2018) GG PAGE 1

5 The IC shall be responsible for the following: The IC will be responsible to construct, own and operate the 138kV line from the Q50 generation station up to the last pole before the TEP switchyard fence, also known as the Point of Change of Ownership. The IC will own all structures up to the last pole before the TEP switchyard fence. TEP will be responsible for taking the 138kV line from that pole into the 138kV breaker, shown as Transmission Provider s Interconnection Facilities. All costs associated with design, specification, procurement and installation of the facilities required to interconnect the project including line upgrades and the required relay and communications upgrades required to safely incorporate the Q50 project onto the TEP transmission system as described in the scope of work and this document. The IC will provide a connection to backup station service power at the point of change of ownership sufficient to supply TEP 75kVA at 208/120 volts. Design, specification, procurement and installation of all inter-company communications interface facilities between the Q50 project and the TEP system required for safely operating the Q50 project in parallel with the TEP transmission system. Coordination with TEP on project related issues. In summary, this Facility Study: Specifies and estimates the cost of the equipment, engineering, procurement and construction work (including overhead line upgrades) needed to implement the facilities for the Q50 solar project interconnection. Estimates the time required to complete the construction and installation of such facilities. Identifies the electrical switching configuration of the equipment, including without limitation circuit breakers, disconnect switches, protection, station security, communication facilities and other station equipment. 2.0 COST ESTIMATES Construction schedule estimates are from the date the IC provides written authorization to proceed, provided all interconnection agreements and funding arrangements are in place. Interconnection construction costs and timelines were estimated for Q50 based on the approximate location described above. These good faith non-bidding cost estimates are applicable only to the TEP system. This study reviewed all capacity, construction, flicker, protection and communications requirements to interconnect this generation project. NERC (North American Reliability Corporation) requires that generation facilities provide a primary and secondary (back-up) communications path for data and control. This study does not specifically address any requirements for the IC Generating Facilities. However, the IC shall comply with all TEP requirements for a generator operating in parallel with TEP s electrical system. This estimate has been prepared with +/- 20% accuracy and assumes an in-service date during Q2 of 2020 based on the construction time estimates as shown in section 5.2, Table 5 of this document. All assumptions are clearly defined within this document and should be duly noted. PHX (02/15/2018) GG PAGE 2

6 Many costs included in this report will vary with market conditions and the final design. While this document reflects budgetary estimates, it is important to note that labor and material costs continue to fluctuate. Additionally, the prices of both equipment and construction labor fluctuate. This report is based on current costs, but these costs are subject to change based on market conditions and final design. The cost amounts payable by the IC will be the actual expenses incurred in the completion of work as defined herein (including overheads). 3.0 DISCLAIMER Nothing in this report constitutes an offer of transmission service or confers upon the Interconnection Customer ( IC ) any right to receive transmission service. TEP and other interconnected utilities may not have the Available Transmission Capacity to support the interconnection described in this report. It should also be noted that all results for the IFS are highly dependent upon the assumed topology and timing of new projects in the vicinity of the interconnection, which are subject to change. Estimates, forecasts, projections, and schedules relating to costs, final design, quantities, and pricing (including but not limited to property costs, construction, operation or maintenance costs) are opinions based upon experience, qualifications, and judgment. TEP has no control over the weather, cost, availability of labor, materials and equipment, labor productivity, population demographics, market conditions, regulatory environment, change in technology, or other economic or political factors effecting such estimates or projections. TEP states that actual results may vary significantly from the representations and opinions herein. Nothing herein will be construed as a guarantee or warranty (actual or implied) that rates, demand, pricing, costs, performance schedules, quantities, technology, or any other related items will not vary from opinions contained in this report. All costs included in this estimate are subject to change if the final design, project performance, or requirements change from the preliminary data provided by the IC on November 6, SCOPE OF WORK The scope of work includes the design, procurement, construction, and commissioning of one (1) new Babacomari 138kV switchyard, and line protection upgrades at Vail and Fort Huachuca substations. Microwave radio will be installed at Babacomari to provide communication with Vail and Fort Huachuca substations. The following attachments are included in the scope of work: Attachment A Equipment Layout Plan Babacomari Switchyard Attachment B Single Line Diagram Babacomari Switchyard Attachment C Network Block Diagram Automation Network, Babacomari Switchyard 4.1 Interconnection The Q50 solar project interconnect will require the addition of the proposed Babacomari 138kV switchyard. The switchyard will consist of a three (3) breaker ring connecting the Q50 solar project intertie, a line to Vail 138kV substation and a line to Fort Huachuca 138kV substation along with all the associated protection, communication, automation, and metering (PCAM) equipment. The switchyard will allow transfer trip protection from Vail and Fort Huachuca substations. PHX (02/15/2018) GG PAGE 3

7 4.2 Geotechnical Field Investigations and Engineering A geotechnical investigation will be completed by a TEP approved geotechnical firm paid for by the IC. The results of this report will be evaluated to establish the design basis for foundation and electrical grounding design. 4.3 Babacomari 138kV Switchyard Design Babacomari 138kV Switchyard Site Preparation, Grading and Drainage Design Babacomari 138kV switchyard shall be fenced using 8 Beta fence with 1 of razor wire on top. Final grade and surface with 4 of lime stabilized aggregate base shall extend a minimum of five feet (5 ) outside the fence line on all sides. Babacomari 138kV switchyard shall be sloped away from electrical equipment. Babacomari 138kV Switchyard Civil/Structural Design All station foundations, footings, etc. will be designed according to TEP standards. Babacomari 138kV Switchyard Electrical Design TEP standards will be used for the basis of all electrical design. All grounding required will be designed per ANSI/IEEE STD 80 using 4/0 copper cable. The following equipment is required for the Babacomari 138kV switchyard: Three (3) 138kV, 650 kv BIL, 3000A circuit breakers Six (6) 138kV manually operated disconnect switches. Three (3) 138kV line switches with motor operators Ten (10) 138kV, potential transformers (PTs) Nine (9) 138kV surge arresters Three (3) 138kV/208V, station service CCVT s One (1) yard Fiber Distribution Panel (FDP) cabinet One (1) climate controlled shelter containing: o One (1) 125Vdc battery charger o One (1) 125Vdc battery bank o Two (2) 125Vdc distribution panels o One (1) 208/120Vac distribution panel o Three (3) protective relay panels o One (1) Human-Machine Interface (HMI) panel o One (1) communications equipment panel A second source for station service, provided by the IC, will be included in the design All equipment shall be rated at 3000A and be capable of interrupting up to 40kA fault current. Equipment shall be installed that meets local temperature, weather and seismic conditions. PHX (02/15/2018) GG PAGE 4

8 Equipment shall be grounded to adequately protect personnel and the electric infrastructure. TEP shall perform grounding calculations to verify that the new grounding system provides adequate personnel and equipment protection. All grounding installation shall be per TEP standard practices. Overvoltage protection shall be included per TEP standard for surge and the basic impulse level as required. A direct current (dc) system including a suitably sized charger and batteries shall be included in the control house in a separate room from the rest of the equipment. The dc system shall be appropriately sized to sustain all dc loads for at least 8 hours following the loss of ac power. Shielded control, current transformers, potential transformers, communication, and station wiring shall be installed per TEP standards. Babacomari 138kV Switchyard Protection and Control Design The protection and control design shall follow TEP standards. An overview of the protection and metering is presented in the single line diagram shown in Attachment B. The design is intended to provide a means of local and remote control of equipment and switching of the electrical system. It is also intended to protect the electrical infrastructure under abnormal system conditions or faults and to minimize system outages and disturbances. The following generally represents the protection and control design: Install all protection, communication, metering and SCADA equipment inside the climate controlled shelter Protection systems shall be dc powered and shall utilize SEL microprocessor based relays per TEP standard design. The protection system shall include: o 138kV breaker failure protection (50BF) for all breakers three (3) total o 138kV breaker failure lockout relays (86BF) for all breakers three (3) total o 138kV primary line protection relays (87LP/21P) for 138kV lines to Vail substation and Fort Huachuca substation. o 138kV secondary line protection relays (87LS/21S) for 138kV lines to Vail substation and Fort Huachuca substation. o 138kV primary interconnection protection relay (21P/67NP) for Q50 intertie o 138kV secondary interconnection protection relay (21S/67NS) for Q50 intertie o 138kV sync check relay (25) Relay settings shall be developed by TEP for all relays. Install SCADA and remote access per TEP standard practice. Babacomari 138kV Switchyard Communication and Automation Design Fiber optics and microwave communication paths will be utilized to exchange protection, metering, control and communication signals between Babacomari 138kV switchyard and the TEP system operations. PHX (02/15/2018) GG PAGE 5

9 TEP s existing fiber optic network will be utilized where available. New fiber will be installed as part of the communication network between the new 138kV Babacomari switchyard and the IC site substation. An overview of the automation network is presented by the automation block diagram shown in Attachment C. Communication and automation equipment required at Babacomari 138kVswitchyard includes: One (1) 19 communication rack One (1) 144 fiber count Single Mode (SM) fiber distribution panel (FDP) One (1) 48 fiber count Multi Mode (MM) FDP Two (2) Wilmore Vdc converters One (1) PowerWorx 48Vdc fuse panel One (1) Nokia 7705 SAR-8 One (1) RX1500 Layer 3 router for Operations Network One (1) Cisco IE2000 One (1) Wireless Access Point (WAP) with POE injector One (1) Internet Protocol (IP) phone One (1) HMI Panel containing: o Two (2) Orion LX communication processors o Two (2) RX1500 modular switches o One (1) each: HMI display, keyboard, and keyboard tray o One (1) SEL-2440 Discrete Input/Output (DIO) module o One (1) SEL-2488 satellite clock o One (1) 2 port Keyboard/Video/Mouse (KVM) switch One (1) SEL-3610 serial port server Three (3) SEL-2440 DIO modules One (1) SEL-2440 DIO module and one (1) SEL-2407 satellite clock located at each breaker total of three (3), to be provided by breaker manufacturer. Babacomari 138kV Switchyard Metering Design The revenue metering for the Q50 Solar project will be performed at Babacomari 138kV switchyard and will consist of primary and check meters. An additional line metering unit will be installed for each transmission line exiting Babacomari 138kVswitchyard. Metering equipment required at Babacomari 138kV switchyard will include: Four (4) Square-D ION8650A meters with power quality monitoring Four (4) Brooks test switches 4.4 Vail 138kV Substation Design Vail 138kV Substation Protection and Control Design The protection and control design shall follow TEP standards. The design interfaces with the construction of the Babacomari 138kV switchyard to provide a means of local and remote control of equipment and switching of the electrical system. It is also intended to protect the electrical infrastructure under abnormal system conditions or faults and to minimize PHX (02/15/2018) GG PAGE 6

10 system outages and disturbances. The following generally represents the protection and control design: The protection system shall be altered such that: o One (1) 138kV primary line protection relay (87LP/21P-FH) is removed and replaced with one (1) 138kV primary line protection relay (87LP/21P-BC). o One (1) 138kV secondary line protection relay (87LS/21S-FH) is modified to communicate with Babacomari 138kV switchyard Any change to relay settings shall be developed by TEP for all relays. Any change to SCADA and remote access shall conform to TEP standard practice. Vail 138kV Substation Communication and Automation Design Communication and automation equipment required at Vail 138kVsubstation includes: One (1) 144 fiber count SM FDP One (1) Tele-protect card (for existing Nokia 7705 SAR-8) 4.5 Fort Huachuca 138kV Substation Design Fort Huachuca 138kV Substation Protection and Control Design The protection and control design shall follow TEP standards. The design interfaces with the construction of the Babacomari 138kV switchyard to provide a means of local and remote control of equipment and switching of the electrical system. It is also intended to protect the electrical infrastructure under abnormal system conditions or faults and to minimize system outages and disturbances. The following generally represents the protection and control design: The protection system shall be altered such that: o One (1) 138kV primary line protection relay (87LP/21P-VL) is removed and replaced with one (1) 138kV primary line protection relay (87LP/21P-BC). o One (1) 138kV secondary line protection relay (87LS/21S-VL) is modified to communicate with Babacomari 138kV switchyard Any change to relay settings shall be developed by TEP for all relays. Any change to SCADA and remote access shall conform to TEP standard practice. Fort Huachuca 138kV Substation Communication and Automation Design Communication and automation equipment required at Ft Huachuca138kVsubstation includes: One (1) 144 fiber count SM FDP One (1) Nokia 7705 SAR-8 PHX (02/15/2018) GG PAGE 7

11 5.0 ESTIMATE OF PROBABLE COST AND CONSTRUCTION TIME ESTIMATES Q50 Solar Project Facilities The IC shall design, procure, construct, install, own and/or control any equipment beyond the TEP Babacomari 138kV switchyard at its sole expense. TEP Interconnection and Transmission Facilities TEP shall design, procure, construct, install, own and/or control the Babacomari 138kV switchyard and modifications at Vail and Fort Huachuca substations at the cost of the IC. 5.1 Estimate of Cost The cost of the Q50 solar project procurement, construction and installation are not included in this estimate. Project dollar amounts shown in this section are in 2018 US dollars. All costs include materials, labor and overheads. TABLE 1: ESTIMATE OF TOTAL COST - BABACOMARI 138KV SWITCHYARD Babacomari 138kV Switchyard Equipment/Materials $2,126,046 Engineering $1,464,855 Construction $462,261 Land Acquisition/Right-of-Way $20,000 Subtotal $4,073,162 Contingency (20%) $814,632 Total Estimated Cost $4,887,794 TABLE 2: ESTIMATE OF TOTAL COST - VAIL 138KV SUBSTATION Vail 138kV Substation Equipment/Materials $23,959 Engineering $35,564 Construction $46,256 Subtotal $105,779 Contingency (20%) $21,156 Total Estimated Cost $126,934 PHX (02/15/2018) GG PAGE 8

12 TABLE 3: ESTIMATE OF TOTAL COST - FORT HUACHUCA 138KV SUBSTATION Fort Huachuca 138kV Substation Equipment/Materials $41,613 Engineering $35,564 Construction $42,192 Subtotal $119,369 Contingency (20%) $23,874 Total Estimated Cost $143,242 TABLE 4: ESTIMATE OF TOTAL COST - Q50 SOLAR PROJECT INTERCONNECTION Q50 Solar Project Interconnection Project Total Equipment/Materials $2,191,618 Engineering $1,535,983 Construction $550,708 Land Acquisition/Right-of-Way $20,000 Subtotal 4,298,309 Contingency (20%) $859,662 Total Estimated Cost $5,157, Construction Time Estimates Construction time estimates are based on current equipment availability and delivery timelines provided by the equipment manufacturers. These timeframes are estimates only and may vary due to unforeseeable circumstances. TABLE 5: CONSTRUCTION TIME ESTIMATES Equipment Procurement Engineering Construction Bidding Site Preparation Site Construction Commissioning 36 weeks 22 weeks 8 weeks 4 weeks 18 weeks 4 weeks The actual start date will be determined by the Interconnection Agreement. A construction schedule will be created with the projected completion dates for each task listed in the table above. Equipment procurement, engineering, construction bidding and site preparation will be coordinated in a manner to be completed at or about the same time. Site construction and upgrades will be completed after all the equipment has been procured with commissioning following construction completion. PHX (02/15/2018) GG PAGE 9

13 6.0 REFERENCES 1. NFPA 70, National Electric Code, 2017 Edition. Quincy, Mass. 2. ANSI/IEEE Std. 80 (2013). IEEE Guide for Safety in AC Substation Grounding, IEEE Society, New York. 3. Tucson Electric Power Civil/Structural Substation Design Criteria, Rev 4, February 4, Tucson Electric Power Engineering Procedural Manual, Procedure SDN 1.3, Substation Security, H. Warner, December 17, TransCo Energy, Q50 System Impact Study, Final Report, Bobby Chavez, September 20, Project Scoping Document Level 0, Q 50 (Babacomari), R. McCarthy, September 20, PHX (02/15/2018) GG PAGE 10

14 Attachment A Equipment Layout Plan Babacomari Switchyard PHX (02/15/2018) GG PAGE 11

15 Attachment B Single Line Diagram Babacomari Switchyard PHX (02/15/2018) GG PAGE 13

16 Attachment C Block Diagram Automation Network, Babacomari Switchyard PHX (02/15/2018) GG PAGE 15

RECITALS. Now, Therefore, in consideration of the mutual covenants and agreements herein set forth, the Parties do hereby agree as follows:

RECITALS. Now, Therefore, in consideration of the mutual covenants and agreements herein set forth, the Parties do hereby agree as follows: LEE COUNTY ELECTRIC COOPERATIVE STANDARD INTERCONNECTION AGREEMENT FOR CUSTOMER-OWNED RENEWABLE GENERATION SYSTEMS GREATER THAN 100 KW AND LESS THAN OR EQUAL TO 1 MW TIER 3 This Interconnection Agreement