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HomeMy WebLinkAbout20240906IPC to Staff 70 Attachment 2 - GIA 549 Amendment 1.pdfGI Queue #549 Franklin Solar Page 1 FIRST AMENDMENT TO THE LARGE GENERATOR INTERCONNECTION AGREEMENT (GIA) BY AND BETWEEN IDAHO POWER COMPANY AND FRANKLIN SOLAR LLC GI QUEUE #549 This First Amendment of the Large Generator Interconnection Agreement (“First Amendment”) is entered into on _____________________ by and between Idaho Power Company, an Idaho corporation (“Idaho Power”), and Franklin Solar LLC, an Idaho limited liability company (“Interconnection Customer”). Interconnection Customer and Idaho Power each may be referred to as a “Party” or collectively as the “Parties.” WITNESSETH: WHEREAS, on February 12, 2020, Idaho Power and Franklin Solar LLC, entered into a Large Generator Interconnection Agreement (“Franklin Solar #549”); WHEREAS, on April 8, 2021, Franklin Solar #549 entered into a System Impact Study Agreement due to configuration changes made by a senior queued project that impacted the configuration of Franklin Solar #549 and requiring a re-study; WHEREAS, on August 16, 2021, Franklin Solar #549 entered into a Technological Advancement Study to add energy storage to the project; WHEREAS, on November 1, 2021, Franklin Solar #549 entered into a 90-day Facilities Study Agreement to re-study the project with the configuration changes captured in the System Impact re-study and Technological Advancement Study. A final Facilities re-study report was completed on February 16, 2022; WHEREAS, the Interconnection Customer and Idaho Power agree the Appendices in the current GIA require amendment due to the changes identified in the System Impact re-study, Technological Advancement Study, and Facilities re-study; and WHEREAS, the Parties now desire to amend the Large Generator Interconnection Agreement by executing this First Amendment to the GIA. Pursuant to provisions of Idaho Power’s OATT, the Interconnection Customer will be responsible for funding approximately $1,867,688 for the project construction, as described in Appendix A of Exhibit A of this First Amendment. NOW, THEREFORE, the Parties, intending to be legally bound, agree as follows: 1.Recitals. The Parties acknowledge and agree as to the accuracy of the Recitals set forth above, and such Recitals are incorporated herein by reference. Response to Staff Request No. 70 - Attachment 2 DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 April 12, 2022 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 2 2.Amendment to Agreement. The Parties hereby agree to amend the February 12, 2020, Large Generator Interconnection Agreement to incorporate Exhibit A, Updated Appendices to the LGIA, attached hereto and fully incorporated herein by this reference. 3.Effect of Amendment.Except as expressly amended by this First Amendment, the Large Generator Interconnection Agreement shall remain in full force and effect. 4. Capitalized Terms. All capitalized terms used in this First Amendment and not defined herein shall have the same meaning as used in Idaho Power’s Open Access Transmission Tariff. 5. Scope of Amendment.This First Amendment shall be binding upon and inure to the benefit of the Parties hereto, and their respective heirs, executors, administrators, successors, and assigns, who are obligated to take any action which may be necessary or proper to carry out the purpose and intent thereof. 6.Authority.Each Party represents and warrants that (i) it validly exists and in good standing in the State in which it is organized (ii) it is the proper party to amend the Agreement, and (iii) it has the requisite authority to execute this First Amendment. 7.Counterparts. This First Amendment may be executed in any number of counterparts, each of which shall be deemed an original and all of which taken together shall constitute a single instrument. DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 3 IN WITNESS WHEREOF, the Parties hereto have caused this First Amendment to be executed in their respective names on the dates set forth below: FRANKLIN SOLAR LLC IDAHO POWER COMPANY By:By: Name:Name: Title:Title: Date:Date: DocuSign Envelope ID : 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 Brian K. Stallman Benjamin C Brandt Yice President Director I cad Serving Operations 4/12/2022 4/12/2022 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 4 Exhibit A Updated Appendices to the LGIA DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 5 Appendix A to LGIA Interconnection Facilities, Network Upgrades and Distribution Upgrades 1. Interconnection Customer’s Interconnection Facilities General Facility Description The Franklin Solar #549 project will consist of 100 MW photovoltaic and 20 MW battery energy storage system (BESS) installation in Twin Falls County, Idaho and connect to the 345kV system at Idaho Power Company’s (IPC) Rogerson Switching Station on the Midpoint– Humbolt transmission line. The total project output as studied is 100 MW. The Interconnection Customer’s Interconnection Facilities are located approximately ¾ mile to the northwest from IPC’s Interconnection Facilities. The Interconnection Customer will install disconnect switches, distribution collector system(s), transformers (including a main step-up transformer), controllers, appropriate grounding measures, and associated auxiliary equipment. The main step-up transformer is a 67/89.3/111.7 MVA. 3-phase, 345/34.5kV wye- grounded/wye-grounded with a delta tertiary and should provide adequate ground source for transmission line protection. Interconnection Customer will build 345kV transmission facilities to the Point of Change of Ownership. Point of Interconnection The Interconnection Facilities are located in IPC’s Southern region in Township 14S, Range 16E and Section 29 and are approximately 15 miles north of the Nevada–Idaho border. The Point of Interconnection (POI) for the Project will be the node on the 345kV ring bus between air-break switches 302B and 303B at Rogerson Switching Station. A drawing identifying the POI is included as Exhibit 1 in this Appendix A. Point of Change of Ownership The Point of Change of Ownership for the Project will be on the Interconnection Customer’s side of air-break switch 302X at IPC’s Rogerson Switching Station. A drawing identifying the Point of Change of Ownership is included as Exhibit 1 in this Appendix A. 2. Transmission Provider’s Interconnection Facilities IPC will install a meter, a dead-end structure, 345kV air-break switch, three CTs, three CCVTs, three line arresters, foundations, and cabling in the IPC Rogerson Switching Station yard to allow the Interconnection Customer to interconnect the Project. IPC will install facilities up to the Point of Change of Ownership. IPC will install equipment to collect Phasor Measurement Unit (PMU) data and manually retrieve the data as necessary. The data can be made available to the Interconnection Customer on request. The minimum acceptable PMU message rate is 30 samples per second. The minimum set of PMU measurement channels recorded at the POI is shown below. Additional or substitute channels may be required on a per case basis depending on the interconnection configuration and facility design details. DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 6 Frequency Frequency Delta (dF/dt) Positive Sequence Voltage Magnitude Positive Sequence Voltage Angle Positive Sequence Current Magnitude Positive Sequence Current Angle 3. Network Upgrades Network Upgrades to Substations The three-position 345kV ring bus at Rogerson Switching Station will be modified to a four- position bus by installing two 345kV air-break switches on existing structures and one 345kV circuit breaker installed on a new concrete foundation and associated relaying/control/communications equipment in a control building, bus, grounding, conduit, and conductor for such equipment. Network Upgrades to the Transmission System No Network Upgrades to the Transmission System are required. 4. Distribution Upgrades No Distribution Upgrades are required. 5. Estimated Costs The following good faith estimates are provided in 2022 dollars and are based on a number of assumptions and conditions. IPC does not warrant or guarantee the estimated costs in the table below, which are estimates only and are subject to change. Interconnection Customer will be responsible for all actual costs incurred in connection with the work to be performed by IPC and its agents, under the terms and subject to the conditions included in any LGIA executed by IPC and Interconnection Customer. The estimated cost below is required to be paid in full by the Interconnection Customer, or other arrangements acceptable to IPC are made with IPC’s Credit Department, prior to IPC commencing construction on the project. As of the date of this executed LGIA amendment, there are Contingent Facilities in the queue (GI numbers 502, 503, 513, 514, 517 and 523, and an associated transmission service request [TSR] #88754178) ahead of Franklin Solar #549 for which costs related to network upgrades or additions could be passed on to Franklin Solar should changes be made to either their queue position or generation output. DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 • • • • • • First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 7 In calculating cost estimates, the recommended upgrades for GI numbers 502, 503, 513, 514, 517 and 523, and associated TSR #88754178 were assumed to be completed prior to the interconnection of the Project. For this and other reasons, the cost estimates included in this table below are estimates only, are based on currently known or assumed facts that may not be accurate or materialize, and are subject to change. Description Ownership Funding Responsibility1 Cost Estimate IPC Interconnection Facilities: Install Interconnection Facilities as described in Section 2 above. IPC Interconnection Customer $916,524 Contingency 10%$91,652 Overheads 7.25% $73,093 Subtotal $1,081,269 Network Upgrades: Install Substation Network Upgrades as described in Section 3 above. IPC Interconnection Customer $666,598 Contingency 10% $66,660 Overheads 7.25% $53,161 Subtotal $786,419 GRAND TOTAL $1,867,688 1 Funding responsibility is described in the standard LGIA in Idaho Power’s OATT (OATT Attachment M). Interconnection Facilities are funded by the Interconnection Customer without reimbursement. Network Upgrades are funded by the Interconnection Customer and those funds are eligible for reimbursement under LGIA section 11.4.1. DocuSign Envelope ID : 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 8 Exhibit 1: Single-Line Diagram DocuSign Envelope ID : 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 JACKPOT SOLAR ( l 20 ~W) .l4 5kV t 1 l 301X I ----$--------' ~"">~ I f I F £1:N"!D=r !U' 3-·,, I .,..~°:'.:1. I I I I I "~ L ___ _ ~TfE' r.i~ t1'•~-- -------'0-------J -------'O------- P RO.IF CT I OC AT)ON· TY.'1111 t,1,llS CMTY. IDAHO Ti-'S , R16E, SECTION 29 ' 0 ,)"!J.t'V Hs [ J.l!t.U c::ico { ~:~ l -.~c _____.,. HM~T J~ J 345k V ' ' LAT= if ;f {N LO\G =-';J'W E'IISI ONS t ;.:'""'""'llool• ~ .... ROG ER SON SWI TCHI NG STATI O 345 kV RI NG BUS SI NG LE LI E 210-7.SJJ SHT 001 ~ 01 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 9 DocuSign Envelope ID : 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 JACKPOT SOLAR ( l 20.W) 34 5kV i ~~~ I ¼ I J<E'l!H'lUF :tQ° .um,rn:.:· u» I "T1 !U II,. IUI, I I I I I L ___ _ TO I i OS ! ATS Ml&FJ'!.EJ ~ •3"1 I I ' 'l AL MOM-,,~~~{r-,-,~~;r;~, :f~: r·;-~?i"---~~;---r;~r -1..--------.J I..---___ ..J 1 • ,~:ff • L __________________ _ " i ' L1 m,T fi-t. ,.,. 5 _______ ,._ _____ _ f F..\I L!'. L-s ~,.{ .I I REVISION S "' m, .. .; ,rt,lbqln ,, I mo:,, 1rn,x«ct R l 4'.'~ .... 1 MP SN ,-----l_"_j------.----,--!_______._ ."5-'5 W PRO,IECT I nrATTON TWIN r.11 LLS COJ,,I TY. JO,tHO n +s, 1m E, :SECTlOtl 29 ,r-TI E ' 1" ""'!'-· (~1"' ----, J~~r__ I -~-7.: I;,' I I P[l'1 .:.T[f> R ~ I_ ' ,,. T 1, nr 11-T II.-I I II,-L 11,- P,,tJt I 11-~ ,,_, r l ' J> I ' ' • I ' -:--1-.-: f I I I I _J REFERENCE Da,11 \lll GS LAT = t' /f f N LOOC = ·j f W ROG ER SON SWITCHI NG STATI ON 345 kV RI NG BUS SI NG LE LI E -, D:r~AJ:-Y.5f ~!'_ .. --= Ii)A HO PO'ol[R CQ&.IPAW OOIS[. JD.IHI) -~ • -•,:,',·~ •--;, r•· "-..0::1 .....,.,.r ~::~:i ~":"-~·'_•..:_, \~--->-~~ >--------~~--< _ .... -:. -·/.I;.,...,.:..--,~-.,;.:. ·:,ll:': -~ ~:-:-,;-::::~-~-.;;~,;- First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 10 Appendix B to LGIA Milestones These milestones will begin, and the construction schedule referenced below will only be valid, upon receipt of funding from Interconnection Customer or its authorized third party no later than the date set forth below for such payment. IPC will not commit any resources toward Project construction that have not been funded by Interconnection Customer. Additionally, failure by Interconnection Customer to make the required payments as set forth in this Study by the date(s) specified below may result in the loss of milestone dates and construction schedules set forth below. In the event that the Interconnection Customer is unable to meet dates as outlined below, Interconnection Customer may request an extension of the Operation Date of up to three (3) years. Interconnection Customer’s request will be evaluated by IPC to ensure Interconnection Customer’s request does not negatively impact other projects in IPC’s Generator Interconnection Queue. Such extension will be allowed only if IPC determines, in its sole discretion, that the extension will not negatively impact other projects in IPC’s Generator Interconnection Queue. Estimated milestones, which will be updated and revised for inclusion in the LGIA in light of subsequent developments and conditions, are as follows: Estimated Date Responsible Party Estimated Milestones Upon execution of First Amendment Interconnection Customer IPC receives Notice to Proceed and construction funding or arrangements acceptable to IPC are made with IPC’s Credit Department 24 months after construction funds received IPC IPC Engineering and Design Complete 24 months after construction funds received IPC IPC Long Lead Material Procured/Received 6 months prior to IPC Commissioning IPC New generation must be modeled and submitted to the Western Energy Imbalance Market a minimum of 6 months prior to coming online, failure to submit by given lead time will results in project delay. 36 months after construction funds received IPC IPC Construction Complete 38 months after construction funds received IPC IPC Commissioning Complete 5 days after switching request made to IPC Dispatch Interconnection Customer Switch at the Point of Interconnection can be closed TBD IPC Notification from IPC’s Energy Contracting Coordinator confirming First Energy of Non-Firm Output TBD Interconnection Customer Interconnection Customer testing begins DocuSign Envelope ID : 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 11 Estimated Date Responsible Party Estimated Milestones TBD IPC Notification from IPC’s Energy Contracting Coordinator confirming Operation Date (pending all requirements are met including construction completion and in- service confirmation of all identified Contingent Facilities) of Firm Network Resource Output IPC does not warrant or guarantee the foregoing estimated milestone dates, which are estimates only. These milestone dates assume, among other things, that materials can be timely procured, labor resources are available, and that outages to the existing transmission system are available to be scheduled. As of the date of this executed LGIA amendment, there are Contingent Facilities in the queue (GI numbers 502, 503, 513, 514, 517 and 523, and an associated transmission service request [TSR] #88754178) ahead of Franklin Solar #549 for which construction responsibility related to network upgrades or additions could be passed on to Franklin Solar should changes be made to either their queue position or generation output. The recommended upgrades for GI numbers 502, 503, 513, 514, 517 and 523, and associated TSR #88754178 were assumed to be completed prior to the interconnection of the Project. For this and other reasons, the milestone dates included in the table above are estimates only, are based on currently known or assumed facts that may not be accurate or materialize, and are subject to change. Additionally, there are several matters, such as permitting issues and the performance of subcontractors that are outside the control of IPC that could delay the estimated Operation Date. For purposes of example only, federal, state, or local permitting, land division approval, identification of Interconnection Facilities location, access to proposed Interconnection Facilities location for survey and geotechnical investigation, coordination of design and construction with the Interconnection Customer, failure of IPC’s vendors to timely perform services or deliver goods, and delays in payment from Interconnection Customer, may result in delays of any estimated milestone and the Operation Date of the project. To the extent any of the foregoing are outside of the reasonable control of IPC, they shall be deemed Force Majeure events. DocuSign Envelope ID : 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 12 Appendix C to LGIA Interconnection Details Type of Interconnection Service:Studied as Network Resource Integration Service Full Output:100 MW Nominal Delivery Voltage:345kV Affected Parties: None identified Interconnection Customer’s Generating Facilities The Interconnection Customer’s system will be constructed as follows: 1. The photovoltaic inverter system will comprise of 35 SunGrow SG3150U inverters, with each inverter having an apparent power rating of 3,150 kVA. 2. 35 photovoltaic inverter stations will each comprise of one utility inverter and a 3,150 KVA isolating transformer with a 630V grounded-wye to 34.5kV delta rating. 3. The BESS inverter system will comprise of 7 SunGrow SG3600UD inverters, with each inverter having an apparent power rating of 3,600 kVA. 4. 7 BESS inverter stations will each comprise of one utility inverter and a 3,600 KVA isolating transformer with a 630V grounded-wye to 34.5kV delta rating. 5. A plant controller will be used to control the inverter system and to implement smart inverter functionality for operating the project within a voltage range and power factor specified by IPC at the POI. The above referenced inverters, or equivalent inverters that have the same specifications and functionality as stated above must be utilized. If an inverter is utilized that has different specifications and functionality than that which was studied, then additional study and/or equipment may be necessary. The Project is a combined solar and BESS generation project. It has been assumed the BESS will be charged via the solar output. The Interconnection Customer will need to demonstrate the control measures which prevents the BESS from being charged via IPC’s transmission system. Other Facilities Provided by Interconnection Customer Telecommunications The Interconnection Customer is not responsible for any third-party communication circuits for the IPC Interconnection Facilities and Network Upgrades. Any additional telecommunication requirements will be the sole responsibility of the Interconnection Customer. DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 13 Ground Fault Equipment The Interconnection Customer will install transformer configurations that will provide a ground source to the transmission system. Generator Output Limit Control The Interconnection Customer will install equipment to receive signals from IPC Grid Operations for Generation Output Limit Control (GOLC). See the Control Requirements section of this Appendix C. IPC’s recommended method of communication for GOLC is via fiber between the Interconnection Station and the Project. Local Service The Interconnection Customer is responsible to arrange for local service to their site, as necessary. Property All IPC’s Interconnection Facilities will be installed within the existing Rogerson Switching Station property. Site Work The Interconnection Customer is not responsible for site work for any IPC facilities. Monitoring Information If the Interconnection Customer requires the ability to monitor information related to the IPC breaker/relay (i.e., Mirrored Bits) in the interconnection station, they are required to supply their own communications circuit to the interface area of the interconnection yard. The fiber communication circuit used for GOLC is acceptable. Meteorological Data In order to integrate the solar energy into the IPC system and operate IPC’s solar forecasting tool, the Interconnection Customer must provide solar irradiation and weather data from the Facility’s physical location to IPC via real time telemetry in a form acceptable to IPC. The associated cost for obtaining this data is the Interconnection Customer’s responsibility. The data must be provided at 10 second intervals and consist of: 1.Global Horizontal Irradiance 2.Plane of Array Irradiance 3.Ambient Temperature 4.Wind Speed and Wind Direction 5.Relative Humidity The installed instruments must equal or exceed the specifications of the following instruments: Temperature and Relative Humidity:R.M Young Relative Humidity and Temperature Probe Sensors Model 41382 DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 • First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 14 Wind:R.M Young Wind Monitor Model 05103 Pryanometer:Apogee Instruments Model SP-230 Generator Technical Information & Drawings After construction, the Interconnection Customer shall submit to IPC all the as-built information, including prints with the latest approved technical information and commissioning test results. Operating Requirements The Project is required to comply with the applicable Voltage and Current Distortion Limits found in IEEE Standard 519-2014 IEEE Recommended Practices and Requirements for Harmonic Control in Electrical Power Systems or any subsequent standards as they may be updated from time to time. The Project will be subject to reductions directed by IPC Grid Operations during transmission system contingencies and other reliability events. When these conditions occur, the Project will be subject to Generator Output Limit Control (GOLC) and will have equipment capable of receiving an analog setpoint via DNP 3.0 from IPC for GOLC. GOLC will be accomplished with a setpoint and discrete output control from IPC to the Project indicating maximum output allowed. For more detail see the Control Requirements section of this Appendix C. Low Voltage Ride Through The Project must be capable of riding through faults on adjacent sections of the power system without tripping due to low voltage. The interconnection project must meet or exceed the Low Voltage Ride-Through requirements as set forth in NERC Standard PRC-024. Frequency Response Requirements The Project must be capable of providing Fast Frequency Response for both positive and negative frequency deviations from 60Hz ( +/– 0.036 Hz) for Bulk Electric System disturbances. The required frequency response will be linear for a deviation of 0 to +/– 0.1 Hz, a response of 0% to 3% of generator capacity, with a maximum required response of 3% of generator’s full capacity for as long as the generator is able to provide support or the frequency deviation is reduced to within stated limits, whichever occurs first. Provided that the Project meets the above Fast Frequency Response requirements, IPC shall not curtail the Interconnection Customer when such curtailments are caused by a need to comply with applicable Frequency Responsive reliability standards. Momentary Cessation Requirements Momentary cessation should not be used within the voltage and frequency ride-through curves specified in PRC-024. Use of momentary cessation is not considered “ride through” within the “No Trip” zone curves of PRC-024. The use of momentary cessation should be eliminated to the extent possible consistent with NERC’s Reliability Guideline for BPS-Connected Inverter-Based Resource Performance. In digital equipment, frequency should be calculated over a period-of-time (e.g., three to six cycles) and filtered to take control action on the fundamental frequency component of the DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 • • First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 15 calculated signal. Calculated frequency must not be susceptible to spikes caused by phase jumps on the Bulk Electric System. Interconnection Customer will be able to modify power plant facilities on the Interconnection Customer side of the Point of Change of Ownership with no impact upon the operation of the transmission or distribution system whenever the generation facilities are electrically isolated from the system via the 302X switch, and a terminal clearance is issued by IPC’s Grid Operator. Reactive Power It is the Project’s responsibility to provide reactive power capability to have a power factor operating range of at least 0.95 leading (absorbing) to at least 0.95 lagging (supplying) at the high side of the generator substation over the range of real power output (up to maximum output of the project) and for all modes of operations (solar generation only, combined solar/BESS [charging and discharging], and BESS generation only). The Project must have equipment capable of receiving an analog setpoint, via DNP 3.0, from IPC for Voltage Control. IPC will issue an operating voltage schedule for the Project at the time the LGIA is executed. For more detail see the Control Requirements section of this Appendix C. Control Requirements Generator Output Limit Control (GOLC) IPC requires Interconnected Power Producers to accept GOLC signals from IPC’s energy management system (“EMS”). The GOLC signals will consist of four points shared between the IPC EMS (via the IPC RTU) and the Interconnection Customer’s Generator Controller (“ICGC”). The IPC RTU will be the master and the ICGC will be the slave. GOLC Setpoint: An analog output that contains the MW value the Interconnection Customer should curtail to, should a GOLC request be made via the GOLC On/Off discrete output Control point. o An Analog Input feedback point must be updated (to reflect the GOLC setpoint value) by the ICGC upon the ICGC’s receipt of the GOLC setpoint change, with no intentional delay. GOLC On/Off: A discrete output (DO) control point with pulsing Trip/Close controls. Following a “GOLC On” control (DNP Control Code “Close/Pulse On”), the ICGC will run power output back to the MW value specified in the GOLC Setpoint. Following a “GOLC Off” control (DNP Control Code “Trip/Pulse On”), the Interconnection Customer is free to run to maximum possible output. o A Discrete Input (DI) feedback point must be updated (to reflect the last GOLC DO Control Code received) by the ICGC upon the ICGC’s receipt of the GOLC DO control, with no intentional delay. The feedback DI should latch to an OFF state DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 • • First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 16 following the receipt of a “GOLC OFF” control and it should latch to an ON state following the receipt of an “GOLC ON” control. If a GOLC control is issued, it is expected to see MW reductions start within 1 minute and plant output to be below the GOLC Setpoint value within 10 minutes. Voltage Control IPC requires Transmission-Interconnected Power Producers to accept voltage control signals from IPC’s EMS when they are connected to IPC’s transmission system. The voltage control will consist of one setpoint and one feedback point shared between the IPC EMS and the ICGC. The setpoint will contain the desired target voltage for plant operation. This setpoint will have a valid control range between 0.95 and 1.05 per unit (“p.u.”) of nominal system voltage. The control will always be active, there is no digital supervisory point like the Curtail On/Off control above. When a setpoint change is issued an Analog Input feedback point must be updated (to reflect the voltage control setpoint value) by the ICGC upon the ICGC’s receipt of the voltage control setpoint change, with no intentional delay. When a setpoint change is received by the ICGC, the voltage control system should react with no intentional delay. The voltage control system should operate at the voltage indicated by the setpoint with an accuracy of +/- 0.5% of the nominal system voltage. The Interconnection Customer should supervise this control by setting up “reasonability limits”, i.e., configure a reasonable range of values for this control to be valid. As an example, they will accept anything in the valid control range (between 0.95 and 1.05 p.u.) but reject values outside this range. If they were fed an erroneous value outside the valid range, their control system would default to the last known, good value. DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 • • • First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 17 Generation Interconnection Data Point Requirements Digital Inputs to IPC (DNP Obj. 01, Var. 2) Index Description State (0/1)Comments: 0 GOLC Off/On (Control Feedback) Off/On Feedback provided by Interconnection Customer 1 FREQUENCY RESPONSE OFF/ON (Control Feedback) Off/On Feedback provided by Interconnection Customer 2 52A Interconnection Customer Main Breaker (if present)Open/Closed Sourced at substation 3 52A Interconnection Customer Capacitor Breaker (if present) Open/Closed Sourced at substation Digital Outputs to Interconnection Customer (DNP Obj. 12, Var. 1) Index Description Comments: 0 GOLC Off/On Control issued by IPC 1 Frequency Response Off/On Control issued by IPC DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 18 Analog Inputs to IPC (DNP Obj. 30, Var. 2) Index Description Raw High Raw Low EU High EU Low EU Units Comments: 0 GOLC Setpoint Value Received (Feedback)32767 -32768 TBD TBD MW Provided by Interconnection Customer 1 Voltage Control Setpoint Value Rec’d (Feedback)32767 -32768 TBD TBD kV Provided by Interconnection Customer 2 Maximum Park Generating Capacity 32767 -32768 TBD TBD MW Provided by Interconnection Customer 3 Ambient Temperature 32767 -32768 327.67 -327.68 DEG C Provided by Interconnection Customer 4 Wind Direction 32767 -32768 327.67 -327.68 Deg from North Provided by Interconnection Customer 5 Wind Speed 32767 -32768 327.67 -327.68 M/S Provided by Interconnection Customer 6 Relative Humidity 32767 -32768 TBD TBD % Provided by Interconnection Customer 7 Global Horizontal Irradiance 32767 -32768 TBD TBD W/M^2 Provided by Interconnection Customer 8 Plane of Array Irradiance 32767 -32768 TBD TBD W/M^2 Provided by Interconnection Customer 9 SPARE 10 SPARE 11 SPARE 12 SPARE 13 SPARE 14 SPARE 15 SPARE 16 SPARE 17 SPARE DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 19 Analog Outputs to Interconnection Customer (DNP Obj. 41, Var. 2) Index Description Raw High Raw Low EU High EU Low EU Units Comments: 0 GOLC Setpoint 32767 -32768 TBD TBD MW Control issued by IPC 1 Voltage Control Setpoint 32767 -32768 TBD TBD kV Control issued by IPC 2 SPARE 3 SPARE 4 SPARE 5 SPARE 6 SPARE 7 SPARE 8 SPARE 9 SPARE DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 20 Appendix D to LGIA Security Arrangements Details Infrastructure security of Transmission System equipment and operations and control hardware and software is essential to ensure day-to-day Transmission System reliability and operational security. FERC will expect all Transmission Providers, market participants, and Interconnection Customers interconnected to the Transmission System to comply with the recommendations offered by the President’s Critical Infrastructure Protection Board and, eventually, best practice recommendations from the electric reliability authority. All public utilities will be expected to meet basic standards for system infrastructure and operational security, including physical, operational, and cyber-security practices. DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 21 Appendix E to LGIA Commercial Operation Date This Appendix E is a part of the LGIA between Transmission Provider and Interconnection Customer. [Date] Idaho Power Company Attention: Load Serving Operations Director 1221 W. Idaho Street Boise, ID 83702 Re: Franklin Solar #549 Large Generating Facility Dear _______________: On [Date] Franklin Solar LLC has completed Trial Operation of Unit No. . This letter confirms that Franklin Solar LLC commenced Commercial Operation of Unit No. ___ at the Large Generating Facility, effective as of [Date plus one day]. Thank you. [Signature] [Interconnection Customer Representative] DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 22 Appendix F to LGIA Addresses for Delivery of Notices and Billings Notices: Transmission Provider: Idaho Power Company–Delivery Attention: Load Serving Operations Director 1221 W. Idaho Street Boise, ID 83702 Phone: 208-388-5669 Fax: 208-388-5504 Interconnection Customer: Franklin Solar LLC Attention: Director, Solar Operations 550 South Caldwell Street Charlotte, NC 28202 Phone: 704-382-5920 or 980-701-7126 Email: solarmonitorgroup@duke-energy.com Billings and Payments: Transmission Provider: LB447, Idaho Power Company Attention: Corporate Cashier PO Box 35143 Seattle, WA 98124-5143 Phone: 208-388-5697 Email: asloan@idahopower.com Interconnection Customer: Before Commercial Operation: Franklin Solar LLC Attention: Solar Project Controls 550 South Caldwell Street Charlotte, NC 28202 Phone: 513-287-2047 Email: benjamin.devine@duke-energy.com After Commercial Operation: Franklin Solar LLC Attention: Managing Director, Commercial Business Services DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035 First Amendment to LGIA Idaho Power Company GI Queue #549 Franklin Solar Page 23 550 South Caldwell Street Charlotte, NC 28202 Phone: 704-382-6266 Email: janet.bridges@duke-energy.com Alternative Forms of Delivery of Notices (telephone, facsimile or email): Transmission Provider: Idaho Power Company–Delivery Attention: Load Serving Operations Director 1221 W. Idaho Street Boise, ID 83702 Phone: 208-388-5669 Fax: 208-388-5504 Interconnection Customer: Franklin Solar LLC Attention: Managing Director, Commercial Business Services 550 South Caldwell Street Charlotte, NC 28202 Phone: 704-382-6266 Email: janet.bridges@duke-energy.com DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035