20240906IPC to Staff 70 Attachment 2 - GIA 549 Amendment 1.pdf

GI 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
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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
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First Amendment to LGIA Idaho Power Company
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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
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First Amendment to LGIA Idaho Power Company
GI Queue #549 Franklin Solar Page 9
DocuSign Envelope ID : 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035
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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
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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
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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
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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
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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
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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
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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
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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
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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: [phone] Fax: [phone]

Interconnection Customer:
Franklin Solar LLC
Attention: Director, Solar Operations
550 South Caldwell Street
Charlotte, NC 28202
Phone: [phone] or 980-701-7126
Email: [e-mail]
Billings and Payments:
Transmission Provider:
LB447, Idaho Power Company
Attention: Corporate Cashier
PO Box 35143
Seattle, WA 98124-5143
Phone: [phone] Email: [e-mail]
Interconnection Customer:
Before Commercial Operation:
Franklin Solar LLC
Attention: Solar Project Controls
550 South Caldwell Street
Charlotte, NC 28202
Phone: [phone]
Email: [e-mail]

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: [phone]
Email: [e-mail]
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: [phone] Fax: [phone]

Interconnection Customer:
Franklin Solar LLC
Attention: Managing Director, Commercial Business Services
550 South Caldwell Street
Charlotte, NC 28202
Phone: [phone]
Email: [e-mail]
DocuSign Envelope ID: 5CD4F772-6F85-4EAE-BDD6-8C4D7CF1 E035