Idaho Power Presentation Workshop.pdf

IPC-E-20-30
Staff Workshop
November 10, 2020
Introduction
2
1)Smart Inverters
–Voltage control
–IEEE 1547
2)Non-Export Option
–Proposed interconnection requirements
–Non-export control system
3)Energy Storage Devices
–Proposed interconnection requirements
Agenda Key Objective
•Address the technical aspects surrounding:
1)Smart Inverters and IEEE 1547 for distributed
energy resources (“DERs”)
2)The proposed Schedule 68 interconnection
requirements for customer’s installing DERs
•Open to questions and discussion throughout
1
2
3
Idaho Power
Company
Jared Ellsworth Transmission, Distribution & Resource Planning Director
Marc Patterson Senior Engineer, Planning, Engineering and Construction
Connie Aschenbrenner Rate Design Senior Manager
IEEE 1547 and 1547.1
3
Smart Inverters1
IEEE 1547
Standard
IEEE 1547 was the first of a series of standards developed by Standards Coordinating
Committee 21 on Fuel Cells, Photovoltaics, Dispersed Generation, and Energy Storage
(SCC21) concerning distributed resources interconnection
Voltage
Regulation
IEEE 1547 has been amended in response to a widely expressed need to make
changes to subclauses related to voltage regulation, voltage response to Area EPS
abnormal conditions, and frequency response to Area Electric Power System (“EPS”)
abnormal conditions
Test
Procedures
IEEE 1547.1 provides conformance test procedures for equipment interconnecting
DERs with the Area EPS.
ANSI C84.1
4
Smart Inverters1
(a)
(a)
(b)
Nominal
System
Voltage
104
106
108
110
112
114
116
118
120
122
124
126
128
Utilization
Voltage
Service
Voltage
120-600 V
Systems
Service
Voltage
> 600 V
Systems
Utilization
Voltage
Service
Voltage
120-600 V
Systems
Service
Voltage
> 600 V
Systems
Range A Range B•ANSI C84.1 establishes the nominal
voltage ratings and operating
tolerances for 60-Hz electric power
systems above 100 volts up to a
maximum system voltage of 1,200 kV
(steady state voltage levels only)
–Range A: Normal operation
–Range B: Abnormal operation
Overview Range A & Range B Utilization and Service Voltage
Notes:
(a) The shaded portions of the ranges do not apply to circuits supplying lighting load.
(b) The shaded portion of the range does not apply to 120 V –600 V systems
Voltage Deviation & DER
•In most cases, it is the customer with DER that creates the voltage deviation, especially in locations
with high levels of penetration
•Rule K, Section 4: “The customer is solely responsible for the selection, installation, and
maintenance of all electrical equipment and wiring (other than the Company’s meters and
apparatus) on the load side of the Point of Delivery.”
•The customer with a DER can most cost effectively mitigate the deviation through the installation
of a smart inverter
•The alternative would be more costly distribution system upgrades required to allow continued or
expanded operation of the customer-generators
Voltage Deviation and DER Mitigation Overview
5
Smart Inverters1
Load Tap Changer (“LTC”)
6
Smart Inverters1
Illustration of LTC Control LTC Operation
•The LTC Control has a voltage set point, a voltage
bandwidth, and a time delay
•Comparative study of LTC algorithms CIRED2014 –
simulated for high penetration distribution feeder
Voltage profile B is above the
upper limit, but returns before
the time delay –no LTC
operation
Voltage profile A is below the
lower limit, longer than the time
delay –LTC operation occurs
Source: CIRED Workshop –Rome, June 11-12, 2014, Paper 0376
DER Feeder Voltage Rise
7
Smart Inverters1
120.5
121.0
121.5
122.0
122.5
123.0
123.5
124.0
124.5
0 5,000 10,000 15,000 20,000 25,000 30,000 35,000
Vo
l
t
a
g
e
Distance from Substation (Ft.)
No DER Modeled with DER
Normal & Abnormal Operating
Performance Categories
8
Smart Inverters1
Normal Performance Categories Abnormal Performance Categories
•Categories A and B for voltage regulation
performance and reactive power capability
requirements
•Categories I, II, and III for disturbance ride-through
requirements
Category B
•Reactive power requirements to regulate voltage for
DERs that are inverter based with inherent power
output variability (e.g., solar)
123.6
127.2
122.4
128.4 (0.50)
(0.40)
(0.30)
(0.20)
(0.10)
-
0.10
0.20
0.30
0.40
0.50
105 110 115 120 125 130
Vo
l
t
A
m
p
s

P
e
r

U
n
i
t
Volts (120V Base)
Idaho Power Proposed Settings Default B
LTC Bandwidth
120.5V to 123.5V
Distribution Voltage Operation
9
Smart Inverters1
126V
ANSI Range A
114V
127V
ANSI Range B
110V
Abnormal Operating Performance
Categories
Smart Inverters1
•Category I
–Based on minimal bulk power system (BPS) reliability needs
–Reasonably attainable by all DER technologies that are in common use today
•Category II
–Performance covers all BPS reliability needs
–Coordinates with the existing BPS reliability standard, NERC PRC-024-2 [B26]
–Developed to avoid adverse tripping of bulk system generators during system disturbances
•Category III
–Provides the highest disturbance ride-through capabilities
–Intended to address integration issues such as power quality and system overloads caused by DER tripping in
local Area EPS with high levels of DER penetration
–Provides increased bulk power system security by further reduction potential loss of DER during bulk system
events
10
Category III
•Smart Inverters
•0.88 –1.10 per unit (“p.u.”)
continuous operating range
•High-voltage & low-voltage
“ride-through” requirements
•Disconnection “trip”
requirements
11
Smart Inverters1
Non-Export Option
12
Non-Export Option2
General Requirements
•Submit a completed application to the Company to
interconnect non-exporting system
•Feasibility Review to determine the capability of the
Company’s electrical system to incorporate the DER
•All DER would be subject to applicable provisions of
Schedule 68
–Construction and operation of interconnection
facilities and disconnection equipment
–Inverter settings, metering equipment, protection
equipment, and non-export control system
Non-Export Application Process
Submit Application
Feasibility Review
Submit System
Verification Form
Complete Interconnection
Less than 3 MVA 3 MVA or Greater
Submit Application
Study Agreements
Customer Generator
Interconnection Agreement
Complete Interconnection
Non-Export Technical Requirements
The Non-Export generation facility must utilize one or more of the following:
–Advanced Functionality: Prevent unpermitted export
•Internal transfer relay, energy management system, or other customer facility hardware
or software system(s) is required.
–Reverse Power Protection: Ensure export power is limited
•Default setting for protective function is 0.1% (export) of DERs total nameplate capacity,
with maximum 2.0 second time delay
–Minimum Power Protection: Ensure a minimum amount of power is imported at all times
•Default setting shall be 5% (import) of DERs total nameplate capacity, with maximum 2.0
second time delay
13
1
2
3
Non-Export Option2
System Protection
14
Non-Export Option2
Rotating Machines
500 kVA
or less
500 kVA
–3 MVA+
May not require
additional system
protection
System protection
will be required
Inverter-Based*
Less than
3 MVA 3 MVA+
May not require
additional system
protection
System protection
will be required
*UL-1741 and IEEE 1547 compliant inverter required
Telemetering
15
Telemetering Requirements for Non-Export
•Instantaneous bi-directional analog real-power and
reactive-power flow information must be telemetered
directly to the operations center specified by Idaho
Power
•Idaho Power shall own and maintain the SCADA devices
at the facility owner’s expense
•The facility owner shall provide a telecommunications
data circuit to the operations center designated by Idaho
Power
–Idaho Power shall specify the communications
protocol for the data circuit
Non-Export Option2
Telemetering for all non-exporting
systems 3 MVA+
Energy Storage Devices
16
Energy Storage Devices3
AC Coupled Storage DC Coupled Storage
1
2
1
IPC-E-20-30
Staff Workshop
November 10, 2020