COPYRIGHT © MITSUBISHI ELECTRIC CORPORATION. ALL RIGHTS RESERVED. NO PART SHALL BE COPIED OR TRANSFERRED WITHOUT PRIOR PERMISSION. Grid‐Connected Energy Storage Steve Emling Mitsubishi Electric Power Products, Inc (1)
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Grid‐Connected Energy Storage
Steve EmlingMitsubishi Electric Power Products, Inc
(1)
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Agenda
1. Market drivers and regulatory environment2. Component analysis and system
architecture3. Examples of operational energy storage
systems – actual and potential uses
(2)
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MARKET DRIVERS AND REGULATORY ENVIRONMENT
(3)
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Utility Disco’s Utility LSE’s (retail)DR/EE ServicesAggregatorsEnd‐Users
IPP’sUtilitiesDevelopersEPC’sOwner’s EngineersFinancers
Source:: NERC “Understanding the Grid”, http://www.nerc.com/AboutNERC/Documents/Understanding%20the%20Grid%20DEC12.pdf
Energy Storage Stakeholders
Generation
Transco’sUtility Trans. OwnersEPC’sOE’s
Transmission Distribution
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Key Regulatory Entities
(5)
PSC/PUC’sUtility/LSE’sRetail ESCO’sAggregators
FERCNERCRTO/ISO’s
Source:: NERC “Understanding the Grid”, http://www.nerc.com/AboutNERC/Documents/Understanding%20the%20Grid%20DEC12.pdf
Generation
FERCNERCRTO/ISO’sPUC’sUtility PTO’s
Transmission Distribution
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CA AB2514 Applications Overview
(6)
Market ServicesIPP revenue
Utility Self‐Supply
T&D Avoided Cost
Bill Reduction and Incentives
Use Case Primary Benefit Conventional Technology
1 Peaker Plant Capacity, Energy, Ancillary Services
Combustion Turbine
2 Ancillary Services Only
Ancillary Services Combustion Turbine
3 Base Load Plant Capacity, Energy Combined Cycle Gas Turbine
4 Distributed Peaker Upgrade Deferral,Market Services
Circuit Upgrade,Combustion Turbine
5 Substation‐Sited Voltage Regulation Circuit Upgrade
6 Community Storage Voltage Regulation Circuit Upgrade
7 Behind the Meter Bill Management,Market Services
Circuit Upgrade,Combustion Turbine
8 Behind the MeterUtility Controlled
Bill management,Market Services, Grid Reliability
Circuit Upgrade,Combustion Turbine
9 Permanent Load Shifting
Bill Management, Grid Reliability
Combustion Turbine
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MISO ES Policy
• Added short term storage into tariff in 2009– Allowed storage to participate in frequency regulation
•MISO has yet to implement FERC 755– “Pay for Performance”
• Energy storage still cannot participate in other ancillary services such as spinning reserves, supplemental reserves, or ramping
(7)
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MISO ES Policy
• IPL filed a fast track complaint asking FERC to find MISO’s energy storage policies deficient and in need of revision
• IPL’s 20MW storage system provides frequency regulation, frequency response, and contributes to MISO’s NERC compliance– IPL asserts that there is no provision to compensate
them for frequency response – IPL also asserted that MISO’s tariffs for ancillary
services, energy, ramping, and capacity were designed… exclude applicable technologies like batteries
(8)
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MISO ES Policy
• "The Commission should direct that the Tariff be reformed so that Resources technically capable of providing various products under the Tariff be permitted to provide such products, regardless of resource label or technology."
(9)
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FERC: ISO & RTO Regions
(10)
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FERC: Frequency Response
(11)
• FERC announced in Feb. 2016 that they are considering whether all generators should be required to have the ability to provide frequency response and how they should be compensated (currently requirement is on balancing authorities)
• Reaction to increasing synchronous baseload units being replaced with wind and solar
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Industry Groups
• EPRI ESIC (Electric Power Research Institute Energy Storage Integration Council)
• Energy Storage Association (ESA)• IEEE 1547 (Distributed Energy Resources)•MESA Open Standards
(12)
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COMPONENT ANALYSIS AND SYSTEM ARCHITECTURE
(13)
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Battery Chemistry Comparison
(14)
Chemistry Eff.DC‐DC
Cycle Life, Full DoD
Shelf Life
O&M Safety Measures
MW’s Deployed
$/kWh, 4‐hr basis
Li‐ion,Power
98% 10,000 15 yr Low High >200MW 1K‐2K
Li‐ion, Energy
96% 5,000 10 yr Low Very High >100MW 400‐1000
NaS 87% 4,500 15 yr Low Med >500MW 500
Adv. PbA 85% 2,500 7 yr Med Med >100MW 300‐600
Adv. Flow
85% 100,000 30 yr Med Low >20MW 750‐1500
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Storage Technology Comparison
(15)
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Battery Container
(16)
Module24V
Cell3V
Rack800‐1500V
Container800‐1500V, 1MWh
Aisle
Rack
A/C, Communications, Controls
8ft
20ft
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System Architecture
(17)
PCS 2
Battery 1
LV/MV
PLC
Utility Circuit
Router
DC AC
Alarms, Warnings Current, Voltage
SOC, Temperature
Failure, Alarms, Warnings Charge/discharge power
Charge/discharge quantity signal
Measurement/Control Server Router
WAN
T/D
Frequency, Active and reactive power,
Voltage, Current
Control System (SCADA)
BLEnDer ® -RE
CB relay state
CB close/open control signal
Breaker close/open control signal
Battery 2
PCS 1
DC AC
Operation Center
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DC Coupled with Wind/PV
(18)
Batteries Wind/PV
=
1MW 1MW 2MW
2MVA
2MVA
Batteries Wind/PV
=
1MW 1MW 2MW
2MVA
4MVA
=
2MVA
• Reduces power conditioning scope• Avoids rating interconnection for full discharge of Wind/PV and
energy storage when intended operation is to shift Wind/PV output
AC Coupled DC Coupled
1000Vdc
480Vac
1000Vdc
480Vac
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Large Scale ES – STATCOM Interface
(19)
50MW 50MW 50MW 50MW
• Example – 200MW connected in 50MW blocks• Redundancy built into STATCOM components – over 99% availability factor• Lower cost per var than a power conditioning system• Much lower aggregation and balance of plant costs
3kVdc
13.8kVac
= 3kVdc
13.8kVac
= 3kVdc
13.8kVac
= 3kVdc
13.8kVac
=
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EXAMPLES OF OPERATIONAL ENERGY STORAGE SYSTEMS –ACTUAL AND POTENTIAL USES
(20)
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IPL Advancion Energy Storage Array (AES)
(21)
Project Information
• Owner & Operator: IPL
• Location: Indianapolis, Indiana
• Size: 20MW, 20MWh
• In‐operation Date: May 2016
• First large storage project in MISO
• Co‐sited with two 30MW combustion turbines (designated blackstart units)
Purpose: • Frequency regulation• (Frequency reserve)• (Ramping)• (Capacity)• (Energy)• (Blackstart)
Control System AES ADVANCION
Storage Samsung Li‐ionMaybe 2MW strings, not public
Power Conditioning System Parker HannifanMaybe 2MW units, not public
Balance of plant Casteel Corp.Building type system
Key Technologies and Configuration
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Frequency During ESS Blackstart
(22)
Peaker Unit BESS
0 5 10 15 20 25 3057
57.5
58
58.5
59
59.5
60
60.5
Time (s)
Gen
erat
or F
requ
ency
(Hz)
300 hp750 hp1500 hp3000 hp
0 5 10 15 20 25 3057
57.5
58
58.5
59
59.5
60
60.5
Time (s)
Gen
erat
or F
requ
ency
(Hz)
300 hp750 hp1500 hp3000 hp
• It was observed that the BESS provided better regulation of thefrequency at the 69 kV bus than a traditional peaker unit and it’sassociated excitation system
• The BESS resulted in reduced frequency dips at the regulating bus regardless ofthe size of the started generator
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Mitsubishi 50MW, 300MWh
(23)
• Owner & Operator: Kyushu Electric
• Location: Southwestern Japan
• Size: 50MW, 300MWh
• Footprint: 328ft x 460ft
• In‐operation Date: March 2016
• Follow up to two 1MW projects
Purpose: • Improve supply‐demand balance• Control grid voltage• Smooth delivery of renewables
Project Information
Key Technologies and ConfigurationControl System Mitsubishi BLEnDerRE
Storage NGK Sodium‐sulfur252 containers63 800kW strings (4 cont. ea.)
Power Conditioning System TMEIC63 1MVA units
Balance of plant Mitsubishi, Container system3.2MW aggr. ‐> 6kV25MW aggr. ‐> 66kV
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Duke Energy 100kW, 300kWh
(24)
• Owner: Aquion
• Location: Mt. Holly, North Carolina
• Size: 100kW, 300kWh
• In‐operation Date: February 2016
• Located at existing Rankin Substation• One of the distribution lines at
the substation has a 1.2MW PV
Purpose: • Renewable ramping (ultracaps)• Renewable shifting (batteries)• Load Following (batteries)
Project Information
Key Technologies and ConfigurationControl System Win Inertia SHAD
Storage Aquion flow batteryLikely 50kW, 300kWhMaxwell UltracapsLikely 50kW, ~1kWh
Power Conditioning System Win Inertia, DC coupled?
Balance of plant AquionSingle container
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Mitsubishi 6.2MW, 31MWh
(25)
• Owner & Operator: Chugoku Electric
• Location: Oki Island, Japan
• Size: 6.2MW, 31MWh
• In‐operation Date: September 2015
Purpose: • Renewable ramping (Li‐ion)• Frequency regulation (Li‐ion)• Renewable shifting (NaS)• Load Following (NaS)
Project Information
Key Technologies and ConfigurationControl System Mitsubishi BLEnDerRE
Storage NGK Sodium‐sulfur4.2MW, 30MWh (5 800kW strings)GS Yuasa Li‐ion2MW, 1MWh
Power Conditioning System TMEIC
Balance of plant MitsubishiContainer type system
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Golden Valley Electric Association BESS
(26)
• Owner & Operator: GVEA
• Location: Fairbanks, Alaska
• Size: 27MW, 6.75MWh
• In‐operation Date: September 2003
• Located on the load side of a weak transmission line
• Provides 15 min of backup power while local generation is started
Purpose: • Spinning Reserve Capacity
o 584 outages avoidedo Est. 3.8M cumulative
customers protected• Voltage Support
o 5 to 7 MVAR continuously• “Reliability and Quality”
Project Information
Key Technologies and ConfigurationControl System ABB
Storage Saft Ni‐Cad13,760 cells, 165lb each
Power Conditioning System ABB
Balance of plant City ElectricBuilding type systemOperates at over 5kVdc
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ETT/AEP Presidio “Big Old Battery”
(27)
• Owner & Operator: ETT/AEP
• Location: Presidio, Texas
• Size: 4MW, 32MWh (8hr)
• In‐operation Date: April 2010
• Located on the load side of a weak transmission line
• Provides 8hr backup in the case of lost transmission line
Purpose: • Capacity• Non‐spinning reserves• Voltage support
Project Information
Key Technologies and ConfigurationControl System S&C
Storage NGK Sodium‐Sulfur
Power Conditioning System S&C
Balance of plant N/ABuilding type system
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ETT/AEP Presidio “Big Old Battery”
(28)
• Included in rate base
• “The only genuine issue requiring decision by the Commission is one of classification: Is the NaS battery appropriately treated as a transmission asset and eligible for TCOS rate treatment?”
• Commission Staff asserts that the proposed battery should receive a split‐rate treatment because only the reactive‐power portion of the battery is a transmission facility and eligible for recovery in TCOS under P.U.C. SUBST. R. 25.192(c)(1)(D) while the back‐up service portion of the battery providing transmission at distribution voltage is a distribution facility that must be recovered in a separate wholesale transmission rate schedule under which American Electric Power Texas North Company would be a customer.
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AEP Los Andes BESS
(29)
• Owner & Operator: AES (3rd party)
• Location: Los Andes, Chile
• Size: 12MW, 4MWh
• In‐operation Date: Dec 2009
Purpose: • Frequency response• Synthetic Inertia• Frequency regulation
Project Information
Key Technologies and ConfigurationControl System AES
Storage A123 Li‐ion
Power Conditioning System Parker Hannifin
Balance of plant N/AContainer type system
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Transformer Upgrade Deferral
• Load growth experienced at a 40MVA substation
• Transformer overloaded during peak ‐> premature failure
• Can replace with 45MVA TX, or install 5MVA ESS
(30)
Load45 MVA
45 MVA
40 MVA rated
45 MVA
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Transformer Upgrade Deferral
• Load growth experienced at a 40MVA substation
• Transformer overloaded during peak ‐> premature failure
• Can replace with 45MVA TX, or install 5MVA ESS
• Annual Avoided Cost– 45MVA x $538/kVA x 9% FCR = $2.1M/yr
• If deferred for 5 years and re‐located– $21M
• Breakeven point for 5VA, 4hr ESS– $4200/kW, $1050/kWh
(31)
Load45 MVA
40 MVA
40 MVA rated
40 MVA
5 MVA
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Distribution Asset Optimization
(32)
Tran
sfor
mer
Overhead circuits
Distribution Substation
Underground circuit
69kV 12kV
BESS
Inter‐connect
Critical LoadApplications
Peak Load Relief• Expansion Deferral• Life Extension
Full Time V‐Reg Support• LTC switching reduction• V‐Sag mitigation• Loss reduction• Load phases balancing
Critical Load Backup
Overall improved asset utilization
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Lifting Transmission N‐1 Constraint
(33)
1000 MW
1000 MW
1000 MW
0 MW
Constraint• Must assume one line out of
service• Despite having 4000MW of
capacity, can only utilize 3000MW
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Lifting Transmission N‐1 Constraint
(34)
+‐1000 M
W
1000 MW
1000 MW
1000 MW
Constraint• Must assume one line out of
service• Despite having 4000MW of
capacity, can only utilize 3000MW
Solution• Add up to 1000MW of energy
storage to meet N‐1 planning criteria
• Able to utilize an extra 1000MW of transmission capacity
1000 MW
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ES Need to Supply Xcel Energy’s Peak 2030 Demand for 6 hours
(35)
• Based on projected 2030 peak demand of ~10,000MW as specified in Xcel Energy’s 2016 – 2030 Upper Midwest Resource Plan