Index
Note: Page numbers followed by f indicate figures and t indicate tables.
A
Administration Fee (AdminFee)
59
Aggregator Capacity Fee (AggCapFee)
58
Aggregator Energy Fee (AggEnFee)
58
Aggregators, electricity markets
35
business value model
55,
56f
degree of online monitoring
38–39
distribution-grid constraints
38,
39f
energy-schedule optimization
38
grid-connected units
37–38
power-system control services
38
vertically integrated
vs. liberalized system structure
36–37,
37f
Ancillary service market
171
Ancillary service provision, flexible unit portfolios
frequency control approach, benchmark portfolios
control band, energy-storing unit
44
cost function coefficients
46
economic parameters
46,
46t
number of water heaters
vs. parameter ranges
44,
45f
performance evaluation quantities
46
primary control with Portfolio A
46–48,
47f
primary control with Portfolio B
48–50,
49f
secondary control with Portfolio A
50–52,
51f
secondary control with Portfolio B
52–54,
53f
secondary frequency control signal data
44
simulation scenario parameter
44,
44t
net-operating profit
41–43
pay-as-bid pricing method
40
secondary control
40,
41f
structures and nomenclatures
39–40
Area control error (ACE)
99–100
B
Balancing authorities (BAs)
99
Battery-based energy-storage systems (ESS)
benefits and challenges
279
decentralized storage concept
energy and SOC limits
284
state-of-charge control
283
Business value model
55,
56f
C
bilevel cascade-mitigation
118
corrective controller (Level 2)
137–138
economically optimal energy schedule (Level 1)
137
hierarchical control strategy
136,
136f
closed-loop feedback process
117
electrical energy storage
127
natural gas energy storage
127
one-minute time steps
138
siting, sizing, and operational capability
126
temporary energy shortages
126
thermal energy storage
127
Charge-scheduling algorithm, EVs
interval-selection process
257
power-controlled coordinated charging
255
smooth-valley filling
257,
258
time-controlled coordinated charging
255
Compressed to air energy-storage (CAES) system
6–8,
9t
Control Response Fee (CrtlRespFee)
59–60
Control-Service Compensation (CtrlServComp)
58
regulating reserve MCP
173,
194
with regulating reserve procurement
183
D
Day-ahead (DA) energy dispatch
188–189
Day-ahead/real-time (DA/RT) interleave method
Demand response resources (DRR)
171
Discharge time at rated power (DTRP)
171–172
Distribution system operators (DSOs)
36–37
Dynamic regulation signal (REGD)
101–102
E
Electric energy storage (EES)
hydrogen storage system
15–17
lithium-ion batteries
12–13
metals availability
24,
26t
research and development
26
reserves/reserves base
23–24
sodium-sulphur batteries
11–12
Electricity Supplier (Supp)
57
charge-scheduling algorithm
interval-selection process
257
power-controlled coordinated charging
255
smooth-valley filling
257,
258
time-controlled coordinated charging
255
Energy-delivery systems
115
Energy-purchasing cost minimization problem
233–234,
235
Energy storage, fast regulation service
actual regulation responses
101,
101f
advantages of storage resources
98,
98t
ancillary service market
103
fast and slow resources
104
regulation capacity price
104
regulation up-and regulation-down capacity
103
market-clearance processing, PJM
capacity and mileage definition
105–106
mileage correlation factor
106
PJM’s regulation service features
107
regulation procurement
100
secondary frequency control
balancing services and balancing reserves
99
Energy storage level (ESL)
182
nonlinear complimentarity condition
128–129
normal and contingency operation
128
steady-state storage-power values
128
Energy-storage operation strategy
communication channel
237
distribution-network topology
231f
distribution-system economic performance
237
communication and control network structure
236f
energy price determination
233
energy-purchasing cost minimization problem
233–234,
235
longer-term forecasting
235
MPC-based operation strategy
232–234
short-term forecasting
235
state-of-charge (SOC) level
233
IEEE reliability test system
cost/benefit analysis
245
DC optimal power flow
242
expected energy not served (EENS)
243t
reliability evaluation framework
assessment flowchart
240f
Monte Carlo simulation
239
system-state determination
241
Equipment and ICT Cost (EquipICTFee)
59
Equipment and ICT Supplier (ICT)
57
European Power Exchange (EPEX)
40
External Asynchronous Resource (EAR)
F
Fast-responding regulation service (FRRS)
frequency decay, unit trips
111,
111f
Flywheel energy storage
17
Frequency control approach, benchmark portfolios
control band, energy-storing unit
44
cost function coefficients
46
economic parameters
46,
46t
number of water heaters
vs. parameter ranges
44,
45f
performance evaluation quantities
46
primary control with Portfolio A
46–48,
47f
primary control with Portfolio B
48–50,
49f
secondary control with Portfolio A
50–52,
51f
secondary control with Portfolio B
52–54,
53f
secondary frequency control signal data
44
simulation scenario parameter
44,
44t
G
Generation-Coupling Fee (GenCoupFee)
58–59
forecasted optimal “target” system
115,
116f
H
dispatchable hydro units
204
production-cost simulation model
208–209
I
IEEE reliability test system
cost/benefit analysis
245
DC optimal power flow
242
expected energy not served (EENS)
243t
data management and communication
165–166
Dove and Waxwing conductors
159–160
interconnected physical regions
159,
160f
138 kV and 230 kV subsystems
159
73 nodes and 120 branches
159
base-case cascading failure
162
Level 1 economic reference
164f,
165
line temperature reduction
164f,
165
ancillary service market
103
fast and slow resources
104
regulation capacity price
104
regulation up-and regulation-down capacity
103
L
Large-scale battery-storage systems
stochastic
vs. deterministic design
310,
311f
stochastic wind generation
297
Limited energy stored resources (LESR)
172
initial disturbance, overloads and line tripping, and terminal blackout
122–123,
123f
deterministic outage model
120
probabilistic thermal outage model
cumulative density function
120–121
mixed-integer disjunctive line outage
122
transmission and sagging lines
120–121
Lithium-ion batteries
12–13
market-clearing mechanism
233
MPC-based operation strategy
235–236
renewable-energy generation
231–232
Locational marginal prices (LMPs)
70
Lost opportunity cost (LOC)
104,
106
M
Manitoba hydro (MH) system
dispatchable hydro units
202
generation scheduling
202
production-cost savings
224f
reserve-cost savings
224f
Market-clearance processing
233
capacity and mileage definition
105–106
mileage correlation factor
106
PJM’s regulation service features
107
Market clearing price (MCP)
market-wide and zonal reserve MCPs
176–178
Midcontinent Independent System Operator (MISO) energy market design
fast-responsive storage resources
vs. conventional regulation resources
172
market-based capacity payment
172–173
market-based performance payment
172–173
reliable and economical procurement
171
limit constraints and ramp constraints
176
market-product qualification
173–174
market-wide and zonal reserve MCPs
176–178
market-wide constraints
175
resource-level constraints
176
transmission constraints
175
storage device characteristics
171–172
Mid-term (MT) schedule model
210–211
Mileage correlation factor
106
a priori disturbances
134
process/batch control
134
temperature-based predictive algorithms
117–118
tree-based search method
117
electrical energy storage
127
natural gas energy storage
127
one-minute time steps
138
siting, sizing, and operational capability
126
temporary energy shortages
126
thermal energy storage
127
computation and optimization
124
energy-carrier networks
125
interconnected elements
125
N
Net-operating profit, revenue potential
generator ramping cost
41–43
individual revenue and cost terms
41–43
storage cycling cost
41–43
Nickel-cadmium (NiCd) batteries
11
P
Photovoltaics (PVs) power generation
conventional storage strategy
280,
281f
LV grid-supportive storage
power-quality standard (EN 50160)
282
Photovoltaic (PV) systems
distribution system architecture
251,
252f
frequency fluctuations
251
output power daily curve
252f
Point of common coupling (PCC)
281–282
nodes and arcs physical relationship
131
power-balance equation
130,
131
Power nodes modeling framework (PNMF)
35
Power-Plant Capacity Fee (PPCapFee)
58
Power-Plant Energy Fee (PPEnFee)
58
Production-cost simulation model
208–209
Profit-sharing methodology
Equipment and ICT Supplier
57
application, water heater
additional revenue, Portfolio A
64
additional revenue, Portfolio B
64
exchange parameters
61–62
financial compensation
64–65
negative bar, Energy Exchange
63–64
primary control provision by Portfolio A
62
primary control provision by Portfolio B
62
secondary control provision by Portfolio A
62
secondary control provision by Portfolio B
63
yearly financial results of scenarios
62–63,
62t
business value model
55,
56f
graphic and mathematical representation
54
actors cash in-and outflows
57–58
Aggregator Capacity Fee
58
Control Response Fee
59–60
Control-Service Compensation
58
Equipment and ICT Cost
59
Generation-Coupling Fee
58–59
Power-Plant Capacity Fee
58
Power-Plant Energy Fee
58
Wholesale Electricity Fee
59
Pumped hydroelectric storage (PHS)
5–6
Q
Quadratic programming (QP) problem
151–152
R
field result analysis
88,
88f
filtered ramp (violation) rates
88,
90f
minute-to-minute ramp rate
88,
89f
unfiltered ramp rates
88,
89f
Real-time energy dispatch
SERRegDeployfactor results
191,
193t
co-optimization with regulating reserve procurement
183
amount of regulation maximization
184
regulating reserves maximization
184
ramp and limit constraints
185
resource offers and parameters
185,
186t
complementarity condition
152
Level 1 reference trajectories
154
power-balance constraints
153
prediction and control horizons
149
simultaneous charging and discharging
155–157
state and input vectors
150
temperature overload alleviation
154–155
thermal conductor model
152
uncontrollable inputs
149
Regulating reserve MCP, short-term SER
market-wide short-term SER regulating reserve constraint
178
performance-based regulation compensation
cleared regulation capacity
194,
195
market-wide regulating mileage
195
performance accuracy measurement
196
regulating capacity offer
194,
195
regulating mileage MCP
196
regulating mileage offer
194,
195
regulation total offer
195
two-part payment methodology
194
vs. spinning/supplemental reserve MCP
178–179
Regulation market clearing prices (RMCP)
107
Reliability assessment commitment (RAC) energy dispatch
188–189
net-operating profit
41–43
pay-as-bid pricing method
40
secondary control
40,
41f
Run-of-the-river (ROR) hydro units
204
S
Security-constrained economic dispatch (SCED)
103
limit constraints and ramp constraints
176
market-product qualification
173–174
market-wide and zonal reserve MCPs
176–178
market-wide constraints
175
resource-level constraints
176
transmission constraints
175
Shrinking-horizon MPC (SHMPC)
deterministic line-tripping model
138
energy-hub network disturbances
device availability and performance
141
random grid-generating techniques
141–142
storage capacity and storage power limits
142–146
Smart-grid communication
230
Smooth-valley filling
257,
258
generation-shifting capability
negative contributors
82,
83f
off-peak to on-peak
74,
74f
optimal storage-to-wind ratio
82–85
positive contributors
82,
83f
field result analysis
88,
88f
filtered ramp (violation) rates
88,
90f
minute-to-minute ramp rate
88,
89f
unfiltered ramp rates
88,
89f
storage-to-wind ratio
72–74
Sodium-sulphur batteries
11–12
Stochastic unit commitment (SUC)
308
Storage Owner (StrgOw)
57
Superconducting magnetic energy-storage (SMES)
15
SwissIX spot market price
40
T
Tiered bidding method
203,
215
Total harmonic distortion (THD)
254
V
Vanadium redox batteries (VRB)
14–15
Variable renewable electricity sources (VRES)
load-following timescale
21–22
macroscale variations
2–3
microscale variations
2–3
seasonal energy storage
22–23
unit-commitment timescale
22
wind-power integration
3–4
Vehicle-to-grid (V2G) capacity-estimation method
chargeability and drivability
263–265
EV battery-power ratings
263
Virtual power plants (VPPs)
35
W
Wholesale Electricity Fee (WhElecFee)
59
Wholesale Market (WhMa)
57
installed capacity
67,
68f
Wind-to-Battery (W2B) project
72
Z
Zinc-bromine (ZBR) batteries
13–14