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Probabilistic Methods for Energy Networks, King’s College London, March 15, 2017
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Addressing uncertainty in power system operation and planning via two-stage robust
optimization
José M. Arroyo
E-mail: [email protected] Departamento de Ingeniería Eléctrica, Electrónica, Automática y Comunicaciones
Universidad de Castilla – La Mancha
Probabilistic Methods for Energy Networks, King’s College London, March 15, 2017
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Contents
Introduction
Dealing with uncertainty
Two-stage robust optimization
Numerical results
Conclusions
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Introduction
Power balance must be kept under continuously changing conditions
Reaction to changes constrained by:
Physical limits of system components
Non-instantaneous deployment of corrective actions
Need for decision making ahead of time Consideration of uncertainty
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Introduction
Tractability Hierarchical decision-making process according to time horizon
Operation Short-term decisions related to generation scheduling and dispatch
Planning Long-term decisions related to infrastructure investment
Decisions under different levels of uncertainty
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Two-stage decision framework
First-stage decisions anticipate uncertainty
Generation scheduling, base-case dispatch, investment decisions
Second-stage decisions model the reaction against uncertainty
System operation under each uncertainty
realization
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Two-stage decision framework Operation-related example
Day-ahead market clearing, look-ahead unit
commitment
Prior to day d Day d
Generation schedule and
base-case dispatch
Actual generation dispatch
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Two-stage decision framework Planning-related example
Static transmission network expansion
planning
Planning horizon
Investment
decisions
System operation
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Contents
Introduction
Dealing with uncertainty
Two-stage robust optimization
Numerical results
Conclusions
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Uncertainty sources
Availability of system components
Fluctuations in nodal injections
Demand
Renewable-based generation levels
Injections/withdrawals from electric vehicles
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Addressing component outages
Two types of contingencies:
Random failures Existence of a probability distribution
Non-random deliberate outages Absence of a probability distribution
Industry practice driven by criticality of power system infrastucture
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Addressing component outages
Notion of deterministic security (worst-case
setting) Capability to withstand outages
Implemented via reserves (operation) and redundancy (planning)
Deterministic security criteria: n – 1, n – 2, n – K, n – K
G – K
L
Contingency-constrained models
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Addressing component outages Contingency-constrained models
Power balance guaranteed for:
Pre-contingency state (normal state)
A set of credible contingencies (security criterion)
Replication of operational constraints
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Addressing component outages Contingency-constrained models
Large-scale mixed-integer program
Economic goal
Second-stage constraints
First-stage constraints
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Contingency-constrained models Each event represents a combination of
unavailable assets
Asset availability is characterized by binary
parameters (generator outages) and
(line outages)
1 for available asset
0 for unavailable asset
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Contingency-constrained models
Contingency set determined by the security criterion being adopted
({ }
{
}
)
Objective function does not explicitly depend on second-stage variables
Computational issue Problem dimension depends on the size of the contingency set
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Addressing component outages Contingency-constrained models
Contingency 1
First-stage decisions Second-stage decisions
Contingency 2
Contingency |C|
Feasible reaction under
contingency 1
Feasible reaction under
contingency 2
Feasible reaction under
contingency |C|
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Equivalent penalized model
Nodal power imbalance is allowed Slack variables
Penalty term in the objective function associated with the worst-case system power imbalance
Equivalence guaranteed by a sufficiently large
penalty coefficient
Useful to understand the relationship with robust optimization
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Equivalent penalized model
Also a large-scale mixed-integer program
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Addressing nodal fluctuations Traditional context
Nodal fluctuations were typically associated
with demand, which was characterized by: Short-term fluctuation (typically low)
Long-term demand growth (typically steady)
Use of deterministic models relying on forecast values
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Addressing nodal fluctuations today
Increasing penetration of renewable-based generation and future electric vehicles
Larger short-term fluctuations due to variability and intermittency
Unknown long-term penetration level
Worldwide economic context Unforeseen impact on demand growth
Need to consider associated uncertainty
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Two-stage stochastic programming
Probabilistic approach suitable for two-stage decision making
Uncertainty is modeled based on:
Known probability distributions
Scenario-based discretizations
Best performance “on average” driven by a measure of risk aversion
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Two-stage stochastic programming
Uncertainty
realization 1 with
probability 1
First-stage decisions Second-stage decisions
Uncertainty
realization 2 with
probability 2
Uncertainty
realization || with
probability ||
Not necessarily feasible
reaction under
uncertainty realization 1
Not necessarily feasible
reaction under
uncertainty realization 2
Not necessarily feasible
reaction under
uncertainty realization ||
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Two-stage stochastic programming Scenario-based models
Large-scale mixed-integer program
Scenario-dependent economic goal
Second-stage constraints
First-stage constraints
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Two-stage stochastic programming Scenario-based models
Somewhat similar to contingency-constrained models:
Replication of second-stage constraints
Each scenario represents a combination of nodal injections through parameters
Salient aspect Objective function explicitly depends on second-stage variables
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Two-stage stochastic programming Practical issues
Accurate probabilistic information may be either difficult to obtain or simply unavailable
Scenario-based models Non-trivial tradeoff between accuracy (discretization of uncertainty) and tractability (problem size dependent on scenario set size)
Potential infeasibility in some scenarios Crucial in planning
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Addressing component outages and nodal injection uncertainty
Contingency-constrained two-stage stochastic
programs Increased intractability issues
( )
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Contents
Introduction
Dealing with uncertainty
Two-stage robust optimization
Numerical results
Conclusions
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Modeling framework
Worst-case rather than probabilistic setting:
Optimization process considers the impact of uncertainty realizations on first-stage decisions while disregarding their likelihood
Objective function:
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Modeling framework
Suitable for:
Contingency-constrained models relying on deterministic security criteria
Models with inaccurate probabilistic
characterizations of uncertainty Non-random events, penetration of renewables
Planning models where criticality of power
system infrastructure prevails
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Key aspects Implicit second-stage model
Uncertain parameters ( ,
, ) replaced
with decision variables ( ,
, )
Contingency- or scenario-dependent variables ( , ) replaced with variables ( )
Second-stage constraints replaced with a
max-min problem Trilevel counterpart
Size independent of cardinalities of and
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Key aspects Uncertainty-modeling variables
Driven by the maximization of the “damage” (infeasibility, operation cost) of the reaction against uncertainty
Feasibility characterized by a pre-specified,
uncertainty set, i.e., Y
Y encompasses the security criterion and the
limited availability of probabilistic information
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Key aspects Uncertainty set
Discrete and/or interval based:
{ }
[
]
Bounds based on practical aspects and/or historical data
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Key aspects Uncertainty set
Uncertainty budgets to limit conservativeness:
Security criterion ({ }
{
} )
Fluctuation limits for based on
engineering judgement
Polyhedral versus ellipsoidal uncertainty sets
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Key aspects Variables under uncertainty
Driven by the minimization of the “damage” (infeasibility, operation cost) of the reaction against uncertainty
Feasibility characterized by second-stage constraints parameterized in terms of first-stage and uncertainty-modeling variables:
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Robust counterpart
subject to:
su
First stage
Second stage
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Robust counterpart
Large-scale mixed-integer nonlinear trilevel program
Binary variables may be present both in the objective function and the constraint set at any level
No general exact and computationally-efficient solution approach available
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Existing solution techniques
Heuristics or metaheuristics not based on
sound mathematical programming Greedy randomized adaptive search procedures (GRASP)
Decomposition-based methods Finite convergence to optimality under specific conditions and assumptions
All available methods rely on the solution of the max-min second-stage problem
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Decomposition-based methods
Iterative solution of a master problem and a subproblem:
Accelerated Benders decomposition
Column-and-constraint generation
algorithms
Very similar approaches
Probabilistic Methods for Energy Networks, King’s College London, March 15, 2017
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Decomposition-based methods Master problem
Relaxation of the trilevel counterpart First-
stage decisions
Iteratively tightened with information from the subproblem
Large-scale mixed-integer program of growing dimension along the iterative process
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Decomposition-based methods Subproblem
Two lowermost levels for given first-stage
decisions from the master problem Second-stage decisions:
Worst-case values for uncertainty-modeling
variables
Best reaction
Max-min problem
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Decomposition-based methods
MASTER PROBLEM
First-stage decisions
Tightening constraints
(Benders cuts, lower-level constraints) SUBPROBLEM
Second-stage decisions
Upper bound for optimal value of upper-level objective function
Lower bound for optimal value of upper-level objective function
x
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Decomposition-based methods Techniques for the subproblem
Duality- or KKT-based bilinear single-level equivalent and iterative heuristic (outer
approximation, separation procedure) Fast heuristic suitable for large-scale problems
Duality- or KKT-based linearized single-level
equivalent Exact for correct bounding parameters for dual variables, scalability issues
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Decomposition-based methods Techniques for the subproblem
Block coordinate descent method (no dual information, no linearization schemes, bilevel
structure kept) Fast iterative heuristic suitable for large-scale problems
Column-and-constraint generation algorithm (in the presence of lower-level binary
variables) Exact, scalability issues
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Contents
Introduction
Dealing with uncertainty
Two-stage robust optimization
Numerical results
Conclusions
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Models
Contingency-constrained generation scheduling (CC-GS)
Contingency-constrained generation scheduling under wind uncertainty (CC-U-GS)
Contingency-constrained transmission network expansion planning (CC-TE)
Transmission network expansion planning with uncertain generation and demand (U-TE)
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CC-GS
Accelerated Benders decomposition and linearized duality-based single-level conversion
Master problem and subproblem are MILP solved with CPLEX under GAMS
IEEE RTS, IEEE 118-bus system, 1 period
n – K and n – KG – K
L security criteria
Optimality gaps well below 1%
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CC-GS. IEEE RTS case
K Contingency-
dependent model Robust model
System cost ($)
Time (s) System cost ($)
Time (s)
0 2068020 00000.30 2068020 00.34
1 2688760 00003.60 2688760 00.75
2 3751680 00334.78 3751680 01.79
3 - 14400.00 5232740 16.77
4 Out of memory Infeasible 01.31
5 Out of memory Infeasible 02.45
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CC-GS. IEEE 118-bus case
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CC-U-GS
Column-and-constraint generation algorithm and linearized duality-based single-level conversion
Master problem and subproblem are MILP solved with CPLEX under GAMS
IEEE 118-bus system, 24 periods
Single-component outages, 10 wind farms
Optimality gaps well below 1%
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CC-U-GS. IEEE 118-bus case Performance of solution approach
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CC-U-GS. IEEE 118-bus case Solution quality
118-BUS SYSTEM–RESULTS FROM THE OUT-OF-SAMPLE ASSESSMENT
Imbalance (%)
ARO model Conventional model
Number of
samples
0 8668 8706 8779 9140 5606 (0.0, 0.5] 1267 1271 1199 0847 4256 (0.5, 1.0] 0064 0023 0021 0013 0133
>1.0 0001 0000 0001 0000 0005
Expected imbalance (%) 00.028 00.022 00.021 00.014 00.053 CVaR of imbalance (%) 00.435 00.367 00.366 00.271 00.500
Cost increases between 0.1% and 6.8%
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CC-TE
Accelerated Benders decomposition and linearized duality-based single-level conversion
Master problem and subproblem are MILP solved with CPLEX under GAMS
n – K security criterion
IEEE 118-bus system, IEEE 300-bus system
Optimality gaps well below 1%
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CC-TE. IEEE 118-bus case
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CC-TE. IEEE 300-bus case
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U-TE
Column-and-constraint generation algorithm
Primal block coordinate descent method (P-CC) versus linearized duality-based single-level conversion (D-CC)
MILP and LP solved with CPLEX under GAMS
IEEE 118-bus system, 2383-bus system
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U-TE. IEEE 118-bus case Quality and performance
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U-TE. 2383-bus system Practical applicability
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Contents
Introduction
Dealing with uncertainty
Two-stage robust optimization
Numerical results
Conclusions
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Conclusions
Robust optimization is suitable for operational and planning models under uncertainty
Implicit consideration of uncertainty realizations yields significant computational advantages over contingency- and scenario-dependent models
Tradeoff between accuracy of the uncertainty characterization, conservativeness and computational tractability
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Further research
Incorporation of impact of correlated uncertainty sources
Consideration of more accurate/sophisticated operational models (ramping, nonlinear load flow, line switching, quick-start units)
Analysis of alternative solution approaches to avoid the duality-based transformation
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References
A. Street, A. Moreira, J. M. Arroyo. “Energy and reserve scheduling under a joint generation and transmission security criterion: An adjustable robust optimization approach”. IEEE Transactions on Power Systems, vol. 29, no. 1, pp. 3-14, January 2014
A. Moreira, A. Street, J. M. Arroyo. “An adjustable robust optimization approach for contingency-constrained transmission expansion planning”. IEEE Transactions on Power Systems, vol. 30, no. 4, pp. 2013-2022, July 2015
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References
A. Moreira, A. Street, J. M. Arroyo. “Energy and reserve scheduling under correlated nodal demand uncertainty: An adjustable robust optimization approach”. International Journal of Electrical Power and Energy Systems, vol. 72, pp. 91-98, November 2015
N. G. Cobos, J. M. Arroyo, A. Street. “Least-cost reserve offer deliverability in day-ahead generation scheduling under wind uncertainty and generation and network outages”. IEEE Transactions on Smart Grid, in press, 2017
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References
A. Street, A. Moreira, J. M. Arroyo. “On the solution of large-scale robust transmission network expansion planning under uncertain demand and generation capacity”. https://arxiv.org/abs/1609.07902