Three-Level Co-optimization Model for Generation Scheduling of Integrated Energy and Regulation Market
|
|
- Winfred Andrews
- 5 years ago
- Views:
Transcription
1 MITUBIHI ELECTRIC REEARCH LABORATORIE Three-Level Co-optimization Model for Generation cheduling of Integrated Energy and Regulation Market un, H.; Takaguchi,.; Nikovski, D.N.; Hashimoto, H. TR Decemer 2017 Astract This paper proposes a three-level co-optimization model for determining energy production and regulation reserve schedule in a day-ahead market y minimizing the total cost of unit commitment, generation dispatch, frequency regulation and performance. The unscented transformation and historical profiles are used to generate scenarios for modelling the fluctuations of intermittent renewale and stochastic loads at different time scales. Through detailed modelling and simulation of generation dispatch and frequency regulation, the determined generation schedule can have sufficient reserve capacity and adequate response speed to deal with the renewale and load variations occurred etween shorter dispatching and regulating intervals, as well as longer scheduling intervals. Numerical results on a 5-us sample system are given to demonstrate the effectiveness of proposed method. IEEE Innovative mart Grid Technologies Conference This work may not e copied or reproduced in whole or in part for any commercial purpose. ermission to copy in whole or in part without payment of fee is granted for nonprofit educational and research purposes provided that all such whole or partial copies include the following: a notice that such copying is y permission of Mitsuishi Electric Research Laoratories, Inc.; an acknowledgment of the authors and individual contriutions to the work; and all applicale portions of the copyright notice. Copying, reproduction, or repulishing for any other purpose shall require a license with payment of fee to Mitsuishi Electric Research Laoratories, Inc. All rights reserved. Copyright c Mitsuishi Electric Research Laoratories, Inc., Broadway, Camridge, Massachusetts 02139
2
3 Three-Level Co-optimization Model for Generation cheduling of Integrated Energy and Regulation Market Hongo un 1, usuke Takaguchi 2, Daniel Nikovski 1, and Hiroyuki Hashimoto 2 1 Mitsuishi Electric Research Laoratories Camridge, MA 02139, UA 2 Advanced Technology R&D Center Mitsuishi Electric Corporation Hyogo , Japan Astract This paper proposes a three-level co-optimization model for determining energy production and regulation reserve schedule in a day-ahead market y minimizing the total cost of unit commitment, generation dispatch, frequency regulation and performance. The unscented transformation and historical profiles are used to generate scenarios for modelling the fluctuations of intermittent renewale and stochastic loads at different time scales. Through detailed modelling and simulation of generation dispatch and frequency regulation, the determined generation schedule can have sufficient reserve capacity and adequate response speed to deal with the renewale and load variations occurred etween shorter dispatching and regulating intervals, as well as longer scheduling intervals. Numerical results on a 5-us sample system are given to demonstrate the effectiveness of proposed method. Keywords co-optimization; energy productin; frequency regulation; frequency regulation preformance; generation dispatch; regulation reserve; unit comitment I. INTRODUCTION Independent system operators are responsile for maintaining an instantaneous and continuous alance etween supply and demand of power system through managing the energy and reserve markets, including day-ahead market and real-time market. According to the forecasted or historical load and non-dispatchale generation profiles for next day, the commitment schedule of dispatchale generation units for next 24 hours are determined through solving a security-constrained unit commitment prolem. This task is complicated y the increased presence of distriuted energy resources and the continuing improvements on market regulations. The unpredictale nature of renewale energy sources leads to greater fluctuations in the amount of generated power availale [1]. Meanwhile, the renewale may demonstrate different characteristics in term of fluctuation magnitudes and frequency if its data sets are collected at different sampling rates. A unit commitment schedule, that conventionally determined ased on renewale and load profiles generated at longer time scale might not e optimal when implemented in real time due to the unit s technical constraints such as ramping rates and min up/down times. In addition, the market regulatory rules have also required the generation units rewarded y their services that they have actually provided or achieved in real time [2]. ithout taking the real-time renewale and load fluctuations into account in some manners, the gaps or deviations etween day-ahead schedules and real-time dispatch and control hardly e mitigated. There are many approaches availale for solving the stochastic unit commitment prolems, specially targeting for co-optimization of energy and reserve markets, such as [3]- [9]. Most of these approaches are focused on hourly generation and load variations, i.e. variations at scheduling intervals. In light of this, this paper proposes a three-level cooptimization model for determining the optimal energy production and regulation reserve schedule for generation units y minimizing the total cost of unit commitment, generation dispatch, frequency regulation and performance. The unscented transformation method is used to generate sample uncertainty scenario for renewale and load at scheduling intervals, and typical/historical renewale generation and load profiles are used to simulate the load and renewale fluctuations at dispatching and regulating intervals. Through detailed modelling of unit commitment, generation dispatch and frequency regulation in the process of co-optimization, the gaps or deviations etween day-ahead schedules and real-time dispatch and control implementation will e reduced, and thus the system efficiency can e improved and the profits for generation companies can e increased. II. THE ROOED METHOD The co-optimization of the energy production and regulation reserve services in a day-ahead market is proposed to e achieved through a three-level optimization process as shown in Fig. 1, including unit commitment, generation dispatch, and frequency regulation. The generation units are divided into dispatchale units that can perform energy production and regulation reserve tasks, and non-dispatchale generation units, such as renewale units that can only e used as constant powers. ome dispatchale units may do not have frequency regulation capaility, so can only e used for energy production. Based on the needs of system power alance, renewale spillage and load shedding may e used ut at certain penalty charges. A. Uncertainty Modeling The uncertainty of renewale and load at scheduling intervals are modelled through a set of sample uncertainty scenarios that generated ased on unscented transformation technique [10]. Assumed " is the vector of active powers contriuted or consumed y renewale sources or load demands at scheduling interval h, and follows the Gaussian distriution with mean " and covariance Q " : " ~N( ", Q " ) (1a) A set of scenarios, h is created y using a set of (2n1) sample points: " = " " n λ 0 Q " Q " (1)
4 where, n is the total numer of renewale sources and load demands, λ = α 3 n κ n, α and κ are the parameters that determine the spread of the sigma points around. For example, we set: α = 1.0, κ = 1. The square root of the covariance matrix, Q h can e solved using the Cholesky factorization method. Using For any variale " associated with " according to " = f( " ), its mean vector, " can e determined ased on the sample points of " : 3< " = => ": f ": (1c) where ": is the weight factor for uncertainty scenario h A, "B = λ/ n λ, and ": = 0.5/ n λ if k>0. Dividing the sample points with corresponding forecasted means as shown in (1), we can get a set of scale factors for each uncertainty scenario. Those scaling factors are solely defined y the renewale and load covariance, and can e used to derive the values for uncertainty scenario ased on renewale and load forecasts. Fig.1. Three-level co-optimization model for generation schedulin For a given scheduling interval h, the generation output of renewale r and power demand of load d under uncertainty scenario h A, FGH and FGH can e determined as: FGH = FG α FGH JGH = JG α JGH (2a) (2) where FG and JG, and α FGH and α JGH are the forecasted generations and demands, and scaling factors for renewale r and load d respectively. The renewale and load variations at dispatching and regulating intervals are determined ased on the corresponding variation factors defined ased on the historical profiles. For a dispatching interval m within scheduling interval h and uncertainty scenario h A, the renewale generation and load demand, FGH K and JGH K are determined as: FGH K = FGH 1 β FG,K (3) JGH K = JGH 1 β JGK (3) where β FG,K and β JGK are the renewale and load variation factors to represent the variations at dispatching interval m around average renewale generation and load demand at scheduling level h. imilarly, the renewale generation and load demand at regulating interval s within dispatching interval m of uncertainty scenario h A of scheduling interval h, FGH KM and JGH KM are determined as: FGH KM = FGH 1 β FGK β FGKM (4a) JGH KM = JGH 1 β JGK β JGKM (4) where β FGKM and β JGKM are the renewale and load variation factors for regulating inteval s. B. Unit Commitment The first level of co-optimization is to determine the unit commitment schedule under forecasted ase scenarios and sample uncertainty scenarios for renewale productions and load consumptions. The schedule defines the unit commitment statues and scheduling set points for all dispatchale units, renewale spillages for all renewale units, and load shedding for all loads in each scheduling interval. This level is solved through a master prolem and a set of slave prolems. The master prolem is used to determine the on/off status of dispatchale units, and ase scheduling set points for each generation unit. The slave prolem is used to verify whether the determined unit schedule can withstand certain uncertainty scenarios for each scheduling interval, and determine the sensitives of the generation adjustment cost over scheduling set points given y the determined commitment schedule. The master and slave prolems are iteratively solved to otain a unit commitment schedule with minimum commitment, dispatch and regulation cost. The master prolem in the first level can e formulated as: Minimize c O [ = G>Z C O u C u C \]^u C _`^p C O p C p C F>Z FG p FG C J>Z JG p JG c O` (5a) uject to: p F>Z FG p FG = J>Z JG p JG h (5) r R G J>Z JG p JG h (5c) r R G J>Z JG p JG h (5d) u R GZ RU R u U R R G J>Z JG p JG h (5e) f zg = [ G>Z u RD R u D R s n A>Z GH O`() c GH R G op lm nh (B) lq rn J>Z JG p JG h (5f) () p p c O` (5g) u u R GZ u u = 0 g, h (5h) p p R GZ p p = 0 g, h (5i) p r u R g, h (5j) p r u R g, h (5k) p p R GZ p R GZ r p r G G u R GZ RU R u U R g, h (5l) u RD R u D R g, h (5m) u Rv v>gow r Z u g, h (5n) u Rv v>gw r Z 1 u g, h (5o) FG r, h (5p) JG d, h (5q) p FG p JG π zr p F>Z π zf FG p FG J>Z π zj JG p JG l L O, h (5r) F f " F l L ƒ, h (5s) where, H and K G are total numers of scheduling intervals, and sample uncertainty scenarios at scheduling interval h. G is the total numers of dispatchale generation units. u, u and u are inary variales to indicate the unit committed, started-up and shut-down status. p, p and p andr are the unit scheduling set point for ase,r
5 case, incremental upward/downward generation changes etween two consecutive scheduling intervals, and the rampup and ramp-down reserve contriutions for generation unit \]^, C _`^, C O andc g.c O, C, C are the start-up cost, shutdown cost, fixed non-load cost, per unit variale cost, per unit ramp-up and ramp-down costs for unit g. RU R and RD R, U R andd R, R and R, UT R and DT R are the upward and downward ramping rate thresholds, start-up and shut-down ramping rate thresholds, maximum and minimal generation outputs, and minimum up and down times for unit g. R is the total numers of renewale generation units. p FG andc FG are the renewale spillage, and per unit spillage cost for renewale r. D is the total numers of loads. p JG andc JG are the load shedding, and per unit shedding cost for load d. L O is the set of overload transmission lines. f zg and F z are the power flows on line l at scheduling interval h and its power flow capacity. π zr, π zf and π zj are the allocation factors of dispatchale generator g, renewale r and load d to the power flow on transmission line l, which can e determined using DC load flow formulations. R G and R G, R G and R G are the required ratios of upward and downward reserves, and O` O` regulation speeds over system net loads. c GH and c GH p are the additional scheduling adjustment, dispatch and regulation cost for scenario h A and its sensitivities over ase scheduling set points. p () O`() O`, c GH and c GH p () are corresponding values determined at last iteration or given initially. As expressed in (5a), the ojective of the master prolem is to minimize the total cost related to commitment schedule for the entire operation cycle, c O. It includes the start-up/shutdown cost, the fixed non-load cost, the variale cost for ase scheduling set point, the ramp up/ down costs etween consecutive scheduling intervals, the spillage cost of intermittent renewale, the cost for load shedding, and the additional scheduling adjustment, dispatch and regulation cost for each sample uncertainty scenario (including the ase case), c O` which are considered as a liner function of scheduling set points using sensitivities of associated cost over ase set points. The master prolem is constrained y system-wide constraints, (5)-(5f), device-wise constraints (5h)-(5s). The system wide constraints include power alance equations, system upward/down regulation capacities and speed requirements. The regulation capacities and speeds required for handling the maximum fluctuations of renewale and loads at various sampling intervals. The transmission line security requirements are expressed as power flow equations and limits for the lines. To reduce the computation urden, only equations associated with overload lines are included, and the iterative solution is used until there is no overload existing. The master prolem is related to slave prolems through (4g). ith the determined scheduling set points and unit status, the slave prolem for simulating the system operation under a given uncertainty scenario h A can e formulated as: O` = C O p H F>Z () p H () Minimize c GH C C p R(GH G) C p R(GH G) C FG p FGH p FG J>Z C JG p JGH p JG c GH (6a) uject to: p H F>Z FGH p FGH = J>Z JGH p JGH g (6) f zgh = c () GH Š lm nh (B) lq rnh () p H p H p H = p () p R(GH G) () p H = p R(GZ) p H p H c GH p R(GH G) g (6c) g (6d) p H g (6e) p p R(GH G) u R g (6f) p p R(GH G) u R g (6g) p H () u R(GZ) () U R RU R u g (6h) u RD R u D R g (6i) FGH r (6j) p FGH p JGH JGH d (6k) π zr p H F>Z π zf FGH p FGH J>Z π zj JGH l L O` (6l) p JGH F z f zgh F z l L O` (6m) where L O`is the set of overload lines under scenario h A. p H, p H and p H, p R(GH G) and p R(GH G) are the generation output under scenario h A, the output changes etween the uncertainty scenario and the ase case at previous scheduling interval (h-1), p H and p R(GZ), the output changes etween uncertainty scenario h A and the set point at corresponding scheduling interval h, p H and p. c GH and c GH p H are the additional dispatch and regulation cost for scenario h A and its sensitivities over scheduling set points for the scenario. u (), u (), u (), p () H, c () GH and c () GH p H are corresponding values determined at last iteration or given initially. p FGH, p JGH and f zgh are the renewale spillage for renewale r, load shedding for load d and power flow on line l under scenario h A. The ojective of the slave prolem at the first level is to minimize the total generation adjustment cost for the scenario, c GH O`. Besides the weighted dispatch and regulation costs for each scenario, the uncertainty adjustment cost includes the weighted cost related to the generation output changes etween the previous ase set point and current uncertainty scenario set point, and the current ase set point and current uncertainty scenario set point. It also includes the cost changes for renewale spillage and load shedding etween the ase values determined y the master prolem and the values for the current uncertainty scenario. The slave prolem of the first level is linked with prolems at second and third levels through (6c). The sensitives of generation adjustment cost over ase scheduling set points that used in the master prolem can e determined as: op lm nh Œ (7) (B) = α qrnh β γ lq qr(nh q Œn) r(nh Œn) rn α qrnh, β and γ Œ qr(nh q Œn) r(nh are the dual variales of (6d), Œn) (6f) and (6g) respectively. C. Generation Dispatch The second level of co-optimization is to determine the generation dispatch plans for all dispatch intervals within a given scheduling interval, including the dispatching set points for dispatchale units, renewale spillage and load shedding if needed. The impact of frequency regulation is taken into account through the sensitivities of regulation cost over dispatching set points of dispatchale units. In this level, the
6 determined unit commitment scheme is checked against dispatch operation scenarios to verify whether the unit commitment schedule satisfying the load and renewale fluctuations that occur at a short timescale, i.e. dispatching interval. The historical renewale generation and load profiles are used to create dispatching scenarios along with the renewale and load forecasts within next operation cycle. The generation dispatch prolem can e formulated as: Minimize c GH uject to: = n K>Z C O RK p H K C RK p H K p H K C O RK p R(KGH) F>Z () C FK C R,K p R(KGH ) p FGH K () p FGH \ J>Z C JK p JGH K p JGH c GH (8a) J>Z m F>Z FGH K p FGH K = JGH K p JGH K (8) n K>Z c \() GH K lm nh (B) lq rnh () p H K p H K \ c GH (8c) p H K = p H p R(KGH ) p R(KGH ) g, m (8d) p H K = p H (KZ) p H K p H K g, m (8e) p H p H p R(KGH ) p R(KGH) u R g, m (8f) u R g, m (8g) () p H K τ GK u R(GZ) RU R u U R g, m (8h) p H K τ GK u RD R u D R g, m (8i) p FGH K FGH r, m (8j) p JGH K JGH d, m (8k) f zgh K = π zr p H K F>Z π zf FGH K p FGH K J>Z π zj JGH K p JGH K m, l L (8l) F z f zgh K F z m, l L (8m) where, M G is total numer of dispatching intervals of interval h. p H K, p R(KGH) and p R(KGH ), p H K and p H K are the dispatching set point, the unit output differences etween the scheduling set point p H and the dispatching set point, the unit output changes etween two consecutive dispatching intervals, m and (m-1), p H Kandp H (KZ). The per unit ramp up/down costs and renewale spillage and load shedding costs can e determined ased on corresponding values per scheduling interval and pre-determined conversion factors. \ c GH is the cost related to frequency regulation for the scheduling interval h, and expressed using the sensitivity of cost related to dispatching interval, c GH K over generation output at the dispatching interval, p H K. L is the set of overload lines. τ GK is the ratio of length of dispatching interval over length of scheduling interval, and used to convert ramping thresholds from per scheduling interval to per,p JGH K dispatching interval. p FGH K and f zgh Kare the renewale spillage for renewale r, load shedding for load d and power flow on line l at dispatch interval m under scenario h A. The ojective of generation dispatch is to minimize the total as cost related to generation dispatch and regulation, c GH shown in (8a). The cost includes the additional cost incurred y the generation output changes etween the scheduling set point and dispatching set point, and the set points etween two consecutive dispatching intervals. It is also included the cost changes for renewale spillages and load shedding etween the determined values for the scheduling interval and the values for the dispatching interval. The sensitivities of generation dispatch and regulation cost over scheduling set points are determined as: Š lm nh (B) = α qrnh β q r( ŒnH ) γ q r( ŒnH ) lq rnh n Œ K>Z (9) α, β qrnh q and γ Œ r( ŒnH q ) r( ŒnH are the dual variales of ) (8d),(8f) and (8g) respectively. D. Frequency Regulation The third level of co-optimization is to determine the generation frequency regulation schemes to maintain qualified system frequency in each regulating interval. In this level, the frequency regulation is used to simulate the power system to deal with fluctuations in load and renewale that occur at a much faster timescale, i.e. regulating interval. The historical profile of load and generation for this timescale are used to determine the expected frequency regulation and performance cost for each dispatchale unit. The generation regulation setting points (determined y secondary frequency control) are first determined ased on load and renewale variations and frequency requirements for each regulating interval. The performance for generation units to follow the regulation setting points (implemented y primary frequency control) are then measured y the sum of deviation of setting points and actual achieved mechanical outputs of generation units. The frequency regulation is formulated as: Minimize c \ GH K = n C O RM p H MK C M>Z RM p H MK C O RM p H M C () RM p H M F>Z C FM p FGH KM p FGH K J>Z C JM p JGH KM p JGH K c GH K (10a) uject to: K f GH KM n M>Z K f c GH KM p JGH KM J>Z p H KM n Œ H n H r F>Z FGH KM p FGH K J>Z 1 K f GH KM JGH KM p JGH K K f J>Z p JGH KM g, s (10) f GH KM f GH KM f s (10c) p H KM = p H K p H KM p H KM = p H K MZ š lm nh B p lq H KM rnh p H (MK) p H KM () u n Œ H n H R,G p H K p H K p H KM p H (MK) c GH K (10d) g, s (10e) p H KM g, s (10f) r = p H KM g, s (10g) u R g, s (10h) u R g, s (10i) p H (MK) p H (MK) () p H KM τ GM u R(GZ) RU R u () U R g, s (10j) p H KM τ GM u RD R u D R g, s (10k) p FGH KM FGH KM r, s (10l) p JGH KM JGH KM d, s (10m) f zgh KM = π zr p H KM F>Z π zf FGH KM p FGH KM J>Z π zj JGH KM p JGH KM l L \, s (10n) F z f zgh KM F z l L \, s (10o) where, GK is total numer of regulating intervals of dispatching interval m within scheduling interval h. p H KM, p H (MK) and p H (MK), and p H KMand p H KM are the generation output at regulating interval s, the upward
7 and downward output differences etween the dispatching and regulating intervals, p H KM andp H K, and the upward and downward regulating set point (i.e. generation control command) changes etween two consecutive regulating intervals, s and (s-1), p H KM and p H K MZ. L \ is the overload line set. τ GM is the ratio of length of regulation interval over length of scheduling interval, and used to convert ramping thresholds from per scheduling interval to per regulation interval. f GH KM and f are the system frequency deviation (away from system rated frequency), and its allowed threshold. K is system load frequency sensitivity coefficient, and DR ž is the generation unit droop (in M/HZ). p FGH KM, p JGH KM and f zgh KM are the renewale spillage for renewale r, load shedding for load d and power flow on line l at regulation interval s. The ojective for frequency regulation is to minimize the total cost related to frequency regulation, c \ GH K. It includes the cost related to mismatch etween the dispatching set point and generation output at the regulating interval, and regulation set point changes etween two consecutive regulating intervals, and cost changes related to renewale spillage and load shedding. It also includes the additional cost related to frequency regulation performance, c GH K. The costs related to primary frequency regulation performance for all regulating intervals in the dispatching interval m and scheduling interval h, c GH K is expressed as a linear function of generation set point at the regulation interval using the sensitivity of related cost for the regulation interval over generation set point at the regulation interval, c GH KM p H KM. The constraints for frequency regulation include power alance requirement with frequency changes for interval s (10), and generation droop control equation (10g). The cost for primary frequency regulation performance is defined as: O c GH KM = C M max 0, p H KM p H KM C M max 0, p H KM p H KM (11) O C M and C M are per unit upward/downward mismatch costs etween frequency regulation setting points, p H KM and generation mechanical outputs, p H KM. The sensitivities of primary frequency regulation cost over dispatching set points are determined as: lm nh (B) = α β qrnh q γ Œ M>Z rnh q ( Œ ) rnh (12) ( Œ ) lq rnh n α qrnh, β q and γ Œ rnh q ( Œ ) rrnh are the dual variales of ( Œ ) (10e),(10h) and (10i) respectively. The aility of a generator in following the frequency regulation signal depends on its technology and physical characteristics. ithout loss of generality, we consider a governor-turine control model for each generator where a speed governor senses the changes in its power command set points, i.e., the frequency regulation set points, p GH KM(t) and converts them into valve actions. A turine then converts the changes in valve positions into changes in mechanical power output, i.e., generation signal p GH KM(t). The relationship etween the incremental changes of mechanical output and control signal, p GH KM(t)and p GH KM(t)is descried as: 1 T J w R 1 T J Jv R p Jv GH KM(t) = p GH KM(t) (13) For a given regulating interval s, the mechanical output of generator g can e determined as: M p GH KM = p GH K p GH K p GH K Z >Z ( Œ ) ( Œ ) δ i = 1 T ª Š R e r T w ª ª R e r δ i u t τ M (i 1) (14a) / T R T R w (14) u(t)is a unit step function, δ i is the generation regulation achieving ratio for regulation interval i. The sensitivity of frequency regulation performance cost over regulation setting points is determined according to: š lm nh = δ s C M O max 0, q rn H lq nh C M max 0, q «rn H q rnh q rnh q rnh «q rnh q «rnh q rnh «(15) III. NUMERICAL EAMLE The proposed method has een tested on a 5-us system as shown in Fig. 2. The system has 2 dispatchale units (located at Bus-1, and Bus-2), 1 non-dispatchale unit (located at Bus-5), 2 loads (located at Bus-3 and Bus-4), and 5 lines. All lines have same impedance and capacity as 0.01j0.1 p.u. and 50 M respectively. Fig. 2 also shows the maximal and minimal outputs of generation units, and the ase power consumption/generation for the loads/renewales. The scheduling, dispatching and regulating intervals are set as 1 hour, 15 minutes and 15 seconds respectively. Fig.2. 5-Bus test system that used in this paper Fig. 3 gives the typical daily generation and load profiles sampled once per 15 seconds, and the values at vertical axis are the ratios of actual values with corresponding ase values. Those profiles are used to derive the dispatching and regulating variation factors for renewale and loads. The standard deviations of hourly renewale and load variation are assumed to e 10% of their hourly average values. Those standard deviations are used to generate the covariance matrix and define the scaling factors for sample uncertainty scenarios. The parameters for generation units are given in Tale I. Both generation units have een running for 10 hours. The test results are summarized in Tale II. The required upward/downward regulation reserve capacity and speed ratios are 10%, and the allowed maximum frequency deviation is 1.0Hz. The system load frequency sensitivity coefficient is 5%/HZ. There are two cases in the tale. The generation schedule of Case I is determined y ignoring the impacts of generation dispatch and frequency regulation. In comparison, the impacts generation dispatch and frequency regulation are modelled when determining the generation schedule for Case II. The determined daily schedule of generation energy production and regulation reserve for Case II are depicted in Fig. 4.
8 Fig. 3. Renewale and Load rofiles Attriute Ramping Rate (M/min) tart-up/shutdown ramping rate (M/min) Governor time constant (s) Turine time constant (s) Tale I. Generation Unit arameters Generation Unit Generation Bus Attriute Unit Bus Bus-1 Bus-2 Bus-1 Bus Droop 10% 10% tart-up costs (k$) hut-down costs (k$) Fixed cots(k$/h) ariale cots (k$/mh) Ramping Costs (k$/m/h) Regulation performance cost (k$/mh) min up/down time(h) (a). Generation Unit at Bus /2 2/1 (). Generation Unit at Bus-2 Fig. 4. Generation schedule for energy production and regulation reserve Case I II Unit On chedule (Hrs) Bus-1: 0-23 Bus-2:0-3,7-20 Bus-1: 0-23 Bus-2: 0-3,7-21 Tale II. Test Cases and Results Cost Contriutions (k$) Unit Generation Frequency Commitment Dispatch Regulation Total Compared with Case I, Case II has committed the generation unit at Bus-2 operating one more hour, ut has less additional frequency regulation cost at third level. It is shown that the total cost of Cast II is 1.9 k$ (i.e. 4.75%) less than Case I. This result has preliminarily demonstrated the advantages for using three-level co-optimization model. I. CONCULUION This paper has proposed a three-level co-optimization model for generation scheduling in a day-ahead market. The impacts of renewale and load fluctuations at three different time scales have een taken into account. Through detailed modelling of unit commitment, generation dispatch and frequency regulation in the process of co-optimization, the gaps or deviations etween day-ahead schedules and real-time dispatch and control have een effectively mitigated, and thus the system efficiency can e improved and the profits for generation companies can e maximized. The preliminary results have demonstrated the effectiveness of the proposed method. Future work may include developing more efficient algorithm, testing on practical systems, and more detailed modelling of unit start-up, and shut-down process. REFERENCE [1] J. Morales, A. Conejo, and J. erez-ruiz, Economic aluation of Reserves in ower ystems ith High enetration of ind ower, IEEE Transactions on ower ystems, vol. 24, no. 2, pp , May [2] Frequency Regulation Compensation in the Organized holesale ower Markets, Oct [Online]. Availale: [3] D. Gan, E. Litvinov, A lost opportunity cost model for energy and reserve co-optimization, IEEE ower Engineering ociety ummer Meeting, vol. 3, pp , [4] un Tiam Tan, and Daniel. Kirschen, Co-optimization of Energy and Reserve in Electricity Markets with Demand-side articipation in Reserve ervices, 2006 IEEE E ower ystems Conference and Exposition, pp [5]. ong and J. Fuller, ricing energy and reserves using stochastic optimization in an alternative electricity market, IEEE Transactions on ower ystems, vol. 22, no. 2, pp , May [6] U. Ozturk, M. Mazumdar, and B. Norman, A solution to the stochastic unit commitment prolem using chanced constrained programming, IEEE Transactions on ower ystems, vol. 19, no. 3, pp , Aug [7] L. u, M. hahidehpour, and T. Li, tochastic security-constrained unit commitment, IEEE Transactions on ower ystems, vol. 22, pp , [8]. Ruiz, C. hilrick, E. Zak, K. Cheung, and. auer, Uncertainty management in the unit commitment prolem, IEEE Transactions on ower ystems, vol. 24, no. 2, pp , May [9] E.M. Constantinescu,. M. Zavala,M. Rocklin,. Lee, and M. Anitescu, A computational framework for uncertainty quantification and stochastic optimization in unit commitment with wind power generation, IEEE Transactions on ower ystems, vol. 26, no. 1, pp , Fe [10]. arkka, On unscented Kalman filtering for state estimation of continuous-time nonlinear systems, IEEE Transactions on Automatic Control, vol. 52, no. 9, pp , 2007.
Stochastic Unit Commitment with Topology Control Recourse for Renewables Integration
1 Stochastic Unit Commitment with Topology Control Recourse for Renewables Integration Jiaying Shi and Shmuel Oren University of California, Berkeley IPAM, January 2016 33% RPS - Cumulative expected VERs
More informationProper Security Criteria Determination in a Power System with High Penetration of Renewable Resources
Proper Security Criteria Determination in a Power System with High Penetration of Renewable Resources Mojgan Hedayati, Kory Hedman, and Junshan Zhang School of Electrical, Computer, and Energy Engineering
More informationR O B U S T E N E R G Y M AN AG E M E N T S Y S T E M F O R I S O L AT E D M I C R O G R I D S
ROBUST ENERGY MANAGEMENT SYSTEM FOR ISOLATED MICROGRIDS Jose Daniel La r a Claudio Cañizares Ka nka r Bhattacharya D e p a r t m e n t o f E l e c t r i c a l a n d C o m p u t e r E n g i n e e r i n
More informationSystems Operations. PRAMOD JAIN, Ph.D. Consultant, USAID Power the Future. Astana, September, /6/2018
Systems Operations PRAMOD JAIN, Ph.D. Consultant, USAID Power the Future Astana, September, 26 2018 7/6/2018 Economics of Grid Integration of Variable Power FOOTER GOES HERE 2 Net Load = Load Wind Production
More informationEconomic Operation of Power Systems
Economic Operation of Power Systems Section I: Economic Operation Of Power System Economic Distribution of Loads between the Units of a Plant Generating Limits Economic Sharing of Loads between Different
More informationTight and Compact MILP Formulation for the Thermal Unit Commitment Problem
Online Companion for Tight and Compact MILP Formulation for the Thermal Unit Commitment Problem Germán Morales-España, Jesus M. Latorre, and Andres Ramos Universidad Pontificia Comillas, Spain Institute
More informationFinQuiz Notes
Reading 9 A time series is any series of data that varies over time e.g. the quarterly sales for a company during the past five years or daily returns of a security. When assumptions of the regression
More informationAnalysis of Coupling Dynamics for Power Systems with Iterative Discrete Decision Making Architectures
Analysis of Coupling Dynamics for Power Systems with Iterative Discrete Decision Making Architectures Zhixin Miao Department of Electrical Engineering, University of South Florida, Tampa FL USA 3362. Email:
More informationOptimal Demand Response
Optimal Demand Response Libin Jiang Steven Low Computing + Math Sciences Electrical Engineering Caltech Oct 2011 Outline Caltech smart grid research Optimal demand response Global trends 1 Exploding renewables
More informationHIgh penetration of wind power has greatly challenged the
ACCEPTED MANUSCRIPT, IEEE TRANSACTIONS ON POWER SYSTEMS, 2011 1 A Chance-constrained Two-stage Stochastic Program for Unit Commitment with Uncertain Wind Power Output Qianfan Wang, Student Memer, IEEE,
More informationA Unified Framework for Defining and Measuring Flexibility in Power System
J A N 1 1, 2 0 1 6, A Unified Framework for Defining and Measuring Flexibility in Power System Optimization and Equilibrium in Energy Economics Workshop Jinye Zhao, Tongxin Zheng, Eugene Litvinov Outline
More informationCONTROL AND OPTIMIZATION IN SMART-GRIDS
CONTROL AND OPTIMIZATION IN SMART-GRIDS Fredy Ruiz Ph.D. Pontificia Universidad Javeriana, Colombia Visiting Profesor - ruizf@javeriana.edu.co May, 2018 Course topics Session 1: Introduction to Power systems
More informationComparison of Transmission Loss Allocation Methods in Deregulated Power System
Comparison of Transmission oss Allocation s in Deregulated ower System. Srinivasa Varma & V. Sankar Research Scholar, Department of Electrical Engineering, JNTUACEA, Anantapur, Andhra radesh, ndia e-mail:
More informationBringing Renewables to the Grid. John Dumas Director Wholesale Market Operations ERCOT
Bringing Renewables to the Grid John Dumas Director Wholesale Market Operations ERCOT 2011 Summer Seminar August 2, 2011 Quick Overview of ERCOT The ERCOT Market covers ~85% of Texas overall power usage
More informationCAISO Participating Intermittent Resource Program for Wind Generation
CAISO Participating Intermittent Resource Program for Wind Generation Jim Blatchford CAISO Account Manager Agenda CAISO Market Concepts Wind Availability in California How State Supports Intermittent Resources
More informationToward Combining Intra-Real Time Dispatch (RTD) and AGC for On-Line Power Balancing
Toward Combining Intra-Real Time Dispatch (RTD) and AGC for On-Line Power Balancing Marija D. Ilić, Xiaoqi Yin Dept. of Elec. & Comp. Eng. Carnegie Mellon University Pittsburgh, Pennsylvania 15213 Email:
More informationA Generalized Admittance Based Method for Fault Location Analysis of Distribution System
MITSUBISHI ELECTRIC RESEARCH LABORATORIES http://www.merl.com A Generalized Admittance Based Method for Fault Location Analysis of Distribution System Tan, Z.; Sun, H.; Nikovski, D.N.; Tomihiro, T.; Kojima,
More informationMulti-Area Stochastic Unit Commitment for High Wind Penetration
Multi-Area Stochastic Unit Commitment for High Wind Penetration Workshop on Optimization in an Uncertain Environment Anthony Papavasiliou, UC Berkeley Shmuel S. Oren, UC Berkeley March 25th, 2011 Outline
More informationPrediction of Power System Balancing Requirements and Tail Events
Prediction of Power System Balancing Requirements and Tail Events PNNL: Shuai Lu, Yuri Makarov, Alan Brothers, Craig McKinstry, Shuangshuang Jin BPA: John Pease INFORMS Annual Meeting 2012 Phoenix, AZ
More informationEffects of Various Uncertainty Sources on Automatic Generation Control Systems
Effects of Various Uncertainty Sources on Automatic Generation Control Systems D. Apostolopoulou, Y. C. Chen, J. Zhang, A. D. Domínguez-García, and P. W. Sauer University of Illinois at Urbana-Champaign
More informationThe Impact of Distributed Generation on Power Transmission Grid Dynamics
The Impact of Distributed Generation on Power Transmission Grid Dynamics D. E. Newman B. A. Carreras M. Kirchner I. Dobson Physics Dept. University of Alaska Fairbanks AK 99775 Depart. Fisica Universidad
More informationShort-Term Demand Forecasting Methodology for Scheduling and Dispatch
Short-Term Demand Forecasting Methodology for Scheduling and Dispatch V1.0 March 2018 Table of Contents 1 Introduction... 3 2 Historical Jurisdictional Demand Data... 3 3 EMS Demand Forecast... 4 3.1 Manual
More informationControlling variability in power systems
Daniel APAM Nov 17 2017 A simple example: 100 100 A simple example: 100 100 Only one solution: 200 100 200 100 100 100 A simple example: 100 100 Only one solution: 200 100 200 100 100 100 But what if the
More informationMultistage Adaptive Robust Optimization for the Unit Commitment Problem
Multistage Adaptive Robust Optimization for the Unit Commitment Problem Álvaro Lorca, X. Andy Sun H. Milton Stewart School of Industrial and Systems Engineering, Georgia Institute of Technology, Atlanta,
More informationPowerApps Optimal Power Flow Formulation
PowerApps Optimal Power Flow Formulation Page1 Table of Contents 1 OPF Problem Statement... 3 1.1 Vector u... 3 1.1.1 Costs Associated with Vector [u] for Economic Dispatch... 4 1.1.2 Costs Associated
More informationTemporal Wind Variability and Uncertainty
Temporal Wind Variability and Uncertainty Nicholas A. Brown Iowa State University, Department of Electrical and Computer Engineering May 1, 2014 1 An Experiment at Home One Cup of Coffee We Can All Do
More informationValue of Forecasts in Unit Commitment Problems
Tim Schulze, Andreas Grothery and School of Mathematics Agenda Motivation Unit Commitemnt Problem British Test System Forecasts and Scenarios Rolling Horizon Evaluation Comparisons Conclusion Our Motivation
More informationMulti-Area Stochastic Unit Commitment for High Wind Penetration in a Transmission Constrained Network
Multi-Area Stochastic Unit Commitment for High Wind Penetration in a Transmission Constrained Network Anthony Papavasiliou Center for Operations Research and Econometrics Université catholique de Louvain,
More informationAn Adaptive Clarke Transform Based Estimator for the Frequency of Balanced and Unbalanced Three-Phase Power Systems
07 5th European Signal Processing Conference EUSIPCO) An Adaptive Clarke Transform Based Estimator for the Frequency of Balanced and Unalanced Three-Phase Power Systems Elias Aoutanios School of Electrical
More informationAutomatic Generation Control. Meth Bandara and Hassan Oukacha
Automatic Generation Control Meth Bandara and Hassan Oukacha EE194 Advanced Controls Theory February 25, 2013 Outline Introduction System Modeling Single Generator AGC Going Forward Conclusion Introduction
More informationRobustness Adjustment of Two-Stage Robust Security-Constrained Unit Commitment
Robustness Adjustment of Two-Stage Robust Secury-Constrained Un Commment Ping Liu MISSISSIPPI STATE UNIVERSITY U.S.A October 23, 204 Challenges in smart grid Integration of renewable energy and prediction
More informationPower System Seminar Presentation Wind Forecasting and Dispatch 7 th July, Wind Power Forecasting tools and methodologies
Power System Seminar Presentation Wind Forecasting and Dispatch 7 th July, 2011 Wind Power Forecasting tools and methodologies Amanda Kelly Principal Engineer Power System Operational Planning Operations
More informationA Comparison Between Polynomial and Locally Weighted Regression for Fault Detection and Diagnosis of HVAC Equipment
MITSUBISHI ELECTRIC RESEARCH LABORATORIES http://www.merl.com A Comparison Between Polynomial and Locally Weighted Regression for Fault Detection and Diagnosis of HVAC Equipment Regunathan Radhakrishnan,
More informationForecasting Wind Ramps
Forecasting Wind Ramps Erin Summers and Anand Subramanian Jan 5, 20 Introduction The recent increase in the number of wind power producers has necessitated changes in the methods power system operators
More informationAppendix A Solving Systems of Nonlinear Equations
Appendix A Solving Systems of Nonlinear Equations Chapter 4 of this book describes and analyzes the power flow problem. In its ac version, this problem is a system of nonlinear equations. This appendix
More informationPower System Security. S. Chakrabarti
Power System Security S. Chakrabarti Outline Introduction Major components of security assessment On-line security assessment Tools for contingency analysis DC power flow Linear sensitivity factors Line
More informationAdaptive Coordination of Distributed Energy Resources in Lossy Power Distribution Systems
Adaptive Coordination of Distributed Energy Resources in Lossy Power Distribution Systems Hanchen Xu, Alejandro D Domínguez-García, and Peter W Sauer Department of Electrical and Computer Engineering University
More informationResearch Article Relative Status Determination for Spacecraft Relative Motion Based on Dual Quaternion
Mathematical Prolems in Engineering Volume 214, Article ID 62724, 7 pages http://dx.doi.org/1.1155/214/62724 Research Article Relative Status Determination for Spacecraft Relative Motion Based on Dual
More informationCalifornia Independent System Operator (CAISO) Challenges and Solutions
California Independent System Operator (CAISO) Challenges and Solutions Presented by Brian Cummins Manager, Energy Management Systems - CAISO California ISO by the numbers 65,225 MW of power plant capacity
More informationInternational Workshop on Wind Energy Development Cairo, Egypt. ERCOT Wind Experience
International Workshop on Wind Energy Development Cairo, Egypt ERCOT Wind Experience March 22, 21 Joel Mickey Direcr of Grid Operations Electric Reliability Council of Texas jmickey@ercot.com ERCOT 2 2
More informationEffect of wind generation on dispatch INVESTIGATION 2
Effect of wind generation on dispatch INVESTIGATION 2 WIND GENERATION INVESTIGATION PROJECT MAY 2007 NOTICE COPYRIGHT 2007 TRANSPOWER New Zealand LIMITED ALL RIGHTS RESERVED The information contained in
More informationRecent US Wind Integration Experience
Wind Energy and Grid Integration Recent US Wind Integration Experience J. Charles Smith Nexgen Energy LLC Utility Wind Integration Group January 24-25, 2006 Madrid, Spain Outline of Topics Building and
More informationSpinning Reserve Capacity Optimization of a Power System When Considering Wind Speed Correlation
Article Spinning Reserve Capacity Optimization of a Power System When Considering Wind Speed Correlation Jianglin Zhang 1, Huimin Zhuang 1, *, Li Zhang 2 and Jinyu Gao 3 1 Control Engineering College,
More informationECG 740 GENERATION SCHEDULING (UNIT COMMITMENT)
1 ECG 740 GENERATION SCHEDULING (UNIT COMMITMENT) 2 Unit Commitment Given a load profile, e.g., values of the load for each hour of a day. Given set of units available, When should each unit be started,
More information1 Descriptions of Function
Wide-Area Wind Generation Forecasting 1 Descriptions of Function All prior work (intellectual property of the company or individual) or proprietary (non-publicly available) work should be so noted. 1.1
More informationChapter 2. Planning Criteria. Turaj Amraee. Fall 2012 K.N.Toosi University of Technology
Chapter 2 Planning Criteria By Turaj Amraee Fall 2012 K.N.Toosi University of Technology Outline 1- Introduction 2- System Adequacy and Security 3- Planning Purposes 4- Planning Standards 5- Reliability
More informationIntegrating Wind Resources Into the Transmission Grid
Integrating Wind Resources Into the Transmission Grid Gary D. Bachman Wisconsin Public Utility Institute May 26, 2010 Introduction Statement of FERC Chairman Jon Wellinghoff on Efficient Integration of
More informationA Stochastic-Oriented NLP Relaxation for Integer Programming
A Stochastic-Oriented NLP Relaxation for Integer Programming John Birge University of Chicago (With Mihai Anitescu (ANL/U of C), Cosmin Petra (ANL)) Motivation: The control of energy systems, particularly
More informationWind power and management of the electric system. EWEA Wind Power Forecasting 2015 Leuven, BELGIUM - 02/10/2015
Wind power and management of the electric system EWEA Wind Power Forecasting 2015 Leuven, BELGIUM - 02/10/2015 HOW WIND ENERGY IS TAKEN INTO ACCOUNT WHEN MANAGING ELECTRICITY TRANSMISSION SYSTEM IN FRANCE?
More informationEnergy Forecasting Customers: Analysing end users requirements Dec 3rd, 2013 Carlos Alberto Castaño, PhD Head of R&D
IT Solutions for Renewables Energy Forecasting Customers: Analysing end users requirements Dec 3rd, 2013 Carlos Alberto Castaño, PhD Head of R&D carlos.castano@gnarum.com I. Who we are II. Customers Profiles
More informationChapter 6 Impact of Stochastic Renewable Energy Generation on Market Quantities 6.1 Introduction
Chapter 6 Impact of Stochastic Renewable Energy Generation on Market Quantities 6.1 Introduction One of the most traditional systems for the commercial exchange of electricity production from stochastic
More informationA new stochastic program to facilitate intermittent renewable generation
A new stochastic program to facilitate intermittent renewable generation Golbon Zakeri Geoff Pritchard, Mette Bjorndal, Endre Bjorndal EPOC UoA and Bergen, IPAM 2016 Premise for our model Growing need
More informationDeregulated Electricity Market for Smart Grid: A Network Economic Approach
Deregulated Electricity Market for Smart Grid: A Network Economic Approach Chenye Wu Institute for Interdisciplinary Information Sciences (IIIS) Tsinghua University Chenye Wu (IIIS) Network Economic Approach
More informationRECENTLY, robust optimization (RO) techniques [1, 2,
1 Exploring the Modeling Capacity of Two-stage Robust Optimization Two Variants of Robust Unit Commitment Model Yu An and Bo Zeng Abstract To handle significant variability in loads, renewable energy generation,
More informationA Model for a Zonal Operating Reserve Demand Curve
A Model for a Zonal Operating Reserve Demand Curve Yen-Yu Lee Electrical and Computer Engineering University of Texas at Austin March 5, Outline What is operating reserves? Why do we need elastic reserves
More informationColorado PUC E-Filings System
Page 1 of 10 30-Minute Flex Reserve on the Public Service Company of Colorado System Colorado PUC E-Filings System Prepared by: Xcel Energy Services, Inc. 1800 Larimer St. Denver, Colorado 80202 May 13,
More informationSUBMITTED TO IEEE TRANSACTIONS ON POWER SYSTEMS, AUGUST
SUBMITTED TO IEEE TRANSACTIONS ON POWER SYSTEMS, AUGUST 2014 1 Adaptive Robust Optimization with Dynamic Uncertainty Sets for Multi-Period Economic Dispatch under Significant Wind Álvaro Lorca, Student
More informationJoint Frequency Regulation and Economic Dispatch Using Limited Communication
Joint Frequency Regulation and Economic Dispatch Using Limited Communication Jianan Zhang, and Eytan Modiano Massachusetts Institute of Technology, Cambridge, MA, USA Abstract We study the performance
More informationCascading Outages in Power Systems. Rui Yao
Cascading Outages in Power Systems Rui Yao yaorui.thu@gmail.com Outline Understanding cascading outages Characteristics of cascading outages Mitigation of cascading outages Understanding cascading outages
More informationEUROPEAN EXPERIENCE: Large-scale cross-country forecasting with the help of Ensemble Forecasts
WEPROG Weather & wind Energy PROGnoses EUROPEAN EXPERIENCE: Large-scale cross-country forecasting with the help of Ensemble Forecasts Session 6: Integrating forecasting into market operation, the EMS and
More informationARTIFICIAL BEE COLONY ALGORITHM FOR PROFIT BASED UNIT COMMITMENT USING MODIFIED PRE-PREPARED POWER DEMAND TABLE
ARTIFICIAL BEE COLONY ALGORITHM FOR PROFIT BASED UNIT COMMITMENT USING MODIFIED PRE-PREPARED POWER DEMAND TABLE Kuldip Deka 1, Dr. Barnali Goswami 2 1M.E. student, Assam Engineering College 2Associate
More informationRisk-based Security Constrained Unit Commitment
A decision support system for electric operators 04 December 2015 Eng. chiara.foglietta@uniroma3.it Models for Critical Infrastructure Protection Laboratory (MCIP lab) Engineering Department Università
More informationUNIT-I ECONOMIC OPERATION OF POWER SYSTEM-1
UNIT-I ECONOMIC OPERATION OF POWER SYSTEM-1 1.1 HEAT RATE CURVE: The heat rate characteristics obtained from the plot of the net heat rate in Btu/Wh or cal/wh versus power output in W is shown in fig.1
More informationContents Economic dispatch of thermal units
Contents 2 Economic dispatch of thermal units 2 2.1 Introduction................................... 2 2.2 Economic dispatch problem (neglecting transmission losses)......... 3 2.2.1 Fuel cost characteristics........................
More informationMEDIUM-TERM HYDROPOWER SCHEDULING BY STOCHASTIC DUAL DYNAMIC INTEGER PROGRAMMING: A CASE STUDY
MEDIUM-TERM HYDROPOWER SCHEDULING BY STOCHASTIC DUAL DYNAMIC INTEGER PROGRAMMING: A CASE STUDY Martin Hjelmeland NTNU Norwegian University of Science and Technology, Trondheim, Norway. martin.hjelmeland@ntnu.no
More informationA possible notion of short-term value-based reliability
Energy Laboratory MIT EL 1-13 WP Massachusetts Institute of Technology A possible notion of short-term value-based reliability August 21 A possible notion of short-term value-based reliability Yong TYoon,
More informationStoring energy or Storing Consumption?
Storing energy or Storing Consumption? It is not the same! Joachim Geske, Richard Green, Qixin Chen, Yi Wang 40th IAEE International Conference 18-21 June 2017, Singapore Motivation Electricity systems
More informationCongestion and Price Prediction in Locational Marginal Pricing Markets Considering Load Variation and Uncertainty
The Department of Electrical Engineering and Computer Science Congestion and Price Prediction in Locational Marginal Pricing Markets Considering Load Variation and Uncertainty Dissertation Defense Rui
More informationA Merchant Mechanism for Electricity Transmission Expansion
A Merchant Mechanism for Electricity Transmission Expansion Tarjei Kristiansen, Norwegian University of Science and Technology. Tarjei.Kristiansen@elkraft.ntnu.no Juan Rosellon, Harvard University/CIDE.
More informationReal-time AGC dispatch units considering wind power and ramping capacity of thermal units
J. Mod. Power Syst. Clean Energy (2015) 3(3):353 360 DOI 10.1007/s40565-015-0141-z Real-time AGC dispatch units considering wind power and ramping capacity of thermal units Jingyi ZHANG, Chao LU, Jie SONG
More informationAn Investigation of 3D Dual-Tree Wavelet Transform for Video Coding
MITSUBISHI ELECTRIC RESEARCH LABORATORIES http://www.merl.com An Investigation of 3D Dual-Tree Wavelet Transform for Video Coding Beibei Wang, Yao Wang, Ivan Selesnick and Anthony Vetro TR2004-132 December
More informationReliability-Security Constrained Unit Commitment with Hybrid Optimization Method
Reliability-Security Constrained Unit Commitment with Hybrid Optimization Method Ahmad Heidari 1, Mohammad Reza Alizadeh Pahlavani 2, Hamid Dehghani 3 1, 2, 3 Malek-Ashtar University of Technology (MUT),
More informationRenewables and the Smart Grid. Trip Doggett President & CEO Electric Reliability Council of Texas
Renewables and the Smart Grid Trip Doggett President & CEO Electric Reliability Council of Texas North American Interconnected Grids The ERCOT Region is one of 3 North American grid interconnections. The
More informationElectric Power Systems Research xxx (2017) xxx-xxx. Contents lists available at ScienceDirect. Electric Power Systems Research
Electric Power Systems Research xxx (2017) xxx-xxx Contents lists available at ScienceDirect Electric Power Systems Research journal homepage: www.elsevier.com Multi-period stochastic security-constrained
More informationElectrical Power and Energy Systems
Electrical Power and Energy Systems 44 (2013) 880 888 Contents lists available at SciVerse ScienceDirect Electrical Power and Energy Systems journal homepage: www.elsevier.com/locate/ijepes Profit based
More informationA stochastic integer programming approach to the optimal thermal and wind generator scheduling problem
A stochastic integer programming approach to the optimal thermal and wind generator scheduling problem Presented by Michael Chen York University Industrial Optimization Seminar Fields Institute for Research
More informationOPTIMAL DG UNIT PLACEMENT FOR LOSS REDUCTION IN RADIAL DISTRIBUTION SYSTEM-A CASE STUDY
2006-2007 Asian Research Pulishing Network (ARPN). All rights reserved. OPTIMAL DG UNIT PLACEMENT FOR LOSS REDUCTION IN RADIAL DISTRIBUTION SYSTEM-A CASE STUDY A. Lakshmi Devi 1 and B. Suramanyam 2 1 Department
More informationOFFSHORE INTEGRATION STUDY. Analysis, benchmark and mitigation of storm and ramping risks from offshore wind power in Belgium 05/02/2018
OFFSHORE INTEGRATION STUDY Analysis, benchmark and mitigation of storm and ramping risks from offshore wind power in Belgium 05/02/2018 This study has been developed in close collaboration with 1 TABLE
More informationCyber Attacks, Detection and Protection in Smart Grid State Estimation
1 Cyber Attacks, Detection and Protection in Smart Grid State Estimation Yi Zhou, Student Member, IEEE Zhixin Miao, Senior Member, IEEE Abstract This paper reviews the types of cyber attacks in state estimation
More informationSoftware Tools: Congestion Management
Software Tools: Congestion Management Tom Qi Zhang, PhD CompuSharp Inc. (408) 910-3698 Email: zhangqi@ieee.org October 16, 2004 IEEE PES-SF Workshop on Congestion Management Contents Congestion Management
More information2015 IEEE. Digital Object Identifier: /PTC
2015 IEEE. Personal use of this material is permitted. Permission from IEEE must be obtained for all other users, including reprinting/ republishing this material for advertising or promotional purposes,
More informationUWB Geolocation Techniques for IEEE a Personal Area Networks
MITSUBISHI ELECTRIC RESEARCH LABORATORIES http://www.merl.com UWB Geolocation Techniques for IEEE 802.15.4a Personal Area Networks Sinan Gezici Zafer Sahinoglu TR-2004-110 August 2004 Abstract A UWB positioning
More informationNon-negative Matrix Factor Deconvolution; Extraction of Multiple Sound Sources from Monophonic Inputs
MITSUBISHI ELECTRIC RESEARCH LABORATORIES http://www.merl.com Non-negative Matrix Factor Deconvolution; Extraction of Multiple Sound Sources from Monophonic Inputs Paris Smaragdis TR2004-104 September
More informationDynamic On-resistance and Tunneling Based De-trapping in GaN HEMT
MITSUBISHI ELECTRIC RESEARCH LABORATORIES http://www.merl.com Dynamic On-resistance and Tunneling Based De-trapping in GaN HEMT Zhu, L.; Teo, K.H.; Gao, Q. TR2015-047 June 2015 Abstract GaN HEMT dynamic
More informationAP Physics B 2004 Scoring Guidelines
AP Physics B 004 Scoring Guidelines The materials included in these files are intended for noncommercial use by AP teachers for course and exam preparation; permission for any other use must be sought
More informationTwo-Stage Improved Group Plans for Burr Type XII Distributions
American Journal of Mathematics and Statistics 212, 2(3): 33-39 DOI: 1.5923/j.ajms.21223.4 Two-Stage Improved Group Plans for Burr Type XII Distriutions Muhammad Aslam 1,*, Y. L. Lio 2, Muhammad Azam 1,
More informationSHORT TERM LOAD FORECASTING
Indian Institute of Technology Kanpur (IITK) and Indian Energy Exchange (IEX) are delighted to announce Training Program on "Power Procurement Strategy and Power Exchanges" 28-30 July, 2014 SHORT TERM
More informationModelling wind power in unit commitment models
Modelling wind power in unit commitment models Grid integration session IEA Wind Task 25 Methodologies to estimate wind power impacts to power systems Juha Kiviluoma, Hannele Holttinen, VTT Technical Research
More informationApplication of Artificial Neural Network in Economic Generation Scheduling of Thermal Power Plants
Application of Artificial Neural Networ in Economic Generation Scheduling of Thermal ower lants Mohammad Mohatram Department of Electrical & Electronics Engineering Sanjay Kumar Department of Computer
More informationSensitivity Analysis of a Mixed Integer Linear Programming Model For Optimal Hydrothermal Energy Generation For Ghana
Sensitivity Analysis of a Mixed Integer Linear Programming Model For Optimal Hydrothermal Energy Generation For Ghana Christian John Etwire, Stephen B. Twum Abstract: This paper examines further a Mixed
More informationAnalysis and the methods of forecasting of the intra-hour system imbalance
POSTER 2016, PRAGUE MAY 24 1 Analysis and the methods of forecasting of the intra-hour system imbalance Štěpán KRATOCHVÍL 1, Jan BEJBL 2 1,2 Dept. of Economy, management and humanities, Czech Technical
More informationCorrective Control to Handle Forecast Uncertainty: A Chance Constrained Optimal Power Flow
1 Corrective Control to Handle Forecast Uncertainty: A Chance Constrained Optimal Power Flow Line Roald, Sidhant Misra, Thilo Krause, and Göran Andersson arxiv:169.2194v1 [math.oc] 7 Sep 216 Abstract Higher
More informationOnline Supplementary Appendix B
Online Supplementary Appendix B Uniqueness of the Solution of Lemma and the Properties of λ ( K) We prove the uniqueness y the following steps: () (A8) uniquely determines q as a function of λ () (A) uniquely
More informationBlackouts in electric power transmission systems
University of Sunderland From the SelectedWorks of John P. Karamitsos 27 Blackouts in electric power transmission systems Ioannis Karamitsos Konstadinos Orfanidis Available at: https://works.bepress.com/john_karamitsos/9/
More informationUnivariate Short-Term Prediction of Road Travel Times
MITSUBISHI ELECTRIC RESEARCH LABORATORIES http://www.merl.com Univariate Short-Term Prediction of Road Travel Times D. Nikovski N. Nishiuma Y. Goto H. Kumazawa TR2005-086 July 2005 Abstract This paper
More informationActivity Mining in Sensor Networks
MITSUBISHI ELECTRIC RESEARCH LABORATORIES http://www.merl.com Activity Mining in Sensor Networks Christopher R. Wren, David C. Minnen TR2004-135 December 2004 Abstract We present results from the exploration
More informationImpact of system variables on balancing
Impact of system variables on balancing J. Frunt International Workshop on Exchange of Balancing Services, Market Design and Modeling October 28, 2010 Content Regelduurzaam project Effect of changing system
More informationMixed Integer Linear Programming Formulation for Chance Constrained Mathematical Programs with Equilibrium Constraints
Mixed Integer Linear Programming Formulation for Chance Constrained Mathematical Programs with Equilibrium Constraints ayed A. adat and Lingling Fan University of outh Florida, email: linglingfan@usf.edu
More informationEstimating a Finite Population Mean under Random Non-Response in Two Stage Cluster Sampling with Replacement
Open Journal of Statistics, 07, 7, 834-848 http://www.scirp.org/journal/ojs ISS Online: 6-798 ISS Print: 6-78X Estimating a Finite Population ean under Random on-response in Two Stage Cluster Sampling
More informationFORECASTING: A REVIEW OF STATUS AND CHALLENGES. Eric Grimit and Kristin Larson 3TIER, Inc. Pacific Northwest Weather Workshop March 5-6, 2010
SHORT-TERM TERM WIND POWER FORECASTING: A REVIEW OF STATUS AND CHALLENGES Eric Grimit and Kristin Larson 3TIER, Inc. Pacific Northwest Weather Workshop March 5-6, 2010 Integrating Renewable Energy» Variable
More information