frequency response...2019/11/11 · h. bevrani, “robust power system frequency control”, new...
TRANSCRIPT
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Frequency Response Primary Frequency Response Assessment of Energy Storage Potential Problem Formulation Simulation Results Key Findings References
Presentation Outline
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Frequency Response
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Point A: pre-disturbance frequency Point B: maximum excursion point Point C: settling frequency of the Interconnected system
Frequency response characteristics during loss of generation
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Frequency response is the swift equilibrium between generation and demand provided by system, or elements of system, at time of frequency deviation [1]-[2]
Based upon the definition –
( )_BA
Generation lost MWNadir based Frequency responseFrequency Frequency
=−
( )
CA
Generation lost MWFrequency responseFrequency Frequency
=−
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S. No.
Response type
Time frame Control objectives Function
1 Inertial response 0-5 secs
Power balance and transient frequency dip minimization
Transient frequency control
2 Primary control, (governor)
1-20 secs Power balance and transient frequency recovery
Transient frequency control
3 Secondary control, (AGC)
30secs -15 mins
Power balance and steady-state frequency Regulation
4 Tertiary Control
5 - 30 mins
Power balance and economic-dispatch
Load following and reserve provision
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India [3]
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Primary Frequency Response
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Primary frequency response is of prime concern for system security and reliability (FERC, NERC)
FERC in Feb 2018, by order no. 842 mandates the PFR in all LGIA and SGIA[4]
FERC make PFR, an essential service in ensuring the reliability and resilience of the North American Bulk Power-System
Less PFR would lead to frequent events of frequency falling [5], [6]
PFR prevents the grid frequency from falling below the first stage of under frequency load shedding (“UFLS”) set points
Traditionally, PFR can be provided via Governor employed in conventional generators
9
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Transition towards Low-Carbon Systems
10
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Assessment of Energy Storage Potential
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Intermittency and uncertainty associated with renewable energy sources such as solar and wind would create generation load imbalances
These impacts lead to recurring events of frequency deviation followed by inevitable contingencies
The initial frequency deviation can be arrested by SI and PFR
With an ability of high energy density and power density, PHES comes out as a viable solution for PFR to stabilize post fault frequency dynamics
Generation scheduling is performed for the day-ahead, to estimate the PFR adequacy
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Problem Formulation
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Objective function
Generator scheduling constraints Minimum-up and down time Ramp-up and ramp-down The line power flow is limits
2, ,min . . .
.C . ,, , , , t
g t g tI T Tu dTC a P b P c C C VOLL LSti t t
PV T W Tcur cur cur curP P C g tpv t pv t w t wpv t w t
= + + + + +∑∑ ∑
+ + ∀∑ ∑ ∑ ∑
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PFR Constraints System Inertia Rate of change of frequency Frequency nadir and nadir time Steady-state frequency
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Simulation Results
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Case- Study[7]-[12] New England test system
Hourly data of wind speed and PV irradiance for a day
The frequency data
Nominal frequency (=60 Hz)
Rate of change of frequency (=2 Hz/sec)
Governor dead band (=36mHz)
Maximum steady-state frequency deviation (=0.2Hz)
Load damping rate (=1%)
Under frequency load shedding bound as (=59.1Hz)
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Total installed capacity is 8840 MW and peak demand of 5748 MW
The system PFR requirement is assumed to be 50% of the system largest generator
The capacity of PHES takes as 200MW
PHES fixed operating cost is assumed as 18$/Kw-h yearly
PV and wind curtailment cost as 0.7$/MWh and 1$/MWh, respectively
Largest generator outage is consider at t5
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System Performance
Cases
Limit on RoCoF and Fnadir
No Limit on RoCoF and Fnadir
Without
PHES Operating
Cost ($) With PHES Operating
Cost ($) Base case √ 2606027 - -
Case -ii √ 2037064 √ 2032000
Case- iii √ 1665598 √ 1661624
Case- iv × - √ 1232391 Case- v × - √ 961442
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Fig. gives the hourly load, wind and PV generation profile for 24 hr
Wind and PV power generation shown is at 10% integration
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Fig. shows the PFR contribution from conventional units PFR requirement in most of the instances is increased on
RES integration The same is reduced on PHES integration
Limit on Frequency Security Parameters
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0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24Time (Hrs)
-2
-1.5
-1
-0.5
0
RoCo
F (H
z/sec
)
Base case
30% RES
30% RES + PHES
Impact on RoCoF with 30% RES integration with constraint on frequency parameter
Bound of 2Hz/sec is imposed on RoCoF RoCoF is within range and well behaved with PHES
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0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Time (Hrs)
0
200
400
600
800
Syste
m In
ertia
(Mw-
sec/H
z)
Base Case
20% RES
30% RES
40% RES
50% RES
The variation of SI under different RES integration is plotted
Due to low availability of wind power and decreasing profile of PV power around t15, additional CG are committed to meet the load
Increases SI in these hours
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0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Time (Hrs)
55
56
57
58
59
60
Freq
uenc
y Na
dir (
Hz)
Base case
40% RES
PHES at 40% RES
0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Time (Hrs)
55
56
57
58
59
Freq
uenc
y Na
dir (
Hz)
Base case
50% RES
PHES at 50% RES
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1 2 3 4
Cases of RES integration
0
500
1000
1500
SI an
d PF
R fro
m P
HES
PFR
SI
Case 1 shows results at 20% RES integration, next at 30% integration up to 50%
There is no RES curtailment at 20% and 30%; however, curtailment increases on large integration
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Key Findings
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At low RES integration, conventional units are adequate for PFR
RES integration at 40% and above, response from conventional units is limited and fails to maintain frequency in range
PHES stabilizes post-fault frequency dynamics-RoCoF, frequency nadir and steady-state frequency
PHES reduces additional commitment of conventional units for PFR
Results in reduction in overall system operating cost Large scale RES integration and power flow limits ->
RES curtailment and requires storage proper allocation
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References
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1. Wind speed anChallenges and Opportunities for the Nordic Power System,” 2016.
2. H. Bevrani, “Robust Power System Frequency Control”, New York, NY, USA: Springer, 2009.
3. Central Electricity Regulatory Commission 2017, “Report of Expert Group to review and suggest measures for bringing power system operation closer to National Reference Frequency”, [Online]. Available: http://cercind.gov.in/2018/Reports/50%20Hz_Committee1.pdf
4. FERC Revises Requirements for Provision of Primary Frequency Response, 2018, Available: https://www.ferc.gov/media/news-releases/2018/2018-1/02-15-18-E-2.asp
5. O.I. Elgered, Electric energy system theory: An introduction, 2nd edn , Mcgraw- Hill, New York,1982, pp. 55-60.
6. Joseph H. Eto, John Undrill, Peter Mackin, Ron Daschmans, Ben Williams, Brian Haney, Randall Hunt, Jeff Ellis, “ Use of Frequency Response Metrics to Assess the Planning and Operating Requirements for Reliable Integration of Variable Renewable Generation”, Ernest Orlando Lawrence Berkeley National Laboratory, Dec. 2010
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7. D. Krishnamurthy, W. Li, and L. Tesfatsion, “An 8-zone test system based on ISO New England data: development and application,” IEEE Trans. Power Syst., vol. 31, no. 1, pp. 234–246, 2016.
8. d PV irradiance data, [Online]. Available: http://www.soda-pro.com/.
9. Report on “Pinnapuram integrated renewable energy with storage project, IRESP.
10. [Online].Available: http://environmentclearance.nic.in/writereaddata/Online/TOR/16_Apr_2018_13182853391O82IHRPinnapuramPFRFinalToR.pdf
11. "Updated Capital Cost Estimates for Utility Scale Electricity Generating Plants." Information Administration, Energy, U. S, 2013.
12. V. Trovato, A. Bialecki, and A. Dallagi, “Unit commitment with inertia-dependent and multi-speed allocation of frequency response services,” IEEE Trans. Power Sys., vol. 34, no. 2, pp. 1537-1548, 2018.
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