assessment of risk against regulator requirements for duration of long supply interruptions mohd...
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Assessment of Risk Against Regulator Requirements for Duration of Long Supply Interruptions
Mohd Ikhwan Muhammad RidzuanDr Sasa DjokicThe University of Edinburgh, [email protected]
Introduction
• Distribution network operators (DNOs) have to make sure the frequency and duration of interruptions experienced by their customer are within specified or agreed limits and targets
• DNOs may be rewarded, penalized or liable for compensation based on their actually achieved reliability performance
• An important aspect of the related analysis is assessment of RISK that DNOs face (based on relevant characteristics and operation strategies of their networks and other influential factors)
Input Data & Parameters: Fault Rates & Repair Time
Input Data & Parameters: Daily Variation of Interruption Probability
Continuity of Supply Requirements: UK Security and Quality of Supply
Continuity of Supply Requirements: UK Guaranteed Standard of Performance
Continuity of Supply Requirements: Italian Supply Quality Standard
Continuity of Supply Requirements: Italian Guaranteed Standard of Performance
Test Network500kVA
Transformer
11kV 0.4kV
ZT=2.04 + j9.28 (p.u. on 100MVA)
190 customersPMAX= 2.27kW/customer Total Load MAX= 431.3kW (at 1p.u.)
U1
U2
U3
U4
U5 U6
U7
U8
U9 U10
U11
U12 U13
U14 U15U16 U17
U18
U19
78.6m
36m
85m
32m 90m 41m 35m 33m 17m
73m 67m
24m 52m
93m 68m 40m
70m
53m 12m
32m
41m
15m 80m 85m
27m 26m 53m
90m
82m
40m 17m
DE
E
A A B C D E
E E
E E
E E E
E
E EE
E
D D E
C D EE
D
E E
L
L
L
L
L L
L
L
L
L
L
L L
L L
L L
L
L
(15 cust.)
(15 cust.)
(12 cust.)(14 cust.) (9 cust.)
(12 cust.)(12 cust.) (9 cust.)
(12 cust.) (6 cust.)
(9 cust.) (6 cust.)
(6 cust.)
(15 cust.) (15 cust.)
(8 cust.) (8 cust.)
(6 cust.)
(4 cust.)
* L type line length = 30m
To another Primary
Substation
375m 375m 375m 375m 375m 375m 375m 375m 150m
11kV
33kV P P P P Q Q Q Q Q
*2 *3
*4 *5 *6
Reflection Centre
Transformer
Circuit Breaker
Fuse
Disconnector (n. open)
Total : 9120 customers
(48 transformers x190 customers/transformer)
PMAX = 2.27kW/customer
Total LoadMAX = 20.7MW
Zeq=0.063206+j0.0356383 (p.u. on 100MVA)
500kVA
Radial LV Distribution (Underground Cable)
ZLV=5.377+j10.1925 (p.u. on 100MVA)
0.4kV
15MVA
15MVA
Grid Supply System
Zsys
Zsys=0.0269+j0.1822(p.u. on 100MVA)
*2
*6
*5
*4
*3543MVA Source
Typical UK urban distribution networkMV: Meshed (but operated radially in normal conditions), with an alternative supply point (unrestricted support)LV: Radial (3-phase & 1-phase service connections)
Risk Assessment Procedures
Analytical Approaches:Based on mathematical models, which typically limit outputs to oneset of results, e.g. mean values of reliability indices, corresponding tothe specified input mean data.
Offer only a general “snapshot” characterisation of the analysedsystem, as they will always provide the same set of output results forthe same set of input data, parameters and models.
Probabilistic (Monte Carlo) Approaches:Allow to model a wide range of variations of practically all inputparameters and data in one or few simulation/calculation set-ups,without the need to repeat calculation after a change in input data.
Outputs are reliability indices, which are typically presented asprobability distributions with the corresponding mean values.
Risk Assessment ProceduresWHY COMBINE PROBABILISTIC & ANALYTICAL RELIABILITY
ASSESSMENT?
Probabilistic Approaches give probability distributions of customerinterruptions (which customers will be interrupted and how frequently) and probability distributions of interruption durations
Analytical Approaches could incorporate Regulator Requirements, if actual limits are used as input data For example, if we assume that every faulted component has repair time of exactly 18 hours, with the same duration applied for transfer to alternative supply and time required for network reconfiguration, the worst possible network reliability performance for which there will still be no penalty incurred due to supply interruptions longer than 18 hours will be calculated
Afterwards, analytically calculated reliability indices are used as “benchmark limits” for directly assessing risks of penalty
Considered Scenario
12
Considered Scenarios (Existing Networks & Future “Smart Grids”):
Existing Network Configurations & Functionalities (SC-1A/B): In accordance with Security of Supply Requirements (MV network have switching functionalities for transferring to alternative supply and for reconfiguration; otherwise large number of customers will be exposed to excessively long supply interruptions)
Considered Scenario
13
Considered Scenarios (Existing Networks & Future “Smart Grids”):
“Smart Grid” Scenarios (SC-6A/B): Represent functionalities available in future networks -- in this case automatic remote-controlled switching implemented in MV network (LV network is still protected only by the fuses)
Considered Scenario
14
Considered Scenarios (Existing Networks & Future “Smart Grids”):
Various Regulator Requirements (SC 2A/2B to SC-5A/5B): Used ONLY for analytical assessment and formulation of corresponding limits and thresholds against which risks of penalties will be assessed after probabilistic results are obtained
Results: Analytical Assessment15
MV Network Only MV Network & LV Equivalent
Results: System Assessment
Significant increase of CAIDI value is indicated for Scenario SC-6A/6B,when “smart grid“ automatic switching is applied… (?!)
CAIDI (MV Network) CAIDI (MV Network & LV Equivalent)
0 200 400 600 800 1000 1200 1400
0.0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
SC-1A Analytical Mean=8.953SC-6A Analytical Mean=40.295
(for mean
, mean
and mean load)
CA
IDI
hours/customer interruption
SC-1A (MCS Mean=7.807) SC-6A (MCS Mean=47.326)
0 5 10 15 20 25
0.0
0.2
0.4
0.6
0.8
limit SC-3ARisk=7.4% (SC-1A)Risk=9.8% (SC-6A)
limit SC-2ARisk=7.2% (SC-1A)Risk=9.7% (SC-6A)
0 20 40 60 80 1000.00008
0.00010
0.00012
0.00014
0.00016
0.00018
0.00020
0.00022
0.00024
0.00026
SC-1B Analytical Mean=14.732SC-6B Analytical Mean=39.488
(for mean
, mean
and mean load)
limit SC-3BRisk=81.4% (SC-1B)Risk=100% (SC-6B)
limit SC-2BRisk=49.8% (SC-1B)Risk=100% (SC-6B)
CAID
I (PD
F)
hours/customer interruption
SC-1B (MCS Mean=15.487) SC-6B (MCS Mean=41.575)
Results: System AssessmentSAIFI (MV Network) SAIFI (MV Network & LV Equivalent)
All faults previously cleared after 15min or 3 hours are in SC-1A/1B resulting inshort interruptions (due to <3min automatic switching).
Corresponding supply interruptions are no longer contributing to the averageinterruption duration (resulting in a higher risk of penalty… still, number of faultsreduced in SC-6A/6B
0.0 0.5 1.0 1.5 2.0 2.5 3.0
0.0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
SC-1A Analytical Mean=0.172SC-6A Analytical Mean=0.108
(for mean
, mean
and mean load)
SA
IFI (P
DF
)
long interruption/customer/year
SC-1A (MCS Mean=0.140) SC-6A (MCS Mean=0.059)
0.0 0.1 0.2 0.3 0.4
0.0
0.2
0.4
0.6
0.8
limit 1 interruptionRisk=3.9% (SC-1A)Risk=0.8% (SC-6A)
0.000 0.002 0.004 0.006 0.008 0.010 0.012 0.014 0.016 0.018 0.020 0.022
0.000
0.005
0.010
0.015
0.020
0.025
0.030
0.035
0.040
0.045
SC-1B Analytical Mean=0.0066SC-6B Analytical Mean=0.0063
(for mean
, mean
and mean load)
limit 1 interruptionRisk=73.8% (SC-1B)Risk=68.6% (SC-6B)
SAIF
I (PD
F)long interruption/customer/year
SC-1B (MCS Mean=0.0064) SC-6B (MCS Mean=0.0059)
Results: Customer Assessment
0 50 100 150 200 250 300 350
0.0
0.2
0.4
0.6
0.8
CAID
I (PD
F)
hours/customer interruption
SC-1A Cust 1 (MCS Mean=4.499) SC-1A Cust 8 (MCS Mean=4.1817)
0 4 8 12 16 200.0
0.2
0.4
0.6
0.8
limit SC-3ARisk=6.4% (Cust 1)Risk=5.7% (Cust 8)
limit SC-2ARisk=5.9% (Cust 1)Risk=5.1% (Cust 8)
SAIFI (SC-1A) CAIDI (SC-1A)
0.0 0.5 1.0 1.5 2.0 2.5 3.0
0.0
0.2
0.4
0.6
0.8limit 1 interruptionRisk=2.7% (Cust 1)Risk=6.9% (Cust 8)
LI (P
DF)
long interruption
SC-1A Cust 1 (MCS Mean=0.067) SC-6A Cust 8 (MCS Mean=0.207)
Results: Customer AssessmentSAIFI (SC-1B) CAIDI (SC-1B)
0 20 40 60 80 100
0.0000
0.0005
0.0010
0.0015
0.0020
0.0025
0.0030
limit SC-3BRisk=70.8% (Cust 1)Risk=72.6% (Cust 8)
limit SC-2BRisk=41.9% (Cust 1)Risk=41.3% (Cust 8)
CAID
I (PD
F)
hours/customer interruption
SC-1B Cust 1 (MCS Mean=16.0916) SC-1B Cust 8 (MCS Mean=15.1101)
0 1 2 3 4 5
0.00
0.02
0.04
0.06
0.08
0.10
0.12
0.14
0.16
limit 1 interruptionRisk=57.6% (Cust 1)Risk=65.4% (Cust 8)
LI (P
DF)
long interruption
SC-1B Cust 1 (MCS Mean=1.1375) SC-1B Cust 8 (MCS Mean=1.2720)
Results: Customer Assessment
0 200 400 600 800 1000 1200 1400
0.0
0.2
0.4
0.6
0.8
1.0
CAI
DI (
PDF)
hours/customer interruption
SC-6A Cust 1 (MCS Mean=18.8242) SC-6A Cust 8 (MCS Mean=13.0869)
0 4 8 12 16 200.0
0.2
0.4
0.6
0.8
1.0
limit SC-3ARisk=7.7% (Cust 1)Risk=5.8% (Cust 8)
limit SC-2ARisk=7.5% (Cust 1)Risk=5.4% (Cust 8)
SAIFI (SC-6A) CAIDI (SC-6A)
0.0 0.5 1.0 1.5 2.0 2.5 3.0
0.0
0.2
0.4
0.6
0.8
1.0limit 1 interruptionRisk=0.3% (Cust 1)Risk=1.4% (Cust 8)
LI (P
DF)
long interruption
SC-6A Cust 1 (MCS Mean=0.0268) SC-6A Cust 8 (MCS Mean=0.0829)
Results: Customer Assessment
0 50 100 150 200 250 300
0.0000
0.0005
0.0010
0.0015
0.0020
0.0025
0.0030
0.0035
limit SC-3BRisk=82.6% (Cust 1)Risk=86.0% (Cust 8)
limit SC-2BRisk=80.2% (Cust 1)Risk=83.9% (Cust 8)
CAID
I (PD
F)
hours/customer interruption
SC-6B Cust 1 (MCS Mean=41.7844) SC-6B Cust 8 (MCS Mean=40.7858)
0 4 8 12 16 200.000
0.001
0.002
0.003
0.004
SAIFI (SC-6B) CAIDI (SC-6B)
0 1 2 3 4 5
0.00
0.02
0.04
0.06
0.08
0.10
0.12
0.14
0.16
limit 1 interruptionRisk=56.4% (Cust 1)Risk=58.7% (Cust 8)
LI (P
DF)
long interruption
SC-6B Cust 1 (MCS Mean=1.1113) SC-6B Cust 8 (MCS Mean=1.1557)
Risk Results
SC-1A (%) SC-6A (%) SC-1B (%) SC-6B (%)
Limit SC-2A/2B (GSP-UK) 0.28 0.08 36.8 68.6
Limit SC-3A/3B (GSP-Italy) 0.28 0.08 60.1 68.6
SC-1A (%)
SC-6A (%)
SC-1B (%)
SC-6B (%)
SC-1A (%)
SC-6A (%)
SC-1B (%)
SC-6B (%)
Customer 1 8 1 8 1 8 1 8
Limit SC-2A/2B (GSP-UK)
0.16 0.35 0.02 0.07 24.1 27.0 45.2 49.2
Limit SC-3A/3B (GSP-Italy)
0.17 0.39 0.02 0.08 40.8 47.5 46.6 50.5
System Risk’s
Customer Risk’s
THANKS!
Questions?
Mohd Ikhwan Muhammad RidzuanDr Sasa DjokicThe University of Edinburgh, [email protected]