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EEE812: ADVANCED POWER
SYSTEM PROTECTION
Distributed Generation: Impact on
Protection
Content prepared by Dr Campbell Booth
University of Strathclyde
Overview
 Conventional distribution networks and protection -
summary
 How distribution network are changing (active distribution
networks, DG, potential for islanded operation)
 Potential issues for future networks
– Protection “blinding”, false tripping/coordination problems (several examples)
– DG ride-through
– Converter-interfaced sources
– Use of DC for distribution?
– Fault current limitation
Protection solutions?
Distributed Generation Basics
 Technologies
 Small and Large scale combined heat and power units
 Energy from waste units
 Wind Farms
 Tidal and wave energy units
 Stand-by generators (diesel)
 Types of generating units
 Self-excited asynchronous generator
 Mains-excited asynchronous generator
 Power factor corrected asynchronous generator
 Doubly fed induction generator (DFIG)
 Synchronous generator
 Inverter connected Synchronous Generator (Wind)
 Inverter connected DC source (fuel cell, PV)
Distributed Generation Basics
 Main reasons for Distributed Generation
 Reduction of gaseous emissions (mainly CO2)
 Diversification of energy sources
 Ease of finding sites for smaller generators
 Short construction times
 Potentially reduced transmission losses
 Increased efficiency with combined Heat and Power
(CHP) units
Conventional distribution networks
 Operated radially
 Designed for unidirectional power flow
11 kV
POWER FLOW DIRECTION
 Protected with over-current protection relays, reclosers
and fuses
How distribution networks are changing
– Increase of distributed generation:
– Wind
– Hydro
– Biomass
– Photovoltaic
– Wave/Tidal
– others
– Introduction of network automation
– Connection of energy storage
Active distribution networks
Fault current magnitudes and directions becomes unpredictable,
potentially causing problems:
11 kV
– false tripping of feeders;
– lack of coordination between protection devices;
– other problems.
Islanding operation
– Reduced fault levels
– Changed fault current direction
– System control?
11 kV
Protection of Distribution Networks
 132/33kV
 Distance, differential (some), overcurrent
 11kV/415V
 Overcurrent, reclosers, sectionalisers, fuses, RCDs
 Remember, majority of faults transient – fuses should only operate if
fault is permanent
 Typically, faults are isolated very quickly by reclosers, multiple
reclose attempts are attempted, and if fault is permanent and
downstream of fuses, fuses ultimately melt while system is in
reclosed state
 Reclose is then successful
 If permanent fault between recloser and fuse, then recloser will lock-
out after pre-defined number of attempts
 Automatic sectionalisers/smart links sometimes used
B
A
t
I
t
Decreasing Fault Current
I
Fault 1
Fault 1
tF1
Fault 2
tF2
Fault 2
tF2
Fault 2
Relay 1 Relay 2
Source
Protection of Distribution Networks
(HV/MV)
Protection of distribution networks
(MV/LV)
 Distribution network protection is
based on overcurrent protection,
reclosers and fuses (and
sectionalisers)
 In rural overhead distribution
networks, >80% of faults are
temporary and auto reclosure
automation is adopted.
CBT1-11
CBT1-33
CBT2-11
CBT2-33
B33kV
B11kV
SpurA1
SpurA2
SpurA3
SpurA4
SpurA5
SpurA6
SpurA7
SpurA8
SpurB1
SpurB2
SpurB3
SpurB4
SpurB5
R-A R-B
PMAR-A
PMAR-B
Feeder
A
Feeder
B
SpurA9
SpurA10
SpurA1
 Transient fault
 Recloser will
successfully reclose
 Permanent fault
 Recloser will reclose
multiple times (with
variable delays before
re-opening) and fuse will
melt before max
reclosures attempted
 Sectionalisers/“smart
links” may be used
instead of, or to “save”
fuses
Gers and Holmes
“Protection of
Electricity
Distribution
Networks”,
IEE Power &
Energy Series 47
Protection of distribution networks
(MV/LV)
Gers and Holmes
“Protection of Electricity
Distribution Networks”,
IEE Power & Energy Series 47
Protection of distribution networks
(MV/LV)
B
A C
Permanent Fault
PMAR
(fast/delayed
interruptions
and reclosures)
Sectionaliser
(counts number of
overcurrents/interruptions
- opens after certain number)
Fuse
IDMT
(with auto-reclose)
PMAR
Sectionaliser
Fuse
IDMT Start
Open
Count 1
1 “shot”
Reset
Open
Count 1
1 “shot”
Reset
Close
Count 1
2 “shots”
Start
Open
Count 2
2 “shots”
Reset
Open
Count 2
2 “shots”
Reset
Close
Count 2
melt
Reset
Close
Reset
melted
t
Fault inception
1
2
0
Protection of distribution networks
(MV/LV)
B
A C
PMAR Sectionaliser
Fuse
IDMT
PMAR
Sectionaliser
Fuse
IDMT Start
Open
Reset
Open
Reset
Close
Reset
Close
t
Fault inception
Protection of distribution networks
(MV/LV)
Transient Fault
Protection of distribution networks
(MV/LV)
 Sectionalisers may be used instead of or in
conjunction with fuses (“fuse savers”)
http://www.hubbellpowersystems.com/catalogs/switching/10D-Elec_Sect.pdf
B
A C
Source
(Grid)
Operate (quickly)
Operate
(after a delay)
Don’t operate
V
V=IZ
11kV 30MVA Source (Zsource= j4.03W) j1W impedance to fault (ZAB=j0.2W)
Fault Behaviour – no DG
B
A C
Operate (quickly)
Operate
(after a delay)
Don’t operate
V
V=IZ
With DG at B
No DG
DG fault
contribution
14MVA
Fault Behaviour – with DG
Source
(Grid)
11kV 30MVA Source (Zsource= j4.03W) j1W impedance to fault (ZAB=j0.2W)
Equivalent circuit – no DG
j4.03W
j0.8W
j0.2W
If Z from source to fault = j1W
(j0.2W for first feeder + j0.8 W for second
feeder):
Ifault= Igrid = Vph/Z = 6351/5.03 = 1263A
VB = 1263x0.8=1010V
VA = 1263x1=1263V
Grid
V
V=I/Z
With DG at B
No DG
B
A
Equivalent circuit – with DG
j4.03W
0.8W
j0.2W
j8.64W
Z from sources to fault =
j4.23//j8.64 + j0.8 = j3.64W
Ifault = Vph/Z = 6351/3.64 = 1745A
Igrid = (8.64)/(4.23+8.64) x1745
= 1171A
IDG = (4.23)/(4.23+8.64) x1745
= 574A
VB = 1745x0.8=1396V
VA = VB + (1171x0.2) =1630V
Grid DG
V
V=I/Z
With DG at B
No DG
B
A
Protection issues - “blinding”
t
If
Fault current as measured at
upstream relay with no
downstream DG
Protection issues - “blinding”
Under very high DG penetrations and very low grid infeed, infeed from
grid could be markedly reduced, therefore increasing risk of feeder
protection “blinding” (slow or non-operation of relay at A for backup
scenario in this case).
Problem? Probably not significant in interconnected system – but in
islanded mode?
t
If
Fault current as measured at
upstream relay with no
downstream DG
t
If
Fault current as measured at
upstream relay with significant
downstream DG
B
A C
Source
(Grid)
V=0
Infeed=5000A
(4500+500)A
Infeed=
4500A
Infeed=500A
0.6W
0.8W
D
E
Protection issues – generator tripping
on undervoltage
G59 – DG interface protection settings
B
A C
Source
(Grid)
V=0
Fault current=5000A
(4500+500)A
Infeed=
4500A
Infeed=500A
Z=0.6W
Z=0.8W
D
E
VA=VD=5000x0.6=3000V
(less than 50% nominal)
VED=500x0.8=400V, therefore
VE=3400V
So if protection at A does not operate
within 0.4-0.5s, chance of DG at E
tripping, unnecessarily, on
undervoltage – also slight chance of
relay at D operating if threshold
violated
Protection issues – generator tripping
on undervoltage
B
A C
Source
(Grid)
V=0
D
E
If protection at D is non-directional
overcurrent, then if contribution from
DG at E exceeds setting on D,
potential for mal-operation
In this case, if Ithreshold<500A at D,
potential for D to trip unnecessarily
Fault current=5000A
(4500+500)A
Infeed=500A
Z=0.6W
Z=0.8W
Infeed=
4500A
Protection issues – feeder protection
maloperation
Protection issues - DG impact on
instantaneous (“high set”) protection
2
1 3
Operate (time delay)
Operate? Operate (instant)
If
Protection issues - DG impact on
instantaneous (“high set”) protection
2
1 3
DG
If(at 2 and 3)
Protection issues - DG impact on
instantaneous (“high set”) protection
Use of directional relays
to provide correct protection
operation on parallel feeders
From NPAG: - chapter 9
Sensitive and fast acting
directional protection here
(Ithreshold=10% of rated
line current)
Looks “up”
into line
– prevents R2
operating
for this fault
Protection issues - DG impact on
directional protection
DG on load
side – R’2
(and possibly
R2) might
maloperate?
Protection issues - DG impact on
directional protection
DG on load side – R’1 R’2 (and possibly R1 and R2) might maloperate?
Even under load conditions – back-feed if DG>local load?
Protection issues - DG impact on
directional protection
Use of overcurrent
relays for protection
of ring mains
From NPAG: -
chapter 9
Fault as shown:
R5’ operates after 1.7
(R6’ after 2.1)
R2 after 0.5
(R3 after 0.9)
Protection
issues - DG
impact on
directional
protection
Additional DG
contribution may
result in
coordination
problems?
R1’ will operate
for this scenario?
Protection
issues - DG
impact on
directional
protection
Use of overcurrent
relays for protection
of ring mains
From NPAG: -
chapter 9
Impact on section
switches/fuses/…?
 Blinding/maloperation/impact on automation/auto-
reclose/sectionaliser logic?
 Possible problems if DG penetration/fault contribution
is high?
 Performance in islanded mode – if permitted?
B
A C
PMAR Sectionaliser
Fuse
IDMT

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Lec6 impact of embedded generation (1)

  • 1. EEE812: ADVANCED POWER SYSTEM PROTECTION Distributed Generation: Impact on Protection Content prepared by Dr Campbell Booth University of Strathclyde
  • 2. Overview  Conventional distribution networks and protection - summary  How distribution network are changing (active distribution networks, DG, potential for islanded operation)  Potential issues for future networks – Protection “blinding”, false tripping/coordination problems (several examples) – DG ride-through – Converter-interfaced sources – Use of DC for distribution? – Fault current limitation Protection solutions?
  • 3.
  • 4. Distributed Generation Basics  Technologies  Small and Large scale combined heat and power units  Energy from waste units  Wind Farms  Tidal and wave energy units  Stand-by generators (diesel)  Types of generating units  Self-excited asynchronous generator  Mains-excited asynchronous generator  Power factor corrected asynchronous generator  Doubly fed induction generator (DFIG)  Synchronous generator  Inverter connected Synchronous Generator (Wind)  Inverter connected DC source (fuel cell, PV)
  • 5. Distributed Generation Basics  Main reasons for Distributed Generation  Reduction of gaseous emissions (mainly CO2)  Diversification of energy sources  Ease of finding sites for smaller generators  Short construction times  Potentially reduced transmission losses  Increased efficiency with combined Heat and Power (CHP) units
  • 6. Conventional distribution networks  Operated radially  Designed for unidirectional power flow 11 kV POWER FLOW DIRECTION  Protected with over-current protection relays, reclosers and fuses
  • 7. How distribution networks are changing – Increase of distributed generation: – Wind – Hydro – Biomass – Photovoltaic – Wave/Tidal – others – Introduction of network automation – Connection of energy storage
  • 8. Active distribution networks Fault current magnitudes and directions becomes unpredictable, potentially causing problems: 11 kV – false tripping of feeders; – lack of coordination between protection devices; – other problems.
  • 9. Islanding operation – Reduced fault levels – Changed fault current direction – System control? 11 kV
  • 10. Protection of Distribution Networks  132/33kV  Distance, differential (some), overcurrent  11kV/415V  Overcurrent, reclosers, sectionalisers, fuses, RCDs  Remember, majority of faults transient – fuses should only operate if fault is permanent  Typically, faults are isolated very quickly by reclosers, multiple reclose attempts are attempted, and if fault is permanent and downstream of fuses, fuses ultimately melt while system is in reclosed state  Reclose is then successful  If permanent fault between recloser and fuse, then recloser will lock- out after pre-defined number of attempts  Automatic sectionalisers/smart links sometimes used
  • 11. B A t I t Decreasing Fault Current I Fault 1 Fault 1 tF1 Fault 2 tF2 Fault 2 tF2 Fault 2 Relay 1 Relay 2 Source Protection of Distribution Networks (HV/MV)
  • 12. Protection of distribution networks (MV/LV)  Distribution network protection is based on overcurrent protection, reclosers and fuses (and sectionalisers)  In rural overhead distribution networks, >80% of faults are temporary and auto reclosure automation is adopted. CBT1-11 CBT1-33 CBT2-11 CBT2-33 B33kV B11kV SpurA1 SpurA2 SpurA3 SpurA4 SpurA5 SpurA6 SpurA7 SpurA8 SpurB1 SpurB2 SpurB3 SpurB4 SpurB5 R-A R-B PMAR-A PMAR-B Feeder A Feeder B SpurA9 SpurA10 SpurA1
  • 13.  Transient fault  Recloser will successfully reclose  Permanent fault  Recloser will reclose multiple times (with variable delays before re-opening) and fuse will melt before max reclosures attempted  Sectionalisers/“smart links” may be used instead of, or to “save” fuses Gers and Holmes “Protection of Electricity Distribution Networks”, IEE Power & Energy Series 47 Protection of distribution networks (MV/LV)
  • 14. Gers and Holmes “Protection of Electricity Distribution Networks”, IEE Power & Energy Series 47 Protection of distribution networks (MV/LV)
  • 15. B A C Permanent Fault PMAR (fast/delayed interruptions and reclosures) Sectionaliser (counts number of overcurrents/interruptions - opens after certain number) Fuse IDMT (with auto-reclose) PMAR Sectionaliser Fuse IDMT Start Open Count 1 1 “shot” Reset Open Count 1 1 “shot” Reset Close Count 1 2 “shots” Start Open Count 2 2 “shots” Reset Open Count 2 2 “shots” Reset Close Count 2 melt Reset Close Reset melted t Fault inception 1 2 0 Protection of distribution networks (MV/LV)
  • 16. B A C PMAR Sectionaliser Fuse IDMT PMAR Sectionaliser Fuse IDMT Start Open Reset Open Reset Close Reset Close t Fault inception Protection of distribution networks (MV/LV) Transient Fault
  • 17. Protection of distribution networks (MV/LV)  Sectionalisers may be used instead of or in conjunction with fuses (“fuse savers”) http://www.hubbellpowersystems.com/catalogs/switching/10D-Elec_Sect.pdf
  • 18. B A C Source (Grid) Operate (quickly) Operate (after a delay) Don’t operate V V=IZ 11kV 30MVA Source (Zsource= j4.03W) j1W impedance to fault (ZAB=j0.2W) Fault Behaviour – no DG
  • 19. B A C Operate (quickly) Operate (after a delay) Don’t operate V V=IZ With DG at B No DG DG fault contribution 14MVA Fault Behaviour – with DG Source (Grid) 11kV 30MVA Source (Zsource= j4.03W) j1W impedance to fault (ZAB=j0.2W)
  • 20. Equivalent circuit – no DG j4.03W j0.8W j0.2W If Z from source to fault = j1W (j0.2W for first feeder + j0.8 W for second feeder): Ifault= Igrid = Vph/Z = 6351/5.03 = 1263A VB = 1263x0.8=1010V VA = 1263x1=1263V Grid V V=I/Z With DG at B No DG B A
  • 21. Equivalent circuit – with DG j4.03W 0.8W j0.2W j8.64W Z from sources to fault = j4.23//j8.64 + j0.8 = j3.64W Ifault = Vph/Z = 6351/3.64 = 1745A Igrid = (8.64)/(4.23+8.64) x1745 = 1171A IDG = (4.23)/(4.23+8.64) x1745 = 574A VB = 1745x0.8=1396V VA = VB + (1171x0.2) =1630V Grid DG V V=I/Z With DG at B No DG B A
  • 22. Protection issues - “blinding” t If Fault current as measured at upstream relay with no downstream DG
  • 23. Protection issues - “blinding” Under very high DG penetrations and very low grid infeed, infeed from grid could be markedly reduced, therefore increasing risk of feeder protection “blinding” (slow or non-operation of relay at A for backup scenario in this case). Problem? Probably not significant in interconnected system – but in islanded mode? t If Fault current as measured at upstream relay with no downstream DG t If Fault current as measured at upstream relay with significant downstream DG
  • 25. G59 – DG interface protection settings
  • 26. B A C Source (Grid) V=0 Fault current=5000A (4500+500)A Infeed= 4500A Infeed=500A Z=0.6W Z=0.8W D E VA=VD=5000x0.6=3000V (less than 50% nominal) VED=500x0.8=400V, therefore VE=3400V So if protection at A does not operate within 0.4-0.5s, chance of DG at E tripping, unnecessarily, on undervoltage – also slight chance of relay at D operating if threshold violated Protection issues – generator tripping on undervoltage
  • 27. B A C Source (Grid) V=0 D E If protection at D is non-directional overcurrent, then if contribution from DG at E exceeds setting on D, potential for mal-operation In this case, if Ithreshold<500A at D, potential for D to trip unnecessarily Fault current=5000A (4500+500)A Infeed=500A Z=0.6W Z=0.8W Infeed= 4500A Protection issues – feeder protection maloperation
  • 28. Protection issues - DG impact on instantaneous (“high set”) protection
  • 29. 2 1 3 Operate (time delay) Operate? Operate (instant) If Protection issues - DG impact on instantaneous (“high set”) protection
  • 30. 2 1 3 DG If(at 2 and 3) Protection issues - DG impact on instantaneous (“high set”) protection
  • 31. Use of directional relays to provide correct protection operation on parallel feeders From NPAG: - chapter 9 Sensitive and fast acting directional protection here (Ithreshold=10% of rated line current) Looks “up” into line – prevents R2 operating for this fault Protection issues - DG impact on directional protection
  • 32. DG on load side – R’2 (and possibly R2) might maloperate? Protection issues - DG impact on directional protection
  • 33. DG on load side – R’1 R’2 (and possibly R1 and R2) might maloperate? Even under load conditions – back-feed if DG>local load? Protection issues - DG impact on directional protection
  • 34. Use of overcurrent relays for protection of ring mains From NPAG: - chapter 9 Fault as shown: R5’ operates after 1.7 (R6’ after 2.1) R2 after 0.5 (R3 after 0.9) Protection issues - DG impact on directional protection
  • 35. Additional DG contribution may result in coordination problems? R1’ will operate for this scenario? Protection issues - DG impact on directional protection Use of overcurrent relays for protection of ring mains From NPAG: - chapter 9
  • 36. Impact on section switches/fuses/…?  Blinding/maloperation/impact on automation/auto- reclose/sectionaliser logic?  Possible problems if DG penetration/fault contribution is high?  Performance in islanded mode – if permitted? B A C PMAR Sectionaliser Fuse IDMT