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Does a Smarter Power Grid Really Matter Anyway?
… A Reflection of Challenges Experienced in the UK
Professor William Hung MBA, PhD, BSc, CEng FIET
Director/WH Power Systems Consultant LtdHonorary Professor/ University of WarwickTechnical Director/ Cardiff University
University of Warwick School of Engineer Seminar - 29 January 2016
Presentation Overview
• Development of Electricity Supply Industry in the UK and its implications on Key Stakeholder relationships
• Review of frequency control issues
• Collaborative effort between stakeholders since privatization
• Future Challenges in a Low Carbon Economy
• Contributions not only from a smarter grid but smarter demands
• Extension of Stakeholder Engagement Activities
10/15/2015WH PSCL 2
10/15/2015WH PSCL 3
Generating
Companies
Distributors
Transmission
Companies
Suppliers
Electricity Supply Industry – Key Stakeholders
Changes in the UK Electricity Supply Industry
• Privatization – 1990
• Dash for Gas – around 1993
• Liberalization of electricity market - 1999
• NETA- March 2001
• Dash for Wind – ROC payment -2002
• BETTA- April 2005
• EU Large Combustion Plant Directive
• Renewable Obligations
10/15/2015WH PSCL 4
Implications on Key Stakeholders Relationship
• Change of industry structure and generation mix - significant implications on system security from a frequency control perspective.
• From separation of Generation and Transmission businesses after privatization, to dash for gas then for wind and finally the renewable obligations challenges, National Grid in the UK has worked closely with key stakeholders to ensure the transmission Licence obligations are met.
• Be transparent and share concerns with relevant stakeholders in a timely manner to seek collective resolution options
• Developing financial incentives to reward service providers
10/15/2015WH PSCL 5
Frequency Control Issues
• Frequency control requirements• Nominal level: 50Hz
• Statutory limits: +/- 0.5 Hz
• Operational limits: +/- 0.2 Hz (standard deviations 0.07 Hz)
• Cover instant generation loss was up to 1320MW
• Avoid automatic load disconnections • Above 48.8 Hz
• If triggered - could be up to 9 stages and 60% load disconnection
• System needs responsive and flexible plant
10/15/2015WH PSCL 6
Typical Frequency Incidents
49.20
49.30
49.40
49.50
49.60
49.70
49.80
49.90
50.00
50.10
12
:24
:00
12
:25
:00
12
:26
:00
12
:27
:00
12
:28
:00
12
:29
:00
Note:
On this occasion
Gas Turbines started
at 12:29:20
Primary Response 0 - 30 secs
Secondary Response 30 secs - 30 mins
freqcont.ppt 009 24/02/99
Frequency Control Analogy
Frequency Control/ Wheel Pulling Analogy
Generators Vehicles
Frequency Wheel speed
Demand level Slope gradient
Load variations Bumpy road
TV pickup Big rock
Largest generation loss Largest truck stalled
Blackout Wheel run away
Improve Frequency Service Provision after Privatization
• Define frequency services• Primary, Secondary and High Frequency Response services
• Establish payment mechanism
• Establish contract format
• Validate plant capability through dynamic plant testing
• On-line monitoring – gain confidence on service delivery
• Enhance Grid Code minimum technical requirements
• Liaise with main plant suppliers to improve plant/control design
• Collaborate with Generators to improve plant performance
10/15/2015WH PSCL 10
Primary & Secondary Responses
10s 30s 30 mintime
Fre
qu
ency
Ch
an
ge
(Hz)
Pla
nt
Res
po
nse
(M
W)
P S
-0.5 Hz
High Frequency Response
Fre
qu
ency
Ch
an
ge
(Hz)
Pla
nt
Res
po
nse
(M
W)
+0.5 Hz
H
10s time
Frequency Response Contract Format
On-line Monitoring
• Feedback to System Operator
Confirm contracted level of delivery
Improve confidence level in service despatch
Optimise frequency response service cost
• Feedback to Generators
Improve plant performance, if required
Increase incentive for plant control improvement
Gain confidence level in service delivery
• Evidence to support frequency incident investigations
On-line Monitoring - Example 1
On-line Monitoring - Example 2Coal Station 4, 28-Aug-2003
400
410
420
430
440
450
460
470
480
490
17
:05
:00
17
:06
:00
17
:07
:00
17
:08
:00
17
:09
:00
17
:10
:00
17
:11
:00
17
:12
:00
17
:13
:00
17
:14
:00
17
:15
:00
17
:16
:00
17
:17
:00
17
:18
:00
17
:19
:00
17
:20
:00
17
:21
:00
17
:22
:00
17
:23
:00
17
:24
:00
17
:25
:00
17
:26
:00
17
:27
:00
17
:28
:00
17
:29
:00
17
:30
:00
17
:31
:00
17
:32
:00
17
:33
:00
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:34
:00
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:35
:00
17
:36
:00
17
:37
:00
17
:38
:00
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:39
:00
17
:40
:00
17
:41
:00
17
:42
:00
17
:43
:00
17
:44
:00
TIME (GMT)
GE
NS
ET
AC
TIV
E P
OW
ER
OU
TP
UT
(M
W)
49.6
49.7
49.8
49.9
50
50.1
50.2
50.3
FR
EQ
UE
NC
Y (
Hz)
GENSET OUTPUT CAPPED COMMITTED LEVEL (MW) EXPECTED RESPONSE (MW) FREQUENCY TARGET FREQ
Low Frequency Automatic Demand Disconnection Incident - 27th May 2008
England ‘v’ Sweden (20th June 2006, 8pm)
TV Pick-up – Football World Cup
TV Pick Ups met using combination of coal plant,
French Interconnector & pump storage hydro
Half Time
1800MW
Full Time
1600MW
Demand 20 June 2006
England vs Sweden
36000
36500
37000
37500
38000
38500
39000
39500
19:5
0:00
19:5
2:00
19:5
4:00
19:5
6:00
19:5
8:00
20:0
0:00
20:0
2:00
20:0
4:00
20:0
6:00
20:0
8:00
20:1
0:00
20:1
2:00
20:1
4:00
20:1
6:00
20:1
8:00
20:2
0:00
20:2
2:00
20:2
4:00
20:2
6:00
20:2
8:00
20:3
0:00
20:3
2:00
20:3
4:00
20:3
6:00
20:3
8:00
20:4
0:00
20:4
2:00
20:4
4:00
20:4
6:00
20:4
8:00
20:5
0:00
20:5
2:00
20:5
4:00
20:5
6:00
20:5
8:00
21:0
0:00
21:0
2:00
21:0
4:00
21:0
6:00
21:0
8:00
21:1
0:00
21:1
2:00
21:1
4:00
21:1
6:00
21:1
8:00
21:2
0:00
21:2
2:00
21:2
4:00
21:2
6:00
21:2
8:00
21:3
0:00
21:3
2:00
21:3
4:00
21:3
6:00
21:3
8:00
21:4
0:00
21:4
2:00
21:4
4:00
21:4
6:00
21:4
8:00
21:5
0:00
21:5
2:00
21:5
4:00
21:5
6:00
21:5
8:00
22:0
0:00
Time (Local)
De
ma
nd
MW
20th June 2006 30th May 2006
Half time1800MW Full-time
1600MW
TV Pick-up – TV Soaps 25th April 2005
The more popular the TV programme, the larger the MW pick up
Dash for Gas
• CCGT were traditional designed for full load operation not for flexible operation
• The perception was CCGT could not provide frequency response… it would rack the turbine
• Offered service price were 8 times higher than conventional plant
• Falling power/ falling frequency issues
• Could CCGT be exempted for frequency response service? No but Why?
10/15/2015WH PSCL 20
Impact of poor response and inflexible plant on Grid operation
a) For responsive generators, five are required to cover the loss of one generator
60 60 60 6060
Generator Rating 5 x 100MW
Primary Response 4 x 15MW = 60MW
300 MW Load
Generator Rating 5 x 100MW
Primary Response 4 x 15MW = 60MW
Plant Response Capability/Flexibility - 15% Response Capability
Impact of poor response and inflexible plant on Grid operation
b) For less responsive generators, six are required to cover the loss of one generator
Generator Rating 6 x 100MW
Primary Response 5 x 10MW = 50MW
300 MWLoad
50 50 50 5050 50
Plant Response Capability/Flexibility - 10% Response Capability
Dash for Wind
• Traditionally wind turbines were distribution connected• Generally smaller size units
• Not designed for ridding through system fault disturbances
• ‘If in doubt, trip it out’ were the design concept
• The successful integration of large volume of wind farm connections to the Grid will require the review of wind turbine design by the manufacturers, eg• Fault ride through capability
• Frequency and voltage control capability
• DNO will have to strengthen the minimum technical requirement of their connected plants
10/15/2015WH PSCL 23
Stakeholders’ collaborations
• Visited major wind turbine manufacturers to clarify the minimum technical requirements for wind turbine connection to the system
• Made aware of the issues to the Industry in particular the Generation community
• Worked with DNOs to enhance their Technical Codes for connection of the smaller plant
• Campaign for minimizing the impact of small embedded generation on Transmission System performance had been a long and steady process
• First wake up call - The UCTE incident of splitting the European Network into 3 islands and pre-mature tripping of large volume of embedded plant had helped the campaign to drive home the message
• Second wake up call was in the UK where the frequency went down to 48.8 Hz leading to automatic demand disconnections. Large volume of embedded generation was lost due to weakness in the Distribution Code.
• The above had helped in strengthening the Distribution Code to ensure small embedded plants are resilience to system disturbances
10/15/2015WH PSCL 24
Drivers for Renewable Obligations
Greenhouse gas emissions - reduce by at least 80% below an agreed 1990 baseline by 2050
UK Energy Landscape is Changing
A balance of energy trilemma of security of supply, affordability and sustainability
The Network Challenge: Electricity Transmission
Gas CCGT Coal CCS
Nuclear Wind Renewable
Interconnector CHP Other
2010
2020
~75GW
~110GW
The Changing Generation Mix
0
5
10
15
20
25
30
35
40
GW
Gas
Coal
CCS
Wind
Other R
enewable
Nuclear
Interconnectors
Total Connected Generation (GW)
2010 2020 2030 2050
2020:
28GW of wind plus 9GW of
hydro, tidal, biomass
11GW nuclear available post
2.5GW of closures and 3GW
new build
Demand remains flat - growth is
offset by energy efficiency and
smart metering
15 GW of embedded generation
2050:
30GW of nuclear now provides
majority of baseload generation
Increased demand with
electrification of
Transport (mainly during
2030s)
Heat (growth from 2020)
Further Frequency Control Challenges
• Closure of flexible and responsive plant (eg conventional coal, gas and oil stations)
• New plants are less flexibility and less responsive (eg clean coal, supercritical boiler, IGCC, CCS, new nuclear)
• Domination of wind farms – intermittency issues
• Reduction of system inertia and increase of ROCOF risks – significant cost implications
• Secured generation loss – increased to 1800 from 1320 MW
• Significant increase of small embedded generation – less robust and invisible to System Operators
10/15/2015WH PSCL 29
Forecast of RoCoF up to 2020
GCRP WG
Traditional RoCoF protection setting of 0.125 Hz/s but proposed to change to 0.5 then 1 Hz/s
Transmission reinforcement alone is not sufficient …
..Meters
An informative
display showing
energy utilisation
and cost
Increases consumers’
sensitivity to energy prices
and thus reduces demand.
..Grids
Automation and
efficient use of
network systems
Facilitates network flexibility
in a complex generation
pattern
..Demand
Automation of loads in
industrial plants,
commercial buildings,
superstores and home
Facilitates demand side
response in a world of more
inflexible generation
Flexing generation to
meet demand
Flexing demand to
meet generation
Maximising capacity with smart..
Smart Demand meets Smart Grid Objectives
Dynamic Demand and Active Demand Side Management
Smart Grid = Paradigm shift in providing flexibility
From redundancy in assets
to more intelligent operation
through incorporation of
demand side and advanced
network technologies in
support of real time grid
management
Source-HiDEF
Electrification of Transport and Heat Pump Sectors
Value of Smart Demand – equivalent to a saving of almost 40GW of installed generation capacity
Source-HiDEF
Smart Fridges/Freezers – Displacing Power Stations
Wind penetration
Cost savings £/FF/10yr
CO2 savings kg/FF/yr
Low High
10-30
30-5015-30
40-90
Source-HiDEF
…Smart Fridges/Freezers – could help to limit frequency fall
Source-RLTec
Active Demand Side Management –Offset Wind Intermittency
Water
HeaterHVAC
Generation flexibility
Cost savings £/kW/10yr
CO2 savings kg/kW/yr
High Low
3-15
100-250<50
75-100
Source-HiDEF
Widen Downstream Stakeholder Engagement
• The growth of Demand Side Response (DSR) has been slow for years and potential service providers were not forthcoming
• The recent campaign led by the Grid Company is to provide greater clarity
• Hopefully, the raise of profile in the DSR communities will ensure DSR is a long term investment proposition
10/15/2015WH PSCL 37
10/15/2015WH PSCL 38
Generating
Companies
Distributors
Transmission
Companies
Suppliers
Future Electricity Supply Industry
How to meet these challenges in the most economic and
sustainable way whilst maintaining security of supply?
Active Distribution
Networks
Smart Grids
& meters
GenerationDemand
Variable generation
Variable generation
Synthetic inertia
Distributed generation
ROCOF &
Robustness
issues
Active Demand
30
35
40
45
50
55
60
00
:00
01
:00
02
:00
03
:00
04
:00
05
:00
06
:00
07
:00
08
:00
09
:00
10
:00
11
:00
12
:00
13
:00
14
:00
15
:00
16
:00
17
:00
18
:00
19
:00
20
:00
21
:00
22
:00
23
:00
Time of Day
Ele
ctr
icit
y D
em
an
d (
GW
)
2020 Demand ~ 15GWh (daily) - 1.5million vehicles
Typical winter dailydemand
Pe
ak
Co
mm
uti
ng
Tim
e
12,000 miles p.a.
Pe
ak
Co
mm
uti
ng
Tim
e
Optimal Charging
Period
Time of use
tariffs
Inflexible generation
Variable generation
Large generation
1800MW loss risk
Operating the System in 2020
New Technology - to Make It Happen
All this has been used elsewhere, but not together in a densely meshed network
New technology is required to evolve the Transmission network and enable
renewable generation
VSC Technology is still developing
2-3 year lead times for the larger cables
Multi terminal HVDC has very limited operational
experience
Control system optimisation
Sub-synchronous torsional interaction (SSTI)
HVDC
Wide area monitoring to control power flows
Dynamic circuit rating to manage constraints
Special protection schemes to facilitate additional
generation
Automated control to manage complex networks
Congestion management control
Opportunities to implement demand side
management
Smart Tools
Review of protection settings
Sub-synchronous resonance (SSR)
Employed to control stability
Series capacitors
What is a Smart Grid?
Two way communication - Sensing, automation and control
Self Healing and resilient
Asset optimisation
Active power flow management
Integration of renewable and distributed energy
More reliable, more efficient networks
Customer Focused
Tools to engage consumers
with energy efficiency
Network Focused
Integration of new sources
of supply & demand
Smart meters
Improved information and awareness
New energy services and tariffs
Home automation & Demand response solutions
More engaged, more efficient consumption
Taking Stock
• The Grid Company has been successful in providing leadership to the industry to improve frequency response services from all generating plant types including HVDC interconnectors
• The success has been the effective communications with developer and their plant suppliers to ensure their early understanding of system needs and their potential market opportunities.
• Future successes will rely on continual close collaboration within the industry to seek resolution to any identified problems within the legal, regulatory and commercial framework
The Way Forward
• Future of energy for the UK has never been so important and exciting
• The Electricity Market Reform (ERM), environmental legislation, energy costs and developments in the economy will have a major impact on the future energy landscape
• Future Energy Scenarios (FES) forum led by the Grid Company represent transparent, holistic paths through that uncertain landscape to help the Government, the customers and other stakeholders make informed decisions
• Base upon the energy trilemma of security of supply, affordability and sustainability, FES helps to identify system performance requirements and operational challenges and agree operational solutions and opportunities with key stakeholders via the System Operability Framework (SOF) forum.