Smart Grid: Implementation, Challenges & Way Forward · KUMUD WADHWA Sr. General Manager National...
Transcript of Smart Grid: Implementation, Challenges & Way Forward · KUMUD WADHWA Sr. General Manager National...
Smart Grid: Implementation, Challenges & Way Forward
Presented By:-
KUMUD WADHWA
Sr. General Manager
National Smart Grid Mission-PMU
Ministry of Power, GoI
Website: www.nsgm.gov.in 1
Smart Grid Maturity Model
Measured
Estimated
Automated
Manual
Widespread
Limited
L-5
L-4
L-3
Information Processes Communications
OptimizeAnalyze
CommunicateMonitorMeasure
Customer Operation Grid Operation Work and Asset
Management
OptimizeAnalyze
CommunicateMonitorMeasure
OptimizeAnalyze
CommunicateMonitorMeasure
Cross Domain Integration and Optimization
Innovation and Optimization along the Supply Chain
Intr
a-D
om
ain
O
pti
miz
atio
nD
om
ain
In
fras
tru
ctu
re
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Radial feeder without backup and manual fault location identification, rectification and
system restoration
Fault location detection through FPI
With the use of RMUs, switches
Real-time analysis & control of systems with FLISR
Smartness is Step-by-Step & Continuous
Un-measured
Measured
Smart
IntegratedWith the use of AMI, OMS, PQM,PLM, GIS,SCADA
Managed
Technology Evolution
Automated system, Much time saved, one section affected till fault rectification, other section till isolation of fault
Restoration can be faster with analysis and AMI
Whole system affected till fault rectificationmuch delay in Restoration
Fault location identification is fasterWhole network affected from fault
Reliability of system improve with alternate sources of supply
Appropriate use of
network flexible devices, sensors,
networking of above and analysing
software make system Smart
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4
Smart Grid Vision For India
“Transform the Indian power sector into a
secure, adaptive, sustainable and digitally
enabled ecosystem that provides reliable
and quality energy for all with active
participation of stakeholders”
Evolving Power Sector
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Challenges of EV Proliferation
Increase in Harmonics
Managing Mobile Load
Managing Charging Infrastructure
Controlled charging requirements to manage peak load
Performance Expectations
• Utility to Consumer
• Consumer to Utility
• 3rd Parties to Utility
• Utility to 3rd Parties
Prosumer Enablement
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Public Charging Stations
Type Connectors Rated Voltage (V)No. of points/connector
Guns (CG)
Fast
CCS (min. 50 kW) 200-1000 1/1
CHAdeMO (min. 50 kW) 200-1000 1/1
Type-2 AC (min. 22 kW) 380-480 1/1
Moderate / SlowBharat DC-001 (15 kW) 72-200 1/1
Bharat AC-001 (10 kW) 230 3/3 of 3.3 kW each
MoP Guidelines for Charging Station➢ Transformer with all related equipment including safety➢ 33/11 kV cables with metering➢ Civil works and adequate space for parking, entry and exits➢ Adoption of international standards as well as Indian standards (published by BIS)➢ Tie up with online network service providers (NSP) to enable advanced/remote booking with geo
tagging, types and availability information➢ Minimum charging points shall be installed as per below table
Each Charging station need to provide connected load of minimum 150 Kw and acharging station may be required after every 2-3 kms. 7
Challenges of RE Integration
Economic, Policy, and Regulatory Challenges
• Capital-intensive grid upgrades
• Uncertain RE project costs and cash flows
• Commercial impediments to real power balancing such as UI prices
• Generation planning with adequate share of flexible generation to respond to system variability
Technical Challenges
• Managing variability and uncertainty during the continuous balancing of the system
• Balancing supply and demand during generation scarcity and surplus situations.
• Voltage management due to heavy reactive power draw by RE generators
• Sudden ingress or withdrawal of RE from grid require tertiary resources with quick ramp-up rates for balancing
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RTPV: Technical Issues and Challenges
Issues at MV and LT level:
1. Voltage rise: If the generation from PV resources are high enough to offset the loads on the feeder, the surplus power will create voltage rise. With cluster-based installation of PV, the voltage rise impact may propagate to upstream MV network.
2. Effect of clouds: PV output ramps up and down at high rates as per the irradiation level. At certain locations, voltage at inverter end may exceed beyond a certain limit, which may cause undesirable tripping
3. High neutral current: Unbalanced allocation of PV units can create a high neutral current, particularly in the mid-day, when reverse power flow is at the peak level.
4. Lower power Factor: Along with PV generation, reactive power compensation or power factor improvement is needed.
5. Variation of feeder power loss: Power loss may vary due to the variation of PV output throughout the day.
6. Voltage Unbalance: As the allocation of inverters of a feeder are varied by the category of customers, the distribution of PV generation may not be equal at all the phases.
7. Change in tap operations: Voltage rise caused by PV clusters may require the regulators to operate during midday to keep the voltage profile below the upper limit
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Discom Business challenges
“With an average load of 1 KW per household and average use for eight hours a day, an additional 28,000 MW would be needed every year to meet the demand created under Saubhagya ”
Increase in technical losses due to expansion of network, consumers mostly subsidised and with lesser revenue realisation rate. Billing Challenges.
Delhi’s peak power demand during the summers of 2019 around 7400 MW.
Penalty/ incentive for harmonics. Draft amendment proposes that the utilities should record and report in public the data pertaining to harmonics, voltage sag, and swells and disruptions on a monthly basis
5,595 electric buses for 64 cities under the FAME India scheme's second phase. Charging load of Tesla may range from 120kW to 10kW with charging time of 0.5 hrs vs 9hrs for 426 km run
Stranded and Under Utilised assets. Higher capex resulting into tariff hike and operational inefficiency
Proposal to pay damages to consumers in case of load shedding
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Discom Business challenges“Distributed Generation like Solar Roof Top : Loss of subsidizing consumers and cross subsidy, tariff hike of poor .
Cumulative DISCOM losses may touch pre –UDAY level figure of 2.8 lakh crore
MNRE directive to ensure ‘must run’ status to both wind and power projects in line with the Indian Electricity Grid Code 2010and the Electricity Act 2003.
Now mandatory for DISCOMs to open and maintain enough Letters of Credit as the payment security mechanism under power purchase agreements.
CERC proposes for 100% power sale in spot market
Challenges of Power Planning and Scheduling. If enough power not contracted then can not supply 24*7 or else stranded assets
Supply and Network Business Separation
Prosumer Enablement
Mobile Load Management
16/Aug/19 Presented By:- Kumud Wadhwa, Sr. GM(NPMU) 11
Flexibility Needs for System
Flexibility for Power
Flexibility for Energy
Flexibility for Transfer Capacity
Flexibility for Voltage
SMART GRID by adopting Information and Communications Technology to facilitate bidirectional flow of Energy and Information for flexibility needs.
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Smart Grid Solutions System Balancing
Better forecasting
• Widespread instrumentation and advanced computer models allow system operators to better predict and manage RE variability and uncertainty.
Smart inverters
• Inverters and other power electronics can provide control to system operators, as well as to automatically provide some level of grid support.
Demand response
• Smart meters, coupled with intelligent appliances and even industrial scale loads, can allow demand-side contributions to balancing.
Integrated storage
• Storage can help to smooth short-term variations in RE output, as well as to manage mismatches in supply and demand.
Real-time system
awareness
• Sensors across networks allows system operators to have real-time awareness of system conditions, and the ability to actively manage grid behavior.
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Top-5 Ranked Technologies for SG Drivers
Source: ISGAN Annex-2 Survey from 19 participants
0 5 10 15 20 25 30 35
Systemefficiencyimprovements
Reliabilityimprovements
RE standards ortargets
Enabling customer choice andparticipation
Enabling newproducts,services, andmarkets
Reducingoperating and maintenance costs
Advanced metering infrastructure (AMI)Distributed energy resources integration
Smart network management for coordinated transmissionInformation and communications technology
Renewables energy sources integration
Fault detection, identification, and restoration (FDIR)Distribution management systems and outage management
Distributed energy resources integrationAdvanced metering infrastructure (AMI)
Smart network management for coordinated transmission
Renewables energy sources integrationWind
Distributed energy resources integrationSolar photovoltaic and solar thermal energy
Hydro power
Advanced metering infrastructure (AMI)Smart homes
Information and communications technologyDistributed energy resources integration
Distribution management systems and outage management
Advanced metering infrastructure (AMI)Smart homes
Information and communications technologyDistributed energy resources integration
Building energy management and automation
Condition-based monitoring and maintenanceDistribution management systems and outage management…
Advanced metering infrastructure (AMI)Information and communications technology
Distribution feeder circuit automation
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Smart Grid Pilot Projects
11 pilots including SGKC
1.56 lakh Smart Meters installed out of 1.66 lakh envisaged
10 out of 11 pilots declared go-live / completed / commercially operated
Remaining 1 pilot nearing completion
Completed / Declared Go-Live / Commercially OperatedNearing CompletionMap not-to-scale
Guwahati, AS
(APDCL)
Jeedimetla, TS
(TSSPDCL)
Kala Amb, HP
(HPSEB)
Panipat, HR
(UHBVN)
Manesar, SGKC
(POWERGRID)
IIT Kanpur
(IITK)
Siliguri, WB
(WBSEDCL)
Agartala, TR
(TSECL)
Puducherry, PY
(PED)
Mysore, KA
(CESC)
Naroda, GJ
(UGVCL)
N
➢ New generation communication technology with improved performance based on RF mesh developed as an evolution of Technology deployed at CESC, Mysore
➢ PLC technology performed well in Tripura SG Pilot➢ Two new product (Smart Meter) developed & deployed
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Smart Meter: Benefit Analysis
• Meter Readers (third party*) walk from
house to house to capture meter data.
• Manual Punching of meter data by
employees
• Field visits required to verify if meter is
functioning correctly/ damaged
• Manual visits for meter disconnection/
reconnection
• Send interval data directly to the utility
and hence eliminating most of manual
meter reading and punching labor costs
• Real-time remote diagnostic to determine if
meter is operating normally. If meter
receiving voltage, no field personnel
required to investigate
• Enable auto disconnect/ reconnect
Current Operations Smart Meter OperationsK
ey B
en
efi
ts
Meter
Reads
Meter
Operations
Billing
• Overall Billing cycle takes around 15-
20 days
• Average or provisional billing for cases
of meter failure or inaccessible
consumer
• Billing cycle to reduce by 11 days
• No cases of average billing
• Estimated and done at sub-
division/sub-station level/feeder level
• Enable near real time energy accounting
at Feeder and DT level. Energy
Accounting
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Smart Meter: Benefit Analysis
• Current meters do not offer
capabilities to detect
tampering (mis-wired or
bypassed meters)
Generate tampering alarms and
monitored meter data to identify
theft.
Current Operations Smart Meter OperationsK
ey B
en
efi
ts
Power Theft
• Large no. of complaints
related to meter reading and
billing
• Revenue department involved
in both recovery and
grievance redressal
Enable reduction in consumer
complaints on bill, meter failures
and outages and hence reducing
cost for grievance redressal
Grievance
Redressal
• Lack of accurate records on
sanctioned load
• Sizing of DT based on
estimates
• Reduced Distribution Transformer
Failure
• With monitoring of sanctioned load
use and utilization of DT, optimized
transformer load planning can be
undertaken
Load
Management
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Technology Readiness Level (TRL)
AMI
TRL 9
System proven in operational environment
TRL 8
System complete and qualified
TRL 7
Integrated pilot system demonstrated
TRL 6
Prototype system verified
TRL 5
Laboratory testing of integrated system
TRL 4
Laboratory testing of prototype component or process
TRL 3
Critical function, proof of concept established
TRL 2
Technology concept and/or applicationformulated
TRL 1
Basic principles are observed and reported
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TRL for smart grid drivers
AMI
Revenue Efficiency Improvement
Reliability Improvement
Reducing O&M Cost
Enabling New Products, Research & Market
Enabling Customer Choice & Participation
{
{
TRL 9
System proven in operational environment
TRL 8
System complete and qualified
TRL 7
Integrated pilot system demonstrated
TRL 6
Prototype system verified
TRL 5
Laboratory testing of integrated system
TRL 4
Laboratory testing of prototype component or process
TRL 3
Critical function, proof of concept established
TRL 2
Technology concept and/or applicationformulated
TRL 1
Basic principles are observed and reported
National Smart Grid Mission
NSGM has been established vide MoP dtd 27th Mar 2015 and Extended till Mar 2020 vide OM dtd 7th May 2018 (Total Outlay 990 Crore with GBS of 312 Crore) with institutional framework as below:
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Bilingual websitehttps://www.nsgm.gov.in
Governing CouncilChair – Minister of Power
Convenor – AS (Tx) *
Empowered CommitteeChair – Secretary (Power)
Convenor – AS (Tx)*
NSGM Project Management Unit
Head – Director NPMU
State Level Project Management Unit
Chair – Energy Secretary (State)
Utility Smart Grid CellsSmart Grid Knowledge
Centre (SGKC)
Technical CommitteeChair – Chairperson, CEAMem. Secy. – Dir. NPMU
Mission Update - Achievements
• Five projects sanctioned (₹686.6 Cr.) for ~7.50 lakh consumers. 2 projects under approval and 2 projects in pipeline
• Smart Grid Readiness – Self Assessment Tool (SGR-SAT)
• Smart Meter Rollout plan submitted
• Impact assessment of Pilot projects done by QCI
PROJECT PLANNING
AND MONITORING UNIT (PPMU)
• 9 National & 3 International workshops
• SG Course Developed
• 11 Training programs for utilities (320 utility engineers/professionals)
• Bilingual website
• Regular participation in ISGAN and Mission Innovation
CAPACITY BUILDING AND COMMUNICATI
ONS UNIT (CBCU)
• IS 16444 (Part 1 & 2) and IS 15959 (Part 2 & 3)
• Model Smart Grid Regulations
• NSGM Framework, Model RfP & Model DPR
• Active participation in LITD 10, LITD 28 and ETD 13
TECHNOLOGY AND
STANDARDS UNIT (TSU)
• AMI use cases developed
• Workshop on cloud infrastructure & interoperability in association with TSDSI
• NSGM website enforced with HTTPS
INFORMATION AND CYBER
SECURITY UNIT (ICSU)
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• Training MoUs with
• CPRI, Bangalore
• NPTI, Faridabad
• SLPMU meetings held /Proposed
• 5 out of 19 SLPMU
• SLPMU formed for
• 19 out of 37 states /UTs
• Plug & play/ Modular Communication Module
• Standardization of Sub-Ghz RF profile
• Cloud infrastructure’s interoperability
• Projects Worth Rs.800 Crs. pending -lack of funds-
✓ Agartala (TSECL), Naroda (UGVCL), Mumbai (Tata Power), Mysore (CESC), Chennai (TANGEDCO)
• High (70%) counterpart funding
• Microgrid relevance w.r.t. Grid extension
• Distributed Renewable energy source penetration- Circle wise
• Reliability improvement (Circle/feeder/DT/Discom)
• DR relevance in supply sufficiency.
NPMU Challenges
PROJECT PLANNING
AND MONITORING UNIT (PPMU)
CAPACITY BUILDING
AND COMMUNICATIONS UNIT
(CBCU)
TECHNOLOGY AND
STANDARDS UNIT (TSU)
INFORMATION AND CYBER
SECURITY UNIT (ICSU)
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Smart Grid – Role of Regulators
• Smart Grids cannot evolve without dynamic,
flexible regulation (“Enabling”)
• Regulator will be a facilitator to smart grids
business (“Catalyst”)
• Discoms need to demonstrate clear positive
benefits to consumers (“Business Case”)
• Regulators more than ever need to protect the
interests of the consumers (“Avoid Tariff
Shocks”) and (“Data and Privacy Protection”)
Investment Approval Recovery through Tariff
Promoting end use Providing Incentives
Delivering policy objectives.
Ensuring value and protection to customers
INVESTMENT
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AMI: Service Model
Smart Grid ServicesPROJECT For 5.5 lac consumers
Monthly Fixed Charges Base Cost (@4900)
1.0. Project Cost '(Grant+Utility fund 50%, SGIA Equity 50%) 269.9
SGIA Investment 135
2.0. Fixed Charges
2.1.O & M Charges (@ 7.5 %)
(In line with ULDC practice)20.25
2.2 Depreciation (@12.86 %)(For Repayment of SGIA Investment) 17.36
Considering Project Lifecycle-7 years
2.3 Return on SGIA Equity @12% 16.2
2.4 Interest on Domestic Loan @10.5 % 0
2.5 Interest on Working Capital @ 12.8 %
a) on 2 months receivables 1.15
b) O & M (1 month) 0.22
c) Maintenance spares @ 15% of O& M expenses 0.39
Total Annual Fixed Charges 55.55
3.0. Monthly Fixed Charges (for Base Cost) 4.63
AIA to be paid Rs/month/consumer for 7yrs 84
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AMI: Service Model
• Consumers- 5.5 lacs
• Energy Input- 3500MU
AT&C ReductionY15 %
Y22%
Y31%
Y41%
Y51%
Y61%
Y71%
Revenue projections
(business as usual
scenario) (Rs. Cr.)
2081 2194 2285 2381 2480 2583 2660
Increased Revenue for
Utility due to Smart AMI
(Rs. Cr.)
82 135 165 196 230 265 273• Present Revenue -1941 Cr
• AT&C losses- 20%
26.45
79.45109.45
140.45174.45
209.45217.45
0
50
100
150
200
250
Y1 Y2 Y3 Y4 Y5 Y6 Y7
Net Revenue for Utility YoY (Rs. Cr.)
• Profitable from the first year of operations
• Overall net revenue of Rs. 957 Cr. over 7 years for the utility
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Funding Mechanism-Investment Business Model
Smart Meter Comms Collector/DCU HES MDM
Input Power Mgt : High charge agreement at Peak
Demand Response : Asses Stress
Analytics
Data Reading
1Data Transportation
2Data acquisition & Control
3Data Analytics
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AT & C Loss/min 20%
Outage – Opportunity loss
High Revenue Customer Satisfaction : DG free/Customer engagement : opportunity loss Electric Vehicle
Mo
del
System Level SLA : L+G
MAP/MSP
Capex Opex/endpoint/month
Capex Opex/endpoint/month
Return on Fixed Duration Capex
Capex – Investor based model
Capex Opex/endpoint/month Capex
Business Level SLA : TPDDL
DT Metering/DTMU : No of DT burn/year
Dri
vers
CSP DSP
Return on
NSGM fund 30% Utility fund 20% Investor 50%
Upfront money to SP Utility Benefits through Business case and reliability charge/unit to consumer
DER - Futuristic
Co
mp
on
ents
Act
ors
Plan → Build → Operate → Own
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Key Regulatory Considerations for Smart Grid ProjectsInvestment Cost Recovery – Specific Tariff Schemes and Designs
This recovery method involves introduction of specific schemes to incentivize users for promoting a particular application that is likelyto benefit the stakeholders
System operators such as PJM Interconnector USA publish Critical Peak Pricing (CPP) rates, (normally during times of stress for a period of 2 weeks and related to summer cooling load) that encourage downstream connected entities to reduce consumption during this time
Specific Tariff Scheme: CPP
RTP programs are offered by Ameren Illinois and ComEd in Illinois, USA where consumers pay electricity supply rates that vary by the hour. With Ameren's residential real-time pricing program, hourly prices for the next day are set the night before and can be communicated to consumers so they can determine the best time of day to use major appliances
Specific Tariff Scheme: RTP
Through a 3rd party service provider (EnerNoc), Midwest Energy in the US targets consumers with peak summer demand > 30kW. For accounts having 40hp motors at pumping sites there is no charge for participation and sites with a 25hp motor can participate by paying a $500 installation fee. For participation, Midwest Energy pays $20 per kW of interrupted capacity
EnerNoc Incentive Scheme
Source: http://www.enernoc.com/our-resources/case-studies/547-midwest-energy-grows-new-energy-supply-with-enernoc-agricultural-demand-response
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California Utility Electric Rate Plan Options
Tariff Plan Rate plan details Ways to save money and energy
Time-of-Use (Peak Pricing 4 -9 p.m. Every Day)
• It includes a baseline credit that offers residential customers a price discount for usage below their baseline allowance.
• This rate offers bill protection for the first year.
• Save money by reducing energy use within the lower-priced tier (baseline allowance).
• Shift usage to the least expensive hours: before 4 p.m. and after 9 p.m. every day.
Time-of-Use (Peak Pricing 4 -9 p.m. Weekdays) E-TOU-B
• This rate plan has no pricing tiers or baseline allowance.• Prices vary based on time of day, day of the week, and the
season.
• Reduce your energy usage overall. • Shift usage to the least expensive hours: Mon-Fri or any
time on weekends and most holidays.
Time-of-Use (Peak Pricing 3 -8 p.m. Weekdays) E-TOU-A
• This rate plan’s prices vary based on the time of day electricity is used, day of the week, and the season.
• It includes a baseline credit that offers residential customers a price discount for usage below their baseline allowance
• Save money by reducing energy use within the lower-priced tier (baseline allowance).
• Shift more usage to the least expensive hours: before 3 p.m. and after 8 p.m. Mon-Fri or any time on weekends and most holidays.
Tiered Rate Plan E-1• This rate plan has multiple pricing levels, known as tiers.• After exhausting allotted electricity quota for each tier within
a billing period, you move to the next, higher priced tier.
• You can save money each month by using less electricity and avoiding the higher-priced tier. Prices do not vary throughout the day.
Home Charging EV2-A (Non-tiered, Time-of-Use)
• One meter is used for both EV/battery charging and home energy use. The price for usage varies depending on the time of day.
• Save money by charging your EV during off-peak hours.• Consider shifting other household energy use to less
expensive, off-peak hours, especially 12 a.m. to 3 p.m.
EV-B (Non-tiered, Time-of-Use)
• Involves installing a second (separate) electric meter for charging your EV.
• The price you pay for vehicle charging is based on the time of day, and day of the week.
• Save money by charging your EV at night during offpeak hours, especially after 11 p.m. on weekdays and after 7 p.m. on weekends and holidays.
Electricity Vending System (EVS) – A Singapore Case Study
Siemens Power
Automation
Feasibility study found that-
• System will pay off within 3 years by reducing the operational costs and bad debts.
• It will bring benefits to end consumers who will enjoy lower tariffs bills due to competition, choice of TOU
packages and usage pattern changes.
- EMA guarantee to pay anyone the difference if they actually pay more over the period of the trial by
participating in the EVS pilot.
• Pre-Trial Run :
Collect readings for post payment from two months to SP Services Billing system
• Actual Trial Run :
✓ Prepayment option only
✓ 3 pseudo retailers
• 455 EVS meters:
– 206 Volunteers
– 229 Repeaters (mesh)
– 5 Concentrators• Survey Findings
– For the same period of time, the volunteers’ consumption were found to rise less than the national average (Less by 2% overall consumption)
– Load Shifting, Load Saving – Awareness of Usage (Shift of load of 10% from peak to off peak)
• Total number of Purchases
Number of Purchases Made
Number of
purchases
Total Purchase
Count
No. of customers who purchased once 17 17
No. of customers who purchased twice 20 40
No. of customers who purchased three times 64 192
No. of customers who purchased four times 61 244
No. of customers who purchased five times 18 90
No. of customers who purchased six times 11 66
No. of customers who purchased seven times 4 28
No. of customers who purchased eight times 5 40
No. of customers who purchased nine times 4 36
No. of customers who purchased eleven times 1 11
No. of customers who purchased twelve times 1 12
Total 206 776
Quick statistics of the Trial Run (1)
Siemens Power
Automation
Singapore Open Electricity Market
Inherent Features
• Singapore Power Group (SPG) continues to operate and maintain the power grid, while providing market support services such as billing and meter reading
• SP Group is paid for these network costs and market support services that are reviewed annually and regulated by the EMA
• Opting for a different provider will not affect supply reliability
• Even as retailers leave the Open Electricity Market, there will be no power disruptions
• Provision for comparison website that will be updated with the latest price plans
• Retailers are required to safeguard each household’s security deposits, and are banned from making unsolicited calls, messages or door-to-door visits.
Open Market Insight
• Pilot test of the Open Electricity Market began in Jurongon 1st Apr’18- Homeowners were given an option for the first time for switching supplier.
• For five months, more than 30% of consumers switched to different provider, with savings of about 20%
• Energy Market Authority (EMA) announced nationwide roll-out of the Open Electricity Market in Sep’18
• The agency surveyed 400 people that have switched retailers; about 80% agreed that the initiative has its benefits such as competitive pricing and innovative offers.
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Demand Response in India
Demand Side Management and Demand Response programs aim to influence power consumption by active engagement with end consumers.
NPMU is co-leading Demand Response PoW under Mission Innovation Smart Grid Agenda in association with DST.
NPMU engaged with PWC on behalf of British High Commission office under DFID to scoping study on Demand side management and Smart Grids
Tariffs based on Fixed timing (ToD) may not serve the purpose in the city like Delhi where summer peaks are mainly due to residential air-conditioning loads. (Load at 3.00AM > 8.00 PM)However, in Punjab mainly due to agricultural load the gap between peak and off peak loads is reduced by adopting ToD tariff.
It is desirable that regional / locational dynamic tariffs for Demand Response may be adopted by the utilities.
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Demand Response for Flexibility
✓The current pricing mechanism does not provide appropriate signal to end consumer forjudicious use of electricity.
✓If we add some price component to existing tariff that could reflect the real time imbalances,the end consumers may shift their load to get some incentive or to avoid disincentives.
✓In various pilot smart grid projects in the US, participating customers were guaranteed aneutral bill impact from participation.
✓As per survey data, there is probability that consumers will shift/ reduce their loads whenToU tariff is high during the day (and/or if there is a discount at night).
✓Polling commissioned by The Australia Institute in September 2017 found that two-thirds ofAustralians would prefer to see peak demand managed through demand response rather thanbuilding new generators and higher capacity networks.”
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Regulatory Sandbox: DR Case Study
BSES Yamuna
• BSES Yamuna implemented DRprogram to manage its peak loadand maintaining tie- line schedule.
• Overall, 9-15 consumersparticipated in each event,
• Resulted in demand savings of0.89 to 3.45 MW per event.
• Maximum reduction provided bymanufacturing units, followed byhotels, malls, hospitals, and others
Tata Power, Delhi
• Participation - 161 customers >100 kW (cold storage, commercial,education, flour mill, hospital,industrial, pumping, retail.
• 17 DR events for 30 to 60 minuteseach in the summer of 2014
• Achieved max shed potential of7.2 MVA with a cumulative savingof 0.063 MUs.
• Max demand reduction rangedfrom 2% (for Education) to 28%(for Packaging).
Tata Power, Mumbai
• Tata power, Mumbaiimplemented both aggregatorbased and auto DR projects inMumbai at Malls, Hospitals, ITparks and Municipal sewagetreatment plants etc.
• Aggregator level DR was triggered21 times each for duration of 2hours.
• 15 MW curtailment achieved.
Delhi: Seasonal Variations in FY 2018-19
Apr'18 May'18 Jun'18 Jul'18 Aug'18 Sept'18 Oct'18 Nov'18 Dec'18 Jan'19 Feb'19 Mar'19
Max Peak Demand 4530 5283 5535 5842 5159 4948 4544 3660 3619 3657 6716 3577
Max Off Peak Demand 4387 5606 6062 5882 5134 4739 3773 2113 1664 1745 4257 2451
Min Peak Demand 3291 3528 3876 4107 3727 3857 2896 2499 2903 2548 4756 2074
Min Off Peak Demand 2598 3792 4412 3665 4138 2698 2048 1480 1435 1369 3463 1446
0
1000
2000
3000
4000
5000
6000
7000
8000
De
man
d in
MW
Max Peak Demand Max Off Peak Demand Min Peak Demand Min Off Peak Demand
Peak Time - 20:00 Hrs Off Peak Time -03:00 Hrs
Max difference b/w Peak & Off peak Demand: 1955 MW (Dec.)
23rd June
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Delhi: Load Curve for 23rd Jun’18
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EV Penetration & Typical Solar Rooftop Generation Profile
To assess the impact of EVs on the grid, BYPL selected afeeder by considering aspects like EV charging stations,Solar RT penetration in the feeder, feeder loading &voltage profile, DT loading, Consumer mix monthlyconsumption etc.
• Peak Load of the feeder is 4.5MW at 00.15 hrs. &corresponding EV Load is 152.71 kW.
• EV peak load of 257.02 kW at 20:30 hrs. & correspondingfeeder load is 2.99 MW (EV load is 8.6% of the feeder load)
• Total Energy consumed by feeder is 86.73 MWh including3.24 MWh by the connected EV loads (3.74% of feederdaily energy consumption) & 12.75 MWh Solar generation.
Observations:
• Impact of EV charging during rooftop PV generation isminimum or nil.
• Feeder can take up more EV Charging penetration duringPV generation.
• Additional PV load can be taken with PV generation byimplementing ToU.
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DR: Stakeholder Benefits
Stakeholder Benefit
Consumers • Financial incentive for participating in schemes• Provides focus on energy efficiency• Improved supply reliability (in the long term)• Reduced cost of power (in the long term)
DISCOM • Provides focus on load patterns and energy efficiency• Low cost/fast to deploy mechanism to balance supply and demand• Avoided cost in purchasing expensive power from wholesale market/short term contracts required to meet supply deficit• Deferral of asset investment for infrastructure required only to meet peak demand• Improved revenue due to avoidance of load shedding through better load management• Increased integration of RE resources into the grid
System Operators • Low cost/fast to deploy mechanism to provide ancillary services
Regulators • Provides an additional resource to help address power shortages• Demonstrates a move towards energy efficiency and greener solutions for meeting load requirements• Positive impact on cost of power to consumers as DISCOMs and system operators rely less on purchasing expensive power
Economy • Positive impact on cost of power to consumers as DISCOMs and system operators rely less on purchasing expensive power• Low cost/fast to deploy additional resource to help address power Shortages
Environment • Less dependence on thermal power required to manage balancing and regulation issues.• Deferral of asset investment for infrastructure required only to meet peak demand.• Increased RE penetration
Source: USAID Smart Grid Training Course Material
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DR and DSM
Way Forward – State Level PMUs
SLPMUs at 19 States/UTs:1. Andhra Pradesh2. Assam3. Chandigarh4. Chhattisgarh5. Delhi6. Haryana7. Himachal Pradesh8. Jammu & Kashmir9. Jharkhand10. Karnataka11. Kerala12. Maharashtra13. Odisha14. Puducherry15. Rajasthan16. Tamil Nadu17. Telangana18. Tripura19. West Bengal
Vision, goals and roadmap for the state Smart Grid activities
Develop program proposals & submit to NSGM
Evaluate program/project proposals from utilities
Work with SERCs to develop state regulations and policies
Adoption of Smart Grid standards
Monitor the impact of Smart Grid activities
Fun
ctio
ns
of
SLP
MU
Implementation & monitoring Smart Grid Projects
Process change based on learning
Adopting dynamic tariff
Consumer engagement initiatives / programs
Large scale rollout of smart metering
Coordinate among various schemes for sustainable outcomes
Funding for Smart Grid projects through innovative business models
Exp
ecta
tio
ns
fro
m S
LPM
U
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Tariff Design
45
Key Regulations, Legislation & Guidelines
Electricity Act 2003• Section 62(3) guides SERCs to incorporate ToD tariff:
• “The Appropriate Commission shall not, while determining the tariff under this Act, show undue preference to any consumer of electricity but may differentiate according to the consumer's load factor, power factor, voltage, total consumption of electricity during any specified period or the time at which the supply is required or the geographical position of any area, the nature of supply and the purpose for which the supply is required.” (Electricity Act, 2003, p.49)
46
Dynamic Tariff Option for DR
Components considered for tariff design
• Cost of generation and transmission
• Service cost of DISCOM
• Reactive power consumption
• Voltage level
• Sanctioned/contracted load
• Subsidy
• Unscheduled Interchange charges for deviation from agreed drawal and generation schedule
• ToD or pre-announced prices based on a forecast for peak load hours
• ToU/CPP that can be linked to cost price or to an average of daily maximum demand
• Power supply quality- based on voltage fluctuations, reliability and harmonics
Co
mp
on
ents
of
AR
RP
rop
ose
d
Innovation & StandardP
erf
orm
ance
Time
New S-Curve
Ferment
Takeoff
Maturity
Discontinuity
Standard development/ Modification
New Innovation
Standard development/ Modification
47
Regulatory Sandbox
Technology Development
Technology Integration
System Integration
Market Integration
48
49
Way Forward
Explore new/dynamic tariff options with flexibility for DISCOM to decide peak/off peak time and location
Consumer engagement thru tariff options for Demand Response
Consider ICT investment as an option while evaluating infrastructure CAPEX for short term needs
Engage with SLPMU and steer operational transformation
System generated Standard Reporting for KPIs including power quality parameters as notified by CEA in grid connectivity standards
Regulatory sandbox for new process/technology before including it as standard
Thank You
@NsgmIndiawww.nsgm.gov.in
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Smart Inverter
• “Smart Inverter” is a inverter that can contribute to grid support during excursions from
normal operating voltage and frequency conditions by providing:
• Dynamic reactive and real power support
• Voltage and frequency ride-through
• Ramp rate controls
• Communication systems with the ability to accept external commands from the electric utility.
• California and Hawaii have already begun deployment of smart inverter functionality
• IEEE 1547, IEEE1547.1, IEC 62109, IEC 62116 and IEEE 2030.5 are the standards for Smart
inverters.
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Grid Connectivity Standard (33kV & Above)
Parameters Limit Relevent Standards
Voltage and Current Harmonics - IEEE 519
Flicker - IEC 61000DC current Injection 0.50% -
Measuring and metering of harmonics Once in a year IEC 61000-4-30
Reactive Power Capability to maintain power factor at POI
±0.95 -
Frequency withstanding capability47.5 Hz - 52 Hz (rated power in the range
of 49.5 - 50.5Hz)-
Frequency Droop Control 3 to 6% (Dead band max ±0.03 Hz) -
Ramp Rate Control ±10% per minute -
HVRT
1.3 < V - Instant trip 1.3 ≥ V > 1.2 - 0.2 Sec 1.2 ≥ V > 1.1 - 2 Sec V ≤ 1.1 - Continuous
-
LVRT - -Short Circuit Ratio (SCR) not less that 5 at POI -
Grid Connectivity Standard DERs (Below 33 kV)
Parameters Limit Relevent StandardsHarmonic current injection - IEEE 519Flicker - IEC 61000DC current Injection 0.50%Measuring and metering of harmonics - IEC 61000-4-30
Safety -CEA (measures relating to safety & Electricity Supply) Regulation, 2010
Over and Under Voltage protection110% - 80% (clearing time upto 2
Sec)-
Over and Under Frequency protection50.5 Hz - 47.5 Hz (clearing time
upto 0.2 Sec)-
Capacity of Devices of DERs to withstand voltage limit 220% -
Voltage fluctuation at POI at the time of synchronization ±5% -
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