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USING DEMAND RESPONSE TO REDUCE DEMAND AND TOU ENERGY COSTS
Jim Belcher Demand Response Engineer UTA Conference October 24, 2012
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640Kb ought to be enough for anybody. Bill Gates, 1981 There is no reason anyone would want a computer in their home. Ken Olson , President, Chairman and founder of Digital Equipment Corp., 1977 I invented it, Bill made it famous.David Bradley (wrote the code for Ctrl-Alt-Delete on the IBM PC) I have traveled the length and breadth of this country and talked with the best people, and I can assure you that data processing is a fad that won't last out the year. Prentice Hall, editor in charge of business books, 1957
TVA Municipal 14,500 customers
• 305 miles distribution
• 46 customers/mile
• 72% Load Factor
• 70% sales industrial/commercial
Peaks: 167 MW Summer / 165 MW Winter Regional Water System (11 MGD)
• 12,281 Retail Customers
• UD Resale
Telecommunications – Triple Play • First Customer Connected in May 2006
• FTTH Network (5450 Customers)
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Service area
contiguous with
cooperatives
33.6 MW
15.4 MW 17.3 MW
15.3 MW
21.6 MW
Of 163.3 MW Total
Power - Industry makes up 70% of the
load!
10.6 MW
19.7 MW
3.9 MW
25.9 MW
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MUS MUS TVA Peak is not coincidental in
summer
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Modified TOU Wholesale Billing Structure 1) Demand Charges (Seasonal) [~20% of monthly bill]
• Highest 60 min average (top of hour) per month after removal of TDMSA, TDGSA, MSB/C/D customers.
2) TOU Energy Charge [~60% of monthly bill] • For Winter & Summer periods, ON/OFF peak energy is billed
after the removal of the rate schedules mentioned above during the same ON or OFF times.
• For Transitional periods, all is OFF peak billing. Above schedules subtracted.
So reducing the demand during the peak times will yield credit for both demand and energy.
1) TVA Called Demand Reduction per Smart Grid Pilot
• 24 hour notice with direct feedback to TVA required
• 100 hours per year maximum, 2 hours minimum per event
Voltage Reduction (6005 kW)
DLC devices included in this event (2000 kW)
Water load reduction included in this event (740 kW)
2) Demand Peak Control Monthly by MUS • Daily monitoring/control of monthly peak (kW)
• Control only at substations (no VR down line)
• Notification systems in place (Text, Email, SCADA, etc)
• Does not include DLC or Water (at this time)
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Month Date
MUS Billed
Peak
Total System
Peak
Max Temp
at Peak in
Fahrenheit
Demand
Reduction
by VR
Total Days
in VR
Total Hours
in VR
Peak Billed
Demand
(MW) from
TVA Power
Bill
Est. Demand
Reduction
off Billed
Peak
Apr 2011 Tuesday, April 26, 2011 101.11 126.144 81.6 5.02 7 26.5 101.110 4.02 $34,146
May 2011 Tuesday, May 31, 2011 120.01 145.272 93.9 5.78 8 35.5 120.009 4.78 $35,797
Jun 2011 Thursday, June 09, 2011 123.51 149.612 95.5 5.95 7 123.510 4.91 $40,540
July 2011 Wednesday, July 20, 2011 124.86 145.730 93.1 5.80 11 42.3 124.863 4.97 $36,547
Aug 2011 Monday, August 08, 2011 125.26 153.063 93.1 6.09 5 19.0 125.258 4.98 $43,839
Sep 2011 Thursday, September 01, 2011 120.56 147.792 93.6 5.88 1 2.5 120.564 4.80 $44,414
Oct 2011 Tuesday, October 18, 2011 95.87 120.836 79.8 4.81 6 27.5 95.873 3.82 $29,228
Nov 2011 Friday, November 18, 2011 102.57 129.480 25.0 5.27 5 17.5 102.566 3.72 $30,521
Dec 2011 Thursday, December 01, 2011 107.66 133.480 24.0 5.48 4 13.8 107.664 4.1 $34,146
Jan 2012 Wednesday, January 04, 2012 121.83 149.279 12.6 6.50 2 11.9 121.832 5.45 $46,363
Feb 2012 Did not Curtail (TVA Data) 117.80 146.420 17.6 117.800 5.13 $0
Mar 2012 Tuesday, March 06, 2012 101.04 135.740 23.0 5.49 2 4.6 100.496 3.80 $27,672
Apr 2012 Monday, April 30, 2012 101.57 131.162 85.0 6.22 4 14.8 101.568 4.35 $36,678
May 2012 Tuesday, May 29, 2012 112.55 141.670 76.0 6.50 5 17.0 112.546 5.04 $42,484
June 2012 Friday, June 29, 2012 120.11 147.740 101.5 6.08 13 50.0 120.109 5.03 $40,843
July 2012 Thursday, July 26, 2012 124.56 152.910 96.0 6.08 10 35.9 124.560 5.44 $47,213
Aug 2012 Wednesday, August 08, 2012 118.01 144.100 94.0 5.67 6 16.9 118.006 4.79 $43,961
Sep 2012 Wednesday, September 05, 2012 113.83 140.370 93.0 5.91 3 12.0 113.833 4.83 $44,466
Averages 5.80 5.8 21.7 Total Savings to date= $658,859
MW Days Hours Per month= $38,756
SCADA Data (MW) during VR Net Wholesale
Savings (Demand
for one day minus
energy for all VR
days)
Savings since 4/2011
$658,859! Skipping 1 month
~($45,970) Bucket Truck every 3
months
13 days in June, setting new peak nearly every day. Peaked next to last day Loss of energy sales lowers the overall savings
Date
System
Peak
Time of
Peak (EST)
L BCD
Peak
minus BCD
Max Temp
at Peak in
Fahrenheit
Peak Billed
Demand
(MW) from
TVA Power
Demand Red
off TVA Peak
Demand Start Time End Time Event Hours
Demand
Reduction
Savings
kWh Sales Loss
(total kWh
assuming 75%
coincidence
kWh Lost
Sales
Revenue
Net Wholesale
Savings (Demand
for one day minus
energy for all VR
June 2012 50.02
Monday, June 04, 2012 127.080 14:59 101.150 81.0 100.499 4.63 10:20 AM 4:52 PM 6.53 22,683 $984.06
Friday, June 08, 2012 129.310 15:59 96.460 84.3 96.276 4.22 1:00 PM 3:30 PM 2.50 7,906 $343.00
Monday, June 11, 2012 127.790 14:59 97.360 81.3 97.860 4.10 10:48 AM 4:52 PM 6.07 18,643 $808.79
Tuesday, June 12, 2012 136.050 14:59 109.420 85.2 109.129 4.57 2:20 PM 4:20 PM 2.00 6,854 $297.34
Wednesday, June 13, 2012 137.070 14:59 108.180 85.8 108.001 4.52 1:55 PM 4:00 PM 2.08 7,066 $306.53
Thursday, June 14, 2012 138.650 14:59 109.670 90.2 109.291 4.58 1:16 PM 5:30 PM 4.23 14,529 $630.30
Friday, June 15, 2012 135.660 14:59 105.880 87.5 105.540 4.42 12:50 PM 4:30 PM 3.67 12,152 $527.19
Monday, June 18, 2012 139.920 16:59 110.200 91.0 110.313 4.62 1:53 PM 4:55 PM 3.03 10,508 $455.86
Tuesday, June 19, 2012 139.910 14:59 111.760 91.2 111.550 4.67 12:44 PM 4:54 PM 4.17 14,595 $633.20
Wednesday, June 20, 2012 146.870 14:59 117.780 96.0 118.060 4.94 1:14 PM 5:00 PM 3.77 13,964 $605.82
Thursday, June 21, 2012 144.420 14:59 117.700 93.0 117.212 4.91 1:14 PM 5:02 PM 3.80 13,987 $606.79
Monday, June 25, 2012 146.580 14:59 120.240 90.0 120.027 5.03 1:00 PM 5:00 PM 4.00 15,076 $654.06
Friday, June 29, 2012 147.740 14:59 120.040 101.5 120.109 5.03 12:50 PM 5:00 PM 4.17 $48,378 15,715 $681.78 $40,843
Event WindowSCADA Data (MW) during VR
Top 20 hours of June 2012
DRIVING FORCE: TVA returned Distributors to Demand Charge & TOU Energy
How to control peak
hour 20 hrs within 4.7 MW 5 different days Peaked on Friday, June
29, 2-3 pm EST, at 104 °F
END USER METERING
AMI
SCADA DNP
3
SUB
RTU
LTC Controls
MUS performs Demand Reduction through Dynamic Voltage Regulation (DVR) while ensuring that we adhere to the “A” range standard of ANSI C84.1-1995.
CLOSED LOOP
FEEDBACK
Sag alarms in Seconds!
Can Use Any Meter on System!
Feedback Immediate!
Fiber network ensures fast
response!
Needed System Improvements Identified! Not
Just EOL!
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R&D development of DNP product w/ Tantalus
AMI – Tantalus TUNet V2.59 • Voltage Regulation Application (DCVR-via DNP3)
• GE kV2c / ITRON C1SX Meters, Badger Water Meters
• Water Heater SW (LM-1421), Thermostat (ST-1480) Fiber-to-the-home (FTTH) network SCADA – Efacec ACS Prism V10.1
• Dell Servers (Primary, Backup, Oracle, Portal, ICCP)
• Various Networking (Servers, Switches, Firewalls, VLAN, etc.) Substation Control Hardware (DNP3 Protocol)
• ACS Remote Terminal Units (Connex 30)
• ACS Virtual RTU (ACS 7510)
• ACS PCI + ACS 7000 Radio (900 MHz)
• Beckwith LTC Controls (M-2270B)
• Schweitzer Relay Controls (SEL 351, SEL 351S)
• ABB Relay Controls (DPU 2000R)
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FTTH network: Fiber passes each home
FTTH Customers: 43% take telecom services
VPLS network- Cyber secure: 500 IPC collectors
IPC collectors: Targeted <30 meters/collecter via
900 MHz wireless mesh then backhauled over high
speed Ethernet network
Push system: Meters report up every 15 min
Abnormal events: report in sec/min
Special application: Tantalus TUNet server posts
meter info (V) to SCADA real time (DNP3)
SCADA: Linked to TVA through ICCP
Fiber-to-the-Home Optical Network
Keypoint: FTTH Network is not required but has given MUS the ability to process the meter data quickly
• Electric Infrastructure: $15M • Debt retirement: $800K/yr over 20 • Custodian of base network
• Telecom Infrastructure: $5M • 1GB GPON network • Managed VPLS services for electric AMI
STB,
Wiring
STB,
Wiring
DLC switch
Smart Thermo
IP Collector
Smart Meter
Voltages & LV Alarms
Customer Independent (DVR) • Peak Reduction by Voltage Control
• Dispatchable load
Customer Engaged (DLC) • Smart Thermostats
• Water heater Controls
• *Appliances
• DR Programs (5MR, 60MR, Enernoc)
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1) CONSTANT POWER (P) LOADS • Induction motors (manufacturing machines, etc)
• Certain lighting (fluorescent)
• Electronics
P=IV: If we fix P, then ΔI is the inverse of ΔV. -2% ΔV means +2% ΔI = 0 effect!
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Therefore Voltage Reduction has no reducing effect on power, and can
sometimes increase it!
2) CONSTANT IMPEDANCE (Z) LOADS • Incandescent Lighting
• Resistive loads (water heaters, home heat)
• Household appliances (toaster, oven, hair dryer, ..)
Z=V/I: If we fix Z, then ΔI = ΔV. So, using the P=IV formula, decreasing V by 2% yields: P=(.98I)(.98V)=(.96) IV
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Therefore a 2% voltage reduction gives a 4% power reduction!
114V
126V Typical MUS Feeder
Drop 3-5 Volts to EOL Flatter drop = more DR
Cap
Cap
Reg
LTC lowers voltage
X
MUS uses LTC at substation & cap banks, no regulators
114 V
110 V
ANSI c84.1 Voltage Standard
TVA Contract
Requires adherence to
Range A
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Allows for short excursions down to
110V, Range B
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Historical information & temperature Voltage reduction between 2-6% Instigate voltage reduction in steps Script files in SCADA issue commands and
alarms and/or exit VR AMI interface for selected meter
alarms/voltages provide performance verification
Operators can poll for individual voltages Monitor customer calls & LV alarms
"Do, or do not. There is no 'try'." - Yoda ('The Empire Strikes Back')
If 5 min avg demand >
Target : ALARM
Real time Power
VR Activate Target
Prev. Hour Demand
Substation Status
Time to Peak < 30 Min: ALARM
TVA Called Event Status
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Prev Hour Demand
Monthly High Demand
Key point: Flexible SCADA system to
enable calculations
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(time)
(MW
)
Slope = (MW/min)
1) Take 2 points (30 minutes of data) and calculate rate of climb (if non-negative). Resultant is in units of MW/minute (R(ate)).
2) Subtracting the last demand reading from the monthly peak will yield the amount of power before peak is reached. (P2pk =Pm-P2)
3) Dividing P2pk/R results in time (t2pk ) to reach the peak given the rate remains the same.
t2pk==(Pm-P2)/(P2-P1)/30
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As the current demand approaches the target, notifications go out to responsible individuals to take control of the substation voltage and perform DVR.
Email Text Msg
Upon activation of DVR, notifications are sent to inform us that DVR is in progress.
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Voltage Level from RTU
Manually Activate Tap
Changer
Sag Alarm Status (instant)
VR Feedback from RTU
Key Items: 1) EOL Volt
Feedback 2) SAG Alarming 3) LTC on subs 4) Password
Protected
Voltage Status (5 min)
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Prev Hour Billing Demand
Rolling 60 min Demand
5-Min Demand Load
Temp Previous
High
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4.8 MW Reduction
Because our load is comprised of over 70% industry and commercial, we can see big swings in our load
in a short period of time.
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Peak Demand Avoided
Voltage reduction period
First TVA Event Called Sept 6, 2012
Held VR till 5pm EST past own peak for TVA demand response
While in DVR, Tantalus TUNet with DCVR program sends voltages and alarms for the meters of our choice.
Information Updated every 5 min –allows time for LTC to change
Sag is instantaneous.
Key Points: • Use any meter • Using 3 meters per
phase per breaker
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Virtual RTU DNP3
DLC – Direct Load Control • Water Treatment Plant Load • Smart Thermostats • Water Heater Switch
Must be able to cycle the devices as to not create a peak upon leaving DLC control
Intelligent controls a necessity (communication is 2 way)
Customer must have a monetary benefit to allow control (TOU rates)
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Programmed Cycle
Committed kW: 1500 Operational Tests Ongoing
• Difficulty Programming
• Operates on Command
• Feedback Not Robust
Evaluating Viability of Device Plan 1000 Units for Installation 11 Switches Installed Target 3Q 2013 Completion
Committed kW: 500 Communication Tests Ongoing
• Legacy 1.0 Devices - Tantalus
Expanding Testing of Devices • MUS employees
• Local Apartment Owner
Plan 1000 Units for Installation 5 Switches Installed Target 3Q 2013 Completion
Once outside the Peak window and there is no reason to believe that the load will change drastically.
Step the transformer voltage back to standard voltage in
a controlled manner as to not “shock” the system and raise the demand.
Raised Voltage by 1 LTC step
36
As slope increases, the time to reach monthly high decreases
DVR Activated
DVR Cut Loose
Avoided setting a new peak!
(est 127.5 MW)
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For low voltage alarms: • determine the feeder,
• amount of voltage drop from the substation
• and compare to other locations on same feeder.
Make plan to improve low voltage locations. The goal is to have the ability to take the feeder as close
to 114V as possible to yield the best results.
"I can go only as far as my weakest feeder, so [DCVR] allows me to identify the weaker feeders and provides valuable information to tell you where you need to improve your
system.” Jody Wigington in Renew Grid, 4/18/2012
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8 of 9 substations in voltage reduction Only 15 of 11,000 installed meters under 114V 10 of the 15 on one street off same feeder
Review the reports for the event to determine if next step is required
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Sometimes End-of-feeder voltages are not the bellwether indicators
These meters displayed sag alarms before the end-of-feeder
meters due to undersized conductors
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EOL Meters
Substation Feeder
As we perform DR, continuously review the events for problems
Correct any SAG issues quickly Finalize the Voltage Control Program Installation of VAR control where it makes
sense • Controlled automatically by level and production
days of industry • To flatten the curve to allow control close to 114V
EOL
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DR has been around for long time. It does not require a sophisticated system. If you do not have a DR program, maybe
now is the time to develop one!
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Since April 2011, MUS has saved an
estimated $658,859 with the DR
program.
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“The improvement of
understanding is for two ends: first,
our own increase of knowledge;
secondly, to enable us to deliver
that knowledge to others”
- John Locke, 17th century philsopher
Questions?
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“Politicians and diapers
need to be changed
regularly, ….usually for
the same reason.”
For the Season at Hand
Thank You
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