Transcript Slide 1

CECD Capability Discussion with
BPA
April 9, 2008
CECD Overview
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Formed in as Duke Energy Control Area Services LLC (DECA) in 1999
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Built to optimize Duke generation asset based on a fleet management philosophy
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3rd party generators and Load Serving Entities began to request CECD services
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In February 2005 became Constellation Energy Control and Dispatch (CECD)
after an unsolicited offer was made to purchase the DECA LLC Operations.
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Successfully certified and currently manage all-requirements for 5 separate cities
and over 11,400 MW of generation in 5 regions including WECC
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Highly experienced Staff focused on EMS and NERC/Regional policies
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Successfully completed 10 NERC Compliance reviews in October of 2007
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Successfully completed 10 Readiness Audits in October of 2007
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7 to 9 man Certification Team onsite review of facilities and Staff
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Utilize multiple dynamic and/or pseudo ties to and from load and generation
CECD Services
• National control center operates throughout North America
• Secure client web access to performance data activity 24/7 in real time,
historically and forward schedule requirements
• Provide continuous asset management and oversight, power tagging,
ancillary services management, data access and dynamic scheduling
• Enable clients to manage power supplies and sales to maximize
profitability while reducing physical and financial risk
• Employs multiple high-speed data connection to regional authorities,
reliability authorities, RTOs to maintain data integrity
• Energy Integration, regulation, balancing, and demand response
• Implement and coordinate operation of A.G.C., pseudo ties, dynamic
schedules
• Compliance management and reporting (GADS, FERC 714 and EIA 411)
• Energy shadow settlements, reporting and dispute resolution
• Emergency and planned outage response and coordination
• Reserve pool management and energy-replacement services
Optimization and Management Tools – Software
Systems
Performance and Optimization
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C
Pe ECD
rfo
rm Van
ce
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CE
C
Re D V
ne w
CE
C
EM D
SC S
AD
A
Plan and Schedule
(Energy Allocation)
CE
C
ST D E
AR -
Energy Accounting,
Reconciliation and Settlement
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Real-time Operations
and Control
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Integrated EMS, Planning,
Accounting and Reporting System
Generation Management System
Customized for Wind
Full Disaster Recovery Operations
Infrastructure
Web-based Performance Reports
Simplifies communication of Realtime EMS and Other Pertinent
Data
Determine and Monitor Asset
Value
Assess and Optimize Unit
Performance
Energy- Settlements Tracking and
Reconciliation (E-Star)
North Littlerock, Ark
300 MW Peak
Ruston, La.
90 MW Peak
Conway, Ark
210 MW Peak
West Memphis, Ark
80 MW Peak
Benton, Ark
75 MW Peak
Total Load
755 MW & growing
Current CECD
Customer Base
All Requirements
Load Served
Generating Facilities Served
Facility Name
Facility Owner
Facility Capacity
Facility Trading Group
Union/El Dorado
Entegra
2,200 MWs
Entegra
Gila River
Entegra
2,200 MWs
Entegra
APEX
LS Power
640 MWs
Fortis
Batesville
La. Power
650 MWs
Goldman Sachs/JARON
Arlington Valley
Dynegy
640 MWs
Dynegy
Griffith
Dynegy
550 MWs
Dynegy
Fayette
Duke Energy
640 MWs
Duke Energy
Hanging Rock
Duke Energy
1,240 MWs
Duke Energy
Washington
Duke Energy
640 MWs
Duke Energy
Lee
Duke Energy
640 MWs
Duke Energy
Harquahala
LS Power
1,200 MWs
Fortis
Tatanka
Acciona Wind Energy
200 MWs
Acciona
Total
11,440 MWs
CECD Web
The MW Dashboard assesses plant performance in terms of MW
produced and settled against plan.
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Data Drill Down
Display node Detail, Average, Statistics, Frequency, Correlation
Chart display and tabular data result formats
Data filtered according to search criteria
Customize graphs and results on-the-fly
Tab through data for
additional information
Export current view to Excel
Re-chart:
•Add moving averages
•Add Footprint level
•See impact of Load/Control
Tabular display of detail data
presented in chart
Real-Time monitoring reports real-time EMS and other pertinent
data through a series of web-based user reports
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Search
Features
Standard across reports
Flexible multi-selection
Save frequent searches to build a portfolio
Filter results
over/under input
thresholds.
Filter set by days,
hours or product
Quickly find any ISO
node
Rank results by:
•Delta
•Stand Dev
•Day-ahead
•Real Time
•Loss
•Congestion
Memorize selections as
“Preferences”.
Set as default or recall
saved reports with one-click
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Chart Analysis
Choose any point, any ISO and chart results
Compare nodes results against each other
Add in ISO footprint and zone data
Hover over points for detail information
Dispatch Log
Auditable Dispatch Log event data supports back office tie out
activities.
Real Time Data to RTU Four sec update of meter data and hourly updates in buffer
“Raw” Meter Freeze reading at end of hour
DATA TO OTHER COMPANY
Tie Line Meter
Integration of Real Time meter pulses with losses calculated
Raw Meter reading delta values
Raw Real Time Meter Pulses
Raw Meter Freeze Reading
Calculated Rollover Meter Accounting Values
SMP Data SERVER can retain 8
days history in case of com. failure
Data To CECD SMP Server
RTU / DCS – Remote
Terminal Unit
CECD Houston Energy
Management System (EMS)
ICCP DATA FEED – Multiple data points and reports
EMS calculates a 32 bit meter reading
to match LSE's and Trans. Operator
MV90 reading. Also calculated are the
integration values, tie line losses and
raw delta values
CECD E-STAR
Energy
Accounting
System
Energy Provider(s)
CUSTOMIZED REPORTS
Redundant SMP Data Server in
Houston maintains additional
history and critical values
Web Data Screen Values
Energy Flow – Gen. Control Area Supplying AGC MW to 3rd party
(Transmission Provider indicated as Intermediary Control Area)
AGC Set Point
(Block Schedule
+
Reg. MW request
+
X% Loss factor)
IPP Generator
Interconnection
Meter
M
CECD
Dynamic or
Pseudo Tie
(AGC MW)
Incumbent
Control Area
M
Tie Meter
( Reg. Request MW + X%
Loss factor)
Dynamic or
Pseudo Tie
Legend:
Heavy arrow denotes actual energy flow
Light arrow denotes pseudo ties for ACE calculation
Dotted arrow denotes 4 second data flow
Dynamic Signal
(Reg. Request MW *
factor for losses)
Receiving
Control
Area or
Load
Center
AGC Incremental/decremental Signal from BPA to IPP
(Data Flow Example)
BPA System
Load
M
BPA Metering
RTU
BPA Pseudo Tie or Dynamic Tie Value to BPA Transmission Control
IPP Generating Station
BPA
EMS
AGC MW desired
from IPP
ICCP
Gateway
Data Circuit
CECD
ICCP
Gateway
IPP Tie Meters
IPP Pseudo Tie
Value to BPA
Transmission
M
Actual MW
AGC MW
Signal
BPA
OATI
E-tag
Schedules
CECD
EMS
Gen(s)
Aux
AGC (Total MW)
NOTE: The RTU Link To BPA is
One method of passing data
We may use only the ICCP Link
IPP
Block Schedules
Data Circuit
Total MW
( Block + BPA
Inc/dec MW
Request)
CECD
Site
SMP
IPP
DCS
RTU
Switchyard
RTU
IPP Dynamic or
Pseudo Tie
Value to BPA
Transmission
ICCP / RTU Data Flow
IPP / CECD
BPA
Transmission
Control Area
BPA Load/
System
Management
Legend:
1.
2.
3.
4.
5.
6.
7.
Daily Contract MW (between BPA and IPP)
RTU also
BPA Regulation Request. BPA Pseudo Tie
Hourly Integrated Pseudo Tie & Rounded MWH
Hourly Integrated Pseudo Tie & Rounded MWH delivered from IPP
Echo BPA Regulation Request
IPP Regulation Flag, IPP Pseudo Tie
Regulation Invalid Flag, Adjusted BPA Regulation Request
Loss Factor
With Losses
Without Losses
CITY METER LOG COMPARISONS FOR RECEIVING COMPANY
METER: Tie 1
DATE
1/1/2007
2/1/2007
3/1/2007
4/1/2007
5/1/2007
6/1/2007
7/1/2007
8/1/2007
9/1/2007
10/1/2007
11/1/2007
12/1/2007
1/1/2008
TIME
0:00
0:00
0:00
0:00
0:00
0:00
0:00
0:00
0:00
0:00
0:00
0:00
0:00
Loss Factor:
Meter Reading Meter Flow Meter Flow
Scaled
3373.000
9629.000
17684.000
27472.000
38243.000
51624.000
60973.000
0.000
0.000
0.000
-6256.000
-8055.000
-9788.000
-10771.000
-13381.000
-9349.000
0.000
0.000
0.000
0.000
0.000
0.000
-6484.970
-8349.813
-10146.241
-11165.219
-13870.745
-9691.173
0.000
0.000
0.000
Acc. Acctg. Accounting
Log Meter
Log Flow
0.000
0.000
0.000
-6323.000
-14816.000
-25003.000
-36147.000
-50017.000
-59699.000
0.000
0.000
0.000
-6323.000
-8493.000
-10187.000
-11144.000
-13870.000
-9682.000
1.036600 (ex. 3% loss, enter 1.03)
Meter
Log Diff
0.000
0.000
0.000
-161.970
143.187
40.759
-21.219
-0.745
-9.173
0.000
0.000
0.000
Previous Accumulated Corr.
Difference Difference
0.000
0.000
0.000
0.000
-161.970
-18.783
21.977
0.758
0.013
0.000
0.000
0.000
0.000
0.000
0.000
-161.970
-18.783
21.977
0.758
0.013
-9.160
0.000
0.000
0.000
-162
-19
22
NOTE: Loss factor in column H3 must be correct for each tie.
Corrections in column K should be entered with the same sign as the accumulated difference in Column J.
(ie. If Column J shows -9.181 then you would enter -9 in Column K, while if Column J shows 12.121 then you would enter 12 in Column K.)
Off
Peak
0
0
0
-53
-6
7
0
0
0
0
0
0
On
Peak
0
0
0
-109
-13
15
0
0
0
0
0
0
Comments
JT Thompson
Office: 713-332-2901
Cell: 281-221-5475
Email: [email protected]
Address: 500 Dallas Street
One Allen Center, Suite 3015
Houston, Texas 77002