ERCOT Monthly Operational Overview ( April 2012 ) May 15, 2012
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Transcript of ERCOT Monthly Operational Overview ( April 2012 ) May 15, 2012
ERCOT Monthly Operational Overview (April 2012)
May 15, 2012
Grid Operations & Planning
3
Content
• Operations– Peak Demand: Actual vs. Forecast
On-line Resources: Total at Peak and Wind– CPS1 Monthly Performance– Historical Peak and Minimum Loads– Day-Ahead Load Forecast Performance– Reliability Unit Commitment Capacity (RUC) by weather zone – Generic Transmission Limits (GTLs)– Advisories, Watches and EEAs– Significant System Incidents– Cooling Reservoir Level Update
• Planning Activities– Summary– Generation Interconnection Requests– Wind Capacity
ERCOT PublicMay 15, 2012
4
April 2012 Daily Peak Demand: Hourly Average Actual vs. Forecast, Wind Day-Ahead COPs & On-line Capacity at Peak
Note: All data are hourly averages during the peak load hour obtained from COPs, and EMMS.
ERCOT Public
0
10,000
20,000
30,000
40,000
50,000
60,000
MW
Actual Peak Load
Actual Online Capacity
Actual Wind Output
ERCOT Load Day-Ahead Forecast
Wind Day-Ahead COPs
Peak Demand for the Month: 48,750 MW @ 4/25/12 HE 18:00
May 15, 2012
5
April 2012 Actual Wind Output plus Curtailments vs. Wind Day-Ahead COPs for All Hours
Note: QSEs must use the AWST 50% probability of exceedance forecast as the HSL in their COPs
ERCOT Public
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
MW
Operating DayDaily Averaged Aggregated Wind Output Estimated Wind Curtailment Daily Averaged Day-Ahead COP HSL
% of Hours when Estimated Uncurtailed Wind Output >= COP HSLs (Target = 50%)
50%
May 15, 2012
6
April 2012 ERCOT’s CPS1 Monthly Performance
ERCOT Public
100
110
120
130
140
150
160
170
100
110
120
130
140
150
160
170
CP
S1 A
ve
rag
e
Monthly Average 12 Month Rolling Average
CPS1 12 Month Rolling Average = 154.07%
May 15, 2012
7
April 2012 Monthly Peak Actual Demand
ERCOT Public
-
10,000
20,000
30,000
40,000
50,000
60,000
70,000
80,000
MW
Month
2011
2012Peak Demand is Peak Interval Demand
May 15, 2012
8
April 2012 Monthly Minimum Actual Demand
ERCOT Public
-
5,000
10,000
15,000
20,000
25,000
30,000
35,000
40,000
MW
Month
2011
2012Minimum Demand is Valley Interval Demand
May 15, 2012
9
Day-Ahead Load Forecast Performance in April 2012
Mean Absolute Percent Error (MAPE) for ERCOT Mid-Term Load Forecast (MTLF) Run at 14:00 Day Ahead
2009MAPE
2010MAPE
2011MAPE
2012MAPE
April 2012MAPE
AverageAnnual MAPE
3.11 2.83 2.83 2.93 2.78
LowestMonthly
MAPE1.93 2.24 1.63 2.51
LowestDailyMAPE
1.52Apr – 27
HighestMonthly
MAPE 4.11 3.79 3.55 3.49
Highest DailyMAPE
6.33Apr – 16
ERCOT PublicMay 15, 2012
10
Reliability Unit Commitment (RUC) Capacity by weather zone in April 2012
ERCOT Public
1 1
0
0.2
0.4
0.6
0.8
1
1.2
NORTH CENTRAL
Days
Weather Zone
RUC Commitments by Weather Zone
Unit-Days RUC Total Days
May 15, 2012
11
April 2012 Generic Transmission Limits (GTLs)
GTL: A transmission flow limit more constraining than a Transmission Element’s normal limit established to constrain flow between geographic areas of the ERCOT Transmission System that is used to enforce stability and voltage constraints that cannot be modeled directly in ERCOT’s transmission security analysis applications.
Note: This table lists how many times a constraint has been activated to avoid exceeding a GTL limit, it does not imply an exceedance of the GTL occurred.
GTLsApr 11DaysGTLs
Feb 12DaysGTLs
Mar 12DaysGTLs
Apr 12DaysGTLs
Last 12 Months
Total Days (Mar11 – Mar12)
North – Houston 0 0 0 0 2
West – North 27 17 17 17Apr (1-2,6-7,11-20,24-27)
236
Valley Import 0 0 0 0 0
ERCOT PublicMay 15, 2012
12
Advisories and Watches in April 2012
• Advisories issued for Physical Responsive Capability (PRC) below 3000 MW.– Issued 2 Days
• Watches issued for Physical Responsive Capability (PRC) below 2500 MW.– 0 Watch issued for PRC below 2500 MW.
• Transmission Watches– None
• Energy Emergency Alerts– None
ERCOT PublicMay 15, 2012
13
Lake Levels Update – 01 May 2012
Surface Water & (MW)*Level @ Full Conservation
Pool*Level on
Jan 1, 2011*Level on
Oct 7 , 2011*Level on
May 01, 2012
Lake Texana (56) 44.50 41.00 32.81 43.19
Bardwell Lake (312) 421.00 420.71 416.23 421.08
Lake Colorado City (407) 2,070.20 2057.33 2052.4 2051.23
Lake Ray Hubbard (916) 435.50 432.37 429.22 435.09
Lake Granbury (983) 693.00 691.90 686.27 692.43
Lake Houston (1016) 41.73 42.10 36.76 41.85
Twin Oaks Reservoir (1616) 400 398.87 398.27 400.18
Lake Limestone (1689) 363 359.03 354 362.62
Martin Lake (2425) 306 300.48 295.06 302.03
* In Feet above Mean Sea Level
ERCOT PublicMay 15, 2012
14
Planning Summary – April 2012
• ERCOT is currently tracking 125 active generation interconnection requests totaling over 34,000 MW. This includes over 18,000 MW of wind generation.
• ERCOT is currently reviewing proposed transmission improvements with a total cost of $81.5 Million
• Transmission Projects endorsed in 2012 total $413 Million• All projects (in engineering, routing, licensing and construction) total
approximately $9.84 Billion• Transmission Projects energized in 2012 total about $108.8 million
ERCOT PublicMay 15, 2012
15
County Location of Planned Generation with Interconnection Requests (all fuels) April 2012
ERCOT PublicMay 15, 2012
16
County Location of Planned Generation with Interconnection Requests (Wind) April 2012
ERCOT PublicMay 15, 2012
17
Wind Generation – April 2012
ERCOT PublicMay 15, 2012
10,035
1,920 2,122 2,242
116
816 977 1,173 1,385 1,854
2,875
4,785
8,005
8,916 9,400 9,604
11,955 12,157 12,277
0
2,000
4,000
6,000
8,000
10,000
12,000
2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014
MW
Cumulative MW Installed
Cumulative Planned (Signed Interconnection Agreement)
ERCOT Wind Installations by Year (as of April 30, 2012)
The data presented here is based upon the latest registration data provided to ERCOT by the resource owners and can change without notice. Any capacity changes will be reflected in current and subsequent years' totals. Scheduling delays will also be reflected in the planned projects as that information is received.
This chart now reflects planned units in calendar year of installation rather than installation by peak of year shown
18
Generation Interconnection Activity by Fuel – April 2012
0
50
100
150
200
250
300
0
20,000
40,000
60,000
80,000
100,000
120,000
Jan-
06
Apr
-06
Jul-0
6
Oct
-06
Jan-
07
Apr
-07
Jul-0
7
Oct
-07
Jan-
08
Apr
-08
Jul-0
8
Oct
-08
Jan-
09
Apr
-09
Jul-0
9
Oct
-09
Jan-
10
Apr
-10
Jul-1
0
Oct
-10
Jan-
11
Apr
-11
Jul-1
1
Oct
-11
Jan-
12
Apr
-12
Pro
ject
Co
un
t
MW
Cap
acit
y
MW Natural Gas MW Nuclear MW Coal MW Wind MW Solar *
MW Biomass * MW Other Total # Projects # Projects Cancelled
* Prior to September 2008, Category "Other" included "Solar" and "Biomass"Projects in all phases of interconnection study are reflected in this graphProject cancellation tracking by month began in March 2008
ERCOT PublicMay 15, 2012
19
Generation Interconnection Activity by Project Phase – April 2012
0
20,000
40,000
60,000
80,000
100,000
120,000
0
50
100
150
200
250
300
350
400Ja
n-06
Apr
-06
Jul-0
6
Oct
-06
Jan-
07
Apr
-07
Jul-0
7
Oct
-07
Jan-
08
Apr
-08
Jul-0
8
Oct
-08
Jan-
09
Apr
-09
Jul-0
9
Oct
-09
Jan-
10
Apr
-10
Jul-1
0
Oct
-10
Jan-
11
Apr
-11
Jul-1
1
Oct
-11
Jan-
12
Apr
-12
MW
Ca
pa
cit
y
Pro
jec
t Co
un
t# In-Service ** # Full Study Suspended # Signed Interconnect Agreement
# Projects Cancelled *** # Completed Full Study # in Full Study
# Screening Study Complete # Initial Screening Study MW Capacity Under Study *
MW In Commercial Operation **
* Nameplate capacity will change across time due to additional projects, cancellations, expirations, adjustments from study results, and projects being placed in service.
** Having begun commercial operation since January 2006
*** Began tracking cancellations by month in March 2008
ERCOT PublicMay 15, 2012
Market Operations
21
Day-Ahead Schedule – April 2012
ERCOT Public
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 240
10,000
20,000
30,000
40,000
50,000
60,000 Scheduled Energy Only Offer
Scheduled Three-part Offer
DAM Energy Purchase
RT System Load
DAM Net Flow
MW
Liquidity and activity is normal in Day-Ahead Market
DAM_Net_Flow = Combined market transmission flow of Energy purchased/sold in Day-Ahead Market plus Point-to-Point Obligations and NOIE CRR Options carried forward to real-time.
May 15, 2012
22
Day-Ahead Electricity And Ancillary Service Hourly Average Prices – April 2012
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 240
10
20
30
40
50
60
70
80
90
100
Regulation Up
Regulation Down
Responsive Reserve
Non Spinning Reserve
DAM Power Balance Price (System Lambda)
Pri
ce
($
/MW
h)
Ancillary Service price reflect the opportunity cost of energy
ERCOT PublicMay 15, 2012
23
Day-Ahead Vs Real-Time Load Zone SPP(Hourly Average) – April 2012
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 240
20
40
60
80
100
120
140 RTSPP - LZ West
RTSPP - LZ North
RTSPP - LZ South
RTSPP - LZ Houston
DASPP - LZ West
DASPP - LZ North
DASPP - LZ South
DASPP - LZ Houston
Pri
ce
($
/MW
h)
Prices reflect relative transmission congestion and system scarcity
Load Zone West prices were higher due to local congestion caused by transmission outages and low wind in the West Zone
ERCOT PublicMay 15, 2012
24
Day-Ahead Vs Real-Time Hub Average SPP (Hourly Average) – April 2012
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 240
20
40
60
80
100
120 RTSPP - Hub Average
DASPP - Hub Average
Pri
ce
($
/MW
h)
Energy prices reflect the risk premium between Day-Ahead & Real-Time
ERCOT PublicMay 15, 2012
25
DRUC Monthly Summary – April 2012
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 240
10,000
20,000
30,000
40,000
50,000
60,000 Self Scheduled Capacity
Self Scheduled Ancillary Service Limit
Load Forecast
DRUC Recommended Capacity
MW
h
30 executions (none missed)None published after 16004.8 minutes average execution time5332 MWh Committed (1 Resource for 6 Hours)
ERCOT PublicMay 15, 2012
26
HRUC Monthly Summary – April 2012
Ser0
20
40
60
80
100
MW
h
720 executions (none missed)5.0 minute average execution timeThere was no HRUC commitment in April 2012.
Colors Indicate Individual Resources
ERCOT PublicMay 15, 2012
27
Non-Spinning Reserve Service Deployment – April 2012
Deployment Start Time
Deployment End Time
Deployment Duration (Hours)
Max Deployment (MW)
Reason
4/7/2012 13:18 4/7/2012 18:46 5.5 279 Local Congestion
4/10/2012 14:57 4/10/2012 18:23 3.4 72 Local Congestion
ERCOT PublicMay 15, 2012
28
CRR Price Convergence – April 2012
Apr-11
May
-11
Jun-1
1
Jul-1
1
Aug-11
Sep-1
1
Oct-1
1
Nov-11
Dec-1
1
Jan-1
2
Feb-1
2
Mar
-12
Apr-12
0
10
20
30
40
50
60
70
Cost
Value
Mil
lio
ns
$
Congestion Revenue Right cost in auction convergence with payment in Day-Ahead Market and Real Time Market
ERCOT PublicMay 15, 2012
29
Reliability Services – April 2012
Reliability Unit Commitment (RUC) $ in Millions
RUC Make-Whole Payments ($0.01)
RUC Clawback Charges $0.00
RUC Commitment Settlement ($0.01)
RUC Capacity Short Charges $0.01
RUC Make-Whole Uplift $0.00
RUC Commitment Cost Allocation $0.00
RUC Decommitment Payments $0.00
RUC Cost continues to trend low.
April 2012 cost was $0.01M, compared to:• A charge of $0.01M in March 2012• A charge of $2.4M in April 2011
ERCOT PublicMay 15, 2012
30
Ancillary Services – April 2012
Capacity Services $ in Millions
Regulation Up Service $4.5
Regulation Down Service $1.6
Responsive Reserve Service $24.6
Non-Spinning Reserve Service $7.3
Black Start Service $0.6
Voltage Support Service $0.0
Total Capacity Service $38.61
Capacity Services costs were increased from last month, but more comparable to April 2011.
April 2012 cost was $38.61M, compared to:• A charge of $25.6M in March 2012 • A charge of $31.3M in April 2011
ERCOT PublicMay 15, 2012
31
Energy Settlement – April 2012
Increases in Day-Ahead and Real-Time energy settlement increased from previous month; reflective of increased load and prices.
Day-Ahead Market Energy Settlement $ in Millions
Energy Purchases $366.80
Point to Point Obligation Purchases $23.91
RMR Day-Ahead Revenue $0.00
Energy Sales ($358.27)
Day-Ahead Congestion Rent $32.43
Day-Ahead Market Make-Whole Payments ($0.09)
Real-Time Market Energy Settlement $ in Millions
Energy Imbalance at a Resource Node ($344.76)
Energy Imbalance at a Load Zone $524.59
Energy Imbalance at a Hub ($139.18)
Real Time Congestion from Self Schedules ($0.97)
Block Load Transfers and DC Ties ($8.78)
Impact to Revenue Neutrality $30.90
Emergency Energy Payments ($0.16)
Base Point Deviation Charges $0.55
Real-Time Metered Generation (MWh in millions) 24.14
ERCOT PublicMay 15, 2012
32
Congestion Revenue Rights (CRR) – April 2012
Auction Disbursements $ in Millions
Annual Auction ($15.20)
Monthly Auction ($8.87)
Total Auction Revenue ($24.07)
Day-Ahead CRR Settlement ($28.61)
Day-Ahead CRR Short-Charges $0.23
Day-Ahead CRR Short-Charges Refunded ($0.23)
Real-Time CRR Settlement ($1.77)
Real-Time CRR Short-Charges $0.01
Real-Time CRR Short-Charges Refunded ($0.01)
Total CRR Proceeds ($30.38)
Day-Ahead Point to Point Obligations Settlement $23.91
Real-Time Point to Point Obligation Settlement ($27.98)
Net Point to Point Obligation Settlement ($4.07)
• Congestion Revenue Rights were fully funded.
• Excess funds available for distribution to load.
ERCOT PublicMay 15, 2012
33
Revenue Neutrality – April 2012
Revenue Neutrality Settlement $ in Millions
Real-Time Point to Point Obligation Settlement ($27.98)
Real-Time Point to Point Options and Options with Refund Settlement ($1.77)
Real-Time Energy Imbalance Settlement $40.65
Real-Time Congestion from Self-Schedules Settlement ($0.97)
DC Tie & Block Load Transfer Settlement ($8.78)
Charge to Load ($1.16)
Revenue Neutrality trending lower than previous months.
April 2012 was a credit of $1.16M, compared to:• $8.29M charge in March 2012• $2.37M credit in April 2011
ERCOT PublicMay 15, 2012
34
Net Uplift to Load – April 2012
Net uplift to load trending higher from the previous month; increases can be attributed to increases in Ancillary Services and other costs associated with increased load.
April 2012 was a charge of $19.36M, compared to:• $14.67M in March 2012• $18.28M in March 2011
Market-Based Uplifts $ in Millions
CRR Auction Revenue Disbursement Settlement ($24.07)
Balancing Account Proceeds Settlement ($3.86)
Net Reliability Unit Commitment Settlement $0.01
Ancillary Services Settlement $38.61
Reliability Must Run Services Settlement $0.0
Real-Time Revenue Neutrality Settlement ($1.16)
Emergency Energy Settlement $0.16
Base Point Deviation Settlement ($0.55)
Total $9.14
Fee Uplifts
ERCOT Administrative Fee Settlement $10.22
Net Uplift Charge to Load $19.36
ERCOT PublicMay 15, 2012
35
Advanced Meter Settlement Impacts – April 2012
April 2012: At month end, settling just under 5M ESIIDs using Advanced Meter data.
April 2012: 85.7% of the load in ERCOT is settled with 15-min interval data (AMS, Competitive IDR, and NOIE IDR).
ERCOT PublicMay 15, 2012
36
ERCOT Wide Load Volumes by Meter Type – INITIAL Settlement – April 2012
ERCOT PublicMay 15, 2012
37
Retail Transaction Volumes – Summary – April 2012
Year-To-Date Transactions Completed
Transaction Type Apr 2012 Apr 2011 Apr 2012 Apr 2011
Switches 292,911 246,843 67,724 61,779
Move - Ins 692,193 673,740 170,266 166,711
Move - Outs 332,973 342,694 83,126 86,398
Continuous Service Agreements (CSA) 177,091 105,246 50,883 25,098
Mass Transitions 0 7,187 0 0
Total 1,495,168 1,375,710 371,999 339,982
Total since June 1, 2001 46,420,012
ERCOT PublicMay 15, 2012
38
Retail Transaction Volumes – Summary – April 2012
ERCOT Public
Switches Move-Ins
Move-Outs Mass Transition
May 15, 2012
39
Retail Performance Measures – Switch – April 2012
1st Quarter 2nd Quarter
3rd Quarter 4th Quarter
ERCOT PublicMay 15, 2012
40
Retail Performance Measures (Priority Move-In) – April 2012
1st Quarter 2nd Quarter
3rd Quarter 4th Quarter
ERCOT PublicMay 15, 2012
41
Retail Performance Measures (Standard Move-In) – April 2012
1st Quarter 2nd Quarter
3rd Quarter 4th Quarter
ERCOT PublicMay 15, 2012
Projects Report
43
ERCOT Portfolio Stoplight Report (as of 5/7/2012)
May 15, 2012 ERCOT Public
Project Number
Project Name PhaseBaseline Phase
StartBaseline Phase
FinishScheduled
Phase FinishSum of 2012
Budgets2012 Forecast
SpendSum of Total
BudgetsTotal Forecast
Spend
PROJECTS IN FLIGHT (Count = 41) Sorted by Phase / Project Num $ 12,206,660 $ 12,230,950 0% $ 21,873,867 $ 21,188,793 3%
006_01 SAGE (System Administrator Gateway Environment) Planning 6/6/2011 12/7/2011 5/10/2012 2 -84% 1 -665% 4%
016_01 ADP-IDM Interface Planning 3/7/2012 5/25/2012 5/23/2012 2% 0% 1%
017_01 Oracle 11g Upgrade Planning 4/11/2012 9/19/2012 8/31/2012 11% 3% 3%
020_01 CIM Upgrade for NMMS Planning 2/2/2012 5/30/2012 5/30/2012 0% 5% 5%
026_01 Support for New Resource Types in ERCOT Systems Planning 1/4/2012 8/1/2012 6/11/2012 24% 32% 32%
030_01 ITRON Load Forecast Planning 3/14/2012 6/26/2012 6/26/2012 0% 19% 19%
037_01 SMTNET Improvements Planning 3/21/2012 6/6/2012 6/6/2012 0% 0% 0%
038_01 Macomber Map NERC SA/Compliance Enhancements Planning 3/29/2012 8/15/2012 8/13/2012 1% 0% 3%
042_01 CRR Upgrade to v12.3 Planning 4/11/2012 5/31/2012 5/31/2012 0% -1% -1%
NPRR365 Change in Resource Outage Approvals from 8 to 45 Days Planning 1/26/2012 4/25/2012 4/25/2012 0% 0% 2%
NPRR382 Verbal RUC Committed or Decommitted Resources Report Planning 4/11/2012 4/30/2012 5/23/2012 4 -121% -3% -3%
001_47 RARF Upgrade for Wind, Solar, and Storage Resources Execution 9/7/2011 4/30/2012 6/29/2012 2 -25% 10% 2 -49%
005_01 Endpoint Security Phase 1 Execution 12/15/2011 4/25/2012 5/8/2012 2 -9% 5 -26% 1%
009_01 Compliance Software Tool Execution 12/1/2011 11/30/2012 12/13/2012 -3% 1% 8%
010_01 MarkeTrak Enhancements for 4.0 Execution 10/26/2011 7/27/2012 6/28/2012 10% 5 -5% 1%
011_01 ERCOT Mobile Execution 3/29/2012 8/8/2012 8/8/2012 0% 4% 4%
014_01 Implementation of NPRR347 and NPRR400 Execution 3/29/2012 11/23/2012 11/23/2012 0% 8 -6% -1%
015_01 Outage Capacity Calculation Tool Execution 1/4/2012 4/30/2012 4/30/2012 0% -1% 0%
019_01 ERCOT Website Enhancements - 2012 Execution 3/8/2012 12/26/2012 1/2/2013 -2% 4% 4%
021_01 Incremental Update Capability - Phase 1 Execution 3/23/2012 1/2/2013 1/2/2013 0% 2% 3%
023_01 Quality Training Database Execution 2/22/2012 5/30/2012 5/31/2012 -1% 36% 36%
025_43 Enterprise DW Platform Transition Execution 2/15/2012 4/30/2012 4/30/2012 0% 29% 9%
029_01 Capital Efficiencies and Enhancements Execution 1/1/2012 12/31/2012 12/31/2012 0% 0% 0%
040_01 Lawson Upgrade to 9.0.1 Execution 4/18/2012 7/31/2012 7/31/2012 0% -1% -1%
10052_01 Settlement System Upgrade Execution 1/25/2012 12/30/2014 12/30/2014 0% 2% 0%
11002_01 Texas SET 4.0 Execution 7/6/2011 7/13/2012 7/13/2012 0% 7 -15% 7%
2012 PC Program Control Project Execution 1/1/2012 12/31/2012 12/31/2012 0% 40% 40%
90006_02Information Lifecycle Mgmt – Mkt Systems, Archive, Reporting
Execution 4/22/2011 12/4/2013 12/4/2013 0% 0% -1%
99911 Minor Cap - Critical - 2012 Execution 1/1/2012 12/31/2012 12/31/2012 0% 0% 0%
NPRR314Requirement to Post Generation Resources Temporal Constraints
Execution 3/5/2012 4/29/2012 4/27/2012 3% 32% 32%
NPRR348 Generation Resource Start-Up and Shut-Down Process Execution 3/29/2012 8/4/2012 7/27/2012 6% 18% 18%
NPRR351 SCED Look-Ahead Step 1: Pricing Execution 1/25/2012 7/31/2012 7/31/2012 0% 38% 0%
NPRR354Revisions to Non-Spin Performance Criteria Language and Provision for ICCP Telemetry of Non-Spin Deployment
Execution 3/29/2012 8/4/2012 7/17/2012 14% 12% 12%
NPRR357Revisions to Collateral Requirements Concerning CRR Auctions
Execution 4/19/2012 10/17/2012 10/17/2012 0% 0% 0%
NPRR359 Monthly TDSP Load Report Execution 3/1/2012 5/2/2012 5/4/2012 -3% 4% 4%
NPRR360 Summary Report of HDL and LDL Execution 4/18/2012 7/11/2012 7/11/2012 0% 19% 9%
NPRR361 Real-Time Wind Power Production Data Transparency Execution 1/11/2012 5/3/2012 5/2/2012 0% 1 -119% 1 -119%
NPRR379EILS Dispatch Sequence and Performance Criteria Upgrades
Execution 4/16/2012 6/26/2012 6/26/2012 0% 13% 13%
NPRR434Increase the Capacity Limitation of a Generation Resource Providing RRS
Execution 3/7/2012 6/1/2012 5/2/2012 34% 66% 66%
NPRR437Allow Aggregation of Multiple Generators Into A Single Resource For Mkt & Eng Modeling
Execution 3/29/2012 7/4/2012 7/4/2012 0% 16% 16%
SCR760Recommended Changes Needed for Information Model Mgr and Topology Processor for Planning Models
Execution 8/25/2011 3/28/2013 3/28/2013 0% 5% 2%
Schedule Status
2012 Variance
Total Variance
44
ERCOT Portfolio Stoplight Report (as of 5/7/2012)
May 15, 2012 ERCOT Public
Project Number
Project Name PhaseBaseline Phase
StartBaseline Phase
FinishScheduled
Phase FinishSum of 2012
Budgets2012 Forecast
SpendSum of Total
BudgetsTotal Forecast
Spend
PROJECTS NOT YET STARTED (Count = 33) Sorted by RankForecast Start
Date $ 7,517,312 $ 5,857,312 $ 12,028,207 $ 10,218,207
TBD CTFC Compliance Not Started n/a 100% 100%
TBD MP Online Data Entry - Ph 1 Not Started Q2 0% 0%
TBD CMS and MIR Replacement Not Started Q2 0% 0%
TBD EMS Upgrade Not Started Q2 0% 0%
TBD MAI Conversion to IGRID Not Started Q2 0% 0%
TBD Contingency Functionality Enhmts. Not Started Q3 0% 0%
NPRR322 Real-Time PTP Option Modeling Not Started Q2 0% 0%
TBD TSAT Wind Model Not Started Q2 0% 0%
TBD UC4 (AppWorx) Automation Upgrade v8 Not Started Q2 0% 0%
TBD MP Communications Tool Not Started Q3 0% 0%PRR830
NPRR269Reactive Power Capability Requirement Not Started Q3 0% 0%
TBD Siebel Upgrade 8.x Not Started Q3 0% 0%
TBD NMMS Upgrade Not Started Q4 0% 0%
TBD Data Center Growth & Asset Replacement - 2012 Not Started Q3 0% 0%
TBD Met Center Lease Reconfiguration Not Started Q3 86% 94%
TBD OA Grid Health Operator View Not Started Q4 0% 0%
TBD Vulnerability Management Not Started Q2 0% 0%
NPRR260Providing Access to MIS Secure Area to MIS Registered Users
Not Started Q3 0% 0%
SCR756 MarkeTrak Upgrade and Enhancements (Phase 2) Not Started Q3 0% 0%
TBD Planning Site Transition to MIS Not Started Q3 0% 0%
NPRR222 Half Hour Start Unit RUC Clawback Not Started Q4 0% 0%
TBD Endpoint Security Phase 2 Not Started Q4 0% 0%
NPRR272Definition and Participation of Quick Start Generation Resources
Not Started Q3 0% 0%
NPRR207 Unit Deselection Not Started Q3 0% 0%
NPRR313Updating the Term Resource Plan to Current Operating Plan / Availability Plan
Not Started Q2 0% 0%
NPRR383 Unconfirmed Trades Reports Not Started Q2 0% 0%
NPRR377 Alternate Inputs to Base Point Deviation Charge Not Started Q3 0% 0%
NPRR327 State Estimator Data Redaction Methodology Not Started Q3 0% 0%
NPRR407 Credit Monitoring Posting Requirements Not Started Q4 0% 0%
NPRR422 Public DAM Shift Factors Not Started Q2 0% 0%
NPRR397 Balance of the Day Ancillary Service Market Not Started Q3 0% 0%
NPRR419Revise Real Time Energy Imbalance and RMR Adjustment Charge
Not Started Q3 0% 0%
SCR768Automatic Non-Spin Redeployment and Deployment Based on Resource Availability
Not Started Q2 0% 0%
Schedule Status
2012 Variance
Total Variance
45
ERCOT Portfolio Stoplight Report (as of 5/7/2012)
PROJECTS COMPLETED IN 2012 (Count = 8) Sorted by Project Number $ 805,726 $ 1,574,621 $ 46,456,473 $ 45,527,866
004_01 Secure Remote Access Management (SRAM) Complete 12/5/2011 3/7/2012 3/7/2012 0% 6 -100% 9%
007_01 Taylor Facility Remodel Complete 9/14/2011 1/15/2012 1/25/2012 2 -8% 6 -999% 7%
013_01 MMS 2012 Release 1: NPRR321/NPRR326/NPRR355 Complete 12/14/2011 2/23/2012 2/23/2012 0% 4% 5%
025_52 HP Openview Upgrade Complete 11/1/2011 12/29/2011 4/1/2012 3 -162% 5 -9% 0%
11000_01 Data Center Buildout Closing 1/3/2011 1/31/2012 1/30/2012 0% 9 -115% 1%
NPRR395 CRR Auction Offer Award Disclosure Closing 2/29/2012 4/25/2012 4/27/2012 -3% 8% 8%
SCR761Provide Price Republication Notifications via API and Provide Price Corrections via XML
Complete 10/5/2011 3/2/2012 2/28/2012 2% 5 -362% 1 -26%
SCR764 Public Access to Select MIS Dashboards Complete 7/24/2011 12/9/2011 2/28/2012 1 -58% 5 -7% -1%
SUMMARYSum of 2012
Budgets2012 Forecast
SpendSum of Total
BudgetsTotal Forecast
Spend
Projects In Flight 12,206,660$ 12,230,950$ 21,873,867$ 21,188,793$ Projects Not Yet Started 7,517,312$ TBD 12,028,207$ TBDProjects Completed 805,726$ 1,574,621$ 46,456,473$ 45,527,866$
TOTAL 20,529,698$ 13,805,571$ 80,358,547$ 66,716,659$
15,000,000$
1
2
3
4
5
6
7
8
9
2012 Project Funding
-2% KPI Budget Measure - Execution/Completed Projects
-8% KPI Schedule Measure - Execution/Completed Projects
Fo
otn
ote
s
Change in design approach resulted in more funding and/or time required for delivery
Current phase took longer than expected, resulting in additional funding and/or time required
Vendor unable to complete w ork planned for 2011
Added scope resulted in more funding and/or time required for delivery
Dates below are final Execution phase dates
Labor hours planned for 2011 occurred in 2012
Purchased items planned for 2011 arrived in 2012
Contract labor replaced FTE labor (2 instances)
Current phase requiring more labor than expected, resulting in additional funding and/or time required
Invalid assumption for 2011 accounting related to treatment of prepaids and hardw are installation
ERCOT PublicMay 15, 2012