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


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


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


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


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


15

County Location of Planned Generation with Interconnection Requests (all fuels) April 2012


16

County Location of Planned Generation with Interconnection Requests (Wind) April 2012


17

Wind Generation – April 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


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


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


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


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


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)


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


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


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


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


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


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


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.


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


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


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).


36

ERCOT Wide Load Volumes by Meter Type – INITIAL Settlement – April 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


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


40

Retail Performance Measures (Priority Move-In) – April 2012




41

Retail Performance Measures (Standard Move-In) – April 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


May 15, 2012 ERCOT Public

Project Number

Project Name PhaseBaseline Phase

StartBaseline Phase

FinishScheduled

Phase FinishSum of 2012


SpendSum of Total


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


NPRR207 Unit Deselection Not Started Q3 0% 0%

NPRR313Updating the Term Resource Plan to Current Operating Plan / Availability Plan


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


SCR768Automatic Non-Spin Redeployment and Deployment Based on Resource Availability


Schedule Status

2012 Variance

Total Variance

45


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


SpendSum of Total


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$

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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


Documents

ERCOT Monthly Operational Overview ( April 2012 ) May 15, 2012