Monthly Report. January Rick Gonzales Rana Mukerji Robert Fernandez

Transcription

1 Monthly Report January 2014 Rick Gonzales Rana Mukerji Robert Fernandez

2 TABLE OF CONTENTS Operations Performance Metrics Report Market Operation s Report Daily Loads Project Status Report Regulatory Filings January 2014

3 Operations Performance Metrics Monthly Report January 2014 Report Operations & Reliability Department New York Independent System Operator Prepared by NYISO Operations Analysis and Services, based on settlements initial invoice data collected on or before February 10, 2014.

4 Table of Contents Highlights Operations Performance Reliability Performance Metrics Alert State Declarations Major Emergency State Declarations IROL Exceedance Times Balancing Area Control Performance Reserve Activations Disturbance Recovery Times Load Forecasting Performance Wind Forecasting Performance Wind Curtailment Performance Lake Erie Circulation and ISO Schedules Broader Regional Market Performance Metrics Ramapo Interconnection Congestion Coordination Monthly Value Ramapo Interconnection Congestion Coordination Daily Value Regional Generation Congestion Coordination Monthly Value Regional Generation Congestion Coordination Daily Value Market Performance Metrics RTM Congestion Residuals Monthly Trend RTM Congestion Residuals Daily Costs RTM Congestion Residuals Event Summary RTM Congestion Residuals Cost Categories DAM Congestion Residuals Monthly Trend DAM Congestion Residuals Daily Costs DAM Congestion Residuals Cost Categories NYCA Unit Uplift Components Monthly Trend NYCA Unit Uplift Components Daily Costs Local Reliability Costs Monthly Trend & Commitment Hours TCC Monthly Clearing Price with DAM Congestion ICAP Spot Market Clearing Price UCAP Awards 1

5 January 2014 Operations Performance Highlights Peak load of 25,738 MW occurred on 1/7/2014 HB 18 Demand response resources activated on 1/7/2014 All-time winter capability period peak load of 25,738 MW occurred on 1/7/2014 HB 18 0 hours of Thunder Storm Alerts was declared 0 hours of NERC TLR level 3 curtailment Broader Regional Market Coordination monthly value was $3.58M Broader Regional Market Coordination year-to-date value was $3.58M Statewide uplift cost monthly average was $(1.73)/MWh Local reliability uplift cost monthly average was $1.38/MWh 2

6 Reliability Performance Metrics Alert State Declarations Occurrences 25 0 Jan-13 Feb-13 Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan-14 Voltage Rating (SOL) Exceedance Thermal Rating (SOL) Exceedance Operating Reserve Deficiency Neighboring System in Voltage Reduction Interface Transfer Limit (IROL) Exceedance Frequency Threshold Exceedance Communication Degradation Adverse Operating Conditions ACE Threshold Exceedance The number and causes of Alert State declarations reflect system operating conditions beyond thresholds associated with Normal and Warning States. Declaration of the Alert State allows the NYISO to take corrective actions not available in the Normal and Warning States. Major Emergency State Declarations 10 8 Occurrences Jan-13 Feb-13 Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan-14 Voltage Rating (SOL) Exceedance Thermal Rating (SOL) Exceedance Operating Reserve Deficiency Neighboring System in Voltage Reduction Interface Transfer Limit (IROL) Exceedance Frequency Threshold Exceedance Communication Degradation Adverse Operating Conditions ACE Threshold Exceedance The number and causes of Major Emergency State declarations reflect system operating conditions beyond thresholds associated with the Alert State. Declaration of the Major Emergency State allows the NYISO to take additional corrective actions not available in the Alert State. 3

7 NERC IROL Time Over Limit Minutes 15 0 Jan-13 Feb-13 Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan-14 IROL Exceedance Time IROL Exceedance Time Limit For IROL exceedances leading to Major Emergency State declarations, the maximum IROL exceedence time is identified. IROL exceedances of less than thirty minutes are considered NERC compliant. NERC Control Performance Standards CPS-1 (%) CPS-2 (%) Jan-13 Feb-13 Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan CPS-1 CPS Limit CPS-2 The values of NERC Control Performance Standards (CPS-1 and CPS-2) are indicators of the NYISO Area resource and demand balancing. Values exceeding the identified thresholds are NERC compliant. 4

8 Reserve Activations Occurrences Jan-13 Feb-13 Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan-14 ACE Not Normal NYCA Loss < 500 MW Simultaneous Activation of Reserve NYCA Loss >= 500 MW NYISO Reserve Activations are indicators of the need to respond to unexpected operational conditions within the NYISO Area or to assist a neighboring Area (Simultaneous Activation of Reserves) by activating an immediate resource and demand balancing operation. DCS Event Time to ACE Recovery Minutes 6 0 Jan-13 Feb-13 Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan-14 NYISO ACE Recovery Time NERC DCS - ACE Recovery Time Limit For NYISO initiated Reportable Disturbances, the maximum ACE recovery time is identified. Recovery times of less than 15 minutes are considered NERC compliant. 5

9 Load Forecast Performance % % % % % MW % -1% 600-2% 400-3% 200-4% 0 Jan-13 Feb-13 Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan-14-5% Average Hourly Error MW Maximum Hourly Error MW Average Hourly Error % Day-Ahead Average Hourly Error % Hourly Error MW - Absolute value of the difference between the hourly average actual load demand and the average hour ahead forecast load demand. Average Hourly Error % - Average value of the ratio of hourly average error magnitude to hourly average actual load demand. Day-Ahead Average Hourly Error % - Average across all hours of the month of the absolute value of the difference between actual load demand and the Day-Ahead forecast load demand, divided by the actual load demand. Wind Forecast Performance Hour Ahead MW Error MW Jan-13 Feb-13 Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan-14 Average Hourly Error MW Maximum Hourly Error MW Hourly Error MW - Absolute value of the difference between the hourly average actual wind generation and the average hour ahead forecast wind generation. 6

10 Wind Forecast Performance Hour Ahead Percent Error Wind Capacity 1710MW MAE % Bias % MAE Forecast MAE Persistence Bias MAE Forecast - Avg actual wind generation - hour ahead forecast wind generation / Wind Capacity MAE Persistence - Avg actual wind generation - hour ahead actual wind generation / Wind Capacity Bias - Avg (actual wind generation - hour ahead forecast wind generation) / Wind Capacity 50 Wind Forecast Performance Hour Ahead Mean Absolute Percent Error Ramp Events - Hourly Changes That Exceed 20% (342MW) of Wind Capacity (1710MW) MAE % Date (Qualifying Ramp Intervals) MAE Forecast MAE Persistence MAE Forecast - Avg actual wind generation - hour ahead forecast wind generation / Wind Capacity MAE Persistence - Avg actual wind generation - hour ahead actual wind generation / Wind Capacity 7

11 Wind Forecast Performance Day Ahead Absolute Percent Error Wind Capacity 1710MW MAE % MAE Forecast Bias MAE Forecast - Avg actual wind generation - Day Ahead forecast wind generation / Wind Capacity Bias - Avg (actual wind generation - Day Ahead forecast wind generation) / Wind Capacity Wind Performance Monthly Production and Economic Curtailments Generated MWh 500, , , , , , , , ,000 50, ,000 40,500 36,000 31,500 27,000 22,500 18,000 13,500 9,000 4,500 0 Curtailed MWh Wind Generation Wind Curtailment Curtailment - Difference between Real-Time Wind Forecast and Economic Wind Output Limit 8

12 Lake Erie Circulation and ISO Net Interchange Schedules Monthly Averages ISO Net Interchange Schedule MW Circulation MW NY-IESO Sched MW PJM-NY Sched MW IESO-MISO Sched MW MISO-PJM Sched MW Circulation MW DAM On Peak MW DAM Off Peak MW Interchange schedules with positive values aggravate clockwise Lake Erie Circulation. Lake Erie Circulation and ISO Net Interchange Schedules Daily Averages ISO Net Interchange Schedule MW Circulation MW NY-IESO Sched MW PJM-NY Sched MW IESO-MISO Sched MW MISO-PJM Sched MW Circulation MW DAM On Peak MW DAM Off Peak MW Interchange schedules with positive values aggravate clockwise Lake Erie Circulation. 9

13 Broader Regional Market Performance Metrics Thousands $4,000 $3,500 Ramapo Interconnection Congestion Coordination Monthly Value Categories $3,000 $2,500 $2,000 $1,500 $1,000 $500 NY RECO January 2014 Ramapo Interconnection Congestion Coordination Daily Value Categories Thousands $800 $700 $600 $500 $400 $300 $200 $100 ($100) NY RECO 10

14 Ramapo Interconnection Congestion Coordination Category NY RECO Description Represents the value NY realizes from Market-to-Market Ramapo Coordination. When experiencing congestion, this includes (1) the estimated savings to NY for additional deliveries into NY, plus (2) PJM compensation to NY for additional deliveries into PJM (as compared to the Ramapo Target level, excluding RECO). This is net of any settlements to PJM when they are congested. Represents the value of PJM s obligation to deliver 80% of service to RECO load over Ramapo This includes (1) the estimated reduction in NYCA congestion due to the PJM delivery of RECO over Ramapo 5018, plus (2) PJM compensation to NY for NYCA congestion for the under-delivery or inability to deliver service to RECO load over Ramapo

15 Thousands $90 $80 Regional Generation Congestion Coordination Monthly Value Categories $70 $60 $50 $40 $30 $20 $10 NY Thousands $7 $6 January 2014 Regional Generation Congestion Coordination Daily Value Categories $5 $4 $3 $2 $1 NY 12

16 Regional Generation Congestion Coordination Category NY Description NYISO savings that result from PJM payments to NYISO when PJM s transmission use (PJM s market flow) is greater than PJM s entitlement of the NY transmission system and NYISO is incurring Western or Central NY congestion. Additionally, NYISO savings may result from the more efficient regional utilization of PJM s generation resources to directly address Western or Central NY transmission congestion. 13

17 Market Performance Metrics Balancing Market Congestion Residual Report Monthly Uplift Cost Categories $25,000 Thousands $20,000 $15,000 $10,000 $5,000 ($5,000) ($10,000) ($15,000) ($20,000) Storm Watch Costs Unscheduled Transmission Outage Interface Derate - NYISO Security Interface Derate - External Security Unscheduled Loop Flows M2M Settlement Cost not categorized Not Investigated January 2014 Balancing Market Congestion Residual Report Daily Uplift Cost Categories $3,000 $2,000 $1,000 Thousands ($1,000) ($2,000) ($3,000) ($4,000) ($5,000) ($6,000) Storm Watch Costs Unscheduled Transmission Outage Interface Derate - NYISO Security Interface Derate - External Security Unscheduled Loop Flows M2M Settlement Cost not categorized Not Investigated 14

18 Event Description January Dates 2 Early return to service Astoria Annex - East 13th Street 345kV (#Q35L) 24 2 Early return to service Freeport-Barrett 138kV (#459) 8,9 2 Early return to service Hudson-Farragut 345kV (#C3403) 3 2 Extended outage Hudson-Farragut 345kV (#C3403) 2 2 Extended outage Long Mountain-Pleasant Valley 345kV (#398) 14 2 Forced outage PJM Neptune 3 2 Forced outage Sprainbrook-East Garden City 345kV (#Y49) 6,7 2 Forced outage Sprainbrook-West 49th Street 345kV (#M52) 23,24 2 Forced outage Valley Stream-Jamaica 138kV (#901 L_M) 23 3 Derate AstoriaE-Hellgate 138kv (#34052) 2 3 Derate Central East 5,6,8,11,19,28,30 3 Derate Dunwoodie-Shore Road 345kV (#Y50) for l/o SCB:SPBK(RNS2): Y49 & M29 3,5 3 Derate Dysinger East 24 3 Derate East 179th Street-HellGate East 138kV (#15054) 24,29 3 Derate East Garden City-Valley Stream 138kV (#262) for l/o BUS:BARRETT 292 & 459 & G2 22,28,29,30 3 Derate Farragut-Rainey 345kV (#61) 23,24 3 Derate Farragut-Rainey 345kV (#63) 23 3 Derate Freeport-Newbridge 138kV (#461) 2,7,22,28,30 3 Derate Gardenville-Stolle Road 230kV (#66) for l/o TWR:GRADENVILLE 79 & Derate Huntley-Sawyer 230kV (#80) for l/o Sawyer-SUNY BUF 230kV (#79) 28 3 Derate Kent Avenue-Vernon 138kV (# ) 23 3 Derate Kent Avenue-Vernon 138kV ( ) for l/o SCB:GOWANUS(16):42&26 23,24 3 Derate Kent Avenue-Vernon 138kV ( ) for l/o SCB:GOWANUS(22):42231&G27&BEC 23 3 Derate Kent Avenue-Vernon 138kV ( ) for l/o SCB:GOWANUS(8):26&CG&VFT 24 3 Derate Kent Ave-Vernon 138kV (# ) for l/o TWR:GOETHALS 22& 21& A Derate MottHaven-Dunwoodie 345kV (#71) for l/o MottHaven-Dunwoodie 345kV (#72) 24,29 3 Derate Niagara-Packard 230kV (#61) for l/o TWR:PACKARD 62 & BP Derate Queensbridge-Vernon 138kV (#31282) 23 3 Derate Rainey-Vernon 138kV (#36311) 25 3 Derate West 49th Street-Sprainbrook 345kV (#M51) 24 3 Derate West 49th Street-Sprainbrook 345kV (#M51) for l/o SCB:SPBK(RS3):W75 & NYCA DNI Ramp Limit 3-9,12,19, Uprate Central East 3-9,19, Uprate MottHaven-Dunwoodie 345kV (#71) for l/o MottHaven-Dunwoodie 345kV (#72) Uprate West 49th Street-Sprainbrook 345kV (#M51) for l/o SCB:SPBK(RS3):W75 & ,31 4 HQ_CEDARS-NY Scheduling Limit 6,7,12 4 HQ_CHAT DNI Ramp Limit 22-27,29,31 4 HQ_CHAT Scheduling Limit 7,28 4 IESO_AC DNI Ramp Limit 2,8,12,15,31 4 IESO_AC-NY Scheduling Limit 2,7,9 4 NE_AC - NY Scheduling Limit 4-6,9,19,31 4 NE_AC DNI Ramp Limit 2,7,19,25,26,28 4 NE_NNC NY Scheduling Limit 2,3,6-9,12,25 4 PJM_AC DNI Ramp Limit 6-8,22-25,28,29 4 PJM_AC-NY Scheduling Limit 2,7 5 Lake Erie Clockwise Circulation, DAM-RTM exceeds 125MW; Central East 5,6,8,11,19,28,30,31 15

19 Real-Time Balancing Market Congestion Residual (Uplift Cost) Categories Category Cost Assignment Events Types Event Examples Storm Watch Zone J Thunderstorm Alert (TSA) TSA Activations Unscheduled Transmission Outage Market-wide Reduction in DAM to RTM transfers related to unscheduled transmission outage Forced Line Outage, Unit AVR Outages Interface Derate - NYISO Security Market-wide Reduction in DAM to RTM transfers not related to transmission outage Interface Derates due to RTM voltages Interface Derate - External Security Market-wide Reduction in DAM to RTM transfers related to External Control Area Security Events TLR Events, External Transaction Curtailments Unscheduled Loop Flows Market-wide Changes in DAM to RTM unscheduled loop flows impacting NYISO Interface transmission constraints DAM to RTM Clockwise Lake Erie Loop Flows greater than 125 MW M2M Settlement Market-wide Settlment result inclusive of coordianted redispatch and Ramapo flowgates Monthly Balancing Market Congestion Report Assumptions/Notes 1) Storm Watch Costs are identified as daily total uplift costs 2) Days with a value of BMCR less M2M Settlement of $100K/HR, shortfall of $200K/Day or more, or surplus of $100K/Day or more are investigated. 3) Uplift costs associated with multiple event types are apportioned equally by hour 16

20 DAM Congestion Residual Report Monthly Cost Categories Thousands ($25,000) ($20,000) ($15,000) ($10,000) ($5,000) $5,000 $10,000 $15,000 NYTO Outage Allocation Central East Commitment Derate External Outage Allocation Costs Not Categorized November 2013 DAM Congestion Residual Report Daily Cost Categories Thousands ($1,400) ($1,200) ($1,000) ($800) ($600) ($400) ($200) $200 NYTO Outage Allocation Central East Commitment Derate External Outage Allocation Costs Not Categorized 17

21 Day-Ahead Market Congestion Residual Categories Category Cost Assignment Events Types Event Examples NYTO Outage Allocation Responsible TO Direct allocation to NYTO's responsible for transmission equipment status change. DAM scheduled outage for equipment modeled inservice for the TCC Auction. External Outage Allocation All TO by Monthly Allocation Factor Direct allocation to transmission equipment status change caused by change in status of external equipment. Tie line required out-ofservice by TO of neighboring control area. Central East Commitment Derate All TO by Monthly Allocation Factor Reductions in the DAM Central East_VC limit as compared to the TCC Auction limit, which are not associated with transmission line outages. 18

22 Monthly Power Supplier Uplift Components Thousands $50,000 $45,000 $40,000 $35,000 $30,000 $25,000 $20,000 $15,000 $10,000 $5,000 DAM BPCG State-wide RT BPCG State-wide DAMAP State-wide Import DAM BPCG State-wide Import RT GP State-wide DAM BPCG Local Reliability RT BPCG Local Reliability DAMAP Local Reliability MOB Thousands $7,000 $6,000 January 2014 Daily Power Supplier Uplift Components $5,000 $4,000 $3,000 $2,000 $1,000 DAM BPCG State-wide RT BPCG State-wide DAMAP State-wide Import DAM BPCG State-wide Import RT GP State-wide DAM BPCG Local Reliability RT BPCG Local Reliability DAMAP Local Reliability MOB 19

23 Thousands $25,000 Local Reliability Cost Monthly RT BPCG, DAM BPCG, DAMAP & Minimum Oil Burn Costs $20,000 $15,000 $10,000 $5,000 CON ED NY CITY LIPA LONG ISLAND 2000 January 2014 Local Reliability Commitment Hours Monthly DARU & SRE Hours CON ED NY CITY LIPA LONG ISLAND NYCA ARTHUR_KILL_3 ASTORIA 5 NEG NORTH_FLCN_SEA NORTHPORT 1 NORTHPORT 2 NORTHPORT 3 NORTHPORT 4 PORT_JEFF_4 RAVENSWOOD 1 RAVENSWOOD 2 AST_ENERGY_2_CC4 BETHLEHEM GS2 BETHLEHEM GS3 EMPIRE_CC_1 ARTHUR_KILL_2 RAVENSWOOD 4 ROSETON 1 EMPIRE_CC_2 OSWEGO 5 ATHENS_STG_2 20

24 Thousands $3,000 $2,500 Local Reliability Cost Monthly RT BPCG, DAM BPCG & DAMAP Costs $2,000 $1,500 $1,000 $500 NMPC WEST NYSEG CENTRAL NMPC GENESEE NMPC MOHAWK VLY O&R HUDSON VLY NMPC CAPITAL NYSEG WEST CENT HUD HUDSON VLY RG&E GENESEE 800 January 2014 Local Reliability Commitment Hours Monthly DARU & SRE Hours NMPC WEST INDECK OLEAN - ARR-23 DUNKIRK 2 - ARR-51 21

25 $45 TCC & Day Ahead Market Selected Internal Path Congestion TCC Monthly Reconfiguration Auction vs. Monthly DAM Average $40 $35 $30 $/MW Hour $25 $20 $15 $10 $5 ($5) West Dunwoodie TCC Auction Dunwoodie LI TCC Auction Dunwoodie NYC TCC Auction West Dunwoodie DAM Congestion Dunwoodie LI DAM Congestion Dunwoodie NYC DAM Congestion $60 TCC & Day Ahead Market West to Dunwoodie Path Congestion TCC Monthly Reconfiguration Auction vs. Monthly DAM Average $50 $40 $/MW Hour $30 $20 $10 ($10) ($20) West Central TCC Auction Central Capital TCC Auction Capital Hud VL TCC Auction Hud VL Dunwoodie TCC Auction West Central DAM Congestion Central Capital DAM Congestion Capital Hud VL DAM Congestion Hud VL Dunwoodie DAM Congestion 22

26 $10 TCC & Day Ahead Market Selected External Path Congestion TCC Monthly Reconfiguration Auction vs. Monthly DAM Average ($10) $/MW Hour ($20) ($30) ($40) ($50) ($60) ($70) ($80) PJM Central TCC Auction NE Central TCC Auction OH Central TCC Auction HQ Central TCC Auction PJM Central DAM Congestion NE Central DAM Congestion OH Central DAM Congestion HQ Central DAM Congestion 23

27 ICAP Spot Market Clearing Price $18.00 $16.00 $14.00 $12.00 $/kw-month $10.00 $8.00 $6.00 $4.00 $ Feb-13 Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan-14 Feb-14 LI NYC NYCA UCAP Sales Capacity (GW) Feb-13 Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan-14 Feb-14 ROS - Gen Sold ROS - Externals ROS - Exports ROS - SCR Sold NYC - Gen Sold NYC - SCR Sold LI - Gen Sold LI - SCR Sold LI - Gen Unsold LI - SCR Unsold NYC - Gen Unsold NYC - SCR Unsold ROS - Gen Unsold ROS - SCR Unsold 24

28 Market Performance Highlights for January 2014 LBMP for January is $183.25/MWh; 176% higher than $66.39/MWh in December 2013 and 130% higher than $79.77/MWh in January Day Ahead and Real Time Load Weighted LBMPs are ~170% higher compared to December. January 2014 average year-to-date monthly cost of $185.55/MWh is a 125% increase from $82.34/MWh in January Average daily sendout is 475 GWh/day in January; higher than 450 GWh/day in December 2013 and 453 GWh/day in January Natural gas prices were higher compared to the previous month, and distillate prices were mixed compared to the previous month. Natural Gas (Transco Z6 NY) was $27.43/MMBtu, up 394% from $5.55/MMBtu in December. Jet Kerosene Gulf Coast was $21.65/MMBtu, down from $21.93/MMBtu in December. Ultra Low Sulfur No.2 Diesel NY Harbor was $22.26/MMBtu, up from $21.80/MMBtu in December. Uplift per MWh is lower compared to the previous month. Uplift (not including NYISO cost of operations) is (.36)/MWh; lower than (.25)/MWh in December. The Local Reliability Share is $1.38/MWh, higher than.12 in December. The Statewide Share is ($1.73)/MWh, lower than (.37)/MWh in December. TSA $ per NYC MWh is.00/mwh. Total uplift costs (Schedule 1 components including NYISO Cost of Operations) are lower than December. 2/10/2014 Market Mitigation and Analysis

29 $440 $420 $400 $380 $360 $340 $320 $300 $280 $260 $240 $220 $200 $180 $160 $140 $120 $100 $80 $60 $40 $20 * Excludes ICAP payments. Market Mitigation and Analysis Prepared: 2/7/2014 8:33 AM A Data reflects true-ups thru Sept TIMESTAMP 1/9/2014 1/18/2014 1/27/2014 2/5/2014 2/14/2014 2/23/2014 3/4/2014 3/13/2014 3/22/2014 3/31/2014 4/9/2014 4/18/2014 4/27/2014 5/6/2014 5/15/2014 5/24/2014 6/2/2014 6/11/2014 6/20/2014 6/29/2014 7/8/2014 7/17/2014 7/26/2014 8/4/2014 8/13/2014 8/22/2014 8/31/2014 9/9/2014 9/18/2014 9/27/ /6/ /15/ /24/ /2/ /11/ /20/ /29/ /8/ /17/ /26/2014 Daily NYISO Average Cost/MWh (Energy & Ancillary Services)* 2013 Annual Average $59.13/MWh January 2013 YTD Average $82.34/MWh January 2014 YTD Average $185.55/MWh

30 NYISO Average Cost/MWh (Energy and Ancillary Services) * from the LBMP Customer point of view 2014 January February March April May June July August September October November December LBMP NTAC 0.56 Reserve 0.78 Regulation 0.27 NYISO Cost of Operations 0.69 Uplift (0.36) Uplift: Local Reliability Share 1.38 Uplift: Statewide Share (1.73) Voltage Support and Black Start 0.36 Avg Monthly Cost Avg YTD Cost TSA $ per NYC MWh January February March April May June July August September October November December LBMP NTAC Reserve Regulation NYISO Cost of Operations Uplift 0.21 (0.15) (0.33) (0.04) 0.16 (0.06) (0.25) Uplift: Local Reliability Share Uplift: Statewide Share (0.23) (0.55) (0.52) (0.35) (0.17) (0.31) 0.80 (0.46) (0.36) (0.21) (0.25) (0.37) Voltage Support and Black Start Avg Monthly Cost Avg YTD Cost TSA $ per NYC MWh January February March April May June July August September October November December LBMP NTAC Reserve Regulation NYISO Cost of Operations Uplift (0.18) (0.11) (0.33) (0.11) Uplift: Local Reliability Share Uplift: Statewide Share (0.05) (0.10) (0.19) (0.25) (0.36) 0.19 (0.26) (0.61) (0.59) (0.41) Voltage Support and Black Start Avg Monthly Cost Avg YTD Cost TSA $ per NYC MWh * Excludes ICAP payments. Data reflects true-ups thru Sept Market Mitigation and Analysis Prepared: 2/7/2014 8:28 AM B

31 NYISO Dollar Flows - Uplift- OATT Schedule 1 components - Data through January 31, 2014 $100,000 Jan-13 Feb-13 Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan-14 Feb-14 Mar-14 Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 $80,000 $60,000 Bid Production Cost Guarantee Balancing Local Reliability Balancing $40,000 NYISO Cost of Operations $20,000 Local Reliability DAM Thousands Bid Production Cost Guarantee DAM -$20,000 Contract Balancing DAM Residuals DAM -$40,000 Residuals Balancing -$60,000 Contract Balancing DAM Bid Production Cost Guarantee DAM Local Reliability DAM Bid Production Cost Guarantee DAM Virtual NYISO Cost of Operations Bid Production Cost Guarantee Balancing Local Reliability Balancing Residuals DAM Residuals Balancing Net DAM Contract Balancing amounts are for payments made to generating units to make them whole for being dispatched below their Day-Ahead schedule, as a result of out-of-merit dispatches. DAM Bid Production Cost Guarantees for Virtual Transactions are included in the chart and are shown from the inception of Virtual Transactions. These values are small and cannot be identified on the chart. DAM residuals consist of both energy and loss revenue collections and payments. By design, there is a net over collection of revenues due to the difference between the marginal losses paid to generation and the average losses charged to loads. Market Mitigation and Analysis Prepared: 2/7/2014 9:23 AM C

32 2014 January February March April May June July August September October November December Day Ahead Market MWh 16,034,264 DAM LSE Internal LBMP Energy Sales 52% DAM External TC LBMP Energy Sales 5% DAM Bilateral - Internal Bilaterals 36% DAM Bilateral - Importl/Non-LBMP Market Bilaterals 5% DAM Bilateral - Export/Non-LBMP Market Bilaterals 2% DAM Bilateral - Wheel Through Bilaterals 1% Balancing Energy Market MWh -240,397 Balancing Energy LSE Internal LBMP Energy Sales -237% Balancing Energy External TC LBMP Energy Sales 109% Balancing Energy Bilateral - Internal Bilaterals 21% Balancing Energy Bilateral - Importl/Non-LBMP Market Bilaterals 0% Balancing Energy Bilateral - Export/Non-LBMP Market Bilaterals 11% Balancing Energy Bilateral - Wheel Through Bilaterals -5% Transactions Summary LBMP 56% Internal Bilaterals 37% Import Bilaterals 5% Export Bilaterals 2% Wheels Through 1% Market Share of Total Load Day Ahead Market 101.5% Balancing Energy % Total MWH 15,793,868 Average Daily Energy Sendout/Month GWh 475 NYISO Markets Transactions 2013 January February March April May June July August September October November December Day Ahead Market MWh 15,140,096 14,116,189 14,250,091 12,963,905 13,451,310 14,872,971 17,974,314 16,090,437 14,021,472 13,411,499 13,692,854 15,406,816 DAM LSE Internal LBMP Energy Sales 56% 55% 56% 57% 56% 57% 59% 57% 55% 51% 52% 52% DAM External TC LBMP Energy Sales 4% 6% 3% 3% 1% 1% 1% 0% 0% 0% 3% 6% DAM Bilateral - Internal Bilaterals 38% 37% 38% 37% 37% 36% 33% 36% 38% 41% 40% 36% DAM Bilateral - Importl/Non-LBMP Market Bilaterals 0% 0% 0% 0% 3% 4% 5% 5% 4% 5% 4% 4% DAM Bilateral - Export/Non-LBMP Market Bilaterals 1% 1% 1% 1% 1% 1% 1% 1% 1% 1% 2% 1% DAM Bilateral - Wheel Through Bilaterals 1% 1% 1% 1% 1% 1% 1% 1% 1% 1% 1% 1% Balancing Energy Market MWh -471, , , , , , , , , , , ,397 Balancing Energy LSE Internal LBMP Energy Sales -131% -117% -127% -123% -133% -115% -189% -113% -120% -123% -134% -131% Balancing Energy External TC LBMP Energy Sales 33% 20% 23% 21% 35% 16% 78% 9% 11% 14% 23% 16% Balancing Energy Bilateral - Internal Bilaterals 4% 10% 11% 3% 5% 4% 11% 3% 6% 6% 4% 13% Balancing Energy Bilateral - Importl/Non-LBMP Market Bilaterals 0% 0% 0% 0% 0% 1% 4% 0% 0% 0% 0% 0% Balancing Energy Bilateral - Export/Non-LBMP Market Bilaterals 5% 3% 4% 5% 4% 2% 3% 1% 2% 4% 7% 5% Balancing Energy Bilateral - Wheel Through Bilaterals -11% -16% -11% -6% -11% -9% -7% 0% 1% 0% 1% -4% Transactions Summary LBMP 59% 59% 58% 59% 55% 56% 59% 54% 53% 49% 52% 56% Internal Bilaterals 39% 39% 40% 39% 39% 38% 34% 39% 41% 43% 41% 38% Import Bilaterals 0% 0% 0% 0% 4% 4% 5% 5% 4% 6% 4% 4% Export Bilaterals 1% 1% 2% 2% 2% 1% 1% 1% 2% 2% 2% 2% Wheels Through 1% 0% 1% 1% 0% 1% 1% 1% 1% 1% 1% 1% Market Share of Total Load Day Ahead Market 103.2% 104.8% 103.6% 104.2% 103.9% 104.7% 101.7% 106.0% 105.7% 105.4% 104.4% 103.6% Balancing Energy % -4.8% -3.6% -4.2% -3.9% -4.7% -1.7% -6.0% -5.7% -5.4% -4.4% -3.6% Total MWH 14,668,929 13,467,615 13,748,838 12,438,627 12,949,362 14,203,656 17,679,368 15,175,205 13,262,421 12,728,932 13,119,732 14,878,419 Average Daily Energy Sendout/Month GWh Balancing Energy: Load(MW) purchased at Real Time LBMP. Notes: Percent totals may not equal 100% due to rounding. The signs for the detail section intuitively reflect the direction of power flow eliminating the use of double negatives when Balancing Energy is negative. Virtual Transactions are not reflected in this chart. Market Mitigation and Analysis Prepared: 2/7/2014 9:26 AM D Data reflects true-ups thru Sept 2013.

33 NYISO Markets 2014 Energy Statistics January February March April May June July August September October November December DAY AHEAD LBMP Price * $ Standard Deviation $ Load Weighted Price ** $ RTC LBMP Price * $ Standard Deviation $ Load Weighted Price ** $ REAL TIME LBMP Price * $ Standard Deviation $ Load Weighted Price ** $ Average Daily Energy Sendout/Month GWh 475 NYISO Markets 2013 Energy Statistics January February March April May June July August September October November December DAY AHEAD LBMP Price * $69.17 $75.82 $45.97 $42.21 $45.87 $42.66 $56.90 $37.19 $38.32 $36.15 $39.18 $57.72 Standard Deviation $47.21 $29.98 $9.40 $7.84 $18.77 $17.98 $37.12 $11.85 $15.21 $9.15 $13.56 $28.61 Load Weighted Price ** $72.17 $77.95 $46.85 $43.13 $48.52 $45.32 $61.77 $39.00 $40.47 $37.37 $40.58 $60.27 RTC LBMP Price * $73.69 $64.15 $45.75 $40.50 $39.51 $42.00 $55.41 $35.90 $39.06 $34.08 $39.57 $54.53 Standard Deviation $88.27 $36.96 $22.62 $14.79 $24.44 $30.96 $58.54 $18.35 $60.70 $17.38 $30.77 $41.66 Load Weighted Price ** $77.52 $66.07 $46.79 $41.52 $42.14 $44.70 $61.64 $37.65 $43.41 $35.49 $41.56 $56.95 REAL TIME LBMP Price * $76.47 $64.87 $45.01 $42.74 $42.32 $43.93 $65.57 $37.03 $39.02 $36.02 $37.28 $52.49 Standard Deviation $83.80 $38.96 $16.27 $15.96 $26.99 $34.72 $89.92 $20.11 $36.85 $19.07 $25.69 $34.01 Load Weighted Price ** $81.71 $66.83 $45.94 $43.73 $45.50 $47.00 $76.32 $38.92 $43.28 $37.47 $38.75 $54.60 Average Daily Energy Sendout/Month GWh * Average zonal load weighted prices. ** Average zonal load weighted prices, load weighted in each hour. Market Mitigation and Analysis Prepared: 2/3/2014 2:03 PM E

34 NYISO Monthly Average Internal LBMPs $180 $160 $140 $120 $/MWh $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 Day Ahead Load Weighted Price 2014 RTC Load Weighted Price 2014 Real-Time Load Weighted Price 2013 Day Ahead Load Weighted Price 2013 RTC Load Weighted Price 2013 Real-Time Load Weighted Price Market Mitigation and Analysis Prepared: 2/3/2014 2:05 PM F

35 January 2014 Zonal LBMP Statistics for NYISO ($/MWh) WEST GENESEE NORTH CENTRAL MOHAWK VALLEY CAPITAL HUDSON VALLEY MILLWOOD DUNWOODIE NEW YORK CITY LONG ISLAND Zone A Zone B Zone D Zone C Zone E Zone F Zone G Zone H Zone I Zone J Zone K DAY AHEAD LBMP Unweighted Price * Standard Deviation RTC LBMP Unweighted Price * Standard Deviation REAL TIME LBMP Unweighted Price * Standard Deviation ONTARIO IESO HYDRO QUEBEC (Wheel) HYDRO QUEBEC (Import/Export) PJM NEW ENGLAND CROSS SOUND NORTHPORT- CABLE NORWALK NEPTUNE LINDEN VFT HUDSON Dennison Controllable Controllable Controllable Controllable Controllable Controllable Line Line Line Line Line Line Zone O Zone M Zone M Zone P Zone N DAY AHEAD LBMP Unweighted Price * Standard Deviation RTC LBMP Unweighted Price * Standard Deviation REAL TIME LBMP Unweighted Price * Standard Deviation * Straight LBMP averages Market Mitigation and Analysis Prepared: 2/4/2014 9:38 AM G

36 $220 West Zone A Monthly Average LBMP Prices $200 $180 $160 $140 $/MWh $120 $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Day Ahead Market Price RTC Market Price Real-Time Market Price Day Ahead Market Price RTC Market Price Real-Time Market Price Market Mitigation and Analysis Prepared: 2/4/ :45 AM H

37 $220 Capital Zone F Monthly Average LBMP Prices $/MWh $200 $180 $160 $140 $120 $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Day Ahead Market Price RTC Market Price Real-Time Market Price Day Ahead Market Price RTC Market Price Real-Time Market Price Market Mitigation and Analysis Prepared:2/4/ :46 AM I

38 Hudson Valley Zone G Monthly Average LBMP Prices $220 $200 $180 $160 $/MWh $140 $120 $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Day Ahead Market Price RTC Market Price Real-Time Market Price Day Ahead Market Price RTC Market Price Real-Time Market Price Market Mitigation and Analysis Prepared:2/4/ :46 AM J

39 NYC Zone J Monthly Average LBMP Prices $/MWh $220 $200 $180 $160 $140 $120 $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Day Ahead Market Price RTC Market Price Real-Time Market Price Day Ahead Market Price RTC Market Price Real-Time Market Price Market Mitigation and Analysis Prepared:2/4/ :46 AM K

40 $220 Long Island Zone K Monthly Average LBMP Prices $200 $180 $160 $140 $/MWh $120 $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Day Ahead Market Price RTC Market Price Real-Time Market Price Day Ahead Market Price RTC Market Price Real-Time Market Price Market Mitigation and Analysis Prepared:2/4/ :46 AM L

41 $/MW $205 $195 $185 $175 $165 $155 $145 $135 $125 $115 $105 $95 $85 $75 $65 $55 $45 $35 $25 $15 $5 -$5 -$15 -$25 -$35 -$45 -$55 -$65 -$75 DAM Zonal Unweighted Monthly Average LBMP Components thru January 31, 2014 WEST GENESE NORTH CENTRL MHK VL CAPITL HUD VL MILLWD DUNWOD N.Y.C. LONGIL OH HQ PJM NPX Average of DAM Energy Average of DAM Losses Average of DAM Congestion LBMP $/MW $205 $195 $185 $175 $165 $155 $145 $135 $125 $115 $105 $95 $85 $75 $65 $55 $45 $35 $25 $15 $5 -$5 -$15 -$25 -$35 -$45 -$55 -$65 -$75 RT Zonal Unweighted Monthly Average LBMP Components thru January 31, 2014 WEST GENESE E NORTH CENTRL MHK VL CAPITL HUD VL MILLWD DUNWOD D N.Y.C. LONGIL L OH HQ PJM NPX. Average of RT Energy Average of RT Losses Average of RT Congestion LBMP Market Mitigation and Analysis Prepared:2/4/ :48 PM M

42 External Comparison ISO-New England $220 Day Ahead Market External Zone Comparison: ISO-NE ($/MWh) $200 $180 $160 $140 $120 $100 $80 $60 $40 $ NYISO DAM view of NE Proxy bus 2014 ISO-NE DAM view of NYISO 2013 NYISO DAM view of NE Proxy bus 2013 ISO-NE DAM view of NYISO Real Time Market External Zone Comparison: ISO-NE ($/MWh) $220 $200 $180 $160 $140 $120 $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 NYISO RT view of NE Proxy bus 2014 NYISO RTC view of NE Proxy bus 2014 ISO-NE R/T view of NYISO 2013 NYISO RT view of NE Proxy bus 2013 NYISO RTC view of NE Proxy bus 2013 ISO-NE R/T view of NYISO Market Mitigation and Analysis Prepared: 2/4/ :47 AM N

43 External Comparison PJM $220 Day Ahead Market External Zone Comparison - PJM ($/MWh) $200 $180 $160 $140 $120 $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 NYISO DAM view of PJM Proxy bus 2014 PJM DAM view of NYISO 2013 NYISO DAM view of PJM Proxy bus 2013 PJM DAM view of NYISO $220 Real Time Market External Zone Comparison - PJM ($/MWh) $200 $180 $160 $140 $120 $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 NYISO RT view of PJM Proxy bus 2014 NYISO RTC view of PJM Proxy bus 2014 PJM R/T view of NYISO 2013 NYISO RT view of PJM Proxy bus 2013 NYISO RTC view of PJM Proxy bus 2013 PJM R/T view of NYISO Market Mitigation and Analysis Prepared: 2/4/ :47 AM O

44 External Comparison Ontario IESO Day Ahead Market External Zone Comparison - Ontario IESO ($/MWh) $220 $200 $180 $160 $140 $120 $100 $80 $60 $40 $ NYISO DAM view of OH Proxy bus 2014 Ontario IESO Pre-Dispatch (in US $) 2013 NYISO DAM view of OH Proxy bus 2013 Ontario IESO Pre-Dispatch (in US $) Real Time Market External Zone Comparison - Ontario IESO ($/MWh) $220 $200 $180 $160 $140 $120 $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 NYISO RT view of OH Proxy bus 2014 NYISO RTC view of OH Proxy bus 2014 Ontario IESO HOEP (in US $) 2013 NYISO RT view of OH Proxy bus 2013 NYISO RTC view of OH Proxy bus 2013 Ontario IESO HOEP (in US $) Notes: Exchange factor used for January 2014 was to US $ HOEP: Hourly Ontario Energy Price Pre-Dispatch: Projected Energy Price Market Mitigation and Analysis Prepared: 2/4/ :48 AM P

45 External Controllable Line: Cross Sound Cable (New England) $220 Day Ahead Market Comparison: Cross Sound Cable ($/MWh) $200 $180 $160 $140 $120 $100 $80 $60 $40 $ NYISO DAM view of Cross Sound Cable 2014 ISO-NE DAM view of Cross Sound Cable 2013 NYISO DAM view of Cross Sound Cable 2013 ISO-NE DAM view of Cross Sound Cable Real Time Market Comparison: Cross Sound Cable ($/MWh) $220 $200 $180 $160 $140 $120 $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 NYISO RT view of Cross Sound Cable 2014 NYISO RTC view of Cross Sound Cable 2014 ISO-NE R/T view of Cross Sound Cable 2013 NYISO RT view of Cross Sound Cable 2013 NYISO RTC view of Cross Sound Cable 2013 ISO-NE R/T view of Cross Sound Cable Note: ISO-NE Forecast is an advisory 18:00 day before. The DAM and R/T prices at the Shorham interface are used for ISO-NE. The DAM and R/T prices at the CSC interface are used for NYISO. Market Mitigation and Analysis Prepared: 2/4/ :48 AM Q

46 External Controllable Line: Northport - Norwalk (New England) $220 Day Ahead Market Comparison: Northport-Norwalk ($/MWh) $200 $180 $160 $140 $120 $100 $80 $60 $40 $ NYISO DAM view of Northport 2014 ISO-NE DAM view of Northport 2013 NYISO DAM view of Northport 2013 ISO-NE DAM view of Northport Real Time Market Comparison: Northport-Norwalk ($/MWh) $220 $200 $180 $160 $140 $120 $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 NYISO RT view of Northport 2014 NYISO RTC view of Northport 2014 ISO-NE R/T view of Northport 2013 NYISO RT view of Northport 2013 NYISO RTC view of Northport 2013 ISO-NE R/T view of Northport Note: ISO-NE Forecast is an advisory 18:00 day before. The DAM and R/T prices at the Northport 138 interface are used for ISO-NE. The DAM and R/T prices at the 1385 interface are used for NYISO. Market Mitigation and Analysis Prepared: 2/4/ :48 AM R

47 External Controllable Line: Neptune (PJM) $220 Day Ahead Market Comparison: Neptune ($/MWh) $200 $180 $160 $140 $120 $100 $80 $60 $40 $ NYISO DAM view of PJM Neptune 2014 PJM DAM view of NYISO Neptune 2013 NYISO DAM view of PJM Neptune 2013 PJM DAM view of NYISO Neptune Real Time Market Comparison: Neptune ($/MWh) $220 $200 $180 $160 $140 $120 $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 NYISO RT view of PJM Neptune 2014 NYISO RTC view of PJM Neptune 2014 PJM R/T view of NYISO Neptune 2013 NYISO RT view of PJM Neptune 2013 NYISO RTC view of PJM Neptune 2013 PJM R/T view of NYISO Neptune Market Mitigation and Analysis Prepared: 2/4/ :56 AM S

48 External Comparison Hydro-Quebec $220 Day Ahead Market External Zone Comparison - HQ ($/MWh) $200 $180 $160 $140 $120 $100 $80 $60 $40 $ NYISO DAM view of HQ - Wheel 2014 NYISO DAM view of HQ - Import/Export 2014 NYISO DAM view of Cedars - Denison 2013 NYISO DAM view of HQ - Wheel 2013 NYISO DAM view of HQ - Import/Export 2013 NYISO DAM view of Cedars - Denison Real Time Market External Zone Comparison - HQ ($/MWh) $220 $200 $180 $160 $140 $120 $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 NYISO RT view of HQ - Wheel 2014 NYISO RT view of HQ - Import/Export 2014 NYISO RT view of Cedars - Denison 2013 NYISO RT view of HQ - Wheel 2013 NYISO RT view of HQ - Import/Export 2013 NYISO RT view of Cedars - Denison Note: Hydro-Quebec Prices are unavailable. Market Mitigation and Analysis Prepared: 2/4/ :57 AM T

49 External Controllable Line: Linden VFT (PJM) $220 Day Ahead Market Comparison: Linden VFT ($/MWh) $200 $180 $160 $140 $120 $100 $80 $60 $40 $ NYISO DAM view of PJM Linden VFT 2014 PJM DAM view of NYISO Linden VFT 2013 NYISO DAM view of PJM Linden VFT 2013 PJM DAM view of NYISO Linden VFT Real Time Market Comparison: Linden VFT ($/MWh) $220 $200 $180 $160 $140 $120 $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 NYISO RT view of PJM Linden VFT 2014 NYISO RTC view of PJM Linden VFT 2014 PJM R/T view of NYISO Lindent VFT 2013 NYISO RT view of PJM Linden VFT 2013 NYISO RTC view of PJM Linden VFT 2013 PJM R/T view of NYISO Lindent VFT Market Mitigation and Analysis Prepared: 2/4/ :58 AM U

50 External Controllable Line: Hudson (PJM) $220 Day Ahead Market Comparison: HTP ($/MWh) $200 $180 $160 $140 $120 $100 $80 $60 $40 $ NYISO DAM view of PJM HTP 2014 PJM DAM view of NYISO HTP 2013 NYISO DAM view of PJM HTP 2013 PJM DAM view of NYISO HTP Real Time Market Comparison: HTP ($/MWh) $220 $200 $180 $160 $140 $120 $100 $80 $60 $40 $20 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2014 NYISO RT view of PJM HTP 2014 NYISO RTC view of PJM HTP 2014 PJM R/T view of NYISO HTP 2013 NYISO RT view of PJM HTP 2013 NYISO RTC view of PJM HTP 2013 PJM R/T view of NYISO HTP Market Mitigation and Analysis Prepared: 2/7/ :37 AM V *HTP June 2013 figures reflect partial month

51 NYISO Real Time Price Correction Statistics 2014 January February March April May June July August September October November December Hour Corrections Number of hours with corrections in the month 0 Number of hours in the month 744 % of hours with corrections in the month 0.00% % of hours with corrections year-to-date 0.00% Interval Corrections Number of intervals corrected in the month 0 Number of intervals in the month 9,232 % of intervals corrected in the month 0.00% % of intervals corrected year-to-date 0.00% Hours Reserved Number of hours reserved in the month 2 Number of hours in the month 744 % of hours reserved in the month 0.27% % of hours reserved year-to-date 0.27% Days to Correction * Avg. number of days to correction in the month 0.00 Avg. number of days to correction year-to-date 0.00 Days Without Corrections Days without corrections in the month 31 Days without corrections year-to-date January February March April May June July August September October November December Hour Corrections Number of hours with corrections in the month Number of hours in the month % of hours with corrections in the month 0.81% 0.45% 0.27% 0.14% 0.54% 0.42% 0.40% 0.00% 0.28% 0.00% 0.00% 0.00% % of hours with corrections year-to-date 0.81% 0.64% 0.51% 0.42% 0.44% 0.44% 0.43% 0.38% 0.37% 0.33% 0.30% 0.27% Interval Corrections Number of intervals corrected in the month Number of intervals in the month 9,104 8,230 9,026 8,727 9,083 8,740 9,079 9,002 8,760 9,041 8,854 9,073 % of intervals corrected in the month 0.14% 0.05% 0.02% 0.01% 0.24% 0.19% 0.04% 0.00% 0.03% 0.00% 0.00% 0.00% % of intervals corrected year-to-date 0.14% 0.10% 0.07% 0.06% 0.10% 0.11% 0.10% 0.09% 0.08% 0.07% 0.07% 0.06% Hours Reserved Number of hours reserved in the month Number of hours in the month % of hours reserved in the month 2.82% 0.45% 0.54% 0.56% 0.94% 0.56% 0.40% 0.00% 0.56% 0.00% 0.00% 0.13% % of hours reserved year-to-date 2.82% 1.69% 1.30% 1.11% 1.08% 0.99% 0.90% 0.79% 0.76% 0.69% 0.62% 0.58% Days to Correction * Avg. number of days to correction in the month Avg. number of days to correction year-to-date Days Without Corrections Days without corrections in the month Days without corrections year-to-date * Calendar days from reservation date. Market Mitigation and Analysis Prepared: 2/6/ :22 AM W

52 Percentage of Real-Time Corrections 4.0% 3.8% 3.5% 3.3% 3.0% 2.8% 2.5% 2.3% 2.0% 1.8% 1.5% 1.3% 1.0% 0.8% 0.5% 0.3% 0.0% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Monthly RT Hours Reserved 2014 Monthly RT Hours with Corrections 2014 Monthly RT Intervals Corrected 2014 RT Hours Reserved 2013 RT Hours with Corrections 2013 RT Intervals Corrected Annual average time period for making Price Corrections (from reservation date) * Average Days to Correction Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Monthly avg no. of days to correction Yearly avg no. of days to correction Monthly avg no. of days to correction Yearly avg no. of days to correction * Calendar days from reservation date. Market Mitigation and Analysis Prepared: 2/6/ :21 AM X.

53 NYISO Virtual Trading Average MWh per day 900, , , , , , ,000 Ave erage MWh/day 550, , , , , , , , , ,000 50,000 0 Jan-13 Feb-13 Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan-14 Feb-14 Mar-14 Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Virtual Supply Bid - Scheduled Virtual Supply Bid - Not Scheduled Virtual Load Bid - Scheduled Virtual Load Bid - Not Scheduled Posted Collateral MWhrs Market Mitigation and Analysis Prepared: 2/3/2014 2:14 PM Y

54 Virtual Load and Supply Zonal Statistics through January 31, ,000 30,000 25,000 Average MWh/day 20,000 15,000 10,000 5,000 0 WEST GENESE NORTH CENTRL MHK VL CAPITL HUD VL MILLWD DUNWOD N.Y.C. LONGIL Virtual Supply Bid - Scheduled Virtual Load Bid - Scheduled Virtual Supply Bid - Not Scheduled Virtual Load Bid - Not Scheduled Market Mitigation and Analysis Prepared: 2/3/2014 2:15 PM Z

55 Virtual Load and Supply Zonal Statistics (Average MWh/day) Virtual Load Bid Virtual Supply Bid Virtual Load Bid Virtual Supply Bid Virtual Load Bid Virtual Supply Bid Not Not Not Not Not Not Zone Date Scheduled Scheduled Scheduled Scheduled Zone Date Scheduled Scheduled Scheduled Scheduled Zone Date Scheduled Scheduled Scheduled Scheduled WEST Jan-14 6,213 5,063 2, MHK VL Jan DUNWOD Jan Feb-14 Feb-14 Feb-14 Mar-14 Mar-14 Mar-14 Apr-14 Apr-14 Apr-14 May-14 May-14 May-14 Jun-14 Jun-14 Jun-14 Jul-14 Jul-14 Jul-14 Aug-14 Aug-14 Aug-14 Sep-14 Sep-14 Sep-14 Oct-14 Oct-14 Oct-14 Nov-14 Nov-14 Nov-14 Dec-14 Dec-14 Dec-14 GENESE Jan , CAPITL Jan N.Y.C. Jan Feb-14 Feb-14 Feb-14 Mar-14 Mar-14 Mar-14 Apr-14 Apr-14 Apr-14 May-14 May-14 May-14 Jun-14 Jun-14 Jun-14 Jul-14 Jul-14 Jul-14 Aug-14 Aug-14 Aug-14 Sep-14 Sep-14 Sep-14 Oct-14 Oct-14 Oct-14 Nov-14 Nov-14 Nov-14 Dec-14 Dec-14 Dec-14 NORTH Jan ,579 1,592 HUD VL Jan LONGIL Jan Feb-14 Feb-14 Feb-14 Mar-14 Mar-14 Mar-14 Apr-14 Apr-14 Apr-14 May-14 May-14 May-14 Jun-14 Jun-14 Jun-14 Jul-14 Jul-14 Jul-14 Aug-14 Aug-14 Aug-14 Sep-14 Sep-14 Sep-14 Oct-14 Oct-14 Oct-14 Nov-14 Nov-14 Nov-14 Dec-14 Dec-14 Dec-14 CENTRL Jan , MILLWD Jan NYISO Jan Feb-14 Feb-14 Feb-14 Mar-14 Mar-14 Mar-14 Apr-14 Apr-14 Apr-14 May-14 May-14 May-14 Jun-14 Jun-14 Jun-14 Jul-14 Jul-14 Jul-14 Aug-14 Aug-14 Aug-14 Sep-14 Sep-14 Sep-14 Oct-14 Oct-14 Oct-14 Nov-14 Nov-14 Nov-14 Dec-14 Dec-14 Dec-14 Market Mitigation and Analysis Prepared: 2/3/2014 2:15 PM AA

56 100,000 NYISO Multi Hour Block Transactions Monthly Total MWh 90,000 80,000 70,000 60,000 50,000 40,000 30,000 20,000 10,000 0 Market Mitigation and Analysis Prepared: 2/3/2014 1:39 PM AB Total l monthly MWh Jan-13 Feb-13 Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan-14 Feb-14 Mar-14 Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Multi Hour Block Transaction Bid and Scheduled Multi Hour Block Transaction Bid - Not Scheduled

57 $40 East West NYISO Monthly Average Ancillary Service Prices Day Ahead Market $35 $30 $25 $20 $15 $10 $5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 10 Min Spin Res Avg East Min Non-Synch Avg East Min Op Res Avg East Regulation Average East Min Spin Res Avg West Min Non-Synch Avg West Min Op Res Avg West Regulation Average West Min Spin Res Avg East Min Non-Synch Avg East Min Op Res Avg East Regulation Average East Min Spin Res Avg West Min Non-Synch Avg West Min Op Res Avg West Regulation Average West Market Mitigation and Analysis Prepared: 2/3/2014 2:01 PM AC

58 NYISO Monthly Average Ancillary Service Prices RTC Market $40 $35 $30 East West $25 $20 $15 $10 $5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 10 Min Spin Res Avg East Min Non-Synch Avg East Min Op Res Avg East Regulation Average East Min Spin Res Avg West Min Non-Synch Avg West Min Op Res Avg West Regulation Average West NYCA Regulation Movement Average Min Spin Res Avg East Min Non-Synch Avg East Min Op Res Avg East Regulation Average East Min Spin Res Avg West Min Non-Synch Avg West Min Op Res Avg West Regulation Average West NYCA Regulation Movement Average Market Mitigation and Analysis. Prepared: 2/3/2014 2:01 PM AD

59 $40 NYISO Monthly Average Ancillary Service Prices Real Time Market $35 $30 East West $25 $20 $15 $10 $5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 10 Min Spin Res Avg East Min Non-Synch Avg East Min Op Res Avg East Regulation Average East Min Spin Res Avg West Min Non-Synch Avg West Min Op Res Avg West Regulation Average West NYCA Regulation Movement Average Min Spin Res Avg East Min Non-Synch Avg East Min Op Res Avg East Regulation Average East Min Spin Res Avg West Min Non-Synch Avg West Min Op Res Avg West Regulation Average West NYCA Regulation Movement Average Market Mitigation and Analysis Prepared: 2/3/2014 2:01 PM AE

60 NYISO Markets Ancillary Services Statistics - Unweighted Price ($/MWH) 2014 January February March April May June July August September October November December Day Ahead Market 10 Min Spin East Min Spin West Min Non Synch East Min Non Synch West Min East Min West 1.77 Regulation East Regulation West RTC Market 10 Min Spin East Min Spin West Min Non Synch East Min Non Synch West Min East Min West 0.08 Regulation East Regulation West NYCA Regulation Movement 0.28 Real Time Market 10 Min Spin East Min Spin West Min Non Synch East Min Non Synch West Min East Min West 0.92 Regulation East Regulation West NYCA Regulation Movement January February March April May June July August September October November December Day Ahead Market 10 Min Spin East Min Spin West Min Non Synch East Min Non Synch West Min East Min West Regulation East Regulation West RTC Market 10 Min Spin East Min Spin West Min Non Synch East Min Non Synch West Min East Min West Regulation East Regulation West NYCA Regulation Movement Real Time Market 10 Min Spin East Min Spin West Min Non Synch East Min Non Synch West Min East Min West Regulation East Regulation West NYCA Regulation Movement Market Mitigation and Analysis Prepared: 2/3/2014 2:02 PM AF June 2013 Regulation Movement is based on partial data.

61 NYISO In City Energy Mitigation - AMP (NYC Zone) Percentage of committed unit-hours mitigated 30% This chart shows energy mitigation of the generating units in the NYC zone. Only hours during which a generating unit is scheduled are counted toward the 100%. If a unit's bid is mitigated at any point during an hour, that entire hour is counted as mitigated. 25% Percent of unit hours mitigated 20% 15% 10% 5% 0% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec DAM % of unit hours mitigated Real Time % of unit hours mitigated DAM % of unit hours mitigated Real Time % of unit hours mitigated Market Mitigation and Analysis Prepared: 2/4/2014 2:20 PM AG

62 NYISO In City Energy Mitigation (NYC Zone) Monthly megawatt hours mitigated 300, , ,000 MWh mitigated 150, ,000 50,000 0 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec DAM MWh mitigated Real Time MWh mitigated DAM MWh mitigated Real Time MWh mitigated Market Mitigation and Analysis Prepared: 2/4/2014 2:22 PM AH

63 700, , , , , , ,000 0 Market Mitigation and Analysis Prepared: 2/3/2014 1:33 PM AI Jan-13 Feb-13 Mar-13 Average daily DAM MWh Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan-14 Feb-14 Mar-14 Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 NYISO Average Daily DAM Load Bid Summary MP Bid Load Accepted Physical Price Capped Load Accepted Virtual Supply Accepted Virtual Load Accepted NYISO Load Forecast

64 Monthly Implied Heat Rate mmbtu/mwh Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec mmbtu Day Ahead 2014 mmbtu RTC 2014 mmbtu Real Time 2014 mmbtu Day Ahead 2013 mmbtu RTC 2013 mmbtu Real Time 2013 Market Mitigation and Analysis Prepared: 2/4/2014 1:00 PM AJ

65 ONTARIO IMO (O) HYDRO QUEBEC (M) Super Zone - West NORTH (D) WEST (A) GENESEE (B) CENTRAL (C) MOHAWK VALLEY (E) CAPITAL (F) HUDSON VALLEY (G) NEW ENGLAND ISO (N) MILLWOOD (H) PJM RTO (P) DUNWOODIE (I) LONG ISLAND (K) NYC (J) Super Zone - East Market Mitigation and Analysis Prepared: 2/4/2014 2:39 PM AK