Market Highlights 1 (February 8 February 21)

Transcription

1 Market Highlights 1 (February 8 February 21) The average DLAP price in the integrated forward market was $ The maximum and minimum DLAP prices were $66.54 and -$.44, respectively. The maximum and minimum PNode prices in the integrated forward market were $15. and -$15.16 respectively. The top two interties congested in the integrated forward market were MALIN5 and NOB_ITC. Congestion rents in these two weeks totaled $7,635, The average day-ahead ancillary service prices were between $. and $ Approximately percent of the RUC requirements were met from RA units. The average real-time FMM DLAP price was $25.73, with a maximum price of $ and a minimum price of -$ The maximum and minimum PNode prices in the FMM were $1,138.4 and -$8.47, respectively. Out of the total 1,344 FMM intervals, intervals saw DLAP prices above $25, and intervals saw DLAP prices below -$15. Out of the total 1,344 FMM intervals, 5 intervals saw ELAP prices above $25 and intervals saw ELAP prices below -$15. The average real-time FMM ELAP price was $21.5, with a maximum price of $1,26.79 and a minimum price of -$ The average real-time RTD DLAP price was $27.69, with a maximum price of $1,74.2 and a minimum price of -$ The maximum and minimum PNode prices in the RTD were $1,547.9 and -$624.69, respectively. Out of the total 4,32 RTD intervals, 44 intervals saw DLAP prices above $25 and 1 intervals saw DLAP prices below -$15. Out of the total 4,32 RTD intervals, 148 intervals saw ELAP prices above $25 and 1 intervals saw ELAP prices below -$15. The average real-time RTD ELAP price was $21.71, with a maximum price of $1,184.5 and a minimum price of - $ Root cause for daily high price events are noted in Table 1. Trade Date RTD Feb 8 HE 16 RTD Feb 9 HE 15 int 5 RTD Feb 9 HE 15 int 11-12; Feb 1 HE 15 RTD Feb 1 HE 16 Table 1 RTD Intervals Root Cause Renewable deviation and load changes Congestion on PATH15_S-N, load changes and generator de-rate Renewable deviation and re-dispatch of resources 1 A description of the metrics presented in this report is available at Market Quality and Renewable Integration/J.Sage 1

2 2-Feb GW Trade Date RTD Feb 11 HE 15 RTD Feb 12 HE 6 RTD Feb 12 HE 7 RTD Feb 12 HE 18 RTD Feb 15 HE 2 RTD Feb 16 HE 16 RTD Feb 16 HE 17 RTD Feb 17 HE 18 RTD Feb 17 HE 2 RTD Feb 2 HE 14 RTD Feb 2 HE 17 int 8 HE 18 int 1 RTD Feb 2 HE 18 int 3 RTD Feb 21 HE 7, 9, 1, 11 Table 1 RTD Intervals Root Cause Renewable deviation and re-dispatch of resources Load changes Load changes and re-dispatch of resources Load changes Renewable deviation, load changes and re-dispatch of resources Reduction of net import, load changes and renewable deviation Reduction of net import and renewable deviation Congestion on PATH15_S-N Renewable deviation and re-dispatch of resources Reduction of net import and generator de-rate Figure 1: Day-Ahead (IFM) LAP LMP and Cleared Bid-In Demand PGAE SCE SDGE VEA Cleared Bid-In Demand (GW) Market Quality and Renewable Integration/J.Sage 2

3 2-Feb Congestion Rents (in Millions) Figure 2: Day-Ahead Congestion Rents $1.4 $1.2 $1. $.8 $.6 $.4 $.2 $. Flow-Gates MALIN5 NOB_ITC Figure 3: Day-Ahead Congestion Rents for Flow-Based Constraints Congestion Transmission Constraint Rent 782_TL234_IV_SPS_NG $ 1,313, PATH15_S-N $ 1,11, _OLD TOWN_23_2254_MISSION _23_BR_1 _1 $ 6, _D-VISTA2_OOS_SOL5_NG $ 398, _IMPRLVLY_23_2236_IMPRLVLY_5_XF_81 $ 384, _DOUBLTTP_138_223_FRIARS _138_BR_1 _1 $ 38,22.62 HUMBOLDT_IMP_NG $ 98, _MAGUNDEN_23_24153_VESTAL _23_BR_1 _1 $ 87, _GRNT HLL_138_22852_TELECYN _138_BR_1 _1 $ 6, _OLDTWNTP_23_2254_MISSION _23_BR_1 _1 $ 47, _WHEELER _7._34756_WHEELER _115_XF_2 $ 41, _MISSION _138_22865_GRNT HLL_138_BR_1 _1 $ 39, _CASCADE _6._31581_OREGNTRL_6._BR_1 _1 $ 26, _TL 23S_OVERLOAD_NG $ 26, _JESSTAP _115_31464_COTWDPGE_115_BR_1 _1 $ 22, _SANMATEO_115_33315_RAVENSWD_115_BR_1 _1 $ 15, _MIRAMAR _69._22756_SCRIPPS _69._BR_1 _1 $ 15, _BANGOR _6._3238_COLGATE _6._BR_1 _1 $ 14, _COTWDPGE_115_315_COTTNWD _23_XF_1 $ 1, Market Quality and Renewable Integration/J.Sage 3

4 2-Feb Figure 3: Day-Ahead Congestion Rents for Flow-Based Constraints (cont) Congestion Transmission Constraint Rent 32314_SMRTSVLE_6._32316_YUBAGOLD_6._BR_1 _1 $ 2, _HYMPOMJT_6._31553_BIG BAR _6._BR_1 _1 $ 1, _KESWICK _6._31582_STLLWATR_6._BR_1 _1 $ 1, _HUMBOLDT_6._3188_HMBLT JT_6._BR_1 _1 $ 215. Total $ 4,69, Figure 4: Day-Ahead (IFM) Average A/S Price Non Spin Spin Reg Up Reg Dn Mile Up Mile Dn Market Quality and Renewable Integration/J.Sage 4

5 2-Feb 8-Feb 2-Feb Figure 5: Day-Ahead Average RUC Price Figure 6: Real-Time FMM Average A/S Price Non Spin Spin Reg Up Reg Dn Mile Up Mile Dn Market Quality and Renewable Integration/J.Sage 5

6 2-Feb 8-Feb 2-Feb Figure 7: Real-Time FMM DLAP LMP PGAE SCE SDGE VEA Figure 8: Real-Time RTD DLAP LMP PGAE SCE SDGE VEA Market Quality and Renewable Integration/J.Sage 6

7 2-Feb 8-Feb 2-Feb Figure 9: Real-Time FMM ELAP LMP AZPS NEVP PACE PACW PSEI Figure 1: Real-Time RTD ELAP LMP AZPS NEVP PACE PACW PSEI Market Quality and Renewable Integration/J.Sage 7