Market Highlights 1 (November 16 November 29)
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1 Market Highlights 1 (November 16 November 29) The average DLAP price in the integrated forward market was $ The maximum and minimum DLAP prices were $8.18 and -$.8, respectively. The maximum and minimum PNode prices in the integrated forward market were $78.89 and -$3. respectively. The top two interties congested in the integrated forward market were PALOVRDE_ITC and NOB_ITC. Congestion rents in these two weeks totaled $27,34, 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 $27.92, with a maximum price of $57.19 and a minimum price of -$ The maximum and minimum PNode prices in the FMM were $68.41 and -$43.4, respectively. Out of the total 1,344 FMM intervals, 3 intervals saw DLAP prices above $25 intervals saw DLAP prices below -$. Out of the total 1,344 FMM intervals, 5 intervals saw ELAP prices above $25 and intervals saw ELAP prices below -$. The average real-time FMM ELAP price was $21.86, with a maximum price of $ and a minimum price of -$ The average real-time RTD DLAP price was $36.43, with a maximum price of $1,86.27 and a minimum price of -$ The maximum and minimum PNode prices in the RTD were $1, and -$957.85, respectively. Out of the total 4,32 RTD intervals, 92 intervals saw DLAP prices above $25 and intervals saw DLAP prices below -$. Out of the total 4,32 RTD intervals, 163 intervals saw ELAP prices above $25 and 14 intervals saw ELAP prices below -$. The average real-time RTD ELAP price was $23.83, with a maximum price of $1,. and a minimum price of -$5.63. Root cause for daily high price events are noted in Tables 1 and 2 Trade Date FMM Nov 2 HE 18 FMM Nov 23 HE 13 FMM Nov 28 HE 18 Table 1 FMM Intervals Root Cause Load and renewable forecast changes Congestion on OMS 4497 TL2355_NG and renewable forecast changes Congestion on OMS 4416 TL2355_NG and load changes 1 A description of the metrics presented in this report is available at Market Quality and Renewable Integration/J.Sage 1
2 GW Table 2 RTD Intervals Trade Date Root Cause RTD Nov 16 HE 8 Renewable deviation RTD Nov 16 HE 11,, 16, 17, 19; Nov 17 HE 2, Load changes and renewable deviation 4, 5, 8, 16 RTD Nov 16 HE 12 Congestion on LBN_S-N and renewable deviation RTD Nov 17 HE 8 Renewable deviation RTD Nov 2 HE 9, 13, 14, Load changes and renewable deviation RTD Nov 21 HE 16 Load changes, renewable deviation and re-dispatch of resources RTD Nov 23 HE 1, 11, 12, 13, 16 Congestion on OMS 4497 TL2355_NG and renewable forecast changes RTD Nov 23 HE 19 Congestion on 2486_LUGO _5_24238_RANCHVST_5_BR_1 _1 RTD Nov 26 HE 14, Load changes and renewable deviation RTD Nov 27 HE 14, Renewable deviation RTD Nov 28 HE 16, 17 Load changes and renewable deviation RTD Nov 28 HE 17, 18 Congestion on OMS 4416 TL2355_NG RTD Nov 29 HE 5, 6 Reduction of net import RTD Nov 29 HE 18 Generator de-rates and re-dispatch of resources 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 Congestion Rents (in Millions) Figure 2: Day-Ahead Congestion Rents $3.5 $3. $2.5 $2. $1.5 $1. $.5 $. Flow-Gates PALOVRDE_ITC NOB_ITC Figure 3: Day-Ahead Congestion Rents for Flow-Based Constraints Congestion Transmission Constraint Rent 2486_LUGO _5_26_VICTORVL_5_BR_1 _1 $ 4,24,631.1 OMS 4866 ELD-LUGO $ 3,56, PATH_S-N $ 2,919, _IMPRLVLY_23_2236_IMPRLVLY_5_XF_81 $ 1,98,22.21 OMS_ _SCIT_NG $ 1,34, _DOUBLTTP_138_223_FRIARS _138_BR_1 _1 $ 445, MIGUEL_BKs_MXFLW_NG $ 247, OMS IVALLEY BNK81_NG2 $ 148,86.1 OMS IVALLEY BNK81_NG1 $ 13, _HPLND JT_6._3126_HPLND JT_1_XF_2 $ 1, _GATES _23_397_MIDWAY _23_BR_1 _1 $ 91, _SYCAMORE_138_22124_CHCARITA_138_BR_1 _1 $ 52, _LA FRESA_23_2465_HINSON _23_BR_1 _1 $ 42, _ESCNDIDO_69._22724_SANMRCOS_69._BR_1 _1 $ 23, HUMBOLDT_IMP_NG $ 18, _WHEELER _7._34756_WHEELER _1_XF_2 $ 13, _MOSSLD _23_379_PANOCHE _23_BR_1 _1 $ 12, _CISCO GR_6._32372_SPAULDNG_6._BR_1 _1 $ 7, Market Quality and Renewable Integration/J.Sage 3
4 Figure 3: Day-Ahead Congestion Rents for Flow-Based Constraints (cont) Congestion Transmission Constraint Rent 3112_NEWBURG _6._31_RIODLLTP_6._BR_1 _1 $ 6, _COTWDPGE_1_3_COTTNWD _23_XF_1 $ 5, _HGHLNDJ2_1_3195_CORTINA _1_BR_1 _1 $ 5, IID-SCE_BG $ 5, _TL 23S_OVERLOAD_NG $ 4, _HUMBOLDT_1_31452_TRINITY _1_BR_1 _1 $ 3, _HYMPOMJT_6._353_BIG BAR _6._BR_1 _1 $ 2, _MPLE CRK_6._3193_HYMPOMJT_6._BR_1 _1 $ _SWNS FLT_6._3111_BRDGVLLE_6._BR_1 _1 $ _HPLND JT_6._3137_CLVRDLJT_6._BR_1 _1 $ _JESSTAP _1_31464_COTWDPGE_1_BR_1 _1 $ _DRUM _1_32222_DTCH2TAP_1_BR_1 _1 $ _SANYSDRO_69._2268_OTAY TP_69._BR_1 _1 $ Total $ 14,24, 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 16-Nov 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 16-Nov 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 16-Nov 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
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