Grid Alpha

LYU LLC DBA Grid Alpha
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Grid Alpha turns real-time data from all nine North American power markets (ERCOT, PJM, CAISO, ISO-NE, NYISO, MISO, SPP, AESO, IESO) into short, trader-ready signal. Each episode reads the tape: fuel mix, LMP/DART spreads, congestion, storage response, and LinkedIn commentary from analysts, developers, and policy watchers who actually move size. No background music, no fluff, just the setups that matter this week for U.S. power and gas traders. Live dashboards at gridalpha.us.

  1. 7h ago

    SPP Duncan Nodes Split $183 as FERC Approves Topology Fix

    A $183.44/MWh intraday spread ripped through SPP's Oklahoma footprint in the 04:00 UTC interval on Aug. 22, with the maximum print landing at 11 p.m. local time Friday night. The high side: CSWSDUNCANLD1_69 at $171.78/MWh. The low side: CSWSDUNCTP4LDOMPA at negative $11.66, two AEP/CSWS Duncan-area nodes priced a world apart on the same system. The decomposition tells the whole story. Both nodes carried an identical $25.95 energy component; the gap is pure congestion. Duncan LD1 booked a $145.52 congestion adder while the Duncan tap node sat at negative $37.90, a one-sided load pocket with nowhere for local supply to go. The rest of the Oklahoma complex clustered near negative $8: CSWSDUNCN_ESLD138 at negative $8.56, WFECRUSSETTLD4 at negative $8.43, OKGERUSETLD1 at negative $8.03. This was not a regional scarcity event. It was a localized choke, and one open question matters here: which constraint bound, and whether an outage drove it. SPP logged at least 1,173 generation-capacity-on-outage records in the trailing week, with sampled coal outages running 2,278 to 3,428 MW. Sampled solar curtailment intervals showed zero MW curtailed, so renewables were not the binding story. One data caveat: several adjacent high-priced nodes in the same snapshot are stamped a day later, so treat the 08-22 header timestamp as the operative read. The timing is the angle. FERC approved SPP's topology optimization plan on Aug. 20, two days before this print, giving the ISO authority to reconfigure switching to relieve exactly this class of constraint cost. The precedent is MISO, whose market has saved nearly $100 million year-to-date under a similar reconfiguration approach. If SPP's implementation delivers even a fraction of that, congestion rents at chronically constrained pockets like Duncan compress over time. For traders, the near-term read is persistence. If the Duncan split extends beyond a single overnight interval, CSWS-area TCR and congestion exposure gets repriced fast; if it fades with returning coal capacity, this was an outage artifact, not a structural pocket. Watch the constraint-level shadow prices around the Duncan nodes versus the broader Oklahoma cluster near negative $8, and watch SPP's implementation timeline: the spread between today's congestion reality and tomorrow's optimization savings is the trade. > When two nodes sharing a fence line price $183 apart, congestion is the market; topology optimization is now the regulator's bet on killing it. Not investment advice. For informational purposes only. Grid Alpha — daily briefs · live dashboards, all nine markets · public call record

  2. 1d ago

    CAISO Spreads Hit $306; One Grid Alpha Call Missed

    The widest print of the week came Thursday night local time in CAISO: a $306.14/MWh maximum real-time nodal spread at the 04:55 UTC snapshot, 21:55 PDT. The tail of the distribution tells the story. THSP15GEN_ONPEAK-APND printed the top LMP at $306.14/MWh with a congestion component of $110.59 against an energy component near $188.74. At the other end, five APND scheduling nodes across AVA, AZPS, and BPAT paths, including MALIN, printed $0.00/MWh at 10:50 UTC Friday, 03:50 local. Zero, not deeply negative. The spread tape was wide and bifurcated, with congestion doing the work at both poles. The congestion signs matter. THPACWGEN_ONPEAK-APND carried a congestion component of -$94.42/MWh against an LMP of $88.31/MWh in the same 04:55 UTC interval, meaning PACW was trapped on the wrong side of a binding path while SP15 cleared at the system's top print. Behind the snapshot, the trailing seven days logged at least 1,668 CAISO curtailment events, with sampled solar rows at 0 MW and wind up to 1.627 MW. The count is large even if the sampled megawatts are small; the signal is frequency of dispatch intervention, not volume. Whether the 04:55 spread was outage-driven, ramp-driven, or a single binding constraint is not identified in the feed, and I won't pretend otherwise. East of the Rockies, the machinery was strain, not spreads. PJM recorded 147 daily outage records over seven days, with sampled forced outages up to 15,565 MW and maintenance up to 12,639 MW. MISO's estimated outage feed showed 84 records, with one sample at 15,015 MW derated and 12,515 MW forced, and the real-time binding-constraint feed returned at least 5,233 shadow-price events, a number that may be API-truncated. ISONE logged 326 real-time binding intervals, with the SYSTEM_10MINSYNC constraint showing a marginal value of 23.62 in samples. That is the backdrop for the evening hub strength the angle flags: heavy forced-outage stacks plus persistent binding constraints tighten the evening ramp. Exact peak levels are not in this week's feed, so the hub numbers stay out of this column until the data supports them. Now the housekeeping. One published call on this book failed to trigger: the CAISO HPLNDJT negative-LMP call missed at -28.99. The week's verified snapshot prints bottomed at $0.00/MWh on APND scheduling nodes, and no sustained deep-negative prints appear in the data here. A negative-LMP thesis needs renewable saturation plus congestion trapping, and the tape showed curtailment frequency but not the price outcome. We print the miss because a signal book that hides its losers is marketing, not research. The honest read: negative-price setups at scheduling nodes remain a watch item, not a triggered trade. What I'd watch from here. If CAISO curtailment events keep compounding at this pace while APND scheduling nodes pin at $0.00, the path to deep negatives runs through the spring-style solar hours, not 04:55 UTC snapshots; watch the midday intervals rather than the overnight extremes. If PACW congestion stays near -$94 while SP15 holds triple-digit congestion, the SP15-PACW basis is the live expression of the same constraint that built the $306 spread. In MISO, 5,233-plus shadow-price events with 15 GW-scale derates says congestion rent is accruing somewhere; the open question is which constraints repeat. > The spread was real, the strain was real, and the miss was real; the book prints all three because that is what a tape is for. Not investment advice. For informational purposes only. Yesterday's tape: CAISO HPLNDJT6N001 negative_lmp >= 37 — not triggered (observed -28.99). Grid Alpha — daily briefs · live dashboards, all nine markets · public call record

  3. 2d ago

    CAISO Nodal Spread Prints $1,498 as SCHLTE Congests, HPLNDJT Goes Negative

    CAISO's real-time market printed a $1,497.57/MWh nodal spread overnight Thursday, with SCHLTE1PL1X3-APND at $1,472.38/MWh against HPLNDJT6N001 at negative $25.19. That is a 40x gap between the energy component and the delivered price at the top node. The system energy price never moved; the wires did. The decomposition is the story. SCHLTE's LMP breaks down to $1,423.54/MWh of congestion against an energy component of $36.76/MWh and a loss component of negative $1.23. At the bottom of the stack, HPLNDJT carried negative $72.07/MWh of congestion against energy of $37.11. Both tails of the curve are pricing the same system energy within 35 cents of each other; the entire $1,498 spread is transmission. This is not a scarcity event, a gas event, or a ramp event. It is a binding constraint isolating load pockets from supply pockets in the 3:20 to 3:50 AM PDT window, when the system should be at its most relaxed. Four PGST_2 nodes (RDRR01, PDRP42, PDRP40, PDRP39) printed a uniform $686.01/MWh with $636.48 of congestion each, which reads as a second, separate constrained cluster rather than smeared system-wide stress. The negative tail has company. GRANITE6N001A printed negative $14.86, two CLERLKE nodes printed negative $11.20, and HARTLEY6N001 printed negative $9.14, all at 10:20 UTC. A cluster of sub-zero prints in the overnight hours points to must-run or non-dispatchable supply trapped behind the same constraints. CAISO logged at least 1,668 curtailment events over the trailing seven days, though the sampled records are wind-only and dated August 13, so the curtailment linkage to Thursday's negative prints is unconfirmed. One caveat on the headline number: the two extreme prints are 30 minutes apart. SCHLTE's $1,472.38 is a 10:50 UTC reading; HPLNDJT's negative $25.19 is 10:20. The same-interval spread may be tighter, and no constraint name or outage record has surfaced to explain the $1,423 congestion component. Treat the $1,498 as an upper bound on the location pair, not a cleared hourly basis. The trade implication turns on persistence and the DA/RT split. No day-ahead prints are in the data, so the basis cannot be sized yet. If SCHLTE's congestion component survives into Thursday's evening ramp, when solar rolls off and the system tightens, the spread widens rather than closes, and virtual convergence at the constrained cluster gets interesting. If the constraint clears with the morning pickup, the negative tail at HPLNDJT and CLERLKE collapses back toward the $37 energy component first, since those nodes are congestion-short, not energy-short. Watch the next intervals for whether PGST_2's $686 cluster moves in sympathy with SCHLTE; correlated congestion means a shared interface, divergent prints mean two separate trades. > When the energy component sits at $37 on both ends of a $1,498 spread, the grid is the market, and whoever maps the binding constraint first owns the basis. Not investment advice. For informational purposes only. Grid Alpha — daily briefs · live dashboards, all nine markets · public call record

  4. 3d ago

    SPP Overnight Print: $246 Spread Splits CSWS From Aurora

    SPP's real-time market printed a $246.48/MWh top-to-bottom nodal spread in the 04:00 UTC interval, 23:00 CDT Tuesday night. The high side was CSWS46STNOLD1 at $214.45/MWh in the AEP Oklahoma load zone; the low side was EDEAUR1241LDAURORA_124 at -$32.03/MWh in Empire District's Aurora pocket. Both prints came out of the same dispatch interval, and neither was an energy story. The split is pure congestion. The system energy component sat at $21.47/MWh at every listed node, top and bottom alike. CSWS46 carried a $193.22 congestion adder on top of that flat energy price; Aurora carried -$53.89. The high-price side is a cluster, not an outlier: CSWSYALEARCLD1 and CSWSPNEPEORLD1 both printed near $208.6, and the CSWS Mohawk nodes followed close behind. The negative side is also broader than one node: WFECRUSSETTLD4 at -$22.00 and OKGERUSETLD1/2 at -$21.49 show sub-zero pricing extending across Oklahoma into the OG&E footprint. This is a map problem, not a tick problem. No named flowgate is identified in the available data, so the specific element loading up the $193 congestion into CSWS remains an open question. Trailing-seven-day logs show at least 1,173 generation capacity-on-outage records and 1,943 VER curtailment records in SPP, with sampled coal outages ranging roughly 2,406 to 4,071 MW on August 12, though the outage data is low-confidence sampling and no single event cleanly explains tonight's geometry. The setup is the classic overnight SPP pattern: cheap energy system-wide, transmission that cannot move it where load or constraint shadow prices want it. With energy at $21.47, anyone positioned between these two pockets is trading the constraint, not the commodity. If the spread holds into morning ramp, congestion revenue rights and any virtual spread positions spanning CSWS to the Aurora/WFEC/OKGE cluster carry real value; if the binding element relieves with the dawn pickup in dispatchable headroom, the spread collapses toward energy and the trade is over. One caveat on the "live" framing: the snapshot is a single 04:00 UTC interval as of the 06:02 CDT pipeline run. Nothing in the data confirms whether later intervals widened, held, or mean-reverted, so sizing should assume the print may already be stale. Watch whether the negative pricing persists at Aurora and the OKGE Russett nodes into the next several intervals; persistence would suggest structural oversupply in that pocket, likely wind-driven given the region, rather than a transient redispatch artifact. > When energy is flat at $21 and the spread is $246, you are trading the wire, not the watt. Not investment advice. For informational purposes only. Grid Alpha — daily briefs · live dashboards, all nine markets · public call record

  5. 4d ago

    CAISO Prints $810 Spread as CSADIAB Sinks to $-742, SPR Holds $68

    CAISO's real-time market posted a maximum nodal LMP spread of $810.14/MWh in the 10:20 UTC interval, one of the widest single-interval separations on the board. CSADIAB7N001 cleared at $-741.85/MWh while SPRPPGNODE2 held $68.29/MWh at the top of the stack. The decomposition tells the whole story. The system energy component was a uniform $35.92/MWh across every listed node, so none of this spread is energy; it is congestion and losses, full stop. CSADIAB carried a congestion component of -767.65 against losses of -13.82, and it was not alone: CONTROLX1N008, N009, N010 and CSADIAB7N003 all printed $-741.75 with the identical -767.65 congestion figure, a clustered deep-negative pocket rather than a single-node flicker. On the other side, SPRPPGNODE1 and SPR3PP2SOLARGNODE matched GNODE2 at $68.29 with congestion of 29.20, so the premium side is a zone, not an artifact of one bus. The backdrop fits: CAISO logged at least 1,668 curtailment events over the trailing seven days, consistent with active renewable oversupply pressing against a binding constraint somewhere between these pockets. One caution on the angle: 10:20 UTC is 03:20 PDT, dead overnight in California. This is not a midday solar bell print, and the sampled curtailment data shows wind megawatts being cut, not solar. That cuts both ways. A negative-742 node clearing at 3 AM local implies either a genuinely binding local constraint with nowhere for the generation to go, or a telemetry artifact, and no public coverage yet confirms which. If the constraint holds into the morning ramp, the spread should compress as load absorbs the pocket and the SPR premium fades toward system energy; if the negative print persists across intervals, it reads as structural, and congestion revenue rights along that path reprice. What I'd watch: whether CSADIAB repeats in the next interval set, whether the -767.65 congestion component releases, and whether these nodes are actually settleable before sizing anything against the print. > An $810 spread with a $35.92 energy component is pure congestion geometry: trade the constraint's duration, not the price level. Not investment advice. For informational purposes only. Grid Alpha — daily briefs · live dashboards, all nine markets · public call record

  6. 4d ago

    PJM's $1,824 Spread Pits Mardela Against Clifty Creek

    PJM printed a $1,824.50/MWh maximum nodal spread in the 20:50 UTC interval Monday, 16:50 local. Mardela 69 KV topped the book at $1,395.26/MWh; Clifty Creek 4 sat at the bottom at negative $429.24/MWh. One ISO, one dispatch interval, nearly nineteen hundred dollars of separation. The decomposition tells you everything. The system energy component was a uniform $280.25/MWh across every node in both tails, so this is not an energy story. It is a pure congestion and loss print. Mardela's price decomposes into a $1,096.58 congestion component plus $18.43 of losses; Clifty Creek's negative handle comes from a negative $681.29 congestion component against negative $28.20 of losses. Clifty Creek is not one node either: units 1, 4, and 5 and their 15.5 KV gen-ties all printed within ten cents of each other, meaning the entire pocket is trapped on the wrong side of a binding interface. Behind Mardela, four Hebron nodes clustered at $1,111.27/MWh with an $809.08 congestion component, forming a clean second tier. That stacking, two distinct high-price pockets against one generator cluster in the hole, is the signature of a constrained corridor rather than a single tripped element. What is driving it is less visible. PJM logged at least 147 daily outage events over the trailing seven days, and sampled records from August 11 showed forced outage entries ranging from 3,508 MW to 5,221 MW, though the reporting format leaves the system total ambiguous. No binding constraint names or shadow prices accompanied the snapshot, so the specific limit isolating the Mardela and Hebron pocket is unconfirmed. The same goes for the negative congestion at Clifty Creek: it could be a west-side interface limit, a unit outage pattern, or curtailment. The print itself, however, is unambiguous, and it landed at 16:50 EDT on a Monday, directly in front of the evening ramp. The trading implication runs through persistence and DART. This is a single five-minute snapshot, so the first question is whether the 20:55 and 21:00 prints held the spread or collapsed it; a spread this wide that survives consecutive intervals usually means a hard constraint with hours to run, not a transient re-dispatch. If the congestion component at Mardela holds near $1,096 through the ramp while Clifty Creek stays pinned negative, the east-west basis setup is live for anyone positioned across that seam, and DA/RT divergence at those two nodes tomorrow becomes the cleanest expression. If the next print mean-reverts toward the $280 energy component, the move was a dispatch artifact and the trade is over before it started. Watch the constraint list PJM posts for the ramp hours; the shadow price on whatever is binding will size the trade better than the LMP prints themselves. Separately, FERC's approval today of a MISO cost-recovery plan for transmission built inside PJM, affecting Exelon and Duke, is a reminder of how long the structural fix for these seams actually takes. > When energy is $280 everywhere and two nodes sit $1,824 apart, the constraint is the market; the only question is how long it binds. Not investment advice. For informational purposes only. Grid Alpha — daily briefs · live dashboards, all nine markets · public call record

  7. Aug 13

    NYISO's -$112 Node Print Is One Interval, Not a Trend

    OHGENPROXY cleared at -$111.75/MWh in the NYISO real-time feed at 10:50 UTC on August 13, while the system energy component at the very same interval printed +$47.52. The entire move is locational: congestion at -$156.85, losses at -$2.42. And one correction before anything else: 10:50 UTC is 06:50 EDT, Thursday morning, not overnight. The decomposition is unusually clean. Energy of $47.52 was common across the snapshot, and two unconstrained reference nodes, NIAGARA115WLBMP and GLOBE_DSASP, both settled at $44.62 with congestion of exactly 0.00. That bounds the generator-side basis at roughly $156 wide at a single instant. PJMGENKEYSTONE ran the same direction but nowhere near the same magnitude: $35.59 LMP on -$11.88 of congestion, an order of magnitude shallower. So this is not a broad export constraint bleeding across a seam; it is a pocket, and a tight one. What the feed does not give you is the name of the binding element: no flowgate, no contingency, no shadow price. Without that, "oversupply" is an inference rather than a sourced fact, and there is no wind, solar, load, or outage data in the pocket to support it. The data hygiene deserves a flag before anyone sizes anything. The snapshot is labelled NYISO but the top-five list carries PJM-named nodes and an "OH_" prefix, and the PJM row is stamped 2026-08-14T03:00 UTC, roughly 16 hours after the snapshot header, on a different energy component of $50.45 against $47.52 elsewhere. Forward value, feed error, or timezone bug: pick one, but pick it before you map this node to an ISO. What I would watch is persistence, because the thesis that generator-side basis stays deeply negative into the next off-peak window rests on exactly one five-minute interval. If the congestion component repeats across consecutive intervals and shows up in day-ahead at the same node, the constraint is structural and expressible through FTRs; if it does not, this is a state-estimator artifact or a momentary binding that reverses before anyone can clear against it. No day-ahead LMP at this node was published in the snapshot, so the DA/RT spread, the instrument the angle actually implies, cannot be computed from what is in hand. Second thing to watch: whether PJMGENKEYSTONE's -$11.88 deepens in step. Correlated widening across both generator proxies argues for a shared upstream limit; divergence argues for a purely local element behind OHGENPROXY. Separately, and not as a cause: NYISO has proposed cutting 28 of 40 candidate 2027 budget projects to redirect resources toward FERC show-cause compliance on large-load interconnection. None of that touches this interval. It is worth noting only because nodal transparency tooling competes for the same budget line, and prints like this one are precisely what better constraint attribution would resolve in seconds rather than sessions. Depth is not duration. A -$156.85 congestion component tells you the model found a binding limit and priced it hard; it tells you nothing about whether the limit is still there in the next interval, let alone at 23:00 EDT tonight. Historical frequency at this node is absent from the record, so even the question of how anomalous -$111.75 is remains open. > A -$112 print with no named flowgate and no second interval is a data point, not a position. Not investment advice. For informational purposes only. Yesterday's tape: MISO MINN.HUB lmp_peak >= 100 — verified (observed 354.29). Grid Alpha — daily briefs · live dashboards, all nine markets · public call record

  8. Aug 12

    MISO Minnesota Hub Prints $354 Against a $65.84 Mean

    Minnesota Hub real-time LMP tagged $354.29/MWh at 20:20Z Tuesday, 15:20 CDT, roughly 5.4x the $65.84 trailing-24-hour mean. The hub currently quotes $36.44. The distance between those numbers is the story; the data underneath it is thinner than the spike implies. Start with the snapshot's own metadata, which argues with itself. The stated window runs 11:05Z to 20:20Z Tuesday, about 9.25 hours, but the series carries 280 five-minute bars, roughly 23.3 hours. The $354.29 print lands on the final timestamp of that stated window, not inside it. The $24.59 low is stamped 08:40Z Wednesday, 03:40 CDT, outside the window entirely. The $36.44 current print carries no timestamp at all, so the sequencing from spike to collapse is inferred rather than observed. Causation is worse. Nothing in the event data covers 20:20Z. MISO logged at least 84 estimated generation-outage events over the trailing seven days, the largest sampled row showing 12,064 MW forced, 13,161 MW derated and 8,768 MW planned, stamped 2026-08-06 00:00 CDT: five days before the print. Real-time binding-constraint records number at least 6,307 over the same seven days, with the sampled Minnesota-area elements ABBOTT and FORBES both carrying bp1=100 and bp2=102, timestamped Wednesday the 5th, mid-morning. Both counts sit behind sample markers and may be truncated by pagination. There is no LMP component decomposition here, so whether the $354.29 was congestion rent on a Minnesota-area element or a footprint-wide energy tightness is unresolved. That gap matters for the peak-length, off-peak-short structure the angle sets up. A single five-minute bar at the edge of a window whose length does not reconcile is not an intraday shape: the snapshot reports peak, mean and low, and nothing about how many bars cleared above $100/MWh or how long the hub stayed there. If the following sessions put a run of bars through $100 in the 20:00 to 21:00Z hour, the concentration thesis has a basis and the peak-hour leg earns its premium. If the $354.29 stands alone, it is an artifact risk before it is a trade. What I would watch, in order: the recurrence of that hour across the next three sessions; the day-ahead Minnesota Hub curve against realized real-time, which is absent from this material and leaves the DART unanchored; and whether the ABBOTT and FORBES elements bind again inside the evening window rather than in morning hours. Load, wind output and regional gas are all missing here, so there is no way yet to separate an evening net-load ramp from a transmission-limited pocket. Those are different trades with different tenors: the first is a shape play on the peak block, the second is a basis play on the hub against the surrounding zones. Absent the constraint data at the timestamp, the material does not distinguish them, and sizing off the $354.29 alone means sizing off one bar. > A $354 print on the last bar of a window that does not reconcile is a question, not a signal. Not investment advice. For informational purposes only. Grid Alpha — daily briefs · live dashboards, all nine markets · public call record

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Grid Alpha turns real-time data from all nine North American power markets (ERCOT, PJM, CAISO, ISO-NE, NYISO, MISO, SPP, AESO, IESO) into short, trader-ready signal. Each episode reads the tape: fuel mix, LMP/DART spreads, congestion, storage response, and LinkedIn commentary from analysts, developers, and policy watchers who actually move size. No background music, no fluff, just the setups that matter this week for U.S. power and gas traders. Live dashboards at gridalpha.us.

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  • Creator
    LYU LLC DBA Grid Alpha
  • Years Active
    2026
  • Episodes
    54
  • Rating
    Clean
  • Copyright
    © LYU LLC DBA Grid Alpha
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