Tradero study · v2.1 · 2026-09-02 — v2.0 (second research round: information layer, sessions and regions, participants, mood, cause→effect chains, toolkit) plus the Codex review of v2.0 (what changed: §12.3); organised as Part I (essentials) and Part II (knowledge base)

0. How to use this document

The document has two parts. Part I — Essentials (§1–§2) is the human-readable core: the conclusions, the mental model of how the price is formed, the one-page map from the causes of the causes to the price, and the trader's day. Read it first and re-read it when lost. Part II — Knowledge base (§3–§20) is the reference the AI and the engineers use: every driver with mechanism, direction, magnitude, horizon, data series and evidence grade (§3); what the evidence says predicts returns (§4); regimes (§5); the pre-trade checklist (§6); traps (§7); contract mechanics (§8); the calendar (§9); a dated snapshot (§10); the Tradero programme (§11); where the two studies agree and differ (§12); the verification queue (§13); the information layer — how news becomes data (§14); sessions and regions (§15); the participant map (§16); the cause→effect chain catalogue (§17); mood and narrative, including where oil traders talk worldwide (§18); the analytical toolkit and strategy catalogue (§19); and what all of it adds to the programme (§20).

Section numbers are stable across versions so that MASTER-PLAN, memory and code can cite them. Evidence grades (A/B/C) and VERIFY tags are part of the content: a claim without a grade has not been assessed.

Part I — Essentials

1. Executive summary — twenty-three conclusions

1. Oil price is a balance residual. Production − consumption = inventory change. Price moves until observed inventories confirm or refute the expected balance. Everything else in this document is a way of forecasting or observing that identity earlier than the consensus.
2. Price responds to innovations, not levels. A crude draw that the market expected is not bullish. A quota hike that was pre-leaked moves price <1–2 % on the day. The tradable content of every report is actual − expected, and "expected" must be timestamped.
3. The futures curve is the best single public summary of the physical balance. Backwardation = scarcity (low stocks, high convenience yield); contango = surplus. It is an A-grade state variable and a B-grade timing signal: over 20 days the carry is ≈0.4 % against a 10-day return standard deviation of 6–7 %. Use it as a regime filter and conditioning variable, not as a trigger.
4. Not all shocks are alike. Supply-loss shocks, aggregate-demand shocks and precautionary (fear) shocks have different persistence. Precautionary premia decay in 1–8 weeks unless barrels are actually lost. Classify the regime before choosing a trend or a mean-reversion prior.
5. Announced ≠ realised. Barrels "at risk" are consistently larger than barrels lost (Russia 2022: ~3 mb/d feared, ~0.2–0.3 mb/d realised). The 2026 Hormuz episode is the exception that proves the rule: the premium persisted for six months because a chokepoint defeats re-routing and 8.3 mb/d of Gulf output was genuinely shut in. Track loadings and transits, not headlines.
6. The EIA Wednesday report is an event, not a multi-day signal. Price reacts to the surprise within minutes; the one daily-data study that looked (Miao, Ramchander, Wang & Yang 2018) found no drift beyond the announcement day — a single absence result, grade B. For a 2–20 day book it is variance to size for and new state to ingest, not a directional input on its own. It is the right raw material for an intraday overlay (S2).
7. Cushing is a non-linear amplifier at both tails. Below ≈20 mb (EIA: stocks may be near tank bottoms — the floor is a hypothesis to estimate, not a published number) prompt spreads and Brent–WTI go violent (June–July 2026: WTI spot above Brent). When uncommitted storage vanishes (April 2020: ≈60 mb in tank against ≈76 mb working capacity, 76–83 % full) the expiring contract can detach from spot (20 April 2020: −$37.63). It is the most WTI-specific variable there is.
8. Trend and carry are the benchmarks any new idea must beat. Single-market trend on commodities earns a gross Sharpe of roughly 0.3–0.4 over long samples; commodity carry is robust cross-sectionally and weak in a single time series. The bar is low in absolute Sharpe but high in orthogonality: a new factor must add after controlling for trend sign, front spread and the EIA/roll calendar.
9. Macro is state, not signal, at this horizon. The dollar–oil correlation has flipped sign three times since 1990; rates now react to oil supply news rather than lead it; PMI and credit-impulse leads exist only at 1–3 months and are contested. Use macro for regime classification and P&L attribution.
10. Positioning does not lead price. Speculators' positions follow prices (no Granger causality). The one well-identified short-horizon effect is that changes in managed-money positions mean-revert over weeks (liquidity demand), while levels reflect trend and hedging. "Extreme percentile → fade" conflates the two and lacks peer-reviewed support in crude.
11. Seasonality is real in products and runs, weak in crude returns. Refinery turnarounds (Feb–Mar, Sep–Oct) and product cracks are robust physical cycles. Calendar-month crude returns are statistically significant only at the Feb–Sep vs Oct–Jan level, with monthly SDs of 7–14 %. Weak prior, never a stand-alone edge.
12. Tails are in-sample, not hypothetical. Daily moves of ±15–25 % have occurred repeatedly (−25 % 9 Mar 2020; +24.7 % 2 Apr 2020; +14.8 % Abqaiq; ≈+22 % intraday 9 Mar 2026 VERIFY; −16 % 8 Apr 2026), mostly after weekends. Stops do not protect across a gap; only size does. Margins rise after the spike.
13. Contract mechanics are part of the thesis. CL is physically delivered; a retail account must be out before the broker's close-out deadline (IBKR: longs two business days before first notice, shorts two before last trade). MCL and the 10-barrel TCL are cash-settled. TCL has not launched — CME's client-systems page marks the production launch "postponed, pending regulatory review", date TBD (updated 27 Aug 2026). Sizing must assume a 5 % day (≈$4,500 per CL, ≈$450 per MCL at $90).
14. A view is not a trade. A trade adds four things a view lacks: a dated catalyst inside the holding window, knowledge of who is already positioned, the structure (outright vs spread, which month), and the explicit condition that kills it. Andurand's 2023 drawdown with a correct bullish balance is the canonical reminder.
15. For Tradero: the current Oil State v0 is a dashboard, not a forecast model. Both studies converge on the same v1 programme: contract-correct trend and carry as frozen benchmarks; curve-conditioned inventory scarcity as the first real hypothesis; WPSR innovation (not stock level) as the second; everything else context-only until it earns its place out of sample. Details in §11.

Added by the second research round (Part II, §14–§20):

1. A headline is a data object, not a fact. Every item is stored as an immutable claim (announced value, expectation and cutoff, source authority) with append-only observations (confirmations, denials, realised measurements). In the one proprietary-data study that tested it, geopolitical sentiment had a strong immediate impact and no return predictability beyond intraday; the objects worth tracking are the repair timeline, the compliance record and the loading count — never the flash.
2. The day has overlapping liquidity regimes and two structural events. As working priors: Asian hours are thin and usually follow, with local information on China and the RMB; European hours are Brent-led and extend through the 16:30 London physical assessment; US hours are WTI-led around the 10:30 ET report and the 14:28–14:30 ET settlement. Leadership is time-varying and must be tested per session. Weekends open through a thin Sunday book that Gulf equities price first.
3. In the episodes studied, pre-committed flows moved price at the extremes while discretionary money reacted. Published ETF rolls and retail products held into expiry (2020), margin calls on hedgers (2022) and hedge programmes triggered by price levels with vol-targeted CTA cuts (2026) are each documented separately; they are not one established law. There is no stable smart-money group; the CFTC classifies traders, not trades, and every category's net position is an empirical quantity for a specified report, never a structural constant.
4. Retail's documented losses came through instrument mechanics in the cases studied. USO, Bank of China's product and MCX holders in April 2020 were broadly right on direction and lost on roll, expiry and settlement mechanics; EU CFD loss rates (74–89 % of accounts) are documented by ESMA without a direction-versus-structure decomposition. Contract mapping, roll and settlement rules therefore outrank crowd direction.
5. Mood is a volatility and event diagnostic, never a price score. The evidence with any replication concerns second moments: attention and news volume help forecast volatility. The sampled public venues (§18.1) are lopsided — English X and Substacks for the professional narrative, local retail boards for framing — and access, licensing and personal-data law, not modelling, are the binding constraints.
6. Product and refinery supply shocks show up in cracks first; demand shocks hit flat price first. The diesel crack is the first responder to distillate loss; a crude production outage usually hits crude first and can weaken cracks; tariffs and recessions hit flat price first.
7. Slow variables set the sensitivity of fast ones. Decline rates, capex, stock cover, refining configuration and effective spare capacity decide whether a hurricane or a sanctions designation moves price 2 % or 20 %.
8. The professional toolkit is deliberately redundant. A move confirmed by the front spread, cracks, loadings and physical differentials is a different object from the same move with only crowd attention; the toolkit exists to tell them apart. Published single-market trend and carry results sit near a Sharpe of 0.3–0.7; a higher single-market backtest is a review trigger for the deflated-Sharpe and multiple-testing checks in §19.6, not a result.

2. How the oil price is formed — the mental model

2.1 The identity and its lags

Global supply − global demand = stock change. Because short-run demand and supply elasticities are tiny (Hamilton 2009; Baumeister–Hamilton 2019 put both near 0.1 in absolute value VERIFY), small quantity imbalances require large price moves to clear. Oil therefore overshoots by construction. Supply reacts with long lags: US shale needs ~4 months from price to rigs and ~2 more to production (EIA), and in 2026 producers chose not to respond at all (Dallas Fed Q1: 30 % of E&Ps planned no output change despite WTI $57→$111). Demand reacts through China's price-elastic stockpiling (imports 11.6 mb/d in 2025 at low prices, 8.1 mb/d in 2Q26 at high prices) and through demand destruction, both over 1–3 months.

2.2 Inventories are the truth, the curve is the forecast

Inventories are where the identity is observed. The futures curve is where it is priced: the basis F − S equals financing + storage − convenience yield (Working 1949; Fama–French 1987). Convenience yield is a decreasing, convex function of stocks (Gorton–Hayashi–Rouwenhorst 2013), so low stocks ⇒ backwardation and high stocks ⇒ contango. Goldman's framing (Currie): the timespread is "a direct measure of inventory tightness, not a forecast"; Murti: "the truth is in the shape of the forward curve." Causality runs both ways with a lag — EIA's own study found Cushing stocks a significant function of the lagged M2–M1 spread over 2004–2011 (contango pulls barrels into tanks).

2.3 Three kinds of shock

Kilian (2009) decomposes real oil-price changes into oil-supply shocks, aggregate-demand shocks and oil-specific / precautionary demand shocks. Each has different price persistence and macro effects. Baumeister & Hamilton (2019) argue that with plausible elasticity priors supply shocks matter much more than Kilian found. The practical lesson survives the academic dispute: the same $5 move means different things depending on which shock produced it, and the right prior (continuation vs reversion) depends on the shock type. §5 gives deterministic ways to tell them apart.

2.4 Innovations, expectations, and the reaction function

Price reacts to surprises. This has three operational consequences. (i) Every scheduled release needs a timestamped expectation (consensus survey, the API print, a model) or the "surprise" cannot be computed. (ii) Telegraphed policy (OPEC+'s monthly 188 kb/d steps in 2025–26) is nearly priced by the time it is announced; surprises (2 April 2023: >1 mb/d cut a day before a meeting expected to hold; WTI +8 %) are amplified by positioning. (iii) The persistence of a surprise depends on whether the physical market confirms it within days (spreads, Cushing, loadings) — that confirmation is the tradable part for a 2–20 day book.

2.5 Announced versus realised

Every geopolitical or policy headline names a quantity "at risk". Only a fraction is lost, because re-routing, shadow fleets, discounts, SPR releases and demand destruction fill gaps. The premium = probability × expected loss + precautionary stockbuilding, and it appears first in prompt spreads, Brent–Dubai and freight, then in flat price. The ECB finds geopolitical-shock effects "insignificant after one quarter"; TD Securities finds premia fade within about a month in most post-1981 episodes. Abqaiq (14 Sep 2019, ~5 % of world supply hit): +14.8 % Monday settle, largely reversed within days, fully within weeks. The discriminator is realised flow: realised_net_loss = observed_loss − offsets − releases (Codex's formulation), measured in loadings and transits, never in headline capacity.

2.6 The map of causes — from the cause of the cause to the price

SLOW VARIABLES (years)  — set the SENSITIVITY of everything below
  capex cycle & decline rates · effective spare capacity · stock cover · refining configuration
  EV adoption & efficiency · standing policy (ETS, IMO, quotas, price caps) · pipeline & export capacity
        │
        ▼
TRIGGERS (hours–weeks)  — change EXPECTED flows
  OPEC+ decisions · outages, attacks, chokepoints · sanctions ENFORCEMENT · weather (hurricanes, freezes, rivers)
  SPR releases & refills · China quotas & stockpiling · gas/LNG & product shocks · macro & tariff shocks
        │
        ▼
TRANSMISSION (who carries it)
  producers hedge (curve) · merchants store & reroute (spreads, freight) · refiners run or cut (cracks)
  funds and CTAs position (flat price, then curve) · dealers hedge (options, deferred) · states release or refill
        │
        ▼
OBSERVABLES (what the code sees, point-in-time — three classes with different latencies)
  market observables (price, curve & spreads, cracks, differentials, options, OI, margins)   — immediate
  leading physical observations (loadings, transits, port line-ups, nominations, freight)     — hours to days, often licensed
  lagged estimates (WPSR, ARA, JODI, agency balances, positioning reports)                    — days to months, revised
  + the narrative state (attention, topics, confirmation depth)                                — diagnostic only
        │
        ▼
PRICE OBJECTS  →  flat price · front spread · cracks · Brent–WTI
        ↺ FEEDBACK LOOPS: price → producer hedging → curve · volatility → margin → deleveraging
          refinery margins → runs → crude demand · low price → China builds, high price → China draws
          price → politics (SPR, OPEC, sanctions) · positioning → price → positioning

How to read it. A trigger only matters through a transmission and an observable, and the three observable classes have different latencies: the market reprices a probability shock within seconds, often before any barrel is lost; leading physical observations confirm or refute it over hours to days; lagged estimates reconcile it weeks later and are revised. A threat without lost barrels, a designation without enforcement or a communiqué without loadings can therefore move price and still be a premium that decays — the physical observation is the falsifier, not the headline. The slow variables are not signals but they scale every signal, which is why the same headline is worth 2 % in one year and 20 % in another. The feedback loops are why a correct view can lose money: hedging caps the curve after a rally, margin calls remove the sellers a spike needs, and stockpiling buffers both tails. The full catalogue, chain by chain, is §17.

2.7 The trader's day in one page (Rome time, normal offset)

00:00 Globex reopens: weekend news, OPEC+ Sunday statements and Gulf-equity prints are priced through a thin book (§15.2). 03:00–09:00 Asia: INE day session, Chinese data (~04:00), the Dubai window at 10:00–10:30 — a follower session that carries local information on China and the RMB. 10:00 IEA OMR on release days; 14:00 OPEC MOMR. 14:25 macro-risk checkpoint before US releases (CPI, payrolls, FOMC days): an open book is sized for the print before it lands, not after. 14:30 US macro releases. 15:30 the operator's window opens: read the machine handover (overnight returns, curve, cracks, confirmed events, data failures), then only Tier 1–2 exceptions and today's event clock (§14.5). 16:15 Thursdays ARA product stocks (Amsterdam local time). 16:30 Wednesdays the EIA report — code computes the surprise, the trader watches the 16:30–17:00 window, nobody types a number by hand; in holiday weeks the report moves to Thursday, usually 18:00 Rome, and in the DST-mismatch weeks every ET time lands an hour earlier — the calendar is read from the source, never assumed. 17:00–17:30 the London physical window: Platts assesses Dated Brent at 17:30 — the daily physical assessment, editorial judgement included. 18:00 STEO on its days. 19:00 Fridays Baker Hughes — read, never traded on its level. 20:15 decide overnight exposure; 20:28–20:30 CL and Brent settle in the same two minutes; TAS volume spikes and carries no direction. 21:30 Fridays COT lands after the window; 22:30 Tuesdays API lands after the window — both are collected automatically and read next session. 23:00 Globex breaks for an hour.

Before any long or short, four questions (§6): what is the thesis in one sentence, in balance terms; what dated catalyst inside the 2–20-day window forces the market to re-price; who is already positioned, and what pre-committed flows (rolls, expiries, margin) sit in the window; what, written down, kills the trade. Then the mechanical gate: data fresh and point-in-time, the contract month and its roll or broker deadline known, every scheduled event in the window mapped to a tested policy, liquidity measured on the traded contract, the one-contract loss under absolute $/bbl shocks inside limits, the kill switch verified. Size to the weekend gap, never to margin.

Part II — Knowledge base

3. The driver map

Column key — Dir.: sign of the flat-price effect for the bullish version of the driver. Magnitude / speed: how fast the effect arrives and, where an episode gives one, its size. No generic $/bbl bands are offered: magnitudes are to be calibrated on Tradero's own point-in-time event set (uncalibrated buckets become unaudited priors — Codex review). Horizon: I intraday · S 2–20 days · M months. Data: the exact series a collector ingests (EIA v2 ids, FRED ids, CFTC codes). Grade: A/B/C as defined above; split as "mechanism / signal" where they differ.

3.1 Physical supply

3.2 Demand

3.3 Inventories and storage

3.4 Market structure

3.5 Macro and financial

3.6 Positioning and flows

3.7 Geopolitics and policy

3.8 Technical, calendar and flow

3.9 Mechanisms covered thinly in v1.0 (added after the Codex review)

4. What the evidence says actually predicts oil returns

4.1 The hard result

Alquist, Kilian & Vigfusson (2013): futures-based and macro forecasts do not reliably beat the no-change forecast at short horizons; occasional 12-month gains are modest and sample-sensitive. Baumeister & Kilian (2012–16): real-time VAR and industrial-commodity models beat no-change at 1–3 months (MSPE ratios ≈0.87–0.90; directional accuracy 55–65 %), but Benyo (2026) finds "no consistently significant improvements over the end-of-month no-change forecast at short horizons." Everything is monthly, and Benyo's main correction matters: much of the Baumeister–Kilian gain disappears when the no-change benchmark uses the end-of-month spot price rather than the monthly average. This review found no directly transferable, replicated 2–20 day signal in the published forecasting literature.

Consequence: "collect fundamentals, add signs, predict price" is not a strategy. Oil is endogenous, prices aggregate information faster than agencies publish it, and different shocks produce identical price moves. What survives is narrower and more specific.

4.2 Effects with the best support (and their honest horizon)

4.3 Effects commonly over-sold

• COT extremes as reversal signals. No Granger causality from spec positions to prices; speculators "hold the biggest long near the peak" because they are trend-followers. Levels ≠ timing.
• Inventory levels alone. "Below the five-year average = buy" is not established return predictability; weekly changes are noisy balance residuals; crude-only headlines ignore products, trade flows and maintenance.
• Agency balances as trades. Published deficits are neither positions nor guaranteed draws; agencies diverge by 2.2 mb/d on 2026 demand (IEA −1.6 vs OPEC +0.6). Only vintage revisions are candidates.
• Rigs / DUCs. Months-ahead supply monitoring; far too slow and endogenous for next-week direction.
• Static macro betas. Dollar/rates/equity correlations flip with the shock; absolute percentiles with fixed signs create false confidence.
• Calendar seasonality and chart patterns. Physical seasonality does not imply stable excess returns; short-term reversal, support/resistance, weekday effects carry the highest multiple-testing and cost burden.
• News/sentiment counts as a price score. A geopolitical premium can vanish while the news stays alarming, because P(loss) fell. Without cargo/production confirmation it is not a durable factor.
• "EIA moves WTI 2–4 %." Blog folklore; the peer-reviewed magnitude is surprise-scaled and regime-dependent.

4.4 The bar a Tradero hypothesis must clear

Trend and carry are the frozen benchmarks. A new factor earns admission only if it adds walk-forward return/Sharpe after controlling for (a) the sign of the 1–12-month trend, (b) the front spread, and (c) the EIA/roll calendar — otherwise it repackages them. In absolute terms the bar is low (single-market Sharpe ≈0.3); in orthogonality terms it is high. Tradero's admission gate (MASTER-PLAN §7) already encodes this.

5. Regimes — and how to tell them apart deterministically

A NY Fed-style decomposition (partial least squares of weekly Brent moves on financial variables into supply vs demand components) is replicable in code and a candidate for a Tradero regime diagnostic: cheap, deterministic, point-in-time. Caveat from the Codex review, accepted: rolling correlation signs are diagnostics, they do not identify shocks; structural identification needs the Kilian / Baumeister–Hamilton machinery on monthly data. At 2–20 days the classifier is exploratory and never a scored factor.

6. The pre-trade checklist

Two layers: the common gate every trade must pass (mostly vetoes, mechanically encodable) and the case (what the long or the short must be able to say). Tags: E evidence-based · P practitioner consensus · F folklore, retained only as a risk caution.

Four layers, kept apart (Codex review): research-admission tests (MASTER-PLAN §7), machine pre-trade vetoes (the table below), position sizing, and operator monitoring. Displaying state (item 5) is monitoring, not a veto.

6.1 Common gate (PASS / FAIL / NA per item, logged with input, threshold, timestamp and rule version)

6.2 What the long case needs

• A pre-specified positive signal — ideally trend up and/or a tight, backwardated curve. "Looks cheap" is not a signal. (E)
• A mechanism that tightens the marginal prompt barrel: unexpected draws with healthy runs and products, realised (not announced) supply loss, upward demand revision, lower effective spare capacity. (E/P)
• Expected move > costs + roll: if long into contango, the thesis must include a tested spot/curve repricing larger than the carry drag. (E)
• No false draw: the crude draw did not simply migrate into products while cracks and runs collapse — encoded as same-week product-stock change and crack change inside pre-set bounds. (P)
• No premium-chasing after a gap: buying an unconfirmed geopolitical premium after the move is buying decay (1–8-week half-life). (E)
• Defined downside written down: demand shock, restored supply/ceasefire, OPEC reversal, storage stress; orders and P&L negative-price-compatible. (E)

6.3 What the short case needs

• A negative signal plus a loosening mechanism: broad stock builds, weak products/cracks, run cuts, realised output restoration, downward demand revision. (E/P)
• Expected decline > backwardation: a short in steep backwardation pays adverse carry and carries squeeze/gap risk; "fundamentals bearish" without a dated timing trigger is inadequate. (E)
• Realisation, not arithmetic: evidence that announced OPEC barrels or sanctions relief will reach loadings, not just quota tables. (E)
• Explicit upside tail: weekend attack, chokepoint closure, surprise cut, short-covering — a futures short has no natural price cap; low spare capacity makes spikes non-linear (Andurand). (E/P)
• Positioning check as a risk input only: a washed-out spec book raises squeeze risk; it is not a timing signal. (P/F)

6.4 Discount as folklore (keep only as risk cautions)

Fixed "EIA moves 2–4 %" rules · rig count as a Friday catalyst (thin session, slow variable) · "extreme COT percentile → fade" · calendar-month seasonality as a trigger · chart levels as thesis.

6.5 Making it deterministic

Each item becomes a function returning PASS/FAIL/NA with input_series, threshold, observed_at, rule_version. Hard vetoes: stale or quarantined data; prohibited expiry window; unmodelled event exposure; spread above cap; insufficient margin/gap capacity; contract unsupported; minimum unit above risk. Soft states never become free-form overrides: only interactions selected before the backtest may change size. The order generator consumes the checklist output; an LLM may explain a failure but cannot set a threshold or grant an exception (Tradero iron rule).

Undefined predicates are not cured by PASS/FAIL/NA (Codex review): every predicate — "false draw", "premium after a gap", "washed-out positioning", "event policy" — must name its feature, threshold, version and missing-data behaviour, and NA needs an explicit policy. "Expected move exceeds costs" is circular until a calibrated predictive distribution exists; until then it is a research-admission test, not a pre-trade predicate. Hard controls that belong in code, not prose: stale or revised data, clock synchronisation, missing or late releases, contract mapping and roll migration, price collars, maximum slippage, order rejection/cancel reconciliation, gross/net exposure, FX collateral and broker excess liquidity. Every production decision must be reproducible from versioned data, versioned code and immutable parameters.

7. Traps and asymmetries specific to oil

1. Weekend and headline gaps. OPEC+ decides on Sundays; attacks happen on Saturdays. −25 % (Mon 9 Mar 2020), +15 % (Mon 16 Sep 2019), ≈+22 % intraday (Mon 9 Mar 2026 VERIFY). CL/MCL are shut 17:00 Fri–18:00 Sun ET. Size from gap stress, not daily vol.
2. OPEC semantics. "Cut", "extend", "voluntary", "compensation" use slippery baselines. Parse target, dates, country allocation and realised output; reiterated compensation schedules are routinely re-filed (soft).
3. The negative price. 20 Apr 2020: May CL from $17.73 to −$37.63 in one session; Cushing 76–83 % full; OI still 108,593 on the penultimate day; TAS selling into the settlement window; IBKR's systems could not display negative prices (CFTC fine $1.75 m). Rules: never assume price > 0, never divide by price unguarded, never percentage-stop near zero, never hold the front CL into its last three sessions when Cushing is extreme either way.
4. Roll arithmetic. Carry arrives through convergence and contract replacement, not as a daily fee; a $0.50 monthly backwardation is ≈0.03 %/day, but a curve reshaping can be 5 % in a week. Oil ETPs (USO) bleed contango structurally (FINRA 20-14: one ETP lost 41 % in a week).
5. API/EIA whipsaw. Both are sample estimates within ~1 % of each other; Tuesday absorbs most of the surprise. Conflicting crude vs product numbers often reverse the first headline move.
6. Evaporating premium. Fear lifts price without lost barrels; confirmation that loadings continue removes it abruptly. The 2026 exception (barrels actually lost) will itself reverse on physical restoration — 8 Apr 2026 ceasefire: −16 % in a day.
7. Revisions and vintages. WPSR weekly values are not revised but are superseded economically by the PSM (current + two prior months); FRED series revise; EIA weekly production is a model re-benchmarked monthly, not a survey. Latest-value downloads are not backtest data.
8. Consensus is a survey. Reuters polls 4–9 analysts Monday/Tuesday; WSJ and Platts run others; medians shift and cutoffs are unrecorded. Store source, contributors, cutoff and later edits. If 90 of 100 historical events cannot be audited, S2 history is abandoned and the overlay runs forward-only (MASTER-PLAN §5.2).
9. Correlation breaks. USD/equity/oil correlations flip between growth, monetary and supply shocks; a static hedge adds exposure at the worst time.
10. Micro-contract liquidity and basis. MCL is cash-settled from CL but has its own book — measure spread/depth/fills by hour. TCL: not launched (postponed, TBD); when it lists, gate it fresh and ignore promotional "deep liquidity".
11. Pro-cyclical margins. CME raised CL margins 17.6 % four days after the negative print; IBKR house margin (~$1.7 k intraday CL VERIFY) reverts to full overnight margin at the intraday end time. Margin is collateral, not a loss limit; size to a 5 % day.
12. Settlement and expiry mechanics. Front-six CL settle on the 14:28–14:30 ET VWAP; marks can differ from last trade; expiry-day settlement uses 14:00–14:30; flag expiry OI, TAS and holidays.
13. Units and grades. Barrels vs kb/d vs tonnes vs gallons; Brent, WTI Midland, WTI Cushing and products embed location/quality/freight — a "global oil price" factor hides basis risk.
14. Data plumbing surprises. COT was not published 30 Sep 2025–19 Nov 2025 (backlog cleared 23 Jan 2026); the CFTC opened a COT format/frequency review in 2026; EIA discontinued the storage-capacity report after March 2024; holiday releases move to Thursday at varying times. Read calendars from the source each year.

8. Contract mechanics you cannot ignore

Broker close-out (IBKR): does not allow delivery on physically-settled futures; standard deadline — longs by end of the 2nd business day before First Notice Day, shorts by end of the 2nd business day before Last Trade Day; otherwise liquidated without notice. IBKR publishes product-specific close-out rows and reserves the right to liquidate without notice, so the generic formula is illustrative only: the engine must ingest the live product row and take the earliest of broker liquidation date, strategy roll date and exchange expiry — never a hand-derived date (for CLV26 the generic formula would give ~22 Sep for longs and ~18 Sep for shorts; treat both as unverified). Italian residents are served by IBKR Ireland.

Hours: CL on Globex Sun 18:00–Fri 17:00 ET with a 17:00–18:00 ET break Mon–Thu (Rome: 00:00–23:00, break 23:00–00:00). Circuit breakers: NYMEX Rule 589 dynamic circuit breakers (60-minute look-back; energy variant raised 7 %→15 % in March 2020; current value VERIFY); no halts in the last 5 minutes before the close. Negative prices: enabled by CME on 8 Apr 2020 (Advisory 20-152); options margined with the Bachelier model since 22 Apr 2020.

Sizing arithmetic at WTI ≈ $90: a 5 % day = $4.50/bbl = $4,500 per CL, $450 per MCL, $45 per TCL. 1 Sep 2026 was +5.2 %; 8 Apr 2026 was −16 %. Size to the day and the weekend, never to margin.

9. Event calendar (ET / Rome)

Rome = ET + 6 h except 8–28 March and 25–31 October 2026 (ET + 5 h) because US and EU daylight-saving dates differ. Convert America/New_York → Europe/Rome in code; never add six hours by hand.

9.1 Recurring

9.2 Holiday sessions (CME energy, 2026)

Labor Day 7 Sep (halt ≈13:30 ET, reopen 18:00 ET); Thanksgiving 26 Nov (halt ≈13:30 ET) and 27 Nov early close; Christmas 25 Dec closed. Product-specific times are posted ~2 weeks ahead and can change close to the date; CME distinguishes outright Globex trading from TAS early closes. Load the final holiday file from the CME trading-hours page rather than hard-coding halts. EIA/API/CFTC shift as above.

9.3 The next twenty trading days from 2 Sep 2026 (dated example of an event map)

NFP 4 Sep · OPEC+ Sun 6 Sep · Labor Day 7 Sep (early halt) · API Wed 9 Sep · STEO 9 Sep · EIA Thu 10 Sep 12:00 ET / 18:00 Rome · OPEC MOMR 10 Sep · IEA OMR + US CPI 11 Sep · China NBS 15 Sep · FOMC 16 Sep · IBKR short close-out CLV26 ~18 Sep · CLV26 last trade 22 Sep · FND 24 Sep · Brent Nov-26 expiry 30 Sep.

10. Snapshot — the market on 2 September 2026 (dated; will age)

2026 is a supply-shock regime, not a normal balance year. Fighting from ~28 Feb closed the Strait of Hormuz (~20 mb/d of crude pre-war). Brent went $61→$118 in Q1, the largest real quarterly rise since 1988 (EIA); +65 % in March alone (World Bank). Ceasefire 8 Apr (WTI −16 % on the day), front-month Brent high $118 on 29 Apr (EIA; the widely quoted "$126 peak" is unverified and may be a Dated or intraday print), MoU 17 Jun, WTI trough $69.63 on 24 Jun, strait effectively re-closed early July, Houthi Red Sea blockade 20 Jul, fresh US strikes ~1 Sep.

Information cutoff: prices as of 2 Sep 2026 ≈13:00 CET; the US weekly row is the WPSR for the week ending 21 Aug (the week-ending-28-Aug report was released later on 2 Sep and is not reflected); agency figures are the August editions. In the engine, every row of a table like this carries as_of, first_seen, source, contract and price-type fields; the prose below is a snapshot, not a data product.

What this snapshot implies for the study, not for a position: every rolling statistic computed on the last six months is a supply-shock sample; the official base case (EIA, World Bank) is mean-reversion as Hormuz normalises; the 2–20 day variables that matter now are transit/loading counts, the pace of Gulf restart, the Cushing floor, the 6 Sep OPEC+ decision, and agency balance revisions. Slow variables (shale, EVs, non-OPEC projects) are irrelevant at this horizon.

11. Recommendation for Tradero

Both studies reach the same verdict independently: Oil State v0 is a dashboard, not a forecast model, and the way forward is sequential hypothesis testing against frozen benchmarks, not a bigger score.

11.1 Oil State v1 — feature families to compute (never a summed score)

The Codex review rejected the "12-factor" framing as a collection of correlated feature ideas dressed as a model; accepted. v1 is organised as feature families, each with its interactions declared in advance. A factor count is not a research objective.

"Scored" means each family is standardised on its own expanding point-in-time history and exposes sign, confidence and freshness. Nothing is summed. A spare-capacity "buffer" is not a naive sum of nominal series divided by consumption — barrels are not fungible across grade, geography, sanctions and logistics — so STEO spare/outage series stay in context until a defensible construction exists.

11.2 Context-only (collected, displayed, not scored)

Realised vol, OVX, CL skew, liquidity, margin and gap regime (risk controls) · rolling oil–equity and OVX–price correlations as an exploratory regime diagnostic, never a scored factor · vintaged STEO balance revisions and spare/outage series as prospective context (few releases, heavy revisions) · COT 067651 managed-money long/short/spreading ÷ OI with both Tuesday and Friday timestamps — crowding and change, no contrarian score · USD DTWEXBGS, DFII10, DGS2, equities/VIX and rolling correlations · rigs, DUCs, China/India data, freight, floating storage, agency balance levels, GPR · SPR and sanctions as dated event objects whose flows enter the balance factors.

11.3 Drop as noise or mis-specification

Absolute 3-year percentiles of USD, yields or rigs with fixed signs · unconditional "COT extreme = reversal" · news/sentiment/article counts as a price score · calendar seasonality, RSI/support-resistance, ETF flows as standalone direction · any equal-weight sum before factor correlation, horizon and incremental value are established · any continuous futures series with an unknown splice.

11.4 Specific corrections to v0 (from Codex's code read, endorsed)

1. trend is two moving-average signs on a Yahoo/Stooq continuous front month with an unknown roll — replace with contract-correct settlements before any return research; keep a 50/200 rule only as one benchmark.
2. crude_inventory and cushing are stock-level seasonal deviations, not surprises — rename; build balance_innovation separately; replace the prior-five-year ±1-week mean/SD with robust expanding seasonals and expose sample size.
3. products equal-averages gasoline and distillate, omits jet, ignores days-cover — preserve components.
4. positioning hard-codes a contrarian sign — remove it; show OI-normalised long, short, spreading and their changes.
5. usd and rigs score absolute level percentiles — changes only, context-only.
6. The equal-weight aggregate mixes correlated weekly stocks, slow rigs/COT and daily prices with different effective timestamps — retire the directional label until walk-forward rules exist.
7. Historical WPSR values are stamped conservatively on Thursday — safe against holiday leaks but withholds normal Wednesday information and cannot support S2; store the official release calendar plus first-seen latency. Next holiday release: Thu 10 Sep 2026, 12:00 ET.
8. COT backfill starts 2017; disaggregated history begins 2006 — extend before estimating percentiles, preserving release-delay exceptions and the 2025 gap.

11.5 Hypothesis order (each step gated by MASTER-PLAN §7 before the next)

1. Data and execution integrity — individual-contract P&L, rolls, negative prices, MCL bid/ask and commissions; immutable raw release vintages and parse logs for every EIA, CFTC, STEO, IEA and OPEC input; clock and calendar checks.
2. Frozen benchmarks — no-change, long-only, random-entry, one trend family and one curve/carry family, separately and in one fixed combination; frozen without peeking at the final test years.
3. Curve family (F1) — does slope/curvature improve trend or carry? Strongest economic prior.
4. WPSR decomposition (F3) — post-release returns at the single pre-registered horizon; crude, Cushing, products, runs, imports, exports, adjustment; strict availability from the first executable timestamp.
5. Curve × inventory interactions (F1 × F2) — levels vs changes; estimated Cushing tail thresholds.
6. Cracks, location/export arb, outage state (F4–F6) — confirm or veto; only where data are licensed and point-in-time.
7. Slow global context — STEO/IEA/OPEC revisions, spare capacity, COT changes, macro interactions, seasonality — regime filters with long holdouts, preregistered signs, multiple-testing control.
8. S2 prospective EIA overlay — timestamped consensus, minute bars, fill simulation, paper first; never infer an intraday edge from S1 evidence.

Pre-registration: one primary horizon and one loss function are chosen before step 1 (testing 2/5/10/20-day horizons across 20/60/120/252-day lookbacks is a multiple-testing machine); secondary horizons are reported, not selected on. 2026 is a disclosed challenge set, not a clean holdout — it shaped this design.

Look-ahead traps to encode, not remember: F1 changes identity around rolls; inventory seasonals must be expanding-window and built from stored release vintages; EIA history downloads contain revisions; "known flows" must be known before the WPSR, not reconstructed later; cracks must align barrel/gallon units and contract months; STEO/IEA/OPEC tables need first-seen archives; index exclusions need the correct 5–9 vs 6–10 calendars.

Every step: walk-forward incremental return/Sharpe, drawdown and turnover after normal and 2× costs; stability across pre/post-2014, 2020 and the 2026 shock; materially better than the frozen benchmark — otherwise keep the simpler model. The project kill condition (MASTER-PLAN §0) still applies.

11.6 Instrument note

TCL is not executable (postponed, TBD). Signals on CL; paper execution on MCL with its own liquidity gate; TCL re-enters only behind a live product-status and liquidity gate after CME lists it and IBKR supports it. MASTER-PLAN §2 and the project memory should be corrected accordingly.

12. Where Claude and Codex agree, and where they differ

Full agreement (independently reached): trend and carry as the only defensible initial benchmarks · the curve as A-grade state / B-grade timing · EIA report as an intraday event (the evidence of no multi-day drift is a single-study absence result, grade B) · Cushing as the WTI-specific non-linearity · announced ≠ realised, with realised_net_loss as the modelled quantity · macro as context, static betas as noise · COT contrarian scoring unsupported · no equal-weight aggregate · v0 inventory factors are levels, not surprises · negative-price-safe code · size to gaps, not margin.

Differences and how they were resolved:

12.1 The Codex review of v1.0 — what changed in v1.1

Codex reviewed the merged v1.0 as second author (research/codex/2026-09-02-review-oil-fundamentals-doc.md). Accepted and applied: ICE Brent settlement wording and tick value; IBKR close-out treated as a live product row, not a formula; Cushing capacity language (stored volume vs working capacity; the 20 mb floor is a hypothesis); API paragraph downgraded to C; GSCI 5–9 vs BCOM 6–10 roll windows (both verified); WPSR "no drift" downgraded to B and attributed to Miao, Ramchander, Wang & Yang (2018); Benyo's end-of-month benchmark correction; the Brent "$126 peak" replaced with EIA's $118 front-month high on 29 April; an explicit information cutoff for §10; IEA's July draw qualified as mostly oil on water; magnitude bands removed; the regime classifier demoted to a diagnostic; the 12-factor list reorganised into feature families with two new families (location/export arb, physical disruption); the hypothesis order compressed with one pre-registered horizon and 2026 quarantined as a challenge set; checklist items rewritten as machine predicates with a hard-controls list; §3.9 added for thinly covered mechanisms.

Partially adopted: the proposal to replace the single grade with three axes — grades now state mechanism vs signal explicitly, and data reproducibility is delegated to the rights registry rather than a third column in every table. Deferred to the engine: a field-level as_of / first_seen schema for snapshot tables (the prose keeps a stated cutoff instead). Not adopted: none of the review's factual corrections were rejected.

12.2 Round two — the information and behaviour layer

Codex's independent round-two memo (research/codex/2026-09-02-part2-information-behaviour-chains.md, 53 chains) and Claude's six research notes (E–J) were merged into §14–§20.

Independent agreement: news must be stored as data objects with announced, expected and realised values and an append-only confirmation chain; geopolitical headlines have no drift beyond intraday; the three-session model with Brent-led Europe and WTI-led US; Shanghai INE as a conditional, not universal, leader; the participant map and the absence of a stable smart-money group; commercials' short-term position changes as liquidity provision; the narrative state as a diagnostic that reports distributions and never a score; GDELT, official reports and a curated X list as the free, legal core; the realistic single-market edge near a Sharpe of 0.3–0.5; and the chain format (trigger → transmission → observable → lag → sign → grade → destination).

Differences and resolutions:

12.3 The Codex review of v2.0 — what changed in v2.1

Codex reviewed v2.0 as second author (research/codex/2026-09-02-review-oil-fundamentals-v2.md). Its verdict: Part II is useful as an encyclopedia but was not yet a safe registry or collector specification — the merge had inflated conditional mechanisms into universal rules, mixed source authority with licence status, and turned episodes into laws. Accepted and applied: the chain catalogue re-validated (v2.0 claimed 66 chains but carried 70 ids); P5, P8, P9 and P19 split into two chains each because they mixed opposite mechanisms; R5 merged into P7 and X12's slow leg into L2; X8 split into freight-arb and floating-storage chains; four scheduled chains added (P21 inventory-report surprise, P22 expiry and roll, P23 planned versus unplanned refinery work, P24 weekly-to-monthly reconciliation) and placed ahead of slow structural chains; signs and grades corrected on P15, Q8–Q9, Q15, Q19, X4 (narrowed to product and refinery supply shocks, with §1 item 21 and §17.6 rewritten), X10, R3, R11; observables added to Q1, R2, R10, P4. Facts corrected: USO's five-day roll from January 2026; X's live post-read cap and endpoint pricing in place of a quoted per-read price; CME SPAN 2; the CL settlement rule stated in ET, not "Chicago time"; Dated Brent as an assessment, never a fix; ARA stocks in Amsterdam local time, sold not open; the two days-of-cover definitions; Boons & Porras Prado (JF 2019). Statements removed: "commercials are net short by construction", banks as synonymous with Swap Dealers, utilities as structural futures shorts, "all free and licence-clean". Schema changed to immutable claims plus append-only observations with separate authority, independence, measurement-quality, latency and rights fields; social-data retention, deletion compliance and GDPR obligations (household exemption, Garante 2025) written into §14.3 and §18; single-study mood signals downgraded; §18.1 renamed "sampled public venues" with the missing regions named; §15.2 sessions made overlapping and Asia a working prior; TAS treated as an execution diagnostic; §2.6 observables split into three latency classes and the index-inflow loop deleted; §2.7 given the 14:25 macro checkpoint and the WPSR holiday and DST branches; §1 items 16–23 rewritten as conditional statements; §20 rewritten so that the §11.5 order is preserved and a collector backlog is not a hypothesis queue; look-ahead traps and the missing risk tools added.

Partially adopted: the participant table keeps its secondary numbers with an explicit "no decision use" warning rather than deleting them; §1 item 19 keeps the retail finding as a case-study statement rather than being cut. Not adopted: none of the factual corrections were rejected.

13. Verification queue (consolidated VERIFY items, by priority)

P1 — affects decisions now

• TCL: launch date, tick value, expiry rule, IBKR listing, liquidity — re-check CME client-systems page and IBKR before any reliance.
• IBKR product-specific close-out rows for CL months and current house margins (CL, MCL) in TWS; IBKR Ireland specifics.
• CME CL/MCL maintenance margins (official page) and current Rule 589 circuit-breaker variant.
• OPEC MOMR 2026 dates on opec.org; OPEC+ Q4 pause status after 6 Sep. (STEO schedule and BCOM/GSCI roll windows: confirmed, closed.)
• WPSR "adjustment" footnote wording since Nov 2023; days-of-supply denominator.

P2 — affects research design

• Reconstruct 100 EIA events with consensus + cutoff (MASTER-PLAN §5.2 falsification test); no public archive exists.
• Baumeister–Hamilton posterior elasticities (~0.1 / −0.1 to −0.2); OPEC-surprise event-study magnitudes (telegraphed vs surprise); balance-revision day-of effect (1–3 % claim).
• Post-2015 size of the GSCI roll-window distortion; Basu–Miffre hedging-pressure magnitudes.
• Cushing ≈20 mb operational floor (market convention; EIA pilot study pending).
• Seasonality of monthly utilisation averages from the EIA table (secondary summary used).

P3 — context accuracy

• 9 Mar 2026 record daily gain vs exchange settlement; the reported Brent "$126" print (benchmark and timestamp); SPR 308 mb / 172 mb exchange; DUC count 5,319; Iran August loadings; UAE–Iran trade halt 19 Aug; Red Sea 8.5 mb/d; Bloomberg consensus panel; CFTC "77 % automated spread trades"; CME May-2026 skew note; current 2026 producer hedge ratios; Kelly (2023) SPR event study; TD3C March records.

P4 — round two (information, sessions, participants, mood, chains)

• Access and pricing: X API tiers and read caps; Reddit self-service closure and contract pricing; StockTwits API status; Substack, TradingView and Investing.com terms; Weibo and WeChat collectability; LinkedIn terms.
• Sessions: INE night-session end time and deliverable grades; Platts Dubai and Dated Brent methodology details (partials, convergence); TOCOM Dubai contract specs; GME Oman marker time; Baker Hughes release time on bakerhughes.com; IEA OMR clock time; GACC release clock; CME LO option expiry rule and TAS rule 524; EFP mechanics; Tadawul hours; month-end and quarter-end flow evidence; dealer-gamma pinning; ADNOC's November 2026 pricing change.
• Participants: Mexico's historical hedge volumes and the Pemex figure; Treasury's 2022 SPR price-impact number; BCOM assets under management; the HFT share vintage (~47 %); any audited COT-indicator track record; 2026 producer hedge ratios; leveraged-ETF rebalance magnitudes; Norway's arbitration precedent.
• Chains: Uri's ~4 mb/d crude loss; the 2016 E&P default rates; Russian 2023 statistics restriction (primary); Transneft schedule leaks; rig→production lag; Aramco's "largest cut since 2003"; the March 2026 $70→$119 path against settlements; the UAE-exit Brent–WTI sign; Q4-2026 OPEC+ pause; China product-export-quota publisher; South Asian 2022 switching volumes; the 2023 OPEC demand-growth cut; naphtha margin claims; IMO slow-steaming tanker demand.
• Mood: the OOTT origin; unconfirmed X handles (Kemp, Hansen, Sen, McNally, Pies, Nuttall, Young, Kpler, Vortexa, official feeds); Alhajji's Arabic activity; Ed Crooks's affiliation; the Calomiris–Çakır Melek–Mamaysky specifics; the CME CVOL skew page; AI-generated Hormuz videos; peer-reviewed work on 2026 social sentiment (none yet).
• Closed in round two: OPEC MOMR time (12:00 GMT); ARA stocks (Thursday 16:15 CET); BCOM roll days (6–10); STEO time (12:00–12:15 ET).

14. The information layer — how news becomes data

Oil is traded on information long before it is traded on barrels. This section describes the news flow as an engineering problem: which categories of news exist, what each does to price and for how long, which sources carry which authority, what a retail operator may legally automate, what the evidence says about news and attention as signals, and how the day should be organised in Rome time. The iron rule applies throughout: the LLM may classify and explain a headline; deterministic code computes the surprise, the confirmation and the eligibility.

14.1 A headline is a data object, not a fact

Every item, from an OPEC communiqué to a tanker-tracker post, is stored as an immutable claim plus append-only observations — the Codex review's correction to v2.0, which had one row that was both immutable and later overwritten with a realised value. The fields below merge the two studies' schemas. Authority, independence, measurement quality, latency and rights are five different properties and are stored as five fields, not one "tier".

EventClaim (immutable — one row per version of a claim)
  claim_id · category (§14.2) · subtype · entities[] (country / company / facility / vessel IMO / grade)
  announced_value, unit, baseline (quota vs voluntary cut vs production are different fields)
  expected_value, expected_source, expected_cutoff      ← captured BEFORE ts_event or flagged post-hoc
  surprise = announced − expected                       ← computed, never LLM-written
  magnitude in kb/d AND cumulative barrels over the active window
  direction_hint {bullish, bearish, mixed, n/a} + confidence   ← LLM classification, logged with model + prompt hash
  source_authority {official, wire, PRA/professional, expert, crowd} · source_independence (origin count, not outlet count)
  ts_event · ts_published (first version) · ts_first_seen · executable_at (feed + parse latency) · source timezone kept
  revision · content_hash · headline_hash · cluster_id (same fact across outlets) · correction_of · retracted_at
  lang · translated_from · url · rights_tag · retention_class · parser_version · human_override_reason

EventObservation (append-only — many per claim)
  claim_id · observed_at · observation_type ∈ {confirmed, denied, corrected, retracted, measured}
  source, source_authority, measurement_quality {official statistic, licensed measurement, modelled estimate, report}
  realised_value, unit, measurement_window, latency, rights_tag

Rules that make it back-testable: the expectation must exist before the event; a realised value is an observation with its own measurement quality — an official designation is not realised lost supply, while a licensed loadings measurement may be the best available — and never overwrites the claim; the observation log is append-only so a denial after a report stays visible; anonymous "sources say" items keep low independence until the primary party or two independent origins confirm; corrections create a new claim version; the chain of physical confirmation is explicit, e.g. minister statement → operator nomination → port line-up → AIS departure → customs/JODI. Raw social text is not archived immutably: platforms require deletion compliance (X compliance streams; Reddit's requirement to delete cached and derived content), so the store keeps identifiers, permitted metadata and irreversible daily aggregates, with a retention_class per row.

14.2 News taxonomy — what each category does, and whether anything is tradable afterwards

Codex's compression of the same table: realised outages, policy converted into dated barrels, scheduled data as surprises, and cargo confirmations are the classes with after-the-fact value; threats, statements, macro indices and crowd posts are context or risk, never direction.

14.3 Sources by tier and region, with timing and rights

Tier 0 — primary and automatable (free unless marked)

Tier 1–2 — wires, professional services, price-reporting agencies, trackers (paid)

Tier 3 — free and cheap aggregators, newsletters, expert accounts

OilPrice.com (RSS exists, but the terms forbid robots and non-personal use: store headline, link and timestamp only) · Rigzone, Upstream, Oil & Gas Journal (RSS) · Commodity Context (Rory Johnston; free tier, paid $75/mo; Oil Context Weekly Fridays 22:00–23:00 Rome) · HFI Research (paid daily) · Doomberg (paid) · Super-Spiked (Arjun Murti, free) · John Kemp's energy analysis · GDELT (free, 15-minute global event feed in 65 languages — its own datasets are broadly reusable, the linked articles are not, and GDPR still applies; noisy but usable) · Economic Policy Uncertainty and Geopolitical Risk indices (free, CC BY 4.0).

Widely followed X accounts with confirmed identities: Javier Blas (Bloomberg), Amena Bakr (Kpler), Rory Johnston, John Kemp; commonly cited: TankerTrackers, HFI Research, Doomberg, Arjun Murti, Giovanni Staunovo, Helima Croft, official EIA/OPEC/IEA/BSEE/NHC accounts VERIFY handles and current affiliations. Keep a dated registry of author, platform, language and rights rather than a permanent "key account" list.

Tier 4 — crowd (§18): Reddit, StockTwits, TradingView, Weibo/Xueqiu/East Money, Telegram/Discord/WeChat, local forums. Attention and narrative anomaly only; a post never becomes "realised supply".

What a retail operator in Italy can legally automate — source by source, never by category. Government and agency statistics with open terms (EIA, CFTC, JODI, OFAC, EU Official Journal, BSEE, NHC); GDELT's own datasets (broadly reusable, but that grants no rights in the linked articles); EPU/GPR (CC BY 4.0); RSS headline metadata from sites that publish feeds; X through its API only (a 2 million post-read monthly cap and endpoint-specific prices in the Developer Console; filtered streams exist; plan, version and price stored as live configuration, never quoted as a constant); own paid newsletters for personal analysis. Public is not open: the IEA excludes the OMR and standalone datasets from its CC BY licence; Insights Global sells the ARA series; CME's website terms prohibit systematic extraction and AI use without permission; Argus prohibits scraping. Not: full-text scraping of OilPrice, Reuters or Bloomberg; redistributing API, Argus, Platts or IEA numbers; publishing derived series built on licensed feeds; Reddit at commercial scale without a contract (self-service access closed in late 2025 VERIFY); private WeChat or Telegram groups. Personal data: the GDPR household exemption ends where use becomes professional or commercial (recital 18); beyond it the project needs a lawful basis, purpose limitation, minimisation, retention limits, an Article 14 analysis, erasure handling and a legitimate-interest assessment; the Italian Garante has rejected indiscriminate reuse of public social data (2025 decision); author-level histories and bot scores are profiling and are avoided unless necessity is documented. Every field admitted to the system carries a rights tag and a retention class (MASTER-PLAN §5.3).

14.4 What the evidence says about news and attention as signals

Two structural cautions. Attention is endogenous: oil shocks generate searches and posts, so "sentiment predicted price" often means timestamps failed to separate reaction from anticipation. And the robust findings are narrow: scheduled inventory surprises move price and leave intraday momentum; geopolitical headlines move price instantly and then carry no drift; attention and sentiment mostly forecast volatility; any news-based state must classify a geopolitical shock as energy-type or macro-type before it is given a sign.

14.5 The operating routine in Rome time

Use Europe/Rome and exchange calendars in code; never hard-code a six-hour offset (five hours during 8–28 March and 25 Oct–1 Nov 2026). The human reads conflicts, not feeds.

Daily (present 15:30–20:30): 15:30 read the machine-generated Asia/Europe handover — overnight returns by contract, curve, basis, cracks, INE and Dubai moves, new confirmed event objects, data failures; 15:40 inspect Tier 1–2 exceptions and today's event clock; 16:20 Wednesdays freeze the pre-release state; 16:30 WPSR ingest and surprise computation by code, the trader watches the 16:30–17:00 window; 17:00 check whether price, spreads, cracks and observed flows agree; 18:00 on STEO days read the vintage diff; 19:00 Fridays glance at Baker Hughes, never trade its level; 20:15 decide overnight exposure ahead of the 20:28–20:30 settlement; keep an incident log, not a scrolling-news habit.

Weekly: Tuesday 22:30 API arrives outside attendance — collected automatically, parsed surprise delivered Wednesday morning. Friday 21:30 COT and 22:00–23:00 Oil Context Weekly — read Saturday. Sunday evening: OPEC+ statements and weekend geopolitical items checked before the Monday 00:00 Globex open; a system alert fires on any Tier 0–1 item published after Friday 20:30. Friday: compare cargo and loading estimates with their later revisions and score source accuracy.

Monthly: IEA OMR 10:00, OPEC MOMR 14:00, STEO 18:00, PSM on the last business day (triggers revision of weekly series), JODI, Aramco OSPs (poll from the 4th), China customs and NBS, CME/ICE margin cycle, OFAC/EU package cadence — all collected as vintages, read as a one-page revision diff. Quarterly: earnings hedge tables, refinery maintenance schedules, Dallas Fed survey, index weights. January: BCOM/GSCI reweighting audit.

Collect automatically, invoke the LLM only on change:

Hash normalised text (strip timestamps, adverts, "updated x minutes ago"), or every re-fetch looks new.

14.6 Pitfalls, and how desks triage

1. Rewritten pages. Wire stories are updated in place; the first version may carry a wrong number that later disappears. Snapshot every version, bump the revision, keep the first ts_published.
2. Headline versus body. "OPEC+ agrees to cut" over a body that says "delegates say no final decision". Separate hashes; classify from the body; hedging words ("sources", "could", "considering") map to status = sourced, not confirmed.
3. Rumour laundering. A claim moves crowd → aggregator → wire ("reports say") and acquires false authority. In 2013 an Israeli army account tweeting a 1973-war anniversary line lifted Brent about $1 within minutes; in May 2026 an Axios report of a US–Iran memorandum took Brent from $108 to $97 before it recovered to ~$102, one of several "false starts" traders called suspiciously timed VERIFY single-outlet account; doctored strike videos reached millions of views before fact-checks. Rule: at least one Tier 0–1 independent confirmation before an item can change the Oil State; count sources by origin, not by outlet.
4. Duplicate reporting. One Reuters story on dozens of sites inflates "attention". One cluster id, many URLs.
5. Timezone traps. DST-mismatch weeks; "data as of Tuesday, released Friday" (COT); "week ending Friday, released Wednesday" (EIA); holiday shifts to Thursday at varying times. Store event, published and ingested timestamps in UTC with the source zone string; derive Rome time at display only.
6. Translation loss. OPEC, Gulf ministries, Russian and Iranian agencies publish in Arabic, Russian and Farsi; wire translations drop modals and conditionals. Keep the original, mark translated_from, treat machine translations as Tier 3 until a Tier 1 English version exists; GDELT's translingual feed is for detection, not quotation.
7. How desks triage VERIFY: inferred from the services they buy: a speed layer (machine-readable headlines with sentiment and novelty scores, or a human squawk grading priority), a confirmation layer (second independent source or primary document before size is added), and a numbers layer (consensus versus actual computed by code). Tradero mirrors this: Tier 3–4 alerts, Tier 1 confirmation, Tier 0 realisation.

15. Sessions and regions — who moves the market, when

15.1 The master clock

Rome = ET + 6 h and London + 1 h, except during the DST-mismatch weeks (8–28 March and 25 October–1 November 2026: ET + 5 h). ICE states its settlement window in London time and CME states its CL procedure in Eastern Time (14:28–14:30 ET; 14:00–14:30 ET for the expiring contract), so the two windows coincide except in those weeks — a real engineering point for a Brent–WTI overlay. Store every timestamp in the zone the rule names plus UTC and convert at query time.

15.2 The three-session hand-off

Shape of the day. Practitioner sources describe a U-shaped liquidity profile: the London–New York overlap (13:00–17:00 UTC) has the deepest book and tightest spreads, the London morning is second, the Asian window is thinnest; institutional Brent activity thins after London closes and volume migrates to WTI alone VERIFY with tick data before relying on it. The academic evidence is strongest on the announcement spike: EIA surprises move returns inversely and lift volatility asymmetrically (Ye & Karali 2016; Miao 2026 VERIFY), and on EIA days the third half-hour predicts the last half-hour (Wen et al. 2023). Mean absolute daily move peaks on Wednesday (1.91 %) and troughs on Friday (1.61 %) in EIA spot data. A pre-COVID positive Monday effect disappears in the full sample; EIA days carry a positive return effect including holiday-shifted Thursdays (Cogent Economics & Finance 2023).

Sunday open and the weekend. The first tradable print after a weekend is the Sunday 18:00 ET open through a thin book. On Monday 2 March 2026 crude gapped ~8 % higher after a weekend drone strike shut Aramco's Ras Tanura refinery; Gulf equity markets in Dubai and Abu Dhabi closed for two days. Weekend retail CFD quotes are not the futures market and re-align to the Globex open. Gulf equity exchanges open on Sunday (Tadawul trades Sunday–Thursday VERIFY hours), so Aramco's share price and TASI are the first liquid prints on Gulf news before Globex opens — a usable early gauge for a Sunday gap estimate.

Month-end, quarter-end and the January reweighting. The documented calendar flow is the January reconstitution: for 2026 BCOM set WTI at 6.64 % (lowest on record) and Brent at 8.36 % (highest), the largest divergence since Brent's inclusion; BCOM rebalances over business days 6–10 and GSCI rolls from about 8 January over five days, so index flow concentrates around 8–15 January — a "mechanical, price-insensitive" rebalance out of last year's winners. Month-end and quarter-end pension rebalancing is widely discussed but undocumented here VERIFY before coding. Intraday evidence finds index-flow impacts statistically strong but economically modest and temporary (Ready, Roussanov & Ward 2022).

Options expiry and TAS. (TAS gross volume is signless by construction; a signed imbalance is a testable diagnostic.) ICE Brent options cease three business days before the future's expiry, with in-the-money auto-exercise one hour after the 19:30 London settlement. CME WTI monthly options expire three business days before the future VERIFY; Micro WTI weekly options exist since June 2022, and CME has added Monday/Wednesday and Tuesday/Thursday weeklies, so WTI expiry is now near-daily and the classic monthly "gamma pin" is diluted — "options expiry" needs product, underlying, strike and date, not a monthly flag. Dealer-gamma pinning is a practitioner claim without a retrievable study VERIFY. TAS trades at the eventual settlement plus a permitted differential: it concentrates benchmark demand into the 14:28–14:30 window and shows up as a volume spike that by construction carries no directional information.

15.3 Which benchmark leads

The literature is not unanimous and the answer is time-varying: an intraday 2007–12 study has WTI dominating price discovery; a Journal of Asian Economics study finds Brent "the most influential market" with WTI "the most sensitive" and Shanghai SC influencing nothing; a 2023 spread study has Brent driving; the SC contract moved from follower to bidirectional causality about 15 months after its 2018 launch (Frontiers 2022), with newer 15-minute evidence that INE's information share rises during its daytime liquidity and jumps while longer-horizon volatility favours WTI (Shi & Zheng 2026). The robust conclusion is integration, not a permanent horse race. Working assumption: in London and New York hours Brent and WTI are jointly determined, Brent marginally leading on non-US news and WTI leading on US inventory and Cushing news; in Asian hours SC is a follower with occasional local information (Chinese demand, RMB), and Dubai/Oman is a physical-differential market rather than a flat-price leader. Any SC-lead test must be conditioned on session, because SC's night session straddles London and the US settlement.

15.4 Asia

Shanghai INE crude (SC). Listed 26 March 2018, RMB-denominated, physically delivered, 1,000 bbl per lot, deliverable grades including Dubai, Oman, Basrah and Shengli VERIFY grade list; first-year retail share slightly over three-quarters of volume and over half of open interest, ~92 % of volume domestic despite 52 registered overseas agencies; volume regularly far exceeds open interest. Its night session overlaps the entire London afternoon and the US morning through settlement, which is why it looks like a follower: it is open while the leaders trade.

Chinese retail and the April 2020 lesson. Bank of China's "Crude Oil Treasure" was pegged to the flat front-month price with 100 % margin and settled its May exposure on 20 April 2020 at −$37.63; the bank's estimate of retail losses rose from 600 million to more than 7 billion yuan (~$1 bn); the bank absorbed the negative-price losses, refunded 20 % of principal, and was fined 50.5 m yuan. Chinese bank and retail products roll mechanically and late; their forced flows land in the US settlement window on expiry-adjacent days.

Gulf benchmarks traded in Asia. GME (ex-DME) Oman launched June 2007, physically delivered FOB Oman, daily marker at 16:30 Singapore to coincide with Platts; Saudi, Kuwaiti, Omani, Bahraini and Dubai OSP formulas reference it; DFM lists a cash-settled 100-bbl micro Oman contract for Gulf retail. Platts Dubai is assessed in a Singapore MOC ending 16:30 SGT in 25,000-bbl partials converging to a 500,000-bbl cargo after 20 partials, deliverable as Dubai, Oman, Upper Zakum, Al Shaheen or Murban VERIFY methodology details. The Brent–Dubai EFS is the bridge between the sour Asian complex and ICE Brent: a widening EFS makes Dubai-linked barrels cheaper for Asian refiners and is one of the cleanest "Asia versus Atlantic" signals available. ADNOC announced a 2026 move from Murban-based pricing to Platts Dubai plus a differential effective November VERIFY implementation — benchmark methodology is itself market data.

Japan and India. TOCOM's yen-denominated Platts Dubai contract (50 kl ≈ 314.5 bbl, since 2001) is a hedging and Japanese-retail venue, not a leader. India's MCX crude (100 bbl; mini 10 bbl), priced against WTI in rupees, is described as India's most traded commodity contract VERIFY, with an evening session overlapping US releases; MCX settled the April 2020 contract at −₹2,884/bbl, producing ₹418–450 crore of mostly retail losses because domestic hours closed before the NYMEX collapse; negative prices were enabled from 27 July 2020. Both are large retail crowds reacting to the same 10:30 ET and 14:30 ET events — sentiment gauges, not inputs.

Chinese data and Asian-hour correlations. NBS activity data (including refinery throughput) at 10:00 Beijing around the 15th–20th; GACC preliminary trade data in the first ten days of the month, Beijing morning VERIFY clock time. Correlations of oil with Asian equities, CNH and JPY during Asian hours were not sourced — VERIFY with data.

15.5 Europe

The Brent complex. Platts Dated Brent reflects the most competitive of the BFOET-plus-WTI-Midland grades at exactly 16:30:00 London, assessed from bids, offers and trades in the 16:00–16:30 MOC window; WTI Midland was added from June 2023 deliveries, priced CIF Rotterdam like the North Sea grades (WTI flows to north-west Europe had grown from 13 kb/d in 2016 to 778 kb/d in 2022). Around Dated sit the forward BFOE cash market and weekly CFDs (cash-settled on Dated versus first-month cash BFOE, 100,000-bbl lots VERIFY), which tie the physical to the futures curve. The 16:30 London assessment is the daily physical read on North Sea tightness — a PRA assessment with editorial judgement, not an exchange fix; a Dated–futures blow-out is a physical signal the futures screen sees only with a lag (Energy Aspects, April 2026: "physical crude is trading much higher than futures").

ARA product stocks. Insights Global publishes ARA inventories of naphtha, gasoline, jet-kero, diesel/gasoil and fuel oil every Thursday at 16:15 Amsterdam local time, sourced from terminal inventory systems; the series is sold, not open — a subscription and a timestamp SLA come with it.

Refinery structure, gas and why diesel leads. European refineries run mostly sweet crude, yielding gasoline and naphtha; raising diesel yields needs hydrocracking, which "uses a lot of hydrogen" made from gas, so TTF spikes raise European diesel costs directly. July 2026: diesel cracks ~$70/bbl, gasoline ~$40, jet ~$60; a 70:30 hydrocracker earned $30.46/bbl over Brent versus $23.42 for an FCC configuration; refiners rotated yield from jet back to road fuels after the Iran-war jet surge. The structural "diesel-short, gasoline-long" framing is standard but was not confirmed from an IEA/FuelsEurope primary page VERIFY.

Monthlies. IEA OMR mid-month at 10:00 Paris (11 Sep, 14 Oct, 13 Nov, 11 Dec 2026); OPEC MOMR at 12:00 GMT. Both land while Brent leads; no event study of their price impact was retrieved VERIFY with data.

15.6 United States

The weekly cadence and pit hours. "Pit hours" (09:00–14:30 ET) remain the convention for the liquid US session because settlement closes it VERIFY: convention. API Tuesday ≈16:30 ET (thin, post-settlement), EIA Wednesday 10:30 with full tables after 13:00, Baker Hughes Friday 13:00, CFTC Friday 15:30 (an aggregator's 14:30 is wrong — trust the CFTC). Both API and EIA cover roughly 90 % of the industry.

Settlement, TAS, EFP. Settlement is the 14:28–14:30 ET VWAP (§8). EFPs exchange futures for physical positions and are the plumbing between Cushing physical and CL VERIFY mechanics on CME.

The physical rhythm. Argus WTI Houston is Permian-quality WTI at the Magellan East Houston terminal, assessed as the day's volume-weighted spot trades and quoted as a differential to the NYMEX settlement — ~1.25 mb/d and >300 trades a month in Q1 2024, more than the eight or so monthly cargo trades across the Dated Brent basket, with >160,000 lots of open interest in CME/ICE contracts that settle on it. Nearly 2 mb/d of pipeline capacity links Cushing to Houston (Seaway 950 kb/d, Marketlink 750 kb/d VERIFY); exports leave through Corpus Christi, Houston and Beaumont/Port Arthur; Argus approved 12 US export terminals for Midland cargoes eligible in its North Sea Dated assessment. Physical WTI trades in the month before delivery (the "trade month"), so the physical calendar runs roughly a month ahead of the futures expiry VERIFY dates. Roughly 3.85 mb/d of 2025 US crude exports originated in PADD 3, so Gulf Coast export economics (§17, chain P7) matter more than naked Brent–WTI.

Equities and dealer positioning. Interactions with the energy sector and with dealer option positioning were not sourced — hypotheses to test, not facts VERIFY.

15.7 Middle East

Saudi Arabia transmits policy through three different objects — the OPEC+ target, actual production and allocations, and the Aramco OSP — and none should be inferred from another. Nominations reveal customer demand; allocations can express Saudi strategy.

OSPs — the monthly signal. Aramco publishes next-month official selling prices early in the month: February 2026 prices on 5 January (Arab Light +$0.30 vs Oman/Dubai to Asia); July 2026 on 8 June (+$9.50 Asia, +$15.65/15.85 Europe, +$12.60 US — rationing); August 2026 at −$1.50, a cut of ~$11 described as the largest since 2003 VERIFY; September 2026 at −$2.00, the lowest since June 2020, reported 12 August. The Asia OSP is set against the Platts Dubai/DME Oman average, so it embeds Aramco's read of the Dubai structure and the EFS: a large cut signals a seller chasing volume, a large rise signals rationing. Release day floats (5th–12th in 2026): poll rather than schedule. Grade: A as a pricing mechanism, C as a WTI direction signal.

Hormuz mechanics. About 20 mb/d of crude and products transited in 2025 (~15 mb/d crude, 34 % of global crude trade; 80 % to Asia, China and India taking 44 % of the crude). Bypass capacity: Saudi Petroline 7 mb/d nameplate with ~2 mb/d used (3–5 mb/d spare) and UAE ADCOP 1.8 mb/d with ~0.7 mb/d spare, ~3.5–5.5 mb/d total; Iran's Jask terminal effectively non-operational (IEA). A Hormuz story should be a graph of transits, loadings, bypass throughput, insurance and shut-in output — not "tension". 2026 reality: by 14 March Iranian attacks on tankers at Basra and the blockade had cut Iraqi output to 1.4 mb/d from 4.5+ mb/d, with Baghdad pressing to push at least 100 kb/d through Kirkuk–Ceyhan.

Early signals. Gulf equities open before Globex on Sundays (2 March 2026: TASI +0.13 %, Aramco +1.63 %, Qatar −4.29 %, DFM/ADX closed). Accounts that break Gulf and OPEC+ news: Amena Bakr (Kpler), Reuters' Gulf and OPEC desks, Bloomberg's Javier Blas, Argus and Platts MOC reporters VERIFY handles before wiring a collector.

15.8 Russia

Urals is not "Russian Brent". Argus' Urals FOB Primorsk/Novorossiysk quotes are assessments built from Dated Brent, a Brent–Urals spread estimate and freight estimates, increasingly using netbacks from Indian landed prices; a former Gazprom Neft strategist argues official Russian averages (e.g. $46.82/bbl) understate actual sales to India at $70–75. Discounts: ~$15.5/bbl at Primorsk in March 2025; $28/bbl in 9–13 February 2026, deepest since April 2023, on sanctions, falling Indian purchases after a US tariff deal and icy-Baltic freight; Brookings tracks the wedge peaking near $30, narrowing to ~$12.50 by October 2025, widening to ~$27 by December 2025. ESPO/Kozmino has different Asian economics and consistently trades above the cap.

The cap. The G7/EU cap bars coalition firms from financing, shipping or insuring Russian crude sold above the cap; the EU replaced the fixed $60 with a dynamic cap 15 % below the 22-week average Urals price — $47.60 from 3 September 2025, $44.10 from 1 February 2026, six-monthly reviews. It binds through insurance (the International Group of P&I Clubs covered ~90 % of vessels), which is why the shadow fleet matters. Effectiveness is discount + service cost + realised volume, not whether a headline cap was breached.

Shadow fleet and routes. Russia exports 4–5 mb/d of crude by sea; Baltic loadings split ~69 % Primorsk / 31 % Ust-Luga; by March 2025 a ~350-vessel shadow fleet (average age 19) carried over 60 % of Baltic crude; the EU's 18th package listed ~500 vessels; ~0.8 mb/d is sold above the cap FOB.

Ukrainian strikes. Tankers hit at scale (ten sanctioned tankers in one July operation; the Kairos and Virat near Novorossiysk; a first Mediterranean strike); refinery strikes produced fuel shortages and diesel export bans VERIFY dates. "Refinery strike = bullish oil" is usually wrong without the next link: less product supply is bullish cracks, while freed crude can lift exports and depress crude; only storage or export constraints force upstream shut-in. Russian statistics are restricted VERIFY the 2023 primary; coverage comes from Argus (whose Baltic Urals data even the Russian tax authority proposed to use), Kommersant, Bloomberg tanker tracking, IMO GISIS, Kpler/Vortexa/LSEG weekly exports, and Transneft schedules leaked through Reuters VERIFY.

15.9 Other recurring event-source regions

15.10 What this implies for the intraday overlay (engineering, not advice)

1. Store every timestamp in the venue's home zone plus UTC; derive ET, London and Rome at query time.
2. Model the day as three regimes (Asia thin follower; Europe Brent-led; US WTI-led); condition every lead-lag test on session.
3. Treat 10:30 ET as a structural volatility event with documented asymmetry and intraday follow-through, and 14:28–14:30 ET as a benchmark calculation window: settlement is a computed mark, gross TAS volume is signless, and a signed TAS imbalance may carry information — both are execution diagnostics until tested.
4. Carry a real calendar: EIA/API holiday shifts, OPEC 12:00 GMT, IEA mid-month, ARA Thursdays, NBS 10:00 Beijing, the OSP polling window, the 8–15 January index roll, ICE option expiry (futures expiry − 3 business days), near-daily WTI weeklies.
5. Weekend module: Sunday Gulf-equity prints and Middle East feeds produce a Sunday 18:00 ET gap estimate.
6. Regional supply-risk nodes, each with its own event grammar: NOC force majeure (Libya), CPC SPM and tanker strikes (Kazakhstan), Hormuz and bypass capacity (Gulf), Kirkuk–Ceyhan status (Iraq), late-May wildfires (Canada), Norwegian wage rounds (June–July), Urals discount and cap resets (Russia, six-monthly).

16. The participant map — who trades oil, why, and where it shows in the data

16.1 Reading the public footprints

The single most useful public dataset is the CFTC's weekly Disaggregated Commitments of Traders, which splits reportable open interest into Producer/Merchant/Processor/User, Swap Dealer, Managed Money and Other Reportables. Three caveats govern every signal built on it: the CFTC classifies traders, not trades ("by predominant activity" on Form 40 — a merchant or a bank desk can speculate inside a "commercial" bucket, and all of a trader's positions land in one category); index-investor data is gone (the monthly Index Investment Data ended with the October 2015 report); and the programme is under review (Federal Register, 5 May 2026: frequency and content of the reports — assume the format may change).

16.2 The groups

The numbers in this table (fund returns, merchant profits, hedge ratios, index assets, HFT shares, community sizes) are secondary, mutable estimates kept for orientation; none has decision use, and each must be sourced to a filing or method note before it enters any model.

16.3 Hedgers, speculators, and the myth of smart money

Synthesis. There is no stable smart-money group. The CFTC classifies traders by predominant business, so Producer/Merchant/Processor/User positions can be net long or net short in any given report — a rising commercial short in a rally is usually hedging demand (a slow risk-premium signal), while short-term changes in commercial positions reflect liquidity provision to speculators (a mean-reversion signal); both are empirical quantities for a specified report, never structural constants. Managed money is reactive and momentum-like — right in trends, wrong at extremes. Practitioner "COT index" and "commercials vs large specs" rules (Briese, Williams) have no audited track record in crude VERIFY; the closest evidence implies they work only when the horizon of the position change is respected (multi-month hedging pressure, not week-to-week noise). Retail's April 2020 mistake was structural, not proof that retail always loses: dip-buying products held a deliverable expiring future with no preparation for negative settlement.

16.4 Reflexive loops and three episodes

• Positioning → price → positioning. Funds add on strength and cut on weakness; commercials fade them and are paid a liquidity premium; in stress the funds' cuts push risk back to producers. Observable: the rate of change of Managed Money net length versus its percentile.
• Margin calls → forced selling and de-hedging. In 2022 ICE Clear Europe TTF initial margin rose sixfold January–April; structural shorts had to pay variation margin; some "reduced their hedging activities altogether"; TTF open interest fell >40 % with large drops in Brent — hedging capacity contracted exactly when the curve most needed sellers; LSGO margin rose 90.3 % in a single step in March 2022.
• ETF flows → roll → curve. Inflows in contango force front-month buying and a scheduled roll everyone can see; in April 2020 that made USO the fulcrum of the May contract; the CFTC found open interest "much higher than usual" before expiry and liquidity falling "well before April 20".
• Producer hedging → curve. Rallies trigger deferred selling that flattens or flips backwardation (Dec 2016), lowering the price at which the next producer can hedge; collars leave dealers short puts whose delta-hedging accelerates the next fall.

Episode A — April 2020 (demand shock, super-contango). Retail and ETFs bought the dip through instruments with public, late rolls; merchants with tank space bought the contango; TAS hit 21 % of volume; the May contract settled at −$37.63 and the losses landed on retail; the survivors were producers who had hedged 51.7 % of output.

Episode B — 2022 (supply shock, backwardation, margin spiral). Margin calls hit merchants and utilities; open interest collapsed as hedgers de-hedged; Citadel and the merchants booked record profits from dislocation; the US released 180 mb; prices fell back in H2 as managed money de-risked into a curve that hedgers had stopped selling.

Episode C — 2026 (Hormuz closure). Set-up: record Brent managed-money shorts, US producers ~4 % hedged for 2026, no US airline hedged. Shock: strikes on Iran on 28 February and a de-facto closure; Brent $61→$118 over Q1; global supply −10.1 mb/d in March; Brent–WTI $25. By group: CTAs already long rode it then cut on volatility; specialists won, multi-strategy platforms lost; managed money swung to a four-year-high net long by 17 March; unhedged shale captured the upside while hedged peers were capped; the US released 172 mb inside a 400 mb IEA action; refining margins doubled. Q2 retraced ~30 % before a record mid-July weekly rebuild of Brent longs.

What the episodes share, and what it means for Tradero. In each episode, separately documented, a group with pre-committed flows — published rolls and late-rolling retail products (2020), mechanical margin (2022), hedge programmes triggered by price levels and vol-targeted CTA cuts (2026) — moved price at the extreme while the discretionary groups mostly reacted; this is three case studies, not one law. The actionable public data are therefore calendar-known flows (index rolls and the January reweight, ETF roll dates, options expiries and heavy strikes, SPR schedules), the decomposed rate of change of Managed Money positioning, and the contract mechanics that decide who is forced — not the level of "commercial" shorts, which mainly measures hedging demand.

17. The cause→effect chain catalogue

This is the section the owner asked for: the causes of the causes. Every chain is written in one fixed format so it can later become a row in a hypothesis registry — but it is not one yet: a registry row additionally needs trigger_first_seen, an expectation and cutoff where one exists, an executable_at timestamp, a named falsifier and a missing-data policy, and it enters research only through the §11.5 gate (§20). Chains split or added after the Codex review of v2.0 carry a/b suffixes or ids above the original range. Signs are for the trigger as named, first-order and bullish-version: flat + = higher WTI; front + = wider F1–F2 (more backwardation); cracks + = products strengthen versus crude; B–W + = Brent minus WTI widens; ? = no stable first-order sign; reverse the trigger, reverse the sign. Lags are priors to test, not constants. Grade is mechanism / signal where they differ. Enters says where the chain could live in Tradero: S1 (swing), S2 (event overlay), S3 (spreads), context, or never. The catalogue merges Claude's 41 chains (research note I) and Codex's 53 (memo part 2); after the review's splits, merges and additions it holds the chains listed below, each with a unique id.

17.1 Physical and logistics chains

• P1 — Gulf offshore shut-in (hurricane, accident). Trigger: platforms evacuate; crude output stops while refineries and ports stay open. Transmission: lost production → PADD 3 stock draws. Observable: BSEE daily shut-in statistics, NHC advisories, EIA PADD 3 stocks and runs. Lag & decay: headline minutes; stock effect 3–10 days; decays along the reported restoration curve. Sign: flat +, front +, cracks −/0, B–W −. Grade: A mechanism / B timing. Enters: S2 event; S1 confirmation.
• P2 — Hurricane's dual hit. Trigger: a storm closes refineries, LOOP/Houston/Corpus terminals or product pipelines as well as platforms; the dominant lost flow decides direction. Harvey 2017: runs −3.2 mb/d, utilisation 96 %→63 %, retail gasoline +28 ¢/gal in a week while WTI fell to a six-week low. Ida 2021: 96 % of federal Gulf output shut in, 28 shut-in days, Gulf runs −1.6 mb/d. Observable: NHC cone, BSEE, USCG port conditions, EIA runs WCRRIUS2 and exports WCREXUS2, company notices. Lag: forecast days, closures hours, restoration 2–4 weeks (Ida) to months (Katrina/Rita). Sign if downstream loss dominates: flat −, front −, cracks ++, B–W +; production-dominated: the reverse. Grade: A mechanism / B net sign. Enters: context until the net-flow rule is deterministic.
• P3 — Refinery-unit outage. Trigger: fire or power loss at a CDU, FCC, hydrocracker or coker. Transmission: crude intake falls; the product effect depends on the unit (FCC tightens gasoline; hydrocracker/coker tightens distillates and heavy-crude demand). PES Philadelphia (June 2019, ~27 % of East Coast capacity): RBOB +3.9 % on the day; never restarted. Observable: EIA-820 unit capacities, PSM downstream inputs, 8-Ks and press releases, state flaring filings, IIR/Wood Mac feeds (licensed). Lag: products minutes, crude stocks 1–2 WPSRs, decay on restart. Sign for a large USGC FCC outage: flat −, front −, gasoline crack +, B–W +. Grade: A mechanism / B measurement. Enters: S2 and context; S1 after run confirmation.
• P4 — Permian→Cushing inflow restriction. Trigger: leak, power or maintenance reduces Midland inflow. Transmission: Midland weakens, Cushing tightens, delivery-grade WTI strengthens. Observable: operator bulletins, nominations and linefill (licensed) and their later revisions — the weekly Cushing stock is a lagged residual, never the only observable; EIA PSM PADD 3→2 movements, Argus Midland/Cushing. Lag: basis hours, stocks 1–3 weeks, decay after linefill normalises. Sign: flat +, front +, cracks −, B–W −. Grade: A mechanism / B public observability. Enters: S3; S1 context.
• P5a — Cushing inbound loss (Canadian or Bakken leg). Trigger: Keystone or another inbound line outage; 7 Dec 2022 (~14,000 bbl spill, 622 kb/d line): prompt +~5 % intraday on Cushing-draw fears, the Cushing leg shut to month-end. Transmission: fewer barrels arrive at the delivery hub → prompt WTI spread and Mars firm; WCS Hardisty weakens. Observable: operator notices, PHMSA incidents, EIA Cushing stocks, WCS Hardisty vs Houston, nominations (licensed). Lag: basis same day; stocks 1–3 weeks. Sign: flat +, front ++, cracks 0, B–W −. Grade: A. Enters: S3 spreads; S2 event.
• P5b — Cushing outbound loss (Seaway, Marketlink). Trigger: an outbound leg to the Gulf goes down. Transmission: barrels strand at the hub while Houston can tighten. Observable: operator notices, EIA Cushing stocks and PSM PADD movements, Cushing–MEH basis (licensed). Lag: basis same day; stocks 1–2 weeks; decay after restart and linefill. Sign: flat −, front −, cracks +/0, B–W +. Grade: A mechanism / B signal. Enters: S3 spreads.
• P6 — US export-port closure. Trigger: fog, hurricane, channel collision or berth outage. Transmission: loadings queue, PADD 3 crude backs up, WTI discounts until export economics clear. Observable: USCG Marine Safety Information Bulletins, port line-ups and AIS, EIA weekly exports, Census HS 2709. Lag: hours; inventory 1–2 weeks; decays days after reopening. Sign: flat −, front −, cracks 0/+, B–W +. Grade: A mechanism / B AIS quantity. Enters: S2 event; S3 location.
• P7 — The US export netback (the arbitrage opens or closes; absorbs the former R5 loop). Trigger: Dated Brent delivered value rises above WTI Midland/MEH plus terminal, voyage and quality costs (or freight rises and closes it). Transmission: traders nominate and load more US crude → PADD 3 stocks fall → WTI catches Brent; when freight or Dated weakness closes the arb, origin stocks rise, destination grades strengthen and the wider location spread eventually repositions vessels. Roughly 3.85 mb/d of 2025 US crude exports left from PADD 3, so this matters more than naked Brent–WTI. Observable: Platts Dated, Argus MEH/Midland, freight (all licensed), EIA exports, vessel manifests. Lag: paper basis minutes; nominations 1–4 weeks; closes when the netback converges. Sign: flat +, front +, cracks −, B–W −. Grade: A mechanism / B signal. Enters: S3; S1 confirmation.
• P8a — Cushing storage full (the April 2020 tail). Trigger: inbound exceeds contracted outbound plus truly available tank space; April 2020: ~60 mb in tank against ~76 mb working capacity with much of the free space already leased, May CL −$37.63. Transmission: bids for tanks rise, cash WTI discounts, contango pays storage; the expiring contract detaches from spot when holders without booked storage must exit. Observable: EIA Cushing weekly stocks, PSM tank-farm and pipeline stocks, storage lease quotes (licensed VERIFY), spread and OI by contract, days-to-expiry. Lag: days; can persist months; reverses non-linearly when spare tank returns. Sign: flat −, front −−, cracks +, B–W +. Grade: A mechanism / C observable capacity threshold. Enters: S3 and expiry risk; never as a fixed level rule.
• P8b — Cushing near operational minimum (the June–July 2026 tail). Trigger: stocks fall toward the level at which pumps and pipes still function (below ~20 mb in 2026; the floor is estimated, not published). Transmission: the marginal delivery barrel must be bid out of pipelines or other hubs → convenience yield explodes → prompt spreads and Brent–WTI turn violent (Brent–WTI negative 18–24 Jun and 2–8 Jul 2026). Observable: EIA Cushing weekly stocks, prompt spreads, Brent–WTI spot, Midland–Cushing. Lag: days; persists while stocks stay near the floor. Sign: flat + (local), front ++, cracks 0, B–W −−. Grade: A mechanism / C threshold. Enters: S3; S1 WTI-local state with an estimated tail threshold.
• P9a — Western Canada apportionment glut. Trigger: oil-sands growth or maintenance meets Enbridge, Keystone or Trans Mountain constraints; nominations are apportioned. Transmission: WCS discounts until rail or a marginal pipeline clears; cheap heavy feed benefits Midwest refiners; Cushing is affected only later. Observable: CER pipeline throughput and capacity, operator apportionment notices, Alberta production, WCS–WTI (licensed). Lag: differential days; rail response weeks. Sign for WTI: flat 0/−, front 0, PADD 2 cracks +, B–W 0/+. Grade: A regional / C outright. Enters: S3 and context.
• P9b — Canadian wildfire supply loss. Trigger: late-May fire season (2016: >1.1 mb/d peak; 2025: ~345 kb/d for ~2 weeks). Transmission: heavy-sour supply to PADD 2/3 falls → WCS narrows, Mars firms; WTI muted when stocks are high. Observable: AER production, company notices, WCS–WTI, Enbridge nominations. Lag: 1–4 weeks. Sign: flat + (small), front + (small), cracks 0, B–W −. Grade: B. Enters: S1 context.
• P10 — CPC terminal disruption (Kazakhstan). Trigger: storm, single-point-mooring damage, sanctions friction or Russian administrative action. CPC carries >80 % of Kazakh exports (~1 % of world supply); SPM-2 disabled 29 Nov 2025 cut December loadings to ~1.14 mb/d vs 1.7 planned; four tankers hit 17–20 Jul 2026 and output fell to ~1 mb/d as storage filled. Transmission: Mediterranean light-sweet supply tightens; alternatives are small. Observable: CPC press releases and liftings, Kazakh production, Kpler/Vortexa cargoes, CPC Blend differentials. Lag: headline hours, loadings days, global substitution 1–4 weeks. Sign: flat +, front +, cracks −, B–W +. Grade: A mechanism / B duration. Enters: S1 disruption context.
• P11 — Libyan blockade and force majeure. Trigger: a faction closes a field, pipeline or terminal; NOC declares force majeure; restarts can be as fast as the shutdown (2024: Sharara 7 Aug, El Feel 2 Sep, lifted early October; ~1 mb/d → ~450 kb/d). Observable: NOC statements (Tier 0), OPEC secondary-source output, loadings. Lag: hours; physical 2–10 days; decay one day to many months. Sign: flat +, front +, cracks −, B–W +. Grade: A mechanism / B political duration. Enters: S2 event; S1 realised flow.
• P12 — Nigeria outage and theft. Trigger: pipeline sabotage, terminal force majeure, chronic underinvestment; Trans Forcados outages; Amukpe–Escravos (160 kb/d) as a new route. Transmission: Bonny/Forcados/Qua Iboe programmes lose light-sweet barrels; official production is noisy. Observable: NUPRC production, terminal programmes (licensed), company notices, OPEC secondary sources, AIS. Lag: differentials hours; global 1–3 weeks. Sign: flat +, front +, cracks −, B–W +. Grade: A mechanism / B quantity. Enters: S1 context.
• P13 — Iraq–Kurdistan pipeline resolution. Trigger: Baghdad, KRG and Türkiye settle payment, marketing and arbitration terms; Kirkuk–Ceyhan restarted 27 Sep 2025 after 2.5 years (180–190 kb/d) and became the fallback route when Hormuz closed. Transmission: Kurdish crude displaces Mediterranean alternatives. Observable: SOMO/KRG releases, Ceyhan loadings, AIS. Lag: announcement minutes; reliable flow days–weeks; becomes a new supply level. Sign on restart: flat −, front −, cracks +, B–W −/0. Grade: A mechanism / C political timing. Enters: S1 only after metered or loading confirmation.
• P14 — Venezuelan licence and diluent change. Trigger: OFAC licence tightens or eases; imported condensate and power availability change. Transmission: Orinoco blending and Puerto José exports rise or fall → USGC heavy-sour scarcity → Mars and WCS differentials and coker economics. Licence is permission, not capacity. Observable: OFAC general licences, PDVSA and company disclosures, Puerto José AIS, OPEC secondary output, EIA company-level imports. Lag: headline minutes; contracts 2–8 weeks; field response quarters. Sign on easing: flat −, front −, cracks +, B–W 0/−. Grade: A mechanism / B implementation. Enters: S1 context; S3 quality.
• P15 — Russian refinery strike or outage. Trigger: capacity damaged by drones. Transmission: fewer domestic outlets for crude; if storage and export logistics permit, crude exports rise while diesel exports fall (Russia banned product exports and pushed more crude out in 2026); if not, upstream shuts in. Observable: Russian export restrictions, company statements, NASA FIRMS fire detections (detection only, not an outage-volume measure), Kpler/Vortexa crude and product loadings, Argus Urals and gasoil. Lag: product cracks hours; cargo mix 1–4 weeks; repairs weeks–months. Sign (exportable-crude case): flat −/0, front −, cracks +, B–W ?. Grade: A accounting / B net outcome. Enters: context; S3 cracks. "Refinery strike = bullish oil" is usually wrong without the next link.
• P16 — Winter freeze-offs (Texas, February 2021). Trigger: Permian and Eagle Ford wellhead freeze; Uri took ~4 mb/d of crude offline VERIFY and ≥2.6 mb/d of refining. Transmission: supply and refining both lost; WTI modestly bullish, cracks up, then a crude build as refineries lag restarts. Observable: NOAA CPC 6–10-day outlook, Waha and Henry Hub cash, EIA WPSR. Lag: 1–2 weeks; stock reversal 2–3 weeks later. Sign: flat + (days), front +, cracks +, B–W − then +. Grade: A episode / B general. Enters: S2 and S1 context.
• P17 — Rhine low water. Trigger: Kaub gauge below ~40 cm (Oct 2018: Rotterdam→Basel freight ~$5→>$35/bbl, Karlsruhe diesel premium doubled, ARA distillate stocks 15.7→>21 mb; Aug 2026: lowest since records began in 1880, "effectively impassable at Kaub"). Transmission: inland German product prices decouple upward while ARA stocks back up — a location spread. Observable: Pegel Kaub (pegelonline.wsv.de), Argus Rhine barge freight, Insights Global ARA stocks. Lag: weeks–months; ends with rain. Sign: flat 0, front 0, ARA gasoil crack − (hub build) while inland premiums +, B–W 0. Grade: A. Enters: context; S3 European products.
• P18 — Product-pipeline outage (Colonial, May 2021). Trigger: ransomware shut the 2.5 mb/d product line for six days. Transmission: PADD 1 premiums up, USGC product stranded, crude softer if runs are cut; a difference-in-differences study finds only ~4 ¢/gal across 18 states, mostly after restart through panic buying. Observable: Colonial nominations, Argus USGC vs NYH gasoline, EIA PADD 1 stocks. Lag: days; reversed in 2–3 weeks. Sign: flat − (small), front 0, NYH crack + / USGC −, B–W 0. Grade: A (documented as small). Enters: intraday and S1 context.
• P19a — Chokepoint closure: the crude-flow loss (Hormuz 2026). Trigger: hostilities close the strait; Gulf exports −2.1 mb/d to 15 mb/d in July, loadings ~12 mb/d late July; observed stocks −69 mb in July and −410 mb since late February; Dated $105 on 23 July inside a ~$40 July range. Transmission: physical crude loss → violent backwardation and sour-grade scarcity → demand destruction (China imports −3.9 mb/d) and a 400 mb IEA release cap the spike; a pure crude-supply shock can compress cracks if refining is intact. Observable: Kpler/Vortexa transits, bypass-pipeline throughput, IEA/EIA stock estimates, Brent M1–M2, Dubai structure, war-risk premia. Lag: intraday on headlines; physical 3–6 weeks (voyage times); decays only with reopening, then a multi-quarter rebuild. Sign: flat ++, front ++, cracks ?, B–W ++ (WTI cushioned by domestic supply). Grade: A mechanism / B net sign and duration. Enters: intraday through months — the live regime.
• P19b — Chokepoint closure: the refining and product loss. Trigger: the same conflict shuts Gulf refineries and product exports (jet, diesel, naphtha, LPG) and stalls refining hubs. Transmission: product scarcity is a second shock → record cracks and regrades, Asian petrochemical run cuts, airline pass-through. Observable: Platts and Argus cracks by hub, IEA product balances, jet–diesel regrade, ARA and Singapore product stocks. Lag: days; persists with the outage. Sign: flat +, front +, cracks ++, B–W +. Grade: A mechanism / B magnitude. Enters: S3 cracks; S1 context.
• P20 — ENSO and heating demand. Trigger: El Niño winters lower US heating degree days; La Niña tilts colder. Observable: CPC ENSO status, EIA Winter Fuels Outlook, HDD forecasts. Sign: La Niña distillate crack + (winter); El Niño −. Grade: C for oil, B for gas. Enters: context.
• P21 — Scheduled inventory report: expectation → surprise → reaction → confirmation. Trigger: API (Tuesday) and EIA (Wednesday, holiday-shifted) releases against a timestamped consensus and the API pre-print. Transmission: price and the front spread react to the surprise within minutes, volatility rises, the third half-hour predicts the last on EIA days (§3.3, §14.2); the new stock state persists while the return effect does not (single-study evidence of no multi-day drift, grade B); products, runs, imports, exports and the adjustment can reverse the crude headline. Observable: the consensus vintage and cutoff, the API echo, WPSR Tables 1–14 at first retrieval, Cushing, the 10:30–10:45 ET return, then Cushing and spread behaviour over the following sessions as confirmation. Lag: minutes; state persists; drift unsupported. Sign: draw vs expectation → flat +, front +, cracks ?, B–W −. Grade: A impact / B no-drift / B as S1 state. Enters: S2 event; S1 state (F3) — the most important scheduled chain in the catalogue and missing from v2.0.
• P22 — Contract expiry, open-interest migration, roll and convergence. Trigger: the front month approaches expiry (CL: three business days before the 25th; MCL one day earlier; Brent last business day of the second preceding month); index rolls (GSCI 5–9, BCOM 6–10), USO's first-five-day roll and broker close-out deadlines are dated. Transmission: liquidity migrates the week before expiry; the expiring contract converges to physical (Cushing) and can detach when holders cannot deliver (P8a); spreads absorb the scheduled flow. Observable: per-contract OI and volume by days-to-expiry, F1–F2 during roll windows, TAS volume, ETF holdings, broker deadlines. Lag: days; ends at expiry. Sign: flat 0, front ? (scheduled pressure), cracks 0, B–W 0. Grade: A mechanics / C direction. Enters: calendar, risk gate (§6 item 3), expiry stress; roll-window exclusion for spread features.
• P23 — Planned refinery turnaround versus unplanned outage. Trigger: a scheduled maintenance season (Feb–Mar, Sep–Oct; utilisation troughs ≈86–87 %) versus an unplanned unit loss (P3). Transmission: planned work is anticipated in cracks and crude demand weeks ahead and is largely priced; an unplanned outage is a surprise with the P3 dynamics; confusing the two mis-signs the crude effect. Observable: turnaround schedules (IIR/Wood Mac, licensed; company guidance), EIA utilisation and inputs, PADD-level runs, crack term structure. Lag: planned — weeks ahead, priced; unplanned — minutes. Sign (planned season): flat − (crude demand), front −, cracks + seasonal, B–W ?; (unplanned) see P3. Grade: A calendar / B crude effect. Enters: seasonal prior for F4; S2 for unplanned events.
• P24 — Weekly reporting error → apparent draw or build → later reconciliation. Trigger: the WPSR's adjustment term (>2 mb/d at times), unedited weekly customs export data (swings that EIA says are usually within ±2 % of the PSM) and modelled weekly production produce a headline stock change that the Petroleum Supply Monthly later revises. Transmission: the market trades the headline; the monthly reconciliation moves the level quietly weeks later; a headline draw with a large positive adjustment is weaker evidence than the same draw with a small one. Observable: WPSR Table 1 adjustment, weekly exports vs four-week average, PSM two months later, vintage differences. Lag: headline minutes; reconciliation 4–8 weeks. Sign: none by itself — a quality flag on P21 and F3. Grade: A measurement. Enters: F3 data-quality field; never a directional feature.

17.2 Policy and producer-reaction chains

• Q1 — Unexpected OPEC+ cut. Trigger: falling price or inventory forecast, low member revenues and Saudi preference for price defence overcome cheating and market-share concerns. Transmission: target falls → only compliant output and loadings fall. 2 Apr 2023: >1 mb/d cut a day before a meeting expected to hold; WTI +8 % with managed-money Brent shorts far below their average — surprise × positioning. Observable: a timestamped pre-meeting consensus (Reuters/Bloomberg delegate polls) and a leaked-versus-new classification of the wording, OPEC communiqués and allocation tables, MOMR secondary-source output, IMF fiscal breakevens, AIS loadings. Lag: futures seconds and the Sunday gap; barrels 1–3 months; decays if compliance disappoints or demand offsets. Sign: flat +, front +, cracks −, B–W +. Grade: A mechanism / B forecast. Enters: S2 event; S1 compliance.
• Q2 — Telegraphed increments (2025–26 unwind). Trigger: pre-leaked monthly steps (188 kb/d) completing the 1.65 mb/d rollback; 3 Apr 2025 acceleration to +411 kb/d with prices ~6 % lower VERIFY. Transmission: priced by the time of the announcement; supply in 1–3 months. Sign: flat − (small), front −, cracks +, B–W −. Grade: A for 2025 / B generalised. Enters: S2 (fade telegraphed decisions unless spreads confirm within 3–5 sessions); S1 context.
• Q3 — Market-share pivot. Trigger: years of unilateral Saudi restraint invite free-riding and non-OPEC growth; Saudi stops defending price and uses discounts and volume (netback pricing 1985–86; no cut against shale Nov 2014, $112→$27 by Jan 2016; March 2020: Russia refuses cuts on 6 March, Saudi announces 12.3 mb/d and $6–8 OSP discounts, Brent −30 % on 9 March, then a record ~10 mb/d cut in April). Transmission: prompt surplus → producer capex and default stress. The tell is the OSP cut plus a volume announcement, not the communiqué. Observable: Saudi production and exports, Aramco OSPs, OPEC ceiling, non-OPEC supply, Dallas Fed survey, HY energy spreads. Lag: −20–30 % within weeks; regime 6–18 months; investment response 6–24 months. Sign: flat −−, front −−, cracks + initially, B–W −. Grade: A historical mechanism / C timing. Enters: regime context.
• Q4 — Saudi fiscal pressure (a weak constraint). Trigger: Vision 2030 spending raises the fiscal breakeven (IMF: ~$91–96/bbl for 2025). Transmission: ambiguous — revenue need can favour price defence, volume, debt issuance or reserve draws; the breakeven rises when Saudi cuts; off-budget PIF spending is excluded; the Kingdom can run deficits for years; +1 mb/d of output improves the fiscal balance by ~3.2 % of GDP. Observable: IMF Regional Economic Outlook, Saudi budget and quarterly oil revenue, Aramco dividends, reserves. Sign: flat ?, front ?, cracks 0, B–W ?. Grade: A fiscal measure / C meeting signal. Enters: context, never directional.
• Q5 — Cheating and compensation spiral. Trigger: high OSP discounts or fiscal stress reward overproduction (Iraq, Kazakhstan, UAE); compensation schedules are re-filed; credibility falls. Transmission: price weakens; Saudi may demand compensation, deepen its own cut, or pivot to market share (Q3). Observable: country targets, MOMR six secondary sources, compensation tables, loadings. Lag: monthly estimates; 1–6 meeting cycles. Sign while cheating persists: flat −, front −, cracks +, B–W −/0. Grade: A mechanism / B detection. Enters: S1 OPEC state.
• Q6 — Saudi OSP signal. Trigger: Asian refinery margins, Dubai structure, customer nominations and allocation preference. Transmission: Aramco sets grade differentials to the Dubai/Oman marker; relative demand and competing sour differentials adjust; reallocates barrels more reliably than it predicts WTI. September 2026 Arab Light at −$2.00 to Asia, lowest since June 2020, after the ~$11 August cut. Observable: Aramco OSP circular (5th–12th, poll), Platts Dubai, DME Oman, Brent–Dubai EFS, Asian cracks. Lag: immediate in differentials; next loading month; decays into nominations. Sign on a broad hike: flat +/0, front +, cracks −, B–W +/0. Grade: A pricing mechanism / C WTI signal. Enters: Middle East context; S3.
• Q7 — UAE exit from OPEC/OPEC+ (announced 28 Apr 2026, effective 1 May). Trigger: quota lagged ADNOC capacity (3.4 mb/d produced vs 4.2 mb/d capacity in 2025). Transmission: ~0.8 mb/d of disciplined spare capacity leaves the cartel; OPEC+ share of world output ~46 %→~42 %; weaker cohesion lowers the "OPEC put"; masked in 2026 by Hormuz. Observable: ADNOC output (Kpler, MOMR), Murban vs Dubai, STEO spare capacity. Lag: structural. Sign: flat − (medium term), front −, cracks 0, B–W − VERIFY sign. Grade: B. Enters: months; regime context.
• Q8 — US SPR release. Trigger: political response to disruption or pump prices; four mechanisms (emergency drawdown, exchange repaid with premium barrels, test sales, mandated sales). 2022: ~180 mb over six months to 405 mb, lowest since 1984; 2026: 172 mb over ~120 days inside a 400 mb IEA action. Transmission: sour crude delivered at specific sites and grades → the basis effect depends on delivery site, grade, award volume and window; the flat-price announcement is mostly priced within the day; an exchange creates a future repayment bid. Observable: DOE notices of sale and exchange, award and delivery tables (site, grade, volume, window), EIA WCSSTUS1, commercial stocks and exports. Lag: announcement minutes; deliveries weeks–months; partial reversal on return barrels. Sign: flat − (small, B), front − (C), cracks 0, B–W conditional on delivery site and grade. Grade: A barrels / B–C price effects. Enters: S2 event; S1 scheduled flow; S3 basis only with the award table.
• Q9 — SPR refill. Trigger: low inventory, political target, acceptable offers and appropriated cash; the 2022 refill rule targeted WTI ~$67–72. Transmission: dated physical demand for specified grades at specified sites; a soft floor under deferred WTI. Observable: DOE solicitations, awards, delivery windows. Lag: tender headline hours; delivery weeks. Sign: flat + (small, C), front + (C), cracks 0, B–W conditional on grade. Grade: A mechanism / C outright magnitude. Enters: context; S3 basis only with the award table.
• Q10 — Sanctions: designation versus enforcement (Iran, Venezuela). Trigger: OFAC designates a producer, ship, insurer, bank or buyer (Chinese teapots from March 2025 with secondary-sanctions warnings). Transmission: buyers pause → discount widens → flows reroute; after the first teapot designation Iranian Light offers slipped from −$0.8 to −$1.5/bbl versus Brent with no fresh deals for two weeks and China's intake fell from ~1.8 mb/d to ~0.8 mb/d by mid-2025 VERIFY; volume falls only if enforcement and alternative fleet or payment capacity bind. Observable: OFAC SDN additions with timestamps, vessel ownership and port calls, Kpler/Vortexa exports and floating storage, Iranian Light vs Oman, Shandong run rates. Lag: discount days; volumes recover 1–3 months unless enforcement escalates. Sign under effective enforcement: flat + (small), front +, cracks −, B–W + (Asian sour tightens). Grade: B (designation alone decays; buyer enforcement bites). Enters: S2 event; S1 confirmation.
• Q11 — Russian price-cap tightening and major designations. Trigger: G7 cap ($60, Dec 2022) enforced through shipping and insurance attestations; EU dynamic cap $47.60 (Sep 2025) then $44.10 (Feb 2026); Rosneft/Lukoil SDN 22 Oct 2025 touched >5 mb/d of production and ≥2 mb/d of seaborne exports — Brent +~5 % the next morning, then faded as India and China reorganised. Transmission: the cap bites on discount and service cost, not volume; shadow-fleet substitution takes 1–6 months. Observable: OFAC/OFSI/EU texts, Argus Urals FOB vs Dated, Kpler exports and floating storage, sanctioned-vessel lists, Indian refinery intake. Lag: pop 1–3 days, fades 2–4 weeks; discount persists. Sign if volumes bind: flat + (fading), front +, diesel crack +, B–W +. Grade: A "spike fades" / B volume effect. Enters: S1 sanctions state; S3 freight and cracks.
• Q12 — Tariffs and trade-war demand fears. Trigger: 2 April 2025 tariffs: Brent −~$15/bbl in April; OPEC cut 2025 demand growth 10 % to 1.3 mb/d VERIFY; compounded by Q2. Transmission: growth expectations → demand forecasts → positioning; partly reversed on pauses. Observable: COT managed-money length, OPEC/IEA revisions, PMI export orders, customs and Federal Register text with effective dates. Lag: positioning days; macro quarters. Sign: flat −, front −, cracks −, B–W 0. Grade: A episode / B repeatability. Enters: S1 context. A crude or product tariff by an importing country is a separate micro chain: netbacks change, cargoes reroute, affected grades discount — A micro / C outright.
• Q13 — US permitting, leasing, election cycle. Trigger: rule changes; Dallas Fed respondents put regulatory changes since January 2025 at <$2/bbl off breakevens. Transmission: US supply follows price and capital discipline, not permits, within two years; election-year SPR politics (Q8) matters more. Sign: flat ~0 short run; − over years if acreage expands. Grade: B for "small effect". Enters: never at S1.
• Q14 — China independent-refiner import quota. Trigger: MOFCOM grants quota (2025 aggregate allowance 257 Mt; allocations, not the ceiling, matter). Transmission: teapots buy discounted and sanctioned crudes, raise runs and imports; teapot crackdowns and the April 2026 US sanctions on a major teapot cut sour demand. Observable: MOFCOM allowances and company allocations, GACC HS 27090000, NBS throughput, Shandong utilisation (licensed). Lag: policy day; purchases 2–8 weeks; exhausted over the quota year. Sign: flat +, front +, cracks −/0, B–W +/0. Grade: A policy / B execution. Enters: S1 China context.
• Q15 — China product-export quota. Trigger: domestic product surplus and SOE lobbying meet inflation and environmental objectives; batches from MOFCOM/NDRC VERIFY publisher. Transmission: a quota is an allowance, not a run order — refiners may raise runs and export gasoline and diesel if margins justify it → crude demand up, Asian cracks face added supply. Observable: quota batches, GACC HS 2710 exports (the realised quantity), NBS runs. Lag: days to margins, 2–8 weeks to cargoes. Sign: flat +/0, front +/0, Asian cracks −, B–W +/0. Grade: A mechanism / C signal. Enters: S1 context; S3 cracks after exports confirm.
• Q16 — Chinese strategic and commercial stockpiling. Trigger: low delivered price and available tanks raise expected stockpiling value; NOCs directed since 2024 to hold emergency stocks commercially; ~1.4 bn bbl total at end-2025 after +1.1 mb/d in 2025; 169 mb of new capacity planned 2025–26. Transmission: imports exceed reported use plus exports → prompt support until tanks, credit or policy bind; drawing ~1 mb/d in 2026 damped the spike. Observable: GACC imports, NBS runs, JODI, Kpler onshore and floating estimates; the residual imports + production − runs − exports (China publishes no complete inventory series). Lag: cargo buying 2–8 weeks; stock cycle months. Sign (build): flat + (floor), B–W +; (draw): flat − (cap). Grade: A identity and buffer role / C stock level. Enters: context; prospective research only.
• Q17 — China EV mandates and refinery policy. Trigger: NEVs ~55 % of car sales in 2025 (~60 % in 2026); EVs displaced ~1 mb/d in China and ~1.7 mb/d globally in 2025, heading to ~5 mb/d by 2030; LNG trucking erodes diesel; OIES puts China's gasoline peak at 2025–28 VERIFY. Transmission: gasoline yield pressure → exports and petrochemical shift; new crackers offset through naphtha and LPG. Observable: CPCA/CAAM NEV sales, NBS apparent gasoline demand, Singapore 92 RON crack, refinery start-ups. Lag: ~0.3–0.5 mb/d per year. Sign: flat − (slow), front 0, Asian gasoline crack −, B–W −. Grade: A direction / C at 2–20 days. Enters: context, never an S1 trigger.
• Q18 — EU ETS, FuelEU and European fuel taxes. Trigger: EUA ~€73–74/t in 2025, free allocation conditional on efficiency plans 2026–30, ETS2 for road and buildings delayed to 2028+, maritime coverage phasing in. Transmission: higher refinery and shipping cost → marginal closures → more diesel imports from the USGC, Middle East and India → European cracks structurally higher and more shock-sensitive; carbon cost passes to cracks within a quarter. Observable: ICE EUA futures, verified emissions, closure announcements, Euroilstock runs. Lag: years for capacity; quarter for pass-through. Sign: flat ~0, front 0, European diesel crack +, B–W +. Grade: B mechanism / C short-run signal. Enters: context; S3 regional.
• Q19 — IMO sulphur rules (2020 cap; EEXI/CII). Trigger: 0.5 % cap from 1 Jan 2020 (EIA projected diesel margins 43→65 ¢/gal and a light-sweet premium, effects most acute in 2020 then fading; COVID intervened). Transmission: bunker demand shifted grades — HSFO crack collapses, VLSFO and gasoil widen, sweet–sour widens; total oil demand is not mechanically destroyed; slow-steaming rules add small tanker demand VERIFY. Observable: Singapore HSFO 380 crack, Hi-5 spread, Brent–Dubai EFS. Lag: anticipated 6–24 months; structural after. Sign: flat ?/0, front 0, distillate crack +, HSFO −−, B–W 0. Grade: A product-spread direction / C WTI. Enters: S3 cracks; context.
• Q20 — Japan/Korea stockholding and IEA collective action. Trigger: Japan's 70 days of industry stocks (~220 mb) plus 263 mb government; IEA members still held >1 bn bbl after releasing ~290 mb of the 400 mb March-2026 action. Transmission: coordinated releases cap the front; summer LNG-to-oil switching in Japanese and Korean power adds seasonal fuel-oil demand VERIFY. Observable: IEA releases, METI/KNOC stock data. Lag: announcement intraday; physical 1–3 months. Sign: flat −, front −, cracks 0, B–W 0. Grade: B. Enters: S2 and S1 scheduled flow.
• Q21 — Biofuel policy (RVOs, RINs, renewable diesel, SAF). Trigger: EPA's final 2026–27 RVOs (27 Mar 2026) were "significantly higher"; D4 RINs $2.41 in June 2026, near 2021 records; the 2023 reverse (D4 −53 %) came from renewable-diesel overcapacity and a narrower bean-oil–heating-oil spread. Transmission: high RINs subsidise renewable diesel, which displaces petroleum diesel (California, USGC) → softer petroleum diesel crack over months; non-RIN refiners carry compliance cost; soybean oil sets the margin floor. Observable: EPA EMTS RIN prices, CBOT soybean oil, BOHO spread, EIA biofuel capacity. Lag: policy days; supply 6–18 months. Sign: flat ~0, front 0, US diesel crack − over months (+ briefly if runs are cut), B–W 0. Grade: B. Enters: context only.

17.3 Cross-commodity and cross-market chains

• X1 — Gas/LNG/coal spike and fuel switching. Trigger: TTF/JKM or coal far above gasoil and HSFO on a $/mmBtu basis (2021–22). Transmission: industry, Middle East and South Asian power and some refineries burn fuel oil, diesel or LPG instead of gas → product demand → crude runs; IEA raised 2022 demand ~380 kb/d for switching; ~7 bcm of EU industrial gas-to-oil switching in 2022; constrained by plant capability and emissions rules. Observable: ICE TTF M1, Platts JKM, Henry Hub (FRED DHHNGSP), API2 coal, ENTSOG storage, IEA OMR "fuel switching" line. Lag: weeks to a quarter; fades as gas re-prices; ~0.3–0.5 mb/d. Sign: flat + (mild), front + (mild), gasoil/HSFO cracks +, B–W +. Grade: A feasible mechanism / B quantity. Enters: S1 context; S3 products.
• X2 — Henry Hub/NGL versus naphtha feedstock switch. Trigger: US gas and NGL prices rise relative to crude-linked naphtha. Transmission: flexible crackers shift from ethane and propane toward naphtha → naphtha crude demand rises; reverse when gas is cheap (the STEO HGL model uses the HH/WTI ratio). Observable: DHHNGSP, Mont Belvieu propane, naphtha assessments, EIA HGL and petrochemical inputs, US ethane exports. Lag: days to slate, weeks to inventories. Sign: flat + (small), front 0/+, naphtha margin +, B–W 0. Grade: A model mechanism / C WTI magnitude. Enters: context.
• X3 — Coal–gas–power–carbon dispatch. Trigger: power demand and weather move clean-dark versus clean-spark spreads; EUA cost penalises coal while gas scarcity restores coal or oil burn. Observable: TTF, API2, EUA, EEX day-ahead power, ENTSO-E generation by fuel. Lag: power hours; fuel procurement days–months. Sign: flat ?/+ only when oil burn is feasible; cracks +. Grade: A dispatch economics / C oil forecast. Enters: context, never a direct score.
• X4 — Diesel leadership in product and refinery supply shocks (Europe's structural distillate short). Trigger: a middle-distillate loss — refinery outage, product sanctions, Ukrainian strikes on Russian refineries (Russia supplied ~50 % of EU diesel imports in 2022 and <1 % of seaborne imports by 2024). Transmission: gasoil crack jumps first → refiners maximise runs and bid crude if capacity exists → backwardation follows; if capacity is constrained, crude need not rally. 2022: European gasoil crack briefly >$80/bbl VERIFY; 2026: diesel cracks toward $100/bbl with three refining hubs stalled; late 2025: NYH/USGC/ARA cracks above $1/gal on Rosneft/Lukoil sanctions and the Al Zour outage. Scope: this is a product or refinery supply shock rule; a crude production outage usually hits crude first and can weaken cracks (P1, P19a). Observable: ICE gasoil–Brent and NYH ULSD–WTI cracks, ARA distillate stocks (Thursday), EIA distillate vs five-year, days-cover, runs. Lag: crack leads flat price by days–weeks; decays 1–3 months as runs and imports respond. Sign with spare refining: flat +, front +, diesel crack ++ (leads), B–W +. Grade: A crack→structure / B crack→flat price. Enters: S1 confirmation; S3 cracks.
• X5 — Gasoline season (turnarounds, RVP switch, driving season). Trigger: ~25 % of US refineries turn around each spring; 9.0-psi summer RVP from 1 May to 15 September; butane blending returns in September. Transmission: lower runs plus costlier spec plus demand ramp → RBOB crack peaks in spring and fades by autumn. Observable: RBOB–WTI crack, EIA gasoline stocks, utilisation, implied demand. Lag: calendar-driven; crack fronts the Q2 ramp by 4–8 weeks. Sign: flat + (spring), front + (spring), gasoline crack + Feb–May and − Aug–Oct, B–W 0. Grade: A shape / B magnitude. Enters: S3; S1 seasonal prior.
• X6 — Jet versus diesel yield competition. Trigger: jet recovery or diesel shortage — both come from the middle-distillate cut; in 2026 jet and diesel cracks surged together, then refiners rotated yield back to road fuels. Observable: Platts jet–ULSD regrade (NWE, USGC, Singapore), IATA RPKs, EIA jet product supplied. Lag: weeks; regrade mean-reverts within a quarter. Sign: flat + (small), front 0, diesel crack + when jet demand rises, B–W 0. Grade: B. Enters: S3 products.
• X7 — Naphtha, LPG and petrochemicals. Trigger: Chinese cracker start-ups versus ethane substitution; naphtha-cracking margins negative in Asian and European hubs since Q2 2024 VERIFY; IEA still sees China naphtha demand +6 % (2025) and +8.6 % (2026). Transmission: naphtha demand supports light-sweet crude and condensate; ethane substitution erodes it; flexible crackers switch LPG/naphtha share without transport demand changing. Observable: Singapore/NWE naphtha crack, ethylene–naphtha spread, IEA naphtha line, GACC LPG/naphtha imports. Lag: quarters. Sign: flat + (light sweet), front 0, naphtha crack +, B–W +. Grade: B. Enters: context; S3 products.
• X8a — Tanker-freight shock and the arbitrage. Trigger: vessel scarcity, longer routes or a war-risk premium (Mar 2026 VLCC records VERIFY; 2024 Red Sea: day-rates $23k→$73k, 10–14 extra days via the Cape, flat-price premium only ~$2–4). Transmission: delivered parity widens → formerly open crude arbitrages shut, stranded origin grades discount, destination grades and cracks rise; dirty and clean rates diverge by shock type; the wider location spread eventually repositions vessels. Observable: Baltic dirty (TD3C, TD25) and clean indices, war-risk quotes, AIS tonne-miles, origin and destination differentials, loadings. Lag: freight hours–days; cargo rerouting 2–8 weeks; fleet response 1–3 months. Sign for WTI when US exports close: flat −, front −, US cracks +, B–W +. Grade: A delivered-cost mechanism / B sign by route. Enters: S3 location; context.
• X8b — Floating-storage economics. Trigger: deep contango (2020: Brent May–Nov spread a record $13.45/bbl; VLCC time-charter ~$40k→$120k/day; storing six months locked in $7–8 m per VLCC). Transmission: when the spread exceeds charter, finance and insurance, prompt barrels go to sea and contango stops widening; when storage fills or the spread narrows, barrels return and the front weakens; Cushing is the special case (P8a). Observable: Brent M1–M6, VLCC time-charter rates, Kpler/Vortexa floating storage, Dallas Fed tanker-storage model. Lag: freight reacts in days; the arbitrage caps contango while vessels are available. Sign (storage contango): flat −, front − then stabilising, cracks 0, B–W + when Cushing-specific. Grade: A mechanics / B timing. Enters: S3; context.
• X9 — Producer currencies (CAD, NOK, RUB, MXN, BRL). Finding: causality runs oil → FX, same day; Ferraro–Rogoff–Rossi find a robust contemporaneous daily link from oil to CAD/USD, little systematic relation monthly or quarterly, and lagged-oil predictability that is "ephemeral"; FX → oil is not supported. Feedback loop: a stronger producer currency raises dollar costs, improving margins and future supply only over 6–24 months. Observable: FRED DEXCAUS, DEXNOUS, DEXMXUS, DEXBZUS; CBR RUB fixing. Sign (oil up): commodity currencies appreciate; as a predictor of oil: none. Grade: A co-movement / C lead. Enters: context; never a signal.
• X10 — Consumer-currency squeeze (INR, CNH, JPY, EUR). Trigger: an oil rally raises import bills; whether the currency weakens depends on the shock and the policy regime (not every rally weakens every importer's currency). Transmission: where it does, higher local fuel prices → subsidies, taxes and rationing. 2026: China Q2 imports −32 % q/q to 8.1 mb/d, which "softened the upward price effects". Observable: USD/INR, USD/CNH, USD/JPY, PPAC import bill, GACC customs, local retail fuel prices, Kpler onshore stocks. Lag: FX days; demand rationing 1–6 months. Sign (oil up): currencies may weaken; feedback flat − (lagged), front − (months), Asian cracks −, B–W −. Grade: B for the 2026 demand feedback / C as an oil predictor. Enters: months; context.
• X11 — Energy equities (XLE, XOP, OSX) as lead or lag. Finding: no reliable predictive sign; weekly oil changes explain ~2 % of XLE variance; the only correlation peak (XLE leading by a week) is an artefact of weekly-average price construction; XLE decouples from WTI for long stretches. Beta is regime-dependent (high in supply shocks, low in demand shocks). Observable: XLE, XOP, OIH vs CL1; 60-day rolling beta. Grade: C as signal / B as regime diagnostic. Enters: diagnostic only.
• X12 — Acute risk-off deleveraging through energy equities and credit. Trigger: a fall in oil below levered producers' cash cost coincides with fund stress. Transmission: energy equities fall and HY energy spreads widen (2016: energy HY default rate 15 %, E&P 29 % VERIFY; June 2020: 11.2 % with Fitch projecting ~17 %; >200 producers filed since 2015 owing >$130 bn); cross-asset deleveraging can sell crude futures now — much of the same-week co-movement is reverse causality from the oil move itself. Observable: XLE/XOP/OIH, issuer CDS, ICE BofA US HY energy OAS (energy sub-index VERIFY; all-HY on FRED BAMLH0A0HYM2), VIX. Lag: securities seconds; futures liquidation days. Sign: near-term flat − in stress, front ?, cracks 0, B–W 0. Grade: A financing channel / C timing. Enters: context; regime. The 6–18-month supply response (spreads → capex and rig cuts → tight oil falling >35 % within 12 months absent investment) is chain L2.
• X13 — Rates, breakevens, the dollar and the Fed reaction function. Trigger: an oil shock. WTI–TIPS breakeven correlation 0.65 (2011–19); a 10 % oil rise lifts advanced-economy headline inflation ~0.4 pp over ~8 quarters; since 2022 a one-standard-deviation (3 %) oil-supply surprise moved 2-year yields ~4.5 bp at the early-2024 peak, more than three times the pre-2021 response; the gasoline→household-expectations link turned negative in 2025 VERIFY. Transmission: breakevens → rate expectations → USD and growth → demand (second-order negative); a supply-driven rise delays easing, a demand-driven rise confirms growth; the inverse oil–USD correlation is regime-dependent and weaker with the US a net exporter. Observable: FRED T5YIE, T10YIE, DGS2, DFII10, DTWEXBGS, Fed funds futures, Känzig OPEC-surprise series. Lag: breakevens same day; macro feedback over quarters. Sign (oil up): breakevens + intraday; feedback flat − over quarters. Grade: A oil→breakevens / B feedback / C dollar causality and static beta. Enters: context; never a fixed sign.
• X14 — Gold/oil, copper/oil, EM-stress diagnostics. Finding: academic support is for gold–copper predicting equity excess returns and for time-varying gold–oil links tied to geopolitical risk — not for forecasting oil; in a growth regime copper beating gold and EM credit strengthening raise expected oil demand, but in war or inflation shocks gold and oil rise together and the signal breaks. Observable: CME HG/GC, JPM EMBI (licensed), VIX, broad dollar, Baltic dry index. Grade: C (regime descriptor only). Enters: context.
• X15 — Emerging-market stress → demand. Trigger: EM FX or credit crisis (1998: Brent below $11 VERIFY; 2026: China's 3.9 mb/d import drop and ~1.7 mb/d stock draw damped the Hormuz spike). Observable: EM FX basket, EMBI spreads, China and India customs, IEA non-OECD revisions. Lag: 1–3 quarters. Sign: flat −, front −, Asian cracks −, B–W −. Grade: B. Enters: months; context.

17.4 Long cycles and structure

• L1 — Capex cycle, underinvestment, decline rates. Trigger: price-driven cuts; upstream oil investment −6 % in 2025 (first fall since 2020, largest since 2016), US tight oil ~−10 %. Transmission: conventional fields decline 5.6 %/yr post-peak; ~90 % of upstream spending since 2019 offsets decline; without investment global output would fall ~5.5 mb/d per year; Middle East supergiants decline <2 %/yr vs >15 %/yr for small offshore fields; 2–5 years FID-to-first-oil for conventional projects, 6–12 months for shale → low-price years sow later tightness; decline geography defines where spare capacity sits. Observable: IEA World Energy Investment, Rystad/Wood Mac FID trackers, company capex guidance, international rig counts. Lag: years; sets the level of the curve, not daily moves. Sign (capex cut): flat + (2–4 years later), front + (structural backwardation), B–W +. Grade: A mechanism / B timing. Enters: regime context. Slow variables set the sensitivity of fast ones: decline rates, capex, stock cover and spare capacity decide whether a hurricane or a designation moves price 2 % or 20 %.
• L2 — US shale: breakevens, capital discipline, rig lag, consolidation (absorbs the 6–18-month leg of X12). Trigger: WTI versus breakeven (~$65/bbl to drill profitably, $59–68 by size and basin, Dallas Fed Q1 2026 at $66). Transmission: post-2020 capital discipline and consolidation flatten the supply response to high prices (2026: 30 % of E&Ps planned no output change despite $57→$111), but tight oil falls >35 % in 12 months without investment, so discipline cuts both ways; price→rigs 3–6 months, rigs→production 4–8 months VERIFY; productivity gains decoupled output from rig counts (rigs −33 % Dec 2022–Oct 2025 while Permian output +18 %). Observable: Dallas Fed survey (breakevens each Q1), Baker Hughes rigs, EIA DPR and Form 914, frac-spread count, DUC counts, 10-K hedge tables. Sign (WTI < $60 sustained): flat + (lagged), front +, B–W −. Grade: B. Enters: months; context.
• L3 — Supercycle narratives versus the peak-demand debate. Trigger: sell-side supercycle calls (Goldman from October 2020, built on underinvestment and ESG capital limits) cut repeatedly in 2023 as sanctioned supply held; against it, the IEA–OPEC divergence on EV-driven demand, IEA 2026 demand −1.6 mb/d then +2.4 mb/d in 2027, governments making efficiency a policy cornerstone in July 2026. Transmission: narratives move positioning (COT length) more than balances; peak-demand expectations lower the long end and raise capital costs for long-cycle projects → paradoxically tighter mid-decade supply (L1). Observable: COT, forecast dispersion, Brent 5-year forward vs spot, IEA Oil 2030, OPEC World Oil Outlook. Lag: narrative half-life 6–12 months; structural effects years. Sign: supercycle — none reliable (a crowding indicator); peak demand — long-dated WTI −, prompt spread +. Grade: C (supercycle) / B (peak-demand structure). Enters: context; crowding diagnostic.

17.5 Second-order and reflexive loops

• R1 — Price → producer hedging → curve. Trigger: deferred WTI rises above producer budget or breakeven → E&Ps sell swaps and collars; dealers hedge by selling futures concentrated beyond the prompt month. Transmission: the back end is capped and backwardation can steepen without new prompt scarcity (Dec 2016 record options day; 2026 swaps sold above $90); producers and dealers reduce net positions after positive price shocks while money managers add (Dedi & Mandilaras 2022). Observable: 10-Q/10-K hedge tables, CFTC swap-dealer shorts, calendar-average futures, deferred open interest, put OI at budget strikes. Lag: days–weeks; positions roll over quarters. Sign: prompt flat 0/−, front spread +, cracks 0, B–W 0. Grade: A behaviour / B curve effect. Enters: S3.
• R2 — Volatility → margin → leveraged liquidation. Trigger: a shock raises realised and implied vol → exchange and FCM margins and VaR limits rise (CME +17.6 % on CL after the negative print; TTF initial margin sixfold Jan–Apr 2022; LSGO +90.3 % in one step) → leveraged longs and shorts cut gross exposure; the crowded side sets direction and liquidity loss magnifies both (the hedger de-hedging leg is R11). Observable: archived CME performance-bond advisories and broker house-margin snapshots (both change and both bind), OVX and CL implied vol, open interest, bid–ask and depth. Lag: same day to several days; decays over weeks as vol and margins normalise. Sign: flat ?, front ?, cracks ?, B–W ?. Grade: A risk constraint / C direction. Enters: risk sizing and context, never a signal.
• R3 — Index allocation change → scheduled futures demand. Trigger: an index provider's weight change or an allocator's decision (index allocations follow weights and assets under management, not positive carry; "backwardation attracts index money" is a plausible allocator story without documented causality). Transmission: swaps and index products add or cut long futures on a known schedule; dealer hedge flow is distributed by the roll calendar; temporary price pressure meets commercial liquidity. Observable: BCOM/GSCI weights and roll calendars (days 5–9 and 6–10), CFTC swap dealers, fund AUM and flows, per-month OI. Lag: allocation weeks–quarters; roll pressure hours–days and decays quickly. Sign: flat +/0 on the schedule, front +/− around the chosen contract, cracks 0, B–W 0. Grade: C mechanism as a return forecast / A as a calendar. Enters: calendar; context.
• R4 — Refinery margin → runs → crude demand. Trigger: product scarcity widens cracks → refiners raise utilisation and buy crude → crude stocks and spreads tighten → higher crude cost compresses cracks, closing the loop; with US utilisation at 97.4 % in late August 2026 there is no headroom, so autumn maintenance mechanically weakens crude demand. Observable: matched RB/HO/CL and gasoil/Brent cracks, EIA WCRRIUS2, utilisation, product and crude inventories. Lag: futures minutes; runs 1–3 weeks; feedback 2–6 weeks. Sign initially: flat +, front +, cracks + then decay, B–W route-dependent. Grade: A mechanism / B timing. Enters: S1 conditional hypothesis; S3.
• R5 — (merged into P7 — the US export netback: freight → parity → cargoes → regional spread → fleet repositioning.)
• R6 — Sanctions → shadow fleet → freight. Trigger: designations exclude mainstream shipping and insurance → opaque ownership, ship-to-ship transfers and longer voyages expand (~350 vessels carrying >60 % of Baltic crude by 2025; ~500 listed by the EU) → the effective fleet tightens and incident and war-risk cost rise → non-sanctioned freight and delivered crude rise even if sanctioned volume survives. Observable: OFAC/EU lists, Windward/Kpler ownership and dark-activity flags, AIS gaps and STS events, Baltic freight. Lag: weeks–months; persists until enforcement or the fleet adapts. Sign: flat +/0, front +/0, destination cracks +, B–W +. Grade: A channel / B magnitude. Enters: context; S3 freight.
• R7 — Positioning → price → positioning. Trigger: a breakout triggers CTA and macro buying → the rise validates trend and raises managed-money length → producers hedge and dealers sell deferred → flow amplifies the front but resists the back; reversal triggers symmetric liquidation (funds add on strength and cut on weakness; commercials fade them and are paid a liquidity premium; in stress the funds' cuts push risk back to producers). Observable: daily trend replicas (explicitly proxies), CFTC code 067651 changes, OI and volume, issuer hedges. Lag: intraday to weeks; decays at trend reversal or risk limit. Sign during an up-loop: flat +, front +, cracks −/0, B–W 0. Grade: B mechanism / C ex-ante timing. Enters: context only.
• R8 — ETF creations and redemptions → roll → spreads. Trigger: retail demand creates USO baskets → the fund buys its disclosed contract basket; redemptions reverse it; scheduled rolls transfer exposure along the curve — from January 2026 USO rolls over the first five trading days of the month at roughly 20 % per day (SEC-filed prospectus supplement), replacing the older ten-day roll; every ETF methodology is versioned by effective date. In April 2020 the fund's front-month concentration made it the fulcrum of the May contract; leveraged UCO/SCO rebalance daily into the close. Observable: USO daily holdings and shares, SEC filings, the current roll schedule, per-contract OI. Lag: same or next day; price pressure normally decays intraday to days; research on predictable rolls finds liquidity provision limits the impact (Bessembinder et al. 2016). Sign on creations: flat +/0, affected spread ?, cracks 0, B–W 0. Grade: A mechanics / C durable price effect. Enters: calendar; context.
• R9 — Chinese stockpiling elasticity. Trigger: a low crude price widens the perceived policy and refining value → China imports above current use → global price and structure strengthen → a higher price slows purchases or induces destocking (2025 record imports at low prices; 2Q26 −32 % at high prices) → price is damped in both directions, but unobserved stocks make turning points hard. Observable: vintaged GACC imports, NBS runs, domestic production, product trade, licensed tank estimates. Lag: 1–3 cargo cycles; reversal 1–6 months. Sign at low-price buying: flat +, front +, cracks 0/−, B–W +/0. Grade: A economic response / C timing (latent stocks). Enters: context; prospective research.
• R10 — Option-dealer gamma. Trigger: a large customer position leaves dealers short or long gamma near a strike and expiry → hedging buys rallies and sells falls (short gamma) or the reverse (long gamma) → realised intraday volatility changes without new barrels; strongest near expiry and strike proximity; the sign of dealer inventory is not public; the claimed downside asymmetry from producer put buying is a practitioner claim. Observable: CME option OI by strike and expiry, trades and the IV surface; signed option flow is required for any directional use — without it the chain stays risk-only. Lag: seconds; vanishes at expiry. Sign: flat ?, front ?, cracks 0, B–W 0. Grade: A hedge mathematics / C dealer sign. Enters: S2 risk only; never directional without signed flow.
• R11 — Margin calls on futures shorts → de-hedging → fewer curve sellers. Trigger: variation-margin demands on participants short futures — producers and merchants hedging physical length, gas sellers in 2022 — in a spike; fuel consumers hedging long typically receive margin and are not part of this loop. Transmission: some shorts reduce hedging altogether; open interest falls (>40 % in TTF in 2022) with large drops in Brent; hedging capacity contracts exactly when the curve most needs sellers; the position sign must be established per group before the loop is asserted. Observable: exchange OI, clearing-house and broker margin notices, EFET and industry statements, bank liquidity facilities. Lag: days–weeks; persists through the spike. Sign: front + (fewer deferred sellers), flat ?, cracks ?, B–W ?. Grade: A episode (2022) / C direction and repeatability. Enters: risk context.

17.6 Cross-cutting lessons from the catalogue

1. Slow variables set the sensitivity of fast ones (L1, L2, Q7): store decline rates, capex, stock cover and effective spare capacity as regime features, not as signals.
2. Product and refinery supply shocks show up in cracks first; crude production outages hit crude first; demand shocks hit flat price first (X4, P1, P19a, Q12): the diesel crack is the first responder to distillate shocks and can compress in a pure crude outage.
3. Designation is not enforcement (Q10, Q11): sanctions spikes fade in weeks unless buyers are targeted; the persistent variable is the discount.
4. China is a volatility buffer (Q16, R9): building at lows, drawing at highs; latent stocks make its turning points a research question, not a feature.
5. The tell is a physical quantity (Q3, P19, Q1): OSP cuts plus volume, transit counts, loadings, restoration slopes — never the communiqué or the headline.
6. Folklore to demote: equity leads (X11), metal ratios (X14), fiscal-breakeven-triggered cuts (Q4), supercycle calls (L3), "refinery strike = bullish oil" (P15), "backwardation attracts index money" (R3), dealer-gamma direction without signed flow (R10), consumer-currency weakness as an oil lead (X10). Context, never inputs.
7. The scheduled chains come first in any registry (P21, P22, P23, P24): they have expectations, timestamps and falsifiers; ENSO, EVs and capex do not belong ahead of them.

18. Mood and narrative — where oil traders talk, and what it is worth

The owner's brief: know where people who trade and comment on oil are active, in every region, so the general mood can be studied. The research answer has three parts: the map is lopsided and access is the binding constraint; the evidence supports mood as a volatility and event-detection diagnostic, not a price score; and the useful quantities are concentration, novelty, attention and the expectation–spot gap, not the sign of the mood.

18.1 The sampled public venues (not a world map)

Two structural facts about the sample — which omits Spanish- and Portuguese-speaking Latin America, Turkey, Southeast Asia and most Arabic and African communities, while the price-forming professional venues are, correctly, listed as closed. It is lopsided: the professional narrative forms on English X and a few Substacks; Reddit is small for oil; the retail crowd is loudest on Investing.com boards (Italy, Korea), Yahoo Finance Japan, Eastmoney Guba and Indian Telegram — venues that measure local retail framing (inflation in Japan, SC arbitrage in China, CFD levels in Italy), not the marginal futures trader. Access, not modelling, is the binding constraint: every collector must survive a venue vanishing (the TEU index died with X's academic tier), and per-venue terms, GDPR minimisation and deletion obligations apply to an Italian operator. Maintain a dated registry of author, platform, language and rights rather than a permanent "key account" list.

18.2 What the evidence says

Reading. The strongest, most repeated result concerns second moments: news and attention help forecast volatility. For returns, the credible evidence is monthly and uses official or organisational text (IEA/OPEC reports, Google attention), not social feeds. Geopolitical text is priced within the day — the 2026 regime. The best recent negative result says how much is written matters more than how positive it is, and the meaning of the signal changes by regime. Nothing here justifies a directional score; everything justifies an attention and narrative diagnostic.

18.3 The narrative state — a diagnostic, never a price score

A daily (intraday during shocks) vector describing what the oil conversation is about, how loud, how new, from whom, in which languages, and how one-sided — stored point-in-time with model and prompt versions.

NarrativeState
  topic_share[topic]         fixed taxonomy: Hormuz/Gulf security · OPEC+ · Russia/sanctions · China demand · US shale ·
                             inventories · SPR · refining/products · macro-dollar-Fed · recession · transition · weather ·
                             Venezuela/Iran/Libya; aggregated by source tier; report shares and concentration (Herfindahl/entropy)
  attention                  document/post counts per topic and venue vs a rolling 60-day baseline (TEU-SCA-style normalisation);
                             multilingual Google Trends
  polarity[topic]            multi-dimensional: polarity, intensity, uncertainty, forwardness — a distribution, never a mean;
                             per asset and horizon (flat, spread, crack), never one polarity
  source_tier_mix            T0 official · T1 wire · T2 PRA/professional · T3 named analysts and curated #OOTT · T4 open retail · T5 anonymous/tips
  novelty                    embedding distance from the trailing 7–30-day corpus; near-duplicate share; first-seen flag per claim
  confirmation_depth         primary + independent wire + physical observation count
  cross_language_agreement   topic-share vectors per language (EN, ZH, JA, KO, RU, AR, DE/IT/FR); cosine similarity; divergence list
  crowd_stance_proxies       Yahoo JP bull/bear vote; TradingView long/short ratio; StockTwits CL_F; survey expectations − spot; managed-money percentile
  propagation_speed · disagreement_entropy · half_life · bot_score · language_coverage · rights_status · model_version

Deterministic shift and anomaly detection: CUSUM or Bayesian change-points on topic shares and concentration; attention z-scores with venue-specific thresholds; burst detection on Tier 0–1 counts; duplicate-ratio and account-age spikes as bot alarms; divergence alarms when languages disagree; a "headline-reversal" flag when polarity flips intraday (11 Mar 2026: Brent −9.3 % on one report that the US might seize the strait, then $96 six days later). Alert when narrative and market disagree — attention at the 99th percentile but no move in prompt spreads, freight or loadings — or when a low-tier rumour outruns every primary source.

How professionals use it, per the evidence: event detection and risk (where attention demonstrably helps); a crowding gauge (survey stance, COT percentile and narrative concentration together — extremes are a reason to size down, not a direction); a contrarian sanity check (organisational sentiment negatively predicts monthly returns; producer expectations sit below spot in spikes); and explanation (the LLM summarises "why the market moved" — the project's boundary). Evaluation targets are operational: earlier verified-event detection, fewer duplicate alerts, calibration of confirmation, conditional volatility — never P&L first.

Point-in-time failures waiting to happen (Codex review): mutable vote ratios stored without their denominators; account lists built retrospectively; Google Trends rescaling between downloads; GDELT re-processing; API outages that look like low attention; translations or models changed mid-sample; a topic taxonomy designed after seeing 2026. Freeze the venue universe and the taxonomy prospectively, archive permitted raw payloads at ingestion, and store coverage and denominator features beside every count.

Pitfalls and mitigations. Bots (strategic, asymmetric to bad news — source authority, duplicate ratios; author-level bot scores are profiling and need a documented necessity case). Sarcasm and negation (lexicon tools mislabel — classify with an uncertainty dimension, never trust single-post polarity). "Oil down" referring to fuel, equities or a past move. Multilingual entity aliases; platform time versus original time; deleted and edited posts (only forward-collected, timestamped data enters a backtest — retrospective corpora differ from what was visible live). Survivor-biased account lists; follower count as authority; geography and VPN bias; Google Trends normalisation. Reflexivity (curation algorithms and monitors shape what gets posted — expect decay). Synthetic media (AI-generated "Hormuz traffic" videos circulated in August 2026 VERIFY — imagery needs Tier 0–1 corroboration). Data snooping across lexicons, models and horizons. Access decay. Legal: X, Reddit, Weibo, Investing.com and LinkedIn restrict automated collection — keep a per-venue terms register and prefer official APIs, GDELT and licensed vendors.

18.4 What the crowd said versus what happened

• April 2020. USO was the most-bought stock on Robinhood and the highest-volume trade on SoFi on 21 April while down ~80 % year-to-date; buyers "mistakenly thought this fund was a proxy for the spot price"; retail paid "$22 a barrel when the spot market's negative $38" (Kyle Bass); short sellers made ~$300 m against it; USO reverse-split 8-for-1 and moved to multi-month holdings. Lesson: the crowd was right that oil would recover and wrong about instrument and term structure; ETF sentiment signalled flows and forced positioning, not crude. Separate "sentiment about oil" from "sentiment about USO, 1671 or CFDs".
• 2022. Crude and wheat rose 23 % and 36 % within two weeks of the invasion; the top r/wallstreetbets post on invasion day (~32,000 upvotes) was about defence stocks, not oil; Reddit hope/fear indices tracked battlefield events, not markets. Lesson: geopolitical narrative is priced intraday and retail attention went to equities — an oil-only social gauge would have missed the crowd's actual behaviour.
• 2026. One theme dominated every language; polarity flipped on single headlines (11 March −9.3 %; a June closure announcement produced textbook risk-off; 8 July "ceasefire over"); institutions anchored far below the spike (EIA $87 and World Bank $86 for the 2026 average against a $95 spot; Texas producers expecting $74 at year-end); professional dissent argued the opposite risk ("market blindness to the 13 million barrel shock"; SPR draws suppressing futures relative to physical tightness); on 2 September the crowd was split by venue (Yahoo JP 67 % bullish, TradingView ~55 % bearish, Guba divided between "700 will never be seen again" and momentum buyers). Lesson: the informative quantities were concentration, novelty and the expectation–spot gap, not the sign of the mood. No peer-reviewed study of 2026 social sentiment exists yet VERIFY periodically.

18.5 Recommendations for the diagnostic (no trading use)

1. Free and legal core first: GDELT GKG (multilingual tone and themes), EIA/IEA/OPEC reports (monthly organisational sentiment), CFTC COT, Dallas Fed, multilingual Google Trends. Everything else is enrichment.
2. A curated X list of at most ~50 accounts under pay-per-use, read daily; no keyword firehose.
3. Retail boards as attention counters only (post counts, vote ratios with their denominators), collected forward with timestamps, per-site terms respected, no post text or author histories retained beyond permitted metadata, never backfilled; the Italian boards are the owner's local market and deserve a counter for that reason, not for signal.
4. Report distributions, not a score — topic shares, concentration, attention z-scores, tier mix, language divergence, expectation–spot gap — with the LLM writing the explanation and never a number.
5. Validate only against volatility and event timing, under multiple-testing discipline; any return predictability is a pre-registered research question, not a feature.

19. The trader's analytical toolkit and the catalogue of known strategy ideas

What professional and systematic oil traders actually compute and trade, with recipes, evidence grades and failure modes — so the project can maintain a testable idea backlog rather than a list of bullish and bearish nouns.

19.1 Fundamental analytics

19.2 Curve analytics

19.3 Positioning and flow analytics

• COT mechanics (A): Disaggregated categories back-cast to 2006; classification is staff judgement from Form 40; Tuesday data released Friday 15:30 ET — a three-day lag any backtest must respect; ICE publishes an equivalent Brent COT; the programme is under review (2026).
• Normalisations (B): net length ÷ open interest; z-score over 52/156 weeks; the "COT index" = (net − min)/(max − min) × 100. Evidence is mixed: hedging-pressure portfolios earn premia in the cross-section (Basu–Miffre; de Roon–Nijman–Veld), KRT decompose liquidity demand from insurance demand with opposite signs, GHR reject hedging pressure, KAPSARC finds no liquidity premium in crude. Positioning is a conditioning variable, not a standalone signal.
• CTA positioning replicas (B): lookback-straddle or time-series-momentum sleeves at 20/60/125/250/500 days under a common vol target; regressing the SG CTA Trend index on the sleeves gives betas summing ≈1.06, two-thirds in mid and slow horizons; bank "flow monitors" are black boxes.
• ETF and index flows (A for mechanics): USO rolls ~two weeks before expiry (predictable, liquidity-provided); the Bank of China product rolled on the last day, leaving ~38,000 contract-equivalents of retail longs in the May-2020 contract; front-running the GSCI roll earned Sharpe ratios up to 4.39 in 2000–10 and cost index investors ~3.6 %/yr, likely decayed since VERIFY.
• Options (B): OVX applies the VIX method to USO options; the variance risk premium (IV² − RV²) negatively predicts crude futures returns (Kang & Pan); commodity vol term structures are documented; OVX changes negatively predict equity returns; inventory announcements move option prices more persistently than futures with no asymmetry to the surprise sign; put/call skew and 25-delta risk reversals are watched daily but no crude-specific predictive study was located VERIFY; CME CVOL publishes variance-based skew VERIFY.
• Volume, OI, VWAP, settlement, TAS (A mechanics): per-contract time-of-day volume, OI change, spread volume, block and TAS flags; TAS executes at a tick differential to the day's settlement (ICE Brent TAS ±5 cents on the front three months VERIFY); on 20 April 2020 the May contract fell from $17.73 to −$37.63 with exceptional velocity between 13:00 and 14:30, order-book liquidity deteriorating days earlier and >30 dynamic circuit breakers triggered. Market-profile and volume-profile "support" without a tested execution mechanism is C.

19.4 Technical analysis in oil — what survives testing

Reading: trend rules pass when tested as diversified, vol-scaled, long-horizon portfolios; the same rules fail as single-market timing. The single-market oil Sharpe should be expected near 0.3–0.5 gross.

19.5 Known strategy families — evidence, reported numbers, failure modes

19.6 Risk and scenario tools

1. Scenario and stress trees. Replay 2008 (−$100 in five months), 20 April 2020 (−$55.90 intraday, settle −$37.63), March 2022, March 2026; branch trigger → realised loss → offset → duration; shock flat, curve, cracks, basis, EUR/USD, margin and liquidity jointly; include direction reversals (hurricane refinery loss, Russian refinery strikes). No component may assume price > 0; stress the expiring month separately because liquidity vanished days before expiry in 2020.
2. Gap-risk sizing. Size to the worst observed one-day move in the specific contract month and to absolute $/bbl shocks, not to daily σ; the front month is a different asset from M2.
3. VaR limitations. Fat tails and long memory: long-memory GARCH–EVT VaR beats normal VaR for energy (Youssef & Belkacem 2015); VaR cannot capture negative-price or delivery-mechanism risk.
4. Margin modelling. Major CME energy products are margined under SPAN 2 (historical VaR with stress, liquidity and concentration components), not the legacy SPAN scan grid; broker house margins sit on top; budget for margin doubling in stress; margin calls aggravated April 2020.
5. Correlation stress. Carry and trend across asset classes crash together in recessions; commodity co-movement in level factors rose from 53 % (1995) to 68 % (2012) with financialisation.
6. Event-study hygiene. Standardised surprise = (actual − consensus)/σ from the pre-release survey vintage (Kilian–Vega); instrument the noisy consensus (Halova et al.); align to the first tradable second after 10:30:00 ET (WPSR) or 15:30 ET Friday (COT); keep API as a separate event; non-overlapping windows, matched controls, robust errors, transaction costs, walk-forward holdout; post-selection of event class or window is C.
7. Multiple-testing controls. Harvey, Liu & Zhu's t > 3.0 for the cross-section of equity factors is the analogy, not Tradero's test: use Bonferroni/Holm or BHY on the project's own trial family and compute the Deflated Sharpe Ratio (Bailey & López de Prado 2014) from the effective number of independent trials, the dispersion of trial Sharpes, sample length, skew and kurtosis — a logged raw trial count is necessary but not sufficient. An exhaustive parameter search on a random walk almost always produces an "optimal" rule that fails out of sample.
8. Realistic edge sizes. Single-market trend ≈0.3–0.5 Sharpe gross; crude carry 0.6–0.7 over 36 years; long-only commodity excess ≈0; term premia 1–3 %/yr; a single-market backtest above ~1.0 is a review trigger for the deflated-Sharpe and trial-count checks, not proof of overfitting and not a result.
9. Missing from v2.0, added on review: expected shortfall and drawdown or risk-of-ruin limits; liquidity-adjusted slippage and market-impact stress; portfolio delta, gamma and vega with calendar and basis risk; variation-margin cash-flow and EUR collateral stress; broker concentration, default and kill-switch drills; data and order-state failure scenarios; delivery and notice risk; reverse stress ("what joint move exhausts excess liquidity?"). The worst observed day is a floor for stress, not a bound.

19.7 What a professional desk looks at every day

Daily: the front curve (M1, M1–M2, M1–M3, M1–M6, M1–M12, Dec–Dec in $/bbl and annualised %; the F1−2F2+F3 butterfly) for WTI, Brent and Dubai · Brent–WTI (front and M+6), Midland–Cushing, MEH–Cushing, Brent–Dubai EFS · the 3-2-1 crack, RBOB, ULSD and gasoil cracks · settlement prices, the 14:28–14:30 ET window volume, TAS volume, OI by month and the expiring month against days-to-expiry · OVX, ATM implied vol by expiry, 25-delta risk reversals, realised vol (5/20/60-day), the variance risk premium · the roll calendar (GSCI 5–9, BCOM 6–10, USO window, CL and Brent expiries, near-daily WTI weeklies) · estimated CTA position and predicted flow by sleeve · OPEC+ statements, sanctions, outages in announcement windows. Weekly: Tuesday API, Wednesday WPSR (Table 1 balance, crude by PADD and Cushing, products, inputs and utilisation, imports and exports, production, product supplied → surprise, five-year deviation, days of cover), Thursday ARA, Friday Baker Hughes and COT (managed-money net, z-score, ICE Brent COT). Monthly: STEO, OMR, MOMR (secondary-source production, compliance), JODI → recomputed balance, implied vs observed stock change, OECD days-cover, oil on water; tanker-tracking export and import estimates and floating storage. Redundancy is the point: a bullish flat-price move with a weaker front spread, softer cracks, no loading loss and only crowd attention is a different object from the same move with lost cargoes and steeper backwardation.

Reference texts: Downey, Oil 101 (2009); Kaminski, Energy Markets (Risk Books, 2013) VERIFY; Petroleum Economist, Trading and Pricing Oil VERIFY; CME "Introduction to Crack Spreads" and "Trading Crack Spreads" (2024); the ICE Brent FAQ; Blas & Farchy, The World for Sale; Arjun Murti, Crude Oil 101.

20. What the knowledge base adds to the Tradero programme

Section 11 set the v1 feature families and the hypothesis order; nothing in Part II changes that order, but it adds collectors, context objects and later-stage hypotheses. In priority order:

1. Collectors to add now, each after its own rights check (free to access is not the same as free to use — the IEA OMR is non-CC, Insights Global sells ARA, CME's website terms restrict systematic extraction): the official release calendars as data (EIA WPSR holiday shifts, STEO, COT delays, IEA, OPEC, ARA Thursdays, NBS/GACC), stored per week with first-seen latency; BSEE shut-in statistics, NHC advisories and USCG port conditions (chain P1–P2); DOE SPR notices of sale and exchange (Q8–Q9); OFAC and EU designation timestamps (Q10–Q11); Aramco OSP circulars by polling (Q6); CME clearing advisories and ICE circulars as margin objects (R2); GDELT energy themes as the free multilingual attention feed (§18); Pegel Kaub, NOAA CPC and ENSO status (P17, P20); the BCOM/GSCI roll and reweighting calendars (R3, §15.2).
2. The event-object schema (§14.1) and the narrative-state schema (§18.3) become tables in the point-in-time store before any LLM touches news; the LLM classifies and explains, code computes surprise, confirmation depth and eligibility.
3. Feature families F5 and F6 (§11.1) get their data plan: F5 location/export arb needs licensed Midland, MEH, Dated Brent and freight — deferred until the budget step; F6 physical-disruption state can start free with BSEE, NHC, NOC statements, CPC notices and OFAC, with realised_net_loss computed from public loadings proxies until Kpler or Vortexa is licensed.
4. Session-conditioned research (§15.10): every lead-lag or event test is conditioned on session; the Sunday-gap estimator uses Gulf equities and weekend Tier 0–1 items; TAS volume is excluded from directional features; option expiry is a dated object with strike and product.
5. Positioning is decomposed, never levelled (§16): OI-normalised long, short and spreading with Tuesday and Friday timestamps; the rate of change of managed-money length as a step-6 hypothesis; calendar-known flows (index rolls, ETF rolls, expiries) as calendar context and risk-gate inputs, not features, until separately admitted; no "commercials are always right".
6. Chains are a candidate registry, not a queue (§17): each chain is a row with trigger, observables, expected signs, lag priors, falsifier and the Tradero destination. Nothing enters research automatically. The §11.5 order is preserved: only the F5/F6 observables join existing families; a chain graded A/B and marked S1 or S2 may be proposed at step 6, one at a time, with pre-registered sign and horizon and counted in the trial family; chains marked context feed the regime state; chains marked never are recorded so nobody re-proposes them.
7. The mood diagnostic runs beside the market, not inside the score (§18.5): GDELT, organisational sentiment, a ≤50-account X list, retail attention counters (including the Italian boards) — evaluated on event detection and volatility only; a collector backlog is not a hypothesis queue.
8. Rights and reproducibility are fields, not footnotes: every source in §14.3 carries a rights tag and a retention class; licensed values carry methodology version; nothing scraped against terms enters the store.
9. Look-ahead traps specific to this layer (Codex review): current calendar pages backfilled onto old dates; today's ETF methodology applied before its effective date; revised cargo and AIS histories; PDFs silently replaced; ts_published copied from page metadata instead of first retrieval; post deletions ignored; later physical confirmation written into the original claim; a 2026-built topic or account universe run on earlier years; session conditioning chosen after seeing where results are strongest. Snapshot raw releases at first sight, version every calendar, methodology and universe, and never recompute a historical availability timestamp from today's page.

Appendix A — Reading list (in the order a new team member should read them)

1. Morgan Downey, Oil 101 — how prices are set day to day.
2. Hamilton (2009), Understanding Crude Oil Prices (NBER w14492) — elasticities, overshooting.
3. Kilian (2009), Not All Oil Price Shocks Are Alike (AER) — the three-shock lens; Baumeister & Hamilton (2019, AER) — the rebuttal.
4. Gorton, Hayashi & Rouwenhorst (2013), The Fundamentals of Commodity Futures Returns — inventories, basis, risk premia.
5. Alquist, Kilian & Vigfusson (2013), Forecasting the Price of Oil — why no-change is hard to beat.
6. Erb & Harvey (2006); Koijen et al. (2018) Carry; Moskowitz, Ooi & Pedersen (2012) Time Series Momentum; Hurst, Ooi & Pedersen (2017) A Century of Evidence — the benchmarks.
7. Kang, Rouwenhorst & Tang (2020) — what positioning does and does not tell you.
8. Bu (2014); Ye & Karali (2016); Halova, Kurov & Kucher (2014) — EIA announcement effects.
9. CFTC Interim Staff Report on 20 April 2020; Gilje et al. (2026, NBER w34905) — the negative price.
10. Blas & Farchy, The World for Sale; Arjun Murti, Crude Oil 101; Andurand interviews — how practitioners think.
11. EIA "Contango in Cushing?" (2012); EIA Today in Energy on Cushing tank bottoms (July 2026); IEA OMR August 2026 — the physical plumbing and the current regime.
12. Fernandez-Perez, Fuertes & Miffre on 20 April 2020 — cash-and-carry without booked storage, margin calls and TAS, not USO; Gilje, Ready, Roussanov & Taillard (2026) — the retail-long mechanism.
13. Cheng, Kirilenko & Xiong (2015) convective risk flows; Büyükşahin & Harris (2011); Brunetti, Büyükşahin & Harris (2016); Irwin & Sanders — the positioning evidence in one afternoon.
14. Brandt & Gao (RavenPack); Hashami & Maldonado (2025) on news count versus sentiment; Jeong & Ahn (2025) on IEA/OPEC report sentiment — what news is worth.
15. Boons & Prado (2018) basis-momentum; Karstanje, van der Wel & van Dijk (2015) on curve factors; Reeve & Vigfusson on when the curve forecasts; Ellwanger & Snudden on the benchmark convention.
16. Ferraro, Rogoff & Rossi on oil and currencies (same day only); Pierru, Smith & Zamrik (IMF 2022) on OPEC decisions; Loutia, Mellios & Andriosopoulos (2016) on OPEC announcements.
17. Kaminski, Energy Markets; Petroleum Economist, Trading and Pricing Oil; CME crack-spread primers; the ICE Brent FAQ — the practitioner shelf VERIFY editions.

Appendix B — Provenance

• Research note A (physical supply & demand, ~4,400 words, 60 sources, 32 VERIFY), B (inventories & market structure, ~4,000 words, 67 sources, own calculations from EIA series), C (macro, positioning, evidence, ~4,000 words, 91 sources), D (trader process, contracts, calendar, ~3,700 words): research/studies/2026-09-02-oil-fundamentals/.
• Codex memo (4,991 words, 11-factor v1 proposal, code-level v0 audit): research/codex/2026-09-02-crude-oil-fundamentals-deep-study.md; brief in the same study folder. Codex review of the merged v1.0 (2,216 words): research/codex/2026-09-02-review-oil-fundamentals-doc.md.
• Key primary pages verified directly during synthesis: IEA OMR August 2026; EIA Today in Energy #67424 (Q1 2026 price surge) and #67865 (Q2 2026, Brent high $118 on 29 Apr); CME client-systems page for 10-Barrel WTI (launch postponed); Bloomberg BCOM methodology (roll days 6–10).
• Round two (2026-09-02, same day): research notes E (information layer, ~4,400 words, ~90 sources), F (sessions and regions, ~5,400 words), G (participant map, ~4,900 words), H (mood and communities, ~4,700 words, nine languages searched), I (cross-market, policy and long-cycle chains, 41 chains, 113 sources), J (toolkit and strategies, ~4,350 words, ~30 primary PDFs): research/studies/2026-09-02-oil-fundamentals/E-…J-…md. Codex round-two memo (9,413 words, 53 chains, platform map, toolkit): research/codex/2026-09-02-part2-information-behaviour-chains.md; Codex review of v2.0: research/codex/2026-09-02-review-oil-fundamentals-v2.md (when present).