Actionable insights — Oil Prices Break US$100 Again, Here's What's Next

23:06 1. The reserve-life rerating screen — cash-flow multiple vs PDP years, then 2P

1. For each producer, pull the reserve report: PDP (proved developed producing), 1P (proved) and 2P (proved + probable) reserves, and convert each to years of current production.
2. Compute the enterprise or price-to-cash-flow multiple on the forward price deck.
3. Early/mid-cycle rule: the multiple should at least equal PDP years. A multiple well below PDP years is the buy list; rank by the gap.
4. Late-cycle rule: multiples migrate toward 2P years as commodity prices rise and the market gets comfortable paying more — that second leg is the multi-bagger upside.
5. Compare gas and oil names within their own groups — oil reserve lives run shorter, so the absolute numbers differ.

• Year-end reserve reports (PDP and 2P reserve life changes); sector-average multiples crossing average PDP life — the signal the cycle has moved to its later phase.

25:05 2. Use the lagging-equity template — commodity first, multiples later

1. Check whether the commodity has risen while the equities' multiples have not ("nobody cared about the golds" even as gold rose).
2. If so, the equity rerating is still ahead — position before the multiple expansion, not after.
3. Size the index target (he sees "a double or more" in the TSX energy index) and expect outliers ("five and 10 baggers") in the small and mid-caps.

• Sector cash-flow multiples starting to expand while the commodity is flat — the rerating phase has begun; generalist fund flows into energy.

07:54 3. Place the super-cycle by history and supply lead times ("the fifth hole")

1. Anchor to prior commodity super-cycles: 1974–81 and 1999–2008 (roughly 7–9 years each).
2. Date the start of the current one (he uses 2020, the COVID low).
3. Stretch or shrink the expected length by where new supply must come from: regions without infrastructure (South America, Africa, parts of Asia) mean longer lead times and a longer cycle — his estimate is to ~2034.
4. Translate position into a phase ("fifth hole of the golf course") and keep the full-cycle target in mind: in 2000–08 many stocks went up 20–30x low to high.

• Capex announcements and project FIDs in new-supply regions; whether new supply is arriving faster than the historical lag implies.

12:54 4. Price the war premium explicitly and assume it outlasts the political calendar

1. Estimate the no-war price from fundamentals (he puts it "in the 70s") and subtract from spot to get the premium (~$30 on $101).
2. Test the political "it ends after the election" claim against the adversary's incentives — a regime that can absorb pain "wins just by not losing."
3. Model the settlement structure, not just its timing: a permanent toll or "tariff" ($5–10) on strait traffic leaves part of the premium in place.
4. Budget company forecasts on a price deck below spot ($80 this year, $90 next) so the premium is upside, not the base case.

• US Navy convoy announcements; Hormuz toll terms in any deal; midterm results that could let Congress force a resolution.

16:51 5. Track the buffers — SPRs, China's stockpile and the marginal buyer

1. Log strategic and commercial inventories weekly: US SPR level and YoY change, and official forecasts of the floor.
2. Estimate the largest discretionary buyer's stockpile (China's ~1.4 Bbbl) and whether it is importing or drawing — its abstention is what capped the initial spike.
3. Remember price is set "by the buyer at the margin": watch the desperate spot buyers without storage (Bangladesh paying $28.50 vs a $23 Asian average for LNG).
4. Overlay seasonality: winter demand runs ~1.5 Mb/d above the shoulder season; if supply doesn't return, either price rises or inventories fall.

• EIA weekly SPR data; Chinese import resumption; spot LNG cargo prices paid by storage-poor importers; the November–March draw season.

10:07 6. Read refining margins as a capacity bottleneck, not a demand signal

1. Compute product value vs crude: WTI plus the crack spread gives what a diesel/jet refiner realizes (~$101 + ~$100).
2. Check whether capacity can respond: utilization (97.8% vs 94.9% a year ago), closures (BC, California), and whether new builds are economic or NIMBY-blocked.
3. If capacity can't respond, treat high margins as durable and favor refiners and integrateds with refining — "they have good dividend yields."
4. Expect the earnings to show up sequentially (Q3 > Q2, Q4 > Q3 if prices hold).

• US refinery utilization, diesel/jet cracks, and any announced refinery closures or restarts; late-October Q3 reports.

31:48 7. Buy-zone discipline: buy oversold pullbacks, harvest what runs ahead

1. Assume every cycle has pullbacks (1974–81, 2000–08 both did); don't chase the "trophy names" at high valuations.
2. Declare a "table-pounding" buy when prices are clearly unsustainable versus cost/fundamentals (oil in the 50s last March–April).
3. Within a rising market, flag names back in the "attractive buy zone" when oversold — e.g., a stock nearer its 52-week low than its high.
4. Harvest gains in names that "get ahead of themselves" and hold the cash for the next bargains.

• Each name's position within its 52-week range; RSI/oversold readings after a commodity pullback.

34:00 8. Rotate within energy to the laggard sub-sector

1. Split the sector into oil producers, gas/NGL producers, and oil services; compare each against its historic valuation after the latest commodity move.
2. Put new money into the sub-sectors that haven't lifted (after a $10 oil move, gas names only "lifted a bit" and services lagged).
3. Plan the next rotation trigger: a political de-escalation that sends oil back to the 70s would pull oil stocks back and reopen them as bargains.
4. Keep a mixed book across all three (plus oil sands and royalties) so rotation is a rebalance, not a reinvention.

• Relative performance of gas and service names vs oil producers after each oil move; drilling-rig counts as the service-demand lead.

35:49 9. Scale mergers earn a premier multiple — look for the institutional-size threshold

1. When two focused producers in the same play merge, check whether the combination crosses a size that institutions can own (market cap, liquidity).
2. Check the technical story is transferable — the better operator's technique (here waterflooding) applied across the larger land base lowers decline rates.
3. Expect a higher multiple for the combined company, not just summed value.

• Post-close multiple vs the two standalone multiples; Clearwater decline-rate disclosures; follow-on consolidation among small Canadian producers.

42:06 10. Size by cycle length — longer-lead commodities must offer bigger upside

1. Match vehicle to risk tolerance: low tolerance → the large integrateds; more tolerance → cheap but still liquid billion-dollar mid-caps; speculative juniors only as small positions.
2. For mining/critical minerals, the time from discovery to production is much longer than drilling a well, so require a larger upside to compensate.
3. Keep those long-cycle bets small components of the portfolio.

• Permitting and construction timelines for held mining names; whether the upside case still justifies the extra years.