Energy Markets Daily
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Geographic Feature: Alabama
Oct 8, 2026
2m 18s
Geographic Feature: Rwanda
Oct 7, 2026
2m 04s
Technicals: Week 40
Oct 6, 2026
3m 24s
Week 40 Opens
Oct 5, 2026
2m 34s
Geographic Feature: Country of Ireland
Oct 2, 2026
2m 24s
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| Date | Episode | Topics | Guests | Brands | Places | Keywords | Sponsor | Length | |
|---|---|---|---|---|---|---|---|---|---|
| 10/8/26 | Geographic Feature: Alabama | Thursday, October 8, 2026. ALABAMA ENERGY OVERVIEW. Rank #16 nationally by BOE. Small but active onshore/offshore oil and natural gas sector. CRUDE OIL: Jun 2026 ~217.5K bbl monthly, May ~233.2K bbl. Wells ~5,073 (Jun), operators ~54. Conecuh County leads ~119.2K bbl (~229K MCF gas). Mobile ~40.1K bbl, Escambia ~23.4K, Clarke ~10.4K. Cumulative Mobile County ~102.6M bbl (1990+), statewide ~357M bbl oil & ~5.5B MCF gas (1990-Jun 2026). Operators: Pruet Production, Hilcorp, Exxon Mobil, ARP Production, PGP Operating, Sklar Exploration, Breitburn. NATURAL GAS: Jun ~5.6M MCF monthly, May ~5.6M MCF. Cumulative leaders Tuscaloosa, Jefferson, Lamar. Underground storage ~33.95 BCF (Jun). OFFSHORE: Baldwin Offshore ~232 bbl oil, ~1.3M MCF gas (37 wells, May). Mobile Offshore ~181 bbl oil, ~1.08M MCF gas. Negligible vs federal GoM. No major Alabama deepwater 2026 highlighted. GULF OF MEXICO CONTEXT: Federal ~1.8M bpd stable/modest growth. Deepwater 94% crude, 80% gas. Shelf declining. New projects Whale/Ballymore/Dover (2025 onstream), Salamanca/Shenandoah expansions add tens-hundreds K bpd. U.S. forecast ~13.8M bpd. GoM ~13% U.S. crude. COASTAL REVENUE: GoMESA grants Mobile/Baldwin exceeded $52M (Aug 2026). NATIONAL SHARE: ~0.07% U.S. crude, ~0.16% natural gas daily. Comparable Michigan/Mississippi. REGULATORY: Alabama Oil & Gas Board. Sep 9 example: Conecuh Barnett Field (Pruet) swabbing/pressure tests. Ongoing Conecuh/Mobile activity. SUMMARY: #16 nationally. Crude ~217.5K bbl (Jun), ~233.2K bbl (May). ~5,073 wells, ~54 operators. Conecuh leads ~119.2K bbl. Cumulative ~357M bbl, ~5.5B MCF (1990-Jun). Gas ~5.6M MCF. Storage ~33.95 BCF. Offshore Baldwin ~232 bbl, ~1.3M MCF. Negligible offshore vs federal. Federal ~1.8M bpd, deepwater 94%/80%, shelf declining. New projects add tens-hundreds K bpd. GoMESA $52M+. Onshore-dominant. Small-scale contributor. | 2m 18s | ||||||
| 10/7/26 | Geographic Feature: Rwanda | Wednesday, October 7, 2026. RWANDA ENERGY OVERVIEW. No commercial crude oil or conventional natural gas production. Focus Lake Kivu methane extraction, hydroelectric, solar, petroleum imports. LAKE KIVU METHANE: ~60 cubic km dissolved (shared DRC). KivuWatt ~26 MW (2015 operational), Shema Power 56 MW (public-private, $200M, 25-year). Combined ~82 MW current (~21% national electricity 2025). Expansion >100 MW announced. Rwanda-DRC bilateral targets ~700 MW total (~350 Rwanda). Extraction safety measure (limnic eruption risk mitigation). COMPRESSED NATURAL GAS: Gasmeth ~$400M partnership. Karongi plant ~95% complete (May 2026). Q3 2028 commissioning target. CNG cooking/industry/transport. 300K-400K households supply. 600-800 construction jobs. PETROLEUM IMPORTS: Historic Tanzania (Dar es Salaam) primary. NEW KENYA CORRIDOR: Gov-to-gov (Jun signed, Sep active). First 40K metric tons (Mombasa). Target 10x growth (~500-600K cubic meters per year). Northern Corridor pipeline/storage. Diversifies from Tanzania. STRATEGIC RESERVES: Current ~110M liters (~2 months consumption). Expansion target 320+ ML, long-term 400ML. Rusororo, Nyacyonga facilities. Mitigate volatility/disruption risks. ELECTRICITY: Installed ~467 MW (end-2025), 52% renewables. Double target 2034 (~1,066 MW). Hydro, solar, methane, nuclear (~110 MW 2030-2033). LAKE KIVU OIL EXPLORATION: 2D seismic 2021-2022. 13 structural pockets identified. Exploratory pre-drilling. RMB seeking international partners for 3D/drilling. Rift Valley geology, Uganda Albert Basin similarities (~3.5 km depth+). Commercial viability undetermined. SUMMARY: No commercial crude/gas. Kivu methane ~82 MW (~21% electricity), >100 MW expansion planned. Rwanda-DRC ~700 MW potential (~350 Rwanda). Gasmeth CNG Karongi Q3 2028 (300K-400K households). Kenya corridor 10x growth. Reserves 110ML expand 320+ ML. Electricity 467 MW (52% renewables), 2034 target ~1,066 MW (hydro/solar/methane/nuclear). Oil exploration 13 pockets (exploratory). Import-dependent. Methane and renewable focus. | 2m 04s | ||||||
| 10/6/26 | Technicals: Week 40 | Tuesday, October 6, 2026 - LIVE TECHNICAL ANALYSIS. WTI CRUDE: Trading low $90s ($88-$91, four-week low pressure). Support: $84.50-$85 (50% Fib + 100-day SMA confluence - pivotal), $87.35 (near-term floor), $88.20 (swing), $82 (deeper), $80.73 (61.8% Fib). Resistance: $91.16 (near-term), $93.70 (initial), $94.13 (23.6% Fib), $95.91 (strong), $96.35 (next), $98.50 (further), $102.40 (cycle high). Pivot ~$90 flat. Critical inflection $88-$89. Indicators: RSI 37-47 (oversold), MACD negative -0.37 (bearish), MAs sell signals. Bias bearish consolidating short-term. Bullish hold $84.50 target $91-$94.13 → $96.35 → $98.50 → $102.40. Bearish fail $87.35 or $82 breakdown → $80.73 lower. BRENT CRUDE: Trading $99-$100 (consolidation after testing higher). Support: $98.54 (first), $95-$98 (trendline/channel), $87-$90 (deeper), 200-day EMA (anchor). MAs: 50-day $97-$99 (dynamic), 10/20/30-day $101-$104 (above price). Resistance: $101.73 (first), $103-$105 (psychological), $107-$110 (Fib/swings), $113-$114 (longer-term). Indicators: RSI 36-54 (mixed), MACD -0.32 to +1.31 (mixed), MAs bullish (price above multiple). Bias bullish consolidation testing support, hammer formation, regaining momentum. Bullish hold $100-$101.73 target $103-$105 → $107-$110. Bearish fail $98.54 → $95-$97 → $92-$93 (trendline/38.2% Fib major break) → $90-$87-$89. Spread maintained >$11 (maritime premium). NATURAL GAS: Henry Hub spot Oct 5 $3.07/MMBtu (+1.22%), range $3.00-$3.08. Nov futures $3.076 (Oct 4 $3.015, Oct 2 $3.035). Curve Nov $3.06, Dec $3.35, Jan 2027 $3.73. Setup above $3.05 target $3.20-$3.30; below $2.95 test $2.85; hold $2.80 baseline. 52-week range $2.48-$7.83 (mid-range current). SUMMARY: WTI consolidating bearish short-term, critical $88-$89 inflection, support $84.50-$85 strong confluence. Brent solid $100+, bullish consolidation, hold $100-$101.73 target $103-$105. Gas steady $3.00. Bias: Bearish WTI, bullish Brent, neutral gas. Chart levels paramount. Capital preservation. | 3m 24s | ||||||
| 10/5/26 | Week 40 Opens | Monday, October 5, 2026 - LIVE DATA. CRUDE OIL: WTI trading $90.49-$91.57 range (various sources $90.50-$91.11, neutral trend, down 0.16% prev). PolitiKool $90.50 (+57.9% YTD), EnergyRiskIQ $90.66 (-0.16% DoD), GuruFocus $90.66, TwelveData ~$89.72 (range $89.31-$90.90), Investing/MarketWatch $90.49-$91.11 (Oct 2 close $91.11, Oct 4 $90.65-$91.09). Recent: Oct 1 $92.87, Sep 30 $90.42, Sep 29 $89.38 (low-mid nineties volatility). Nov 2026 futures ~$90-$91. Up 48-58% YTD. BRENT: Trading $98.43-$103.06 range. Investing.com SA $102.13 (-0.28% DoD, range $101.94-$102.38, Oct 4 $102.42), UK variant $102.92 (+0.66%), main page $98.47 (-0.24%, range $98.43-$99.55). EIA spot Oct 1 $114.82, Sep 30 $115.91, Sep 29 $113.96 (spot lags futures). FRED Sep 29 $113.96 (up ~65% YoY). Spread Brent-WTI >$11 (maritime premium). MARKET DRIVERS: Houthi escalation ballistic/drone attacks Saudi Aramco Riyadh/Khurais (Yemen response, Saudi strikes). Yemen military Saudi major offensive retake Houthi areas (regional tension). ME exports recovered pre-war levels late Sep. G7 strategic reserve ~100M barrels release (diesel/crude supply relief tempering). Saudi Nov Asia prices six-year lows (soft demand). Tanker shortages elevated insurance longer voyages (seaborne premium). Chinese refinery suspends exports Oct (diesel/gasoline/jet fuel, refined market tight). Global inventory low, ME concerns elevate benchmarks (~40% above pre-conflict Brent comment). OPEC+ PRODUCTION: Oct 4 virtual meeting seven core (Saudi/Russia/Iraq/Kuwait/Kazakhstan/Algeria/Oman) Nov targets unchanged from Sep/Oct. Targets: Saudi 10.478M, Russia 9.949M, Iraq 4.431M, Kuwait 2.676M, Kazakhstan 1.628M, Algeria 1.007M, Oman 0.841M bpd. Aug actual 25M core (+630k Jul, ~5M below pre-conflict Feb). OPEC+ 38.05M (+300k Jul). Actual Gulf below targets (Hormuz disruptions). Voluntary cuts 2M bpd through 2026 end. Sep MOMR latest (Aug data), no Oct released. Next Nov 1. NATURAL GAS: Spot Sep 29 $3.18/MMBtu (latest official). Earlier Sep 28 $3.13, Sep 25 $3.21. NYMEX futures Oct 4-5 $3.01-$3.04 (Oct 4 close ~$3.012 -0.76%, Oct 2 $3.035, Investing Oct 5 $3.042 intraday, Oct 5 close ~$3.032). 52-week range ~$2.48-$7.83. WTI bounces low $90s (~$90.50-$91.27, neutral/slight positive day). Brent holds firm $100-$103 futures, spot $114+. Houthis escalate geopolitical support risk. OPEC maintains Nov targets unchanged (production steady, actual Gulf constrained). G7 reserves release tempering. Tanker premium persists (Hormuz). Week 40 opens cautious, geopolitical volatility, capital preservation paramount. | 2m 34s | ||||||
| 10/2/26 | Geographic Feature: Country of Ireland | Friday, October 2, 2026. IRELAND ENERGY OVERVIEW. Energy import dependency 78.2% (4th highest EU). Natural gas imports >82%. Strategic LNG reserve advance underway. NATURAL GAS: Imports Aug 2026 12,883 TJ (up from 11,880 TJ Jul). >82% sourced externally. Supply breakdown (2026 summer): GB pipeline ~85.2%, Corrib indigenous ~14.8% (down from peak), biomethane <0.1%. No domestic storage/LNG currently. Indigenous production Q1 2026 down ~16% vs 2025, imports up ~5%. CORRIB GAS FIELD (offshore): Production ~14.8% summer demand (down from ~20% historical). Depletion early 2030s, reduced through late 2020s. Operators Vermilion (majority), Nephin (43.5%). Status declining, import dependence increasing. Exploratory licenses extended FEL 3/19 & 4/19 (Slyne Basin, ~18km east). Infrastructure maintenance ongoing 2026. Repurposing discussions (wind/hydrogen/storage post-depletion). SGER LNG PROJECT: Location Cahiracon, Co. Clare (Shannon Estuary). Operator Gas Networks Ireland (state-led). Technology FSRU. Legislation Act signed July 2026 (streamlined approval). Planning end-2026. Operation ~2030. Capacity emergency backup (7-day state/months home). U.S. fracked LNG consideration (New Mexico). Prior fracked-gas import bans removed. PRIVATE LNG: Shannon LNG/FSRU (Tarbert) ~6 mtpa, proposed, legal/planning hurdles. ELECTRICITY & RENEWABLES: Renewable 49% (Mar 2026), wind 38% record (Apr). Capacity 8 GW (5 GW wind, 2.3 GW solar), solar >3 GW summer >1/3 demand. Onshore dominant, 2nd-largest after gas. Wind curtailment H1 ~15% (~667k homes). Target 80% renewable 2030 (22 GW: 9 GW wind, 5 GW offshore). GAS GENERATION: Largest source up 93%, min 12%, avg 43% H1. Critical reliability/flexibility. POLICY: Electrification plan mid-century. Shift the Switch (renewables usage, reduce imports, grid stability). RESS 6 NZIA compliance. Public support 71% renewables (down from 77%). Data centre growth €7B+ costs 2018-2037. EirGrid H1 milestones. STRATEGIC: Declining Corrib + renewable delays = LNG reliance. EU 4th-highest import dependency. Security paramount. Ireland >82% gas imports (12,883 TJ Aug), GB 85.2%, Corrib 14.8% declining depletes early 2030s. SGER FSRU operational ~2030 emergency backup. Fracked U.S. LNG option. Renewables 49%, wind 38% record, 8 GW capacity (5 wind, 2.3 solar), target 80% 2030. Gas 43% avg generation essential reliability. Electrification plan acceleration. Data centre expansion headwind. Supply security focus. | 2m 24s | ||||||
| 10/1/26 | Geographic Feature: State of Montana | Thursday, October 1, 2026. MONTANA ENERGY OVERVIEW. Ranks #8 U.S. by BOE (barrels of oil equivalent). CRUDE OIL: June 2026 ~1.8M bbl monthly, current ~78k bbl/d (EIA), ~6,835 producing wells (Jul 2026), #12 nationally (~45k+ total wells). BAKKEN UNCONVENTIONAL: Bakken/Williston Basin 1.21M bbl/d (Sep 2026), associated gas 3.36M Mcf/d. Montana monthly 2026: Jan 77k, Feb 79k, Mar 79k, Apr 82k, May 77k, Jun 69k, Jul 69k bbl/d. Drilling 58 wells drilled, 69 completed/month. DUC 230. Bakken >50% state output. Range-bound ~1.2M bbl/d, below peak, increasing gas content. NATURAL GAS: June 2026 ~8.0M MCF monthly, #20 nationally. COAL (declining): YTD 2026 (Aug 1) 12.366M short tons, down 13.2% vs 2025 (14.254M). Weekly WY+MT early Sep 5.07M (+3.4% WoW, +7.5% YoY), mid-late Sep 4.5M (Sep 19, +2.25% WoW, -0.7% YoY). Major projects Spring Creek (Decker) expansion, Bull Mountains (federal-approved, legal challenges). Reserves most recoverable U.S. coal. Down 36% from 2014 peak. PRB dominates Western production. FEDERAL LEASING: BLM July 2026 66 parcels, ~29,087 acres (MT+ND). REGULATORY: DNRC/BOGC official (permits, wells, records, hearings). Data Miner online database. Quarterly leasing. Open GIS data. Montana Petroleum Assoc rules/regulatory resources. ENERGY SUMMARY: #8 nationally BOE. Bakken >50% oil (~78k bbl/d, 1.8M bbl Jun). Gas 8M MCF. Coal declining YTD -13.2% (12.4M short tons). Reserves abundant. Regulatory active. Mixed crude/gas growth, coal wind-down. | 2m 20s | ||||||
| 9/30/26 | Week 38, Mid-Week Update | Wednesday, September 30, 2026 - LIVE DATA CORRECTED. CRUDE OIL: WTI rebounded $88.58-$91.96 range, trading ~$89.70-$91.27 (+0.22 to +2.62% various quotes). Oilprice $89.72 (+0.38%), Investing $90.67 (+1.44%), Yahoo $89.58 (+0.22%), Barchart $91.72 (+2.62%), WSJ $91.27 (+2.11%), CNBC open $89, high $91.96, low $88.58. Up ~5.7% past month, up ~47% YoY. Rebounded above $90 on diplomatic signals. BRENT: Sustained elevated $97.74-$99.03 range, trading ~$98.48-$99.03 (+2.4 to +2.98%). Trading Economics $98.70 (+2.64%), Yahoo $98.84 (+2.79% range $95.95-$99.22), MarketWatch $99.03 (+2.98%), Investing $97.74 prev $96.16, Barchart $98.66 (+2.60%), Moneycontrol open $95.82 high $98.93. Geopolitical premium embedded. DRIVERS: WTI rebound ~$90.64-$90.85 (+1.4-1.65% prior), Brent ~$98.48 (+2.4%). Iran received US proposal Hormuz reopening. ME exports recovered ~98% pre-disruption (partial, constrained). Diplomacy hopes tempering rally. INVENTORY: US crude build ~900k barrels (week ending Sep 25), diesel below average (Q4 concern). STRAIT HORMUZ: Effectively closed Day 213 (Feb 28 crisis). Only 1 vessel Sep 27 vs ~85/day (~1% throughput). War-risk ~40x pre-crisis ~$10M VLCC. Incidents tankers struck/boarded, Cape Dao bulk fatalities, mines. Diplomacy Iran proposals stalled, no breakthrough, ops stranded vessels/seafarers Gulf, bypass pipelines reduced, containers rerouted Cape Good Hope, LNG/fertilizer/Asia/Europe disrupted. ANALYSTS: Standard Chartered raised forecasts (ME instability, thin buffers), China Q4 imports cut ~400k bpd, OPEC quotas unchanged, Russia diesel ban Oct 31. GAS: Henry Hub Sep 30 futures ~$3.02-$3.04/MMBtu (WorldOilMonitor $3.022, FT $3.04 +0.86%, MarketWatch ~$3.029, TradingEconomics ~$3.03 +0.44%). EIA spot Sep 29 $3.18 (above futures, tightness/seasonal). Mid-$3 steady. WTI rebound $90+ geopolitical, Brent sustained $98+, Hormuz closed Day 213 (~1% throughput), Gas steady $3, diplomacy uncertainty, supply constrained, month-end consolidation, risk management paramount. Capital preservation. Trade the data, not the headlines. | 3m 09s | ||||||
| 9/29/26 | Technicals: Week 38 | Tuesday, September 29, 2026. CRUDE OIL TECHNICALS: WTI 92.36-93.85 mid-$90s (mixed short-term trend, cautious recovery post-volatility). Support: daily pivot 92.50-92.90, 91-89.66, 88 (7-month resistance turned support), 87-85. Resistance: daily R1 94.28-94.91 (breakout threshold), R2 96.14 (prior high), R3 97.52, extensions 99-99.69, higher 102+. Patterns: bull flag 4H with breakout potential 99.69+. Price breaking above corrective bearish channel, testing daily pivots. Holding above 88 multi-month barrier. Indicators: MACD bullish pressure rising positive territory, RSI(14) neutral-rising (42-55 range, source variance), MAs mixed (bullish bias longer-term SMAs/EMAs, sell signals shorter). Scenarios: Bullish sustained hold 94-94.91 target 96.14-97.52 then 99.69-107 (Fib extensions). Bearish failure below 92.50-92.90 or breakdown 88-91 target 89.72, 88.25, lower 87-85. NATURAL GAS: Henry Hub 3.14/MMBtu (Sep 29 +0.98%), NYMEX 3.135, earlier Sep 22 spot 2.90, 2026 range Jan 30.72 high, recent 2.90-3.14, long-term avg 3.26. Setup: above 3.05 target 3.20-3.30 resistance. Below 2.95, 2.85 support test likely weakness. Hold 2.80 baseline pivot. BRENT TECHNICALS: 98.50-103 range (Sep 28-29). Resistance: 100 psychological/major shelf (break targets further), 101.50 H&S neckline critical short-term (break 105-106), 105-106 confirmed breakout above 101.50, 107-108/110 Fib/prior, 113-114 long-term. Support: 97.50-98.50 (50% Fib/pivot, break accelerates), 95-97 (20-day MA, defensive), 92-93 (trendline/38.2%, major, breakdown lower), 90/87-89 (downside targets), 85+ (200-MA/61.8%, deeper correction). Indicators: MAs strong buy longer-term, oscillators neutral-mixed with sell pressure. Pivots: 102.82/S1 100.17/S2 97.55/R1 105.44. WTI consolidating 92 support, HH tested 3.00+, Brent neutral-mixed. Technicals consolidation post-volatility, chart levels key, risk management paramount. | 2m 33s | ||||||
| 9/25/26 | Geographic Feature: Uruguay | Friday, September 25, 2026. Uruguay: world leader renewable electricity, ~98% grid 2025 (13,040 GWh): hydro 46%, wind 34%, biomass 14%, solar 4%, fossil 2%. Export ~8% (hydro) Argentina/Brazil. Aug 2026 99.4% renewable: hydro 58% (record monthly 11-yr high), wind 28% (440 GWh), biomass 11.7%, solar 1.7%, fossil 0.6%. Installed ~4,900 MW: fossil ~1,200 MW (25% reserve), wind >1,500 MW (31%, ~1,000 private, ~500 UTE), hydro ~1,500 MW (balancing battery variable wind/solar), biomass ~400 MW, solar ~270 MW (growing). Hydro major: Salto Grande binational, Palmar/Constitución ~333 MW, Rincón del Bonete, Baygorria, modernization ongoing, balancing mechanism. Wind global leader (Denmark/Ireland/Germany comparable penetration): ~1,500-1,525 MW stable, historical surpassed hydro (hydrological dependent), limited near-term UTE additions (2032+ focus), hybrid/offshore green hydrogen discussed long-term. Solar expanding: new projects ~100+ MW 2026 target (Melo+), diversify demand. Fossil minimal (2% 2025, 0.6% Aug): natural gas not primary, coal minimal, oil/diesel transport/thermal reserve, grid renewable-focused. Cross-border trade: surplus Argentina/Brazil interconnections, strategic regional stability, demand export revenue. Investment 6-7B renewables recent, private wind/solar/biomass, UTE ~46% hydro-dominant operator, solar ramping cost economics. Demand rising electrification/industrial growth, ~13,000 GWh annual 2025, future growth targets electrification initiatives. Sustainability 97-99% renewable world-leading, climate integrated national policy, export reputation investment attraction, sector expertise global/regional sought. Uruguay ~98% renewable electricity, wind-hydro balanced, ~4,900 MW installed, 6-7B investment, cross-border exports Argentina/Brazil, renewable pioneer supreme. | 2m 45s | ||||||
| 9/24/26 | Geographic Feature: Iceland | Thursday, September 24, 2026. Iceland: global geothermal leader, ~65% primary energy, ~30% electricity, ~90% heat district. Installed capacity ~785-808 MW nine plants (>0.5 MW), +22 MW Svartsengi end-2025. Major plants: Hellisheiði ~303 MW (ON Power/Reykjavík), Nesjavellir 120 MW (ON Power), Reykjanes 100-130 MW (HS Orka), Þeistareykir 90 MW (Landsvirkjun), Svartsengi ~76 MW (HS Orka), Krafla 60 MW (Landsvirkjun), Bjarnarflag ~5 MW. Electricity ~6 TWh/yr (6,000 GWh 2023, 5,651 GWh 2025) ~30% national. Aug 2026 99.4% renewable: hydro 58% (record 11-yr high), wind 28%, biomass 11.7%, solar 1.7%, fossil 0.6%. Direct-use heat 90% homes district heating ~36,335 TJ (~10,093 GWh_th) 2023, households/services/fish/aquaculture/industrial. Geothermal 65% primary energy, per-capita global leader (9th total worldwide). Expansions: Bolaalda 100 MW_e +133 MW_th s. Iceland parliament approval mid-2026. IDDP-3 superhot Nesjavellir Q4 2026 target >400°C, 20-50 MW per well (vs conventional 2-7 MW). Hellisheiði expansion Nordic Investment Bank 2025-27, toward 345 MW_th, new well ~5 MW_e, drilling/infra. Laugarnes/Engjateigur production wells 2026-27 district heating. 2025 Ísor resource assessment 1,860-6,520 MWe key fields 50-yr potential. Gross inland consumption forecast ~193,040 TJ 2026. Reinjection ~70% Hengill major fields (sustainable). Combined heat/power (CHP) standard. Icelandic companies (Iceland Drilling, Reykjavík Geothermal) active internationally. Global sector growth 20-25% 2030. National Master Plan (Rammaáætlun) geothermal utilization categories. Superhot/corrosion-resistant tech focus. Iceland geothermal ~65% primary, ~30% electricity, 99%+ renewable grid, 90% heat, nearly pure renewable supreme global leader. | 2m 15s | ||||||
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| 9/23/26 | Geographic Feature: Greenland | Wednesday, September 23, 2026. Greenland: zero crude production, zero gas production, pursuing renewable energy transition. Grid >70% hydroelectric, minimal fossil. Target 100% renewable 2030. 2021 moratorium new petroleum licenses (climate goals). Single active oil license: Jameson Land Basin (Nunap Qeqqa). Operator: Greenland Energy Company (NASDAQ: GLND via SPAC merger) / 80 Mile PLC (White Flame Energy subsidiary) JV. Greenland targeting up to 70% working interest, 80 Mile 30%. Basin described one world's last major undrilled onshore Arctic, North Sea geological links. Historical ARCO efforts, >$275M (inflation-adj) prior industry investment decades. Prospective resource ~13B barrels gross un-risked (58 prospects, substantial risk). Phase 1 drilling OPW-1/OPW-6 (~3,500m depth each), ~$40M first well, ~$20M second. Partners: Halliburton (integrated services/logistics/drilling), Stampede Drilling Rig 12 (5-year Arctic contract), IPT Well Solutions, Desgagnés logistics. Original timeline: equipment mobilization Canada Sep 2026, drilling Oct 2026/Q4-Q1 2027. Delays: July 2026 unauthorized equipment landing (excavator/containers), government reprimand, warning. Permitting now requires fuller environmental/social impact assessment, public consultations, regulatory review. Timeline shifted winter 2027 or later (2028 possible), single well focus potential. ~$70M raised NASDAQ offering fund exploration. Local Ittoqqortoormiit communities engaged, political interest (US connections), opposition climate/environmental advocates, regulatory scrutiny ongoing. Comparative USGS West Greenland-East Canada (separate basin) ~7.8B barrels oil, 91.9 Tcf gas (not licensed). Greenland frontier Arctic oil exploration delayed permitting 2027+, highly speculative, environmentally sensitive. | 2m 25s | ||||||
| 9/22/26 | Geographic Feature: Alaska | Tuesday, September 22, 2026. Alaska: leading US oil producer. July 2026 statewide ~14.113M barrels (~455k bpd). FY2026 ANS forecast 459.2k bpd, total ~466.8k bpd. June ~414.3k bpd (seasonal MoM decline). July ~456k bpd (+2% MoM). EIA calendar 2026 forecast ~477k bpd (13% growth, largest annual increase decades). FY2027 projected 518.5k bpd. Pikka (Santos/Repsol) first oil spring/Q2 2026, Phase 1 ~80k bpd ramp, major ANS growth contributor. Willow (ConocoPhillips) FY2029. Fields FY2026: Prudhoe Bay core ~181.5k bpd (long-term decline, drilling/workovers/infill offset), satellites (Aurora/Milne Point/Polaris/GPMA) ~107.3k bpd combined, Kuparuk/others substantial, Cook Inlet ~7.6k bpd. Prudhoe Bay operator Hilcorp, 2026 Omega Pad expansion, drilling/workover activity. ANS crude Sep 15 $115.38/bbl (surge amid global/Hormuz supply concerns). TAPS operational stable, production growth offsetting prior throughput decline risk. Cook Inlet gas July 2026 31.3 Bcf. Hilcorp active year 28 wells planned (19 grassroots, sidetracks/infill). BlueCrest Lower Tyonek A funding Sep 2026, first gas ~Mar 2027 ~25 Mcf/d initially. Winter supply context: potential shortfall, Hilcorp holds ~30 Bcf storage entering winter. Legislative discussions on supply adequacy, renewable transitions. Long-term trajectory: FY2027 ~518.5k bpd, early 2030s >600k bpd scenario (Pikka/Willow, reversing multi-decade decline 1980s+). North Slope dominates Alaska energy profile. New projects reversing production decline. | 2m 39s | ||||||
| 9/21/26 | Strategic Positioning: Week 38 Opens | Monday, September 21, 2026. CRUDE OIL: WTI pulled back ~96.08 pre-market (range $94.8-$101+), down from recent Sep 18 ~$100.30 (-1.58%), Sep 17 ~$101.91, Sep 16 ~$102.43 (high $105.63). Broad rally from $82-87 (Aug 20-31) to $90-100+ (early-mid Sep). Brent Sep 20 ~$99.29, recent Sep 18 ~$103.87 (-0.9%), Sep 17 ~$104.82 (-0.95%), earlier Sep 14-16 peaks $105-108. WTI-Brent spread ~$3 Brent premium. Prices fell 3rd session easing supply fears (Saudi pipeline partial restoration days-weeks timelines, extra cargoes offered), remain >$100. Primary driver: Middle East recovery narrative. Brent influenced by Middle East events/Hormuz chokepoint/Saudi export infrastructure. Saudi East-West pipeline damage (drone/Houthi attacks), partial restoration expected days-weeks. Reduced Hormuz traffic, alternative routing advancing. Saudi-Houthi escalation risks, cross-border strikes, broader tension. Forecasts: higher toward $120 if disrupt worsen, elevated into 2027 depending conflict duration. Strait Hormuz: 6-month volume high mid-Sep per US CENTCOM Adm Brad Cooper (Sep 19). Current flows 10-11M bpd (White House) vs IEA 7.6M Aug. Enablers: mine clearance primary lanes, naval escorts 2,000+ ships, Gulf producer/insurer/shipowner coordination. Cumulative >1B barrels crude last months US-facilitated. Status: critical/effectively limited, open negotiated-escorted terms not free. War-risk insurance 40x normal limiting commercial. Route dynamics: dual/contested (Iranian northern vs Omani-US southern), Iran directing/restricting, IRGC risks/mines/attacks. VLCC freight >$1M/day mid-Sep. June 2026 MOU temporarily boosted (30-49 transits/day late June, 11-12M bpd peaks), later fluctuated re-escalations/blockades. 2026 impacts: Cape rerouting, ~2.8B barrels cumulative losses, elevated prices, constrained Iran exports. Outlook: momentum building, full normalization (20M bpd/100+ transits) not imminent; insurance/geopolitical/control risks persist. NATURAL GAS: Henry Hub $2.97/MMBtu (Sep 15 latest, +4.21% prior day). Sep: 14 $2.85, 11 $2.71, 10 $2.76, 9 $2.81, 8 $2.90, 4 $2.92, 3 $2.95, 2 $2.88, 1 $2.90. Monthly avg ~$2.97, Oct futures 2.912 (Sep 18 close), 2026 range Jan high ~30.72 vs recent 2.97 vs long-term avg 3.26. OPEC+: Sep 6-7 keep Oct quotas unchanged Saudi/Russia/Iraq/Kuwait/Kazakhstan/Algeria/Oman. Next Oct 4. Oct unchanged: Saudi 10.478M, Russia 9.949M, Iraq 4.431M, Kuwait 2.676M, Kazakhstan 1.628M, Algeria 1.007M, Oman 841k (~31.01M combined). Saudi Aug slump 6.238M bpd (-1.9M) lowest 1990 geopolitical route disruption. OPEC trims 2026 demand 380-400k bpd (vs prior 600k), global 105.8M, OECD -110k, non-OECD +, 2027 +2.4M (vs prior 2.2M). Gradual unwinding cuts (+188k Sep), actual well below targets geopolitical. UAE exited May. Geopolitical backdrop: US-Iran hostilities, Hormuz-Strait spiking prices, disrupting routes, influencing production. WTI ~96 easing supply fears, Brent 99-104 >100 ~$3 spread, Hormuz 6-month highs 10-11M bpd (White House) vs 7.6M (IEA Aug) mine/escorts/coordination, >1B barrels cumulative, critical status 40x war-risk, dual routes IRGC risks, June MOU 30-49/day 11-12M peaks fluctuated, 2.8B cumulative losses 2026, elevated, Iran constrained, momentum building not normalized 20M/100+ transits, insurance/geopolitical/control risks. HH 2.97 (+4.21%), monthly 2.97, Oct 2.912, 2026 high 30.72 vs 3.26. OPEC+ Oct unchanged Saudi 10.478/Russia 9.949/Iraq 4.431/Kuwait 2.676/Kazakhstan 1.628/Algeria 1.007/Oman 841k. Saudi 6.238M (-1.9M) lowest 1990. Demand trim 380-400k (600k prior), global 105.8M, 2027 +2.4M. Unwinding +188k actual well below. UAE out May. US-Iran Hormuz. | 2m 28s | ||||||
| 9/18/26 | Geographic Feature: Vietnam | Friday, September 19, 2026. Vietnam: declining domestic crude ~8.2M tonnes annually, Jan-Apr 2026 2.9M tonnes (+14.4% YoY, field depletion). Oil imports Jan-Apr 2026 3.8M tonnes (-23%, Kuwait down sharply, diversifying). Crude sources: domestic/US (ExxonMobil/Chevron)/West Africa/Russia (ESPO/Sokol). Gas production ~8 bcm 2025, target >20 bcm 2034 (Ca Voi Xanh/Block B). Upstream market USD 2.82B 2025, projected USD 3.91B 2031 (CAGR 5.57%). LNG scaling: Thi Vai (PV GAS) 1 mtpa current (expanding 3 mtpa, 1.5 GW power supply), pursuing 2nd 5-yr contract 250k-450k Mt (Thi Vai, Jan 2027 start post-Shell 2027-2031), Cai Mep (Hai Linh) 3 mtpa operating fully commissioned ramped (ownership→Nebula/AG&P), Hai Lang 1.5 mtpa, Quynh Lap 1.15 mtpa (construction May 2026, target 2030), Vung Ang 1-3 mtpa phase 1 (2029-30+), Son My 4.8+ mtpa phased, Bac Lieu 2 mtpa floating, N. Vietnam/Hai Phong 1.2 mtpa proposed, Long An/Ca Na/others various. LNG-to-power: Govt 22.5 GW target (current 1.6 GW). T&T-TotalEnergies: USD 1.5B Long Son LNG-fired (1,500 MW Ho Chi Minh). Hai Lang: 1,500 MW linked terminal (T&T/South Korea consortium). Quynh Lap: 1,500 MW power (SK Innovation/PV Power). PDP VIII: flexible LNG-to-power/DPPAs. Dung Quat Refinery (BSR Petrovietnam, Quang Ngai): designed 6.5 Mt/yr (140k-148k b/d), 2026 record target 8.3 Mt highest since 2009, first 7mo 4.76 Mt (106% target, 124% capacity), crude diversified (domestic/US/W. Africa/Russia) 3+ mo mid-2026. Products: RON95/E5/E10 gasoline/diesel/Jet A-1/LPG. BSR-BF biofuels: 100% capacity mid-Apr (~330 m³/d E100 ethanol). Expansion USD 1.5-1.8B (Hyundai/Technip bids) 171k-190k b/d Euro 5, site prep 50% June 2026, EPC Aug 2027, ops ~2028. Revenue target VND 154T (~USD 5.9B) 2026 (+7% YoY), Q1 revenue 41.28T VND profit 3.35T. Cumulative >USD 10B state budget 2009+. Nghi Son 2nd refinery 200k b/d, combined support domestic. Russia: interest expand LNG/refined products supplies Vietnam. International: Russia/TotalEnergies/S. Korea partnerships. Vietnam: declining domestic crude/gas, LNG-to-power 22.5 GW target scaling, Dung Quat record 8.3 Mt 2026 (124% capacity), biofuels 100%, expansion 171k-190k b/d 2028, BSR revenue 5.9B USD target, Nghi Son 200k b/d, Russia expanding supplies. Vietnam: domestic decline, LNG surge, refinery powerhouse, geopolitical partner. | 2m 31s | ||||||
| 9/17/26 | Geographic Feature: Slovenia | Thursday, September 18, 2026. Slovenia: zero domestic crude production zero bpd, zero gas production, entirely import-dependent (52% energy dependency). Oil consumption ~4.4-4.5M tonnes annually, sources Saudi Arabia (27% 2025), Italy, Greece, ~36% total energy consumption. Gas ~1 bcm annually all imported Russia/others. Refining zero (closed 1998-2001 Lendava refinery). Product imports ~4.4M tonnes. Retail fuel: Petrol (largest) + MOL/INA ~81% combined market. 2026 supply disruptions Iran conflict/cross-border stockpiling → 50L/day purchase limits. Hungary-Slovenia-Italy interconnector gas pipeline: ~1.24 bcm/yr capacity, 2026 commissioning, diversify away Russian gas. LNG: Croatia Krk terminal capacity booking 2027+. Renewables ~25% gross final consumption 2024 (25.1% 2023), trajectory 28.4% 2025, 30.2% 2027, 33% target 2030. Electricity mix recent 2025-26: nuclear 40%, hydro 25%, solar >10%, fossils 20%, low-carbon 79%. RES electricity: 6,254 GWh 2024, projected 7,066 2026, 9,462 2030. Hydro: HSE >3,300 GWh/yr, hybrid solar-hydro advancing. NECP (Integrated National Energy Climate Plan): 55.4% RES electricity 2030 (44.9% 2026), 33% renewables overall consumption 2030. New renewable energy law (EU Directive 2023/2413 transpose): simplified permitting/tenders, solar/hydro/geothermal/biogas/biofuels support, green hydrogen (≥100 MW electrolyzers 2030 target). Policy: Recovery Resilience Plan RES/grid/efficiency, Modernisation Fund solar+battery. Japan hydrogen memo Sept 2026: supply chains/technology/infrastructure/grid-gas integration ELES/Plinovodi. Monthly 2026 energy stats: provisional fluctuations electricity generation (nuclear/hydro/solar-wind), gas/petroleum products supply. Total consumption: long-term decline, oil/gas key imports vs. growing RES/nuclear. Slovenia: zero production, zero refining, 52% energy import dependent, oil 36% consumption, gas 1 bcm all imports, retail 81% duopoly (Petrol/MOL/INA), 2026 Iran-driven shortages, Hungary-Slovenia-Italy 1.24 bcm interconnector 2026 commissioning, LNG Krk 2027+, renewables 25% (target 33% 2030), electricity nuclear 40%/hydro 25%/solar 10%/fossil 20%, RES electricity 6,254 GWh 2024 to 9,462 2030, new law simplified renewables, 100+ MW hydrogen electrolyzers 2030, Japan hydrogen partnership Sept 2026. Slovenia: Europe's renewable transition anchor, Russia-import hostage. | 2m 04s | ||||||
| 9/16/26 | Geographic Feature: Panama | Wednesday, September 17, 2026. Panama: zero domestic crude production zero bpd, zero gas production, zero refining capacity (closed 2003). Import dependent all products (~3.6M tonnes 2024, 64-68% final/primary consumption). Trans-Panama Pipeline: 131 km, 36-40" diameter, Chiriquí Grande (Caribbean) to Charco Azul (Pacific), 860k bpd capacity, interoceanic bypass, VLCC overflow route, ~10M barrels/month. Sept 2026: Panama completed 100% ownership acquisition Petroterminal de Panamá (PTP) operator, ~191.7M dollar investment. Panama Canal Q2 2026: ~3.2M bpd crude/condensate/products (94% petroleum ~3M bpd), ~600 Mcf/d LNG. Sept 2026 drought restrictions: 34 vessels/day early Sept, 32 starting Sept 15 (9 Neopanamax+23 Panamax), 34% rainfall below normal May-Aug (El Niño). Canal normally 36-40 transits/day unrestricted. Record slot auction: South Korean LPG tanker (G. Spirit SK Gas) paid 5.3M dollar Sept 1 slot (prev record 4.6M or 4M), avg prices rose from ~55k earlier. Further cuts possible Dec 2026-Apr 2027 if rainfall low. US crude surge: exports to Asia via Canal +46% YoY record 61.6M metric tons Q2 2026, ~5M bpd avg, surge amid Hormuz disruptions (post-Feb 2026 Iran). Rerouting: congestion/diversions push some gas/crude tankers around South America (Cape/Magellan) or ship-to-ship, increased slot competition. Tanker traffic: multiple chem/oil/crude tankers in zone, ~4/day recent increases, waiting times doubled for MR2s. Revenue context: early 2026 strong recovery (+8-17% YoY), ~35 daily transits mid-2026 avg boosted Hormuz flows, FY2026 revenue beating forecasts despite drought. LNG imports: Costa Norte terminal 2018+ (~2 bcm/yr capacity), 2024 imports ~0.6 bcm from US, power generation. Renewables: ~73% power mix 2024 (hydro dominant, wind/solar growing), ~5.1 GW installed capacity, plans further renewables/Colombia interconnect (delayed to 2029). Energy Corridor: proposed ~76-77 km gas/LPG pipeline (propane/butane/ethane, 2.5M bpd capacity), ~4.2B dollar cost, significant investment interest. Shelved: 140 MW gas-fired power (Gas to Power Panama). Policy: national plans target 30% wind/solar by 2050. Panama: zero production, zero refining, pure logistics hub, Trans-Panama 860k bpd bypass, Canal Sept drought (34→32 transits) amid record US crude surge (+46% YoY) and Hormuz rerouting, record 5.3M dollar slot auctions, FY2026 revenues beating forecasts, LNG Costa Norte imports 0.6 bcm from US, renewables 73% power mix, Energy Corridor advanced. Panama: world's busiest energy crossroads, drought-squeezed, Hormuz crisis beneficiary. | 2m 41s | ||||||
| 9/15/26 | Technicals: Week 37 | Tuesday, September 15, 2026. CRUDE OIL TECHNICALS: WTI ~$101.34 (+0.98%), rally from low $80s Aug to $100-$103 zone. Bias: bullish above key levels, consolidation/decision point. Resistance: $103-$105 (immediate), $107-$108 (next upside target), $113 (cycle high strong bullish), $116-$120 (major extension if disruptions intensify). Support: $98.50-$100 (near-term holds bullish), $95.48 (61.8% Fib first pullback), $90-$92.50 (demand band 50% Fib ~$90 Elliott Wave critical break reversal risk), $85-$88 (medium-term 100-day SMA ~$85.38 July ~$94), $84.59/$77.86/~$67 (deeper). Indicators: RSI(14) 71.68 (overbought/sell), MACD +4.63 (buy), oscillators 6 sell/1 neutral/3 buy (sell bias), MA strong buy 12 buy signals (bullish trend), candlesticks mix bearish daily (Deliberation/Doji/Engulfing) bullish shorter, ADX buy strong momentum. Overall: bullish trend but short-term momentum fading, potential pullback before resumption. WTI consolidating near highs, support $98.50-$100 expected holding, resistance $103-$105 breakout targets $107-$108, reversal $95.48 Fib defense, geopolitical premium elevated. NATURAL GAS TECHNICALS: Henry Hub ~$2.88-$2.90 at pivot, recent range ~$2.75-$3.01. Resistance: $2.897-$2.906 dense cluster (50% Fib/VWAP/SMA50/SuperTrend), $2.91 (R2), $2.917/$3.00 psychological. Bullish breakout >$2.906 targets ~$3.026. Support: $2.877 (S1 immediate), $2.87 (S2 Fib), $2.857/$2.715-$2.79 (deeper). Bearish reversal: $2.79-$2.84 downside. Indicators: MA clustered $2.83-$2.89 mostly bullish buy signals, MA200 ~$2.90, pivot ~$2.89. Bias: capped supply/storage, mixed-to-bullish technically. Setup: at pivot, resistance dense $2.897-$2.906 breach target $2.91/$3.00, bears defend $2.877 next $2.87 Fib, storage/LNG (19.6 Bcf/d multi-month high) warmer weather cooling demand geopolitical directing to US. Volatility: summer 2026 realized ~40%+, forward fall-winter Oct-Jan ~60-70%, drivers EIA weekly storage/weather/LNG/geopolitical, institutional long building, OI rising. WTI consolidating $98.50-$105 bullish bias momentum fading RSI overbought, R $103-$105 S $98.50-$100, geopolitical premium intact, monitor consolidation breakout/pullback support hold. NG at pivot $2.88-$2.89, R dense $2.897-$2.906, S $2.877-$2.87, upside $3.00 breakout downside $2.79-$2.84 reversal, storage LNG key drivers, elevated volatility forward higher. Trade charts respect levels manage risk. | 2m 33s | ||||||
| 9/14/26 | Strategic Positioning: Week 37 Opens | Monday, September 14, 2026. CRUDE OIL UPDATE: WTI surging to $102+ range (late session quotes $102.29-$102.55 up 2.23-2.50%). Brent breakout above $107 ($106.91-$108 range), +2% daily, +17-18% month, +58-59% YoY, first time above $100 since July. WTI-Brent spread widening $5-9/bbl premium to Brent signals Hormuz severity. Primary driver: US-Iran conflict seven months, Strait Hormuz effectively closed (normally 15-20M bpd 20% global consumption). Current: ~3 commercial arrivals/day (~4% pre-crisis 74/day baseline), oil flows near-zero, day 198 disruption, war-risk insurance 15x peacetime. Sep 13: Iran commercial vessel struck Qeshm Island (1 fatality, injuries), regional Oman talks indefinitely postponed, vessel transits single-digits 7-10/day vs pre-war 130+, US military facilitated cumulative 1,600+ vessels recent daily 9-11M bbl well below pre-war. Iranian blockade mid-July halted exports, loadings ~220k-255k bpd Aug vs much higher, dozens tankers stranded in Gulf, bypass capacity limited several M bpd cannot compensate. Secondary: drone/Houthi Saudi attacks, East-West pipeline (7M bpd bypass) temporary shutdowns, Red Sea threats, diplomatic uncertainty both sides signaling prolongation fading quick de-escalation hopes. Historical: early 2026 >$120 initial phase, eased temporary ceasefire/Hormuz reopen, re-accelerated renewed hostilities. Banks raising forecasts $95-$120+ if persist, some agencies gradual easing potential later 2026, global supply tightened. NATURAL GAS: Henry Hub $2.88-$2.89/MMBtu. NYMEX NG close Sep 14: $2.882. Trading Econ $2.89 up 2.05%, OilPriceAPI $2.89 spot, Markets Insider ~$2.88, early Sep $2.81, prior sessions $2.83-$2.92 range, 52-week low ~$2.52-$2.56 high ~$7.46. Crude testing $100+ territory, Brent leading, Hormuz paralysis persists, gas holding $2.88-$2.89 decoupled but slightly higher. War premium embedded, diplomatic path unclear, supply deficit widening. Capital preservation first. Do not short active conflict. Respect the levels. Trade the data, not the headlines. | 2m 55s | ||||||
| 9/11/26 | energy productionoil refining+4 | — | BelorusneftYangpur+5 | BelarusRussia+4 | Belaruscrude production+5 | — | 2m 32s | ||
| 9/10/26 | oil productiongas production+5 | — | USGSNV Energy | NevadaCalifornia+7 | Nevadaoil production+6 | — | 2m 30s | ||
| 9/9/26 | crude oilgeopolitical risks+3 | — | WTIBrent+1 | USIran+1 | crude oilWTI+5 | — | 2m 41s | ||
| 9/8/26 | crude oilnatural gas+4 | — | WTI crudeHenry Hub | — | crude oilnatural gas+5 | — | 2m 28s | ||
| 9/4/26 | energy profilerenewable energy+3 | — | ICEDOCSE+1 | Costa Rica | Costa Ricarenewables+6 | — | 2m 27s | ||
| 9/3/26 | oil reservesnatural gas reserves+3 | — | IMFEII+2 | Yemen | Yemenoil reserves+5 | — | 2m 14s | ||
| 9/2/26 | oil pricesnatural gas+3 | — | CRUDE OILNATURAL GAS+6 | Middle East | crude oilnatural gas+3 | — | 2m 03s | ||
| 9/1/26 | crude oiltechnical analysis+3 | — | CRUDE OIL | Barchart | crude oiltechnical analysis+5 | — | 2m 12s | ||
| 8/31/26 | crude oilnatural gas+3 | — | crude oilnatural gas | Cushing, OKStrait of Hormuz | crude oil updatenatural gas update+3 | — | 2m 34s | ||
| 8/28/26 | Oman energy profileoil production+3 | — | Omani crudenatural gas+1 | Oman | Omanoil production+3 | — | 2m 53s | ||
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Chart history for Energy Markets Daily
Peaked at #72 in SG, currently #72 in SG.
| Market | Genre | Peak | Current | Trend |
|---|---|---|---|---|
| SG | — | #72 | #72 | — |
| SG | — | #191 | #191 | — |
Chart Positions
2 placements across 1 market.
Chart Positions
2 placements across 1 market.