Energy Markets Daily
Energy Markets Daily delivers essential intelligence for global energy capital. Hosted with institutional authority, this daily brief covers WTI/Brent crude analysis, natural gas markets, energy M&A activity, drilling in...
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| Date | Episode | Topics | Guests | Brands | Places | Keywords | Sponsor | Length | |
|---|---|---|---|---|---|---|---|---|---|
| 10/23/26 | Geographic Feature: Ethiopia | Friday, October 23, 2026. ETHIOPIA ENERGY OVERVIEW. Ranks 2nd-highest hydropower potential Africa. Energy sector 95-97% hydropower-dependent. Rapid geothermal, natural gas, renewable diversification. HYDROELECTRIC: Grand Ethiopian Renaissance Dam (GERD) 5,150 MW installed (Africa's largest). Inaugurated 2025, full generation FY 2025-26. Contribution 51.5% generation. Drought-vulnerable. Other dams 13K+ MW total. GEOTHERMAL: Corbetti project 1,000 MW planned 2026-27. Tulu Moye ~300 MW potential. Fast-track development. NATURAL GAS: Ogaden Basin exploration Chinese partnerships. Strategic export potential via LNG. Diversification target 2030: Hydro doubling, geothermal, gas, wind 5K+ MW, solar 2K+ MW. Regional exporter potential Kenya, Djibouti, Sudan, Tanzania. Africa's clean energy hub opportunity. | 2m 30s | ||||||
| 10/22/26 | Geographic Feature: Venezuela | Thursday, October 22, 2026. VENEZUELA ENERGY OVERVIEW. Ranks among world's largest proven crude reserves (~300B bbl, majority heavy-extra-heavy Orinoco Belt). Production severely impacted by U.S. sanctions, underinvestment, geopolitical crisis. 2026 shows recovery amid eased sanctions. CRUDE OIL PRODUCTION: Current Sep 2026 ~1.2M bbl/d (PDVSA). Recovery from crisis lows 250K-350K (2021-23). Q3 2026 forecast 1.15M-1.3M bbl/d. ORINOCO BELT: Reserves 300B bbl extra-heavy. Capacity potential 2.5-3M bbl/d (2030 optimistic), current 1.2M-1.3M bbl/d. Operators: PDVSA 70%, Chevron 50K bbl/d, Continental Resources, GEOPark. Chinese partnerships dominant. High-risk high-reward energy asset. | 2m 51s | ||||||
| 10/21/26 | Week 42, Mid-Week Update | Wednesday, October 21, 2026. CRUDE OIL UPDATE. WTI sustaining mid-ninety-seven range. Brent elevated 107-109. Hormuz disruption persisting. Geopolitical hedges active. Mid-week consolidation. WTI: ~$97.20-$97.85 consolidation zone. Support $96.35, resistance $99.24-$99.69. Brent: $107.50-$109 bullish. Support $105.50, resistance $109+. Spread narrowing $10+. Henry Hub $3.02-$3.04 steady neutral. Hormuz day 226 (~1% flow) geopolitical hedge active. Inventory draws supportive. Capital preservation paramount. | 2m 23s | ||||||
| 10/20/26 | Technicals: Week 42 | Tuesday, October 20, 2026. WTI CRUDE OIL TECHNICAL. Current (Oct 19) ~$97.53-$97.74. Support: Immediate ~$96.35-$96.55 (daily pivot), Zone A $94.81-$94.37 (Fib 38.2%), $92.60-$93, $91.87 (S3), $88-$89 (structural). Resistance: $99.24-$99.69 (near-term, break opens upside), $101.35-$101.78 (daily R1), $102.18-$103.65, $104.54-$105.25, $110-$120 (longer-term). Indicators: RSI 62-65 (neutral-bullish, not overbought), MACD positive/above signal (bullish), MAs strong buy (20/50/100/200 all bullish). Pattern: Rising Three Methods (short-term pullback potential before resumption). Fibs: 23.6% $96.25, 38.2% $94.37, 50% $92.85, 61.8% $91.33. Bias: BULLISH above $92-$94. Uptrend intact. Geopolitical support Hormuz. Short-term corrections likely after rallies. BRENT CRUDE OIL TECHNICAL. Current (Oct 19) ~$107.89-$108.09. Support: $104.51 (key, first pullback target), $101.50, $99.34, ~$98 (50/200-day MA), $94 (longer-term). Resistance: $107.97-$109.95 (current consolidation, swing levels), $110-$110.17 (major resistance), $113.46 (FXEmpire weekly high), $114-$116, $117 (prior highs, multi-month resistance), $120+ (extended). Indicators: RSI 64.8 (bullish, approaching overbought), MACD positive/bullish, MAs all bullish (6/7 indicator groups bullish). Pattern: Uptrend intact (higher highs/lows). Testing September highs ~$108. Bias: BULLISH. Break $110 targets $114-$117. Support holds above $104 avoids deeper retracement toward $100 or below. HENRY HUB NATGAS TECHNICAL. Current (Oct 19) ~$3.06-$3.07/MMBtu. Resistance: $3.26-$3.35 (major retracement zone, multiple tests), break above $3.33-$3.40 targets $3.60+, further $3.80-$3.90. Support: $3.087-$3.146 (Fib support zone), $3.00 (psychological/50-200 day EMA), $2.89-$2.97 (deeper). Indicators: RSI ~54-55 (neutral, not overbought), MACD neutral-bearish (recent negative), MAs 50-day ~$3.06-$3.07, 200-day ~$3.09-$3.46. Cloud: Broken below $3.104 intraday (weakness concern). Pattern: Range-bound since March (~$2.60-$3.39). Consolidation, potential breakout/mean-reversion. Bias: NEUTRAL-SLIGHTLY BEARISH. Range-bound $3.00-$3.40. Warm weather/storage builds weighting. Pullbacks to $3.00-$3.09 buying opportunities if structure holds. Choppiness/downside if breaks $3.00. Upside needs $3.30-$3.40 clear. SUMMARY: WTI bullish $92-94 support, rising 3-methods pattern, support $96.35/$94.81, resistance $99.24/$101.35, RSI 62-65, MACD bullish, MAs bullish. Brent bullish testing $108, support $104.51, resistance $110/$113.46, RSI 64.8 (overbought), MACD bullish, 6/7 bullish. Natgas neutral-bearish, range $3.00-$3.40, resistance $3.30-$3.40, support $3.00-$3.15, RSI neutral, MACD bearish, warm weather weighing. Risk management: Respect levels, Hormuz risk, EIA data impact, capital preservation with stops. Trade technicals, respect structure. | 2m 25s | ||||||
| 10/19/26 | Week 42 Opens | Monday, October 19, 2026. CRUDE OIL UPDATE. WTI surged from $91-92 (Oct 12) to $97.53-$97.74 (Oct 19, -1.14% day-over-day). 5-6 dollar rally week-over-week. Month-to-date up ~$9-10 from early Oct lows near $88. YTD up ~48-52%. Trend: Consolidation likely $95-$99. Support $92-$94, resistance $100+. Volatility elevated. Brent rallied $104-$105 (Oct 12) to $107.89-$108.09 (Oct 19, -1.64% day-over-day). 3-4 dollar surge. Bullish momentum. Support $105, resistance $106-$110. YTD up ~52-54%. WTI-Brent spread narrowing $10.35-$10.52 (down from $12-13 prior week, market repricing). HORMUZ CRISIS ESCALATION: Record high ~12 attacks (week ending Oct 16). 10 Strait of Hormuz, 1 Arabian Gulf, 1 Gulf of Oman. Vessel lost: GFS Pride container ship sank (Oct 13, projectile strike, 21 crew safe). Multiple tankers struck by projectiles/RPGs. Tug struck NE Khor Fakkan. Iran claims supertankers hit mines/caught fire. IMO 100+ regional incidents, 24 fatalities cumulative, thousands affected/stranded. Transits down 70% below pre-crisis (~5 vessels some days). Oil flow ~11-12.6M bpd (down from 17M pre-war). One-day peak 6 attacks (Oct 11 or Oct 5-11 period). Iran asserting control vs US blockade. AIS-off routes targeted. Supply squeeze acute. EIA INVENTORY (week ending Oct 9, released Oct 15): Commercial crude down 8.6M bbl to 415.6M (3% below 5-yr avg). SPR unchanged 283M. Cushing up 1.9M to 26.6M. Total stocks down to 698.56M. Refinery crude 16.6M bpd (down 135K), utilization 93.5%. U.S. production 13.7M bpd (down 300K, Hurricane Isaias Gulf evacuations). Motor gas up 3.5M, distillate down 2.5M, propane down 1.5M. Total petroleum down 13.4M. NATURAL GAS: Henry Hub $3.06-$3.07/MMBtu (Oct 19 close). Range $2.90-$3.28 Oct month. Oct avg 3.142. Nov futures 3.116 (Oct 16). Trend: Modest uptick Oct 2-19 ($2.90 to $3.07, ~22% move up-month). Sept avg $2.95. YTD avg $3.48. WEEK 42 POSITIONING: WTI $97 consolidation (support $92-$94, resistance $100+). Brent $108 bullish (support $105, resistance $109-$110). Spread narrowing $10+. Henry Hub steady $3. Risk-on geopolitical hedge. Hormuz escalation driving rally. U.S. inventory draws supportive. Hurricane minimal impact. Capital tightening. Data-dependent decision-making. Trade supply disruption, not headlines. | 2m 41s | ||||||
| 10/16/26 | Geographic Feature: Country of Pakistan | Friday, October 16, 2026. PAKISTAN ENERGY MARKETS. Net energy importer modest domestic crude oil/natural gas supplemented significant LNG imports. Faces acute short-term LNG supply disruptions Qatar force majeure, elevated import costs winter 2026-27. Reserves concentrated Sindh, Khyber Pakhtunkhwa (KP). CRUDE OIL PRODUCTION: August 2026: 68,600 bpd +10% YoY, -5% MoM. Provincial: KP 49% (33,614 bpd), Sindh 35% (24,010), Punjab 15% (10,290), Balochistan 1% (686). Reserves June 2026: 276M barrels (+15% YoY from 240M). New discoveries Baragzai, Spinwam. Reserve life ~19 years. FY2025-26: 23.85M barrels (95% target 25.18M). OGDCL (55% production): FY2025-26: 36,013 bpd. FY2030-31 target: 60,384 bpd (+68%). NATURAL GAS PRODUCTION: August 2026: 3,008 mmcfd +8% YoY, +1% MoM. Provincial: Sindh 62% (1,865 mmcfd), Balochistan 20% (602), KP 15% (452), Punjab 3% (90). Reserves June 2026: 20,664 Bcf (+9-10% YoY from 18,981). Mari Ghazij, Spinwam additions. Reserve life ~19 years. FY2025-26: 1.07 Tcf (below 1.16 Tcf target, mature field depletion). OGDCL gas: FY2025-26: 797 MMscfd sales. FY2030-31 target: 1,167 MMscfd (+46%). LPG PRODUCTION: August 2026: 2,238 tonnes/day (+20% YoY, +7% MoM). FY2025-26: 0.767M tonnes (exceeded target). EXPLORATION: September 2026 +352% MoM exploratory drilling to 7,270 metres. Offshore bid round first 18 years, drilling plans 2026. LNG IMPORTS/WINTER CRISIS: October 2026: First cargo Oct 13-14 (Al Areesh, Engro terminal, 150 mmcfd regasification). Two cargoes October only. Both terminals mostly idle (Engro Sept 26-Oct 13, PGPL Oct 9 onward, low inventory). Qatar force majeure March 2026 (Ras Laffan), extended to ~Nov 6. Pakistan previously ~99% Qatar sourced. Winter 2026-27 demand surge: SNGPL 550→1,550 mmcfd peak. SSGC 300→500 mmcfd. Targets 22-26 cargoes total (vs 36 prior winter). 12 long-term (mostly Qatar, possibly Eni). 10+ spot market ~$26.30/MMBtu (double term rates). Winter import cost exceeds $1B. Spot cargo estimated cost ~$863M (~10 cargoes). Seeking alternatives: US, Middle East, Azerbaijan SOCAR, spot tenders. Load management plan development (domestic priority, possible curtailments export/CNG/cement/power). Policy: Third-party terminal access, allow private power producer direct imports, diplomatic Qatari cargoes. ELECTRICITY SECTOR: Installed capacity March 2026: 49,651 MW (+8.5% YoY). Generation mix July-March FY2026: Cleaner sources (hydel, nuclear, renewables) 53% for first time (exceed thermal). Solar surged. Gas consumption power: 2,929 mmcfd average (July 2025-March 2026), LNG filling gaps. Winter spikes expected, load management needed. E&P PROFITABILITY: ~15% YoY profit decline projected Q2 FY2026 (weak oil prices, lower gas output). Major players: OGDCL (55% crude, 28% gas), Mari Energies, PPL, POL. SUMMARY: Crude oil 68,600 bpd Aug (+10% YoY), KP 49%, Sindh 35%. Reserves 276M barrels (+15% YoY), ~19 year life. OGDCL targets 60% growth 60,384 bpd FY2030-31. Natural gas 3,008 mmcfd Aug (+8% YoY), Sindh 62%. Reserves 20,664 Bcf (+9-10% YoY), ~19 year life. OGDCL targets 46% growth 1,167 MMscfd FY2030-31. LPG 2,238 tonnes/day (+20% YoY). Exploration: Offshore bid first 18 years, drilling 2026. LNG crisis acute: Qatar force majeure severely limits term supplies (was 99%). Oct 13-14 first cargo 150 mmcfd. Two Oct cargoes only. Terminals mostly idle. Winter 2026-27 demand surge SNGPL 1,550 mmcfd peak (550), SSGC 500 (300). Targets 22-26 cargoes (vs 36 prior). 12 long-term, 10+ spot. Spot ~$26.30/MMBtu (double term). Winter bill >$1B (~$863M spot). Seeking alternatives US/ME/Azerbaijan/spot. Load plan development (domestic priority, curtailments possible). Electricity: 49,651 MW capacity (Mar 2026, +8.5% YoY). Cleaner 53% first time (hydel/nuclear/renewables >thermal). Gas power 2,929 mmcfd avg, LNG filling, winter spikes/load management needed. E&P profit ~15% YoY decline Q2 FY2026 (weak oil, lower gas). Pakistan energy dependent imports/LNG. Domestic depletion pressures, severe near-term supply disruptions (Qatar force majeure) create acute winter 2026-27 risks, elevated costs ~$1B+ winter, load management/curtailment pressures. Domestic production modest (69k bpd oil, 3,000 mmcfd gas) insufficient demand. Reserve life ~19 years medium-term supportive, infrastructure aging, exploration/development critical. Electricity generation mix shift renewables positive, winter LNG shortfalls threaten power generation/load stability. Geopolitical factors (Strait Hormuz, Qatar) amplify vulnerability. | 5m 27s | ||||||
| 10/15/26 | Geographic Feature: States of North Carolina and South Carolina | Thursday, October 15, 2026. NORTH CAROLINA & SOUTH CAROLINA ENERGY MARKETS. Both states have ZERO indigenous crude oil and natural gas production. Net importers all fossil fuels. CRUDE OIL: NC/SC no production/reserves. ~125 exploratory wells NC historically, no commercial success. Offshore Atlantic OCS potential exists (BOEM 2026: 4.50 Bbo, 34.35 Tcf nat gas Atlantic-wide; South Atlantic ~1 Tcf range). Manteo Prospect (off Cape Hatteras) estimated 5 Tcf dry gas historically; exploration cancelled. No active federal leases since 2000 Manteo relinquishment. State opposition to Atlantic OCS leasing. Zero refineries; both depend on interstate pipelines (Colonial, Plantation) and marine imports. Vulnerable East Coast tight supplies. Onshore shale potential (NC Triassic) ~1.66 Tcf, minimal development. NATURAL GAS: Zero domestic production. Supplies via interstate pipelines (Transco, Appalachian Marcellus/Utica). Key expansions: Transco Southside Reliability Enhancement (SRE) entered full service +423,400 Dth/d NC/VA. Transco Southeast Supply Enhancement (SSE) FERC Jan 2026, construction underway, partial late Q4 2026, full Q4 2027, +1.6M Dth/d capacity Mountain Valley Pipeline (MVP) interconnect. Duke contracted 1M Dth/d. Mountain Valley Pipeline Southgate extension: Construction underway VA/NC, target mid-2028 (litigation risk). Duke contracted 250k Dth/d. No underground storage; peak LNG peak-shaving. Mild 2026-27 heating (HDD ~3,150, 3% below 10-yr avg). ELECTRICITY: NC generation mix: natural gas ~36%, nuclear ~27%, coal ~12%, solar ~9%, hydro/other ~16%. SC: nuclear ~52%, natural gas ~23%, coal ~17%, low-carbon overall ~60%. NC 2024 total gas consumption 690 Bcf (electric power 431 Bcf/62%, industrial 118, residential 69, commercial 68). SC coal capacity ~5,159 MW (Winyah 1,260 MW, Cross 2,452 MW). SC natural gas capacity ~3,271 MW combined cycle, ~2,630 MW combustion turbines. DUKE ENERGY CAROLINAS 2026 RESOURCE PLAN: 30% winter peak growth target through 2041. Solar 18.5 GW. Natural gas 14 GW (8.2 GW combined cycle, 5.8 GW combustion turbines). Battery storage 13 GW. Nuclear ~4.5 GW new. Specific gas projects: Anderson SC 1.4 GW combined-cycle approved 2026. Davie/Davidson NC advancing. SANTEE COOPER SC PLAN: Load growth unprecedented. Coal retirements delayed (Winyah end-2034 or later). Gas replacements: Canadys ~2,200 MW joint (online early 2030s, Santee share powers ~250k homes), ~870 MW Santee-dedicated gas by 2035. Natural gas near-term reliability resource. Pipeline expansions (Transco SSE 1M Dth/d, MVP Southgate 250k Dth/d) support new gas generation. LOAD GROWTH DRIVERS: Population, data centers, manufacturing, coal retirements. Duke peak burn existing fleet ~980k Dth/d, exceeding current FT (firm transportation), driving new procurement. Winter 2026-27: Mild HDD ~3,150 (3% below), reduces heating demand, supports nat gas price moderation. Fuel costs Carolinas subject to national crude/gas volatility (Brent 2026 avg $96, Q4 $105; HH 2026 avg $3.48). Manufacturing cost exposure ~30% of firms. SUMMARY: NC/SC zero indigenous oil/gas. Zero refineries. Offshore Atlantic potential (1 Tcf gas South Atlantic, BOEM 2026) undeveloped (no leases since 2000, opposition OCS). Natural gas infrastructure major expansion: Transco SRE (full service), SSE (partial late 2026/full 2027 +1.6M Dth/d), MVP Southgate (construction, mid-2028, +250k Dth/d). Electricity dominated by imports interstate transmission. NC: gas 36%, nuclear 27%, coal 12%, solar 9%. SC: nuclear 52%, gas 23%, coal 17%, low-carbon 60%. Duke targets 30% winter peak growth: solar 18.5 GW, gas 14 GW, storage 13 GW, nuclear 4.5 GW by 2041. Santee Cooper: Canadys 2,200 MW joint, 870 MW dedicated gas. Specific approved: Anderson SC 1.4 GW combined-cycle. Load drivers: population, data centers, manufacturing, coal retirements. Winter 2026-27 mild (HDD 3,150, 3% below), supports gas price moderation vs. baseline. Energy policy dominated electricity reliability, renewable integration, storage, natural gas transition fuel. No material upstream oil/gas/refining. States function energy consumers, infrastructure hubs importing all fossil fuels national/global markets. | 4m 45s | ||||||
| 10/14/26 | Week 41, Mid-Week Update | Wednesday, October 14, 2026. CRUDE OIL: WTI trading $94.15-$95.52 range, close ~$95.05. Brent $105.71-$106.33 (spread $10-11 maritime risk premium). Oct 13-14 surge: $91.85→$95.05 (+$3.20, +3.5%). YTD up ~63% from Jan. STRAIT OF HORMUZ ESCALATION: 15+ attacks Oct 6-14, 11 in past 4 days (container ship ~50k tonnes, tanker ~19k tonnes hit unknown projectiles, minor damage). 24+ vessels Oct fortnight. Kpler shows 2.9M barrels transited Oct 11 (lowest month). AIS hormuz.now Oct 14: only 4 AIS-visible transits (2 inbound, 2 outbound, 3 tankers, vs 85 normal daily). Iran expands surveillance/naval presence. IRGC targets "unauthorized" routes. US blockade persists. Iranian crude exports zero September (first time since war). Threat rating severe/restricted. SAUDI PRODUCTION RECOVERY: Saudi reported OPEC Sept output 8.372M bpl, up 2.13-2.134M from Aug (6.238M), highest since war began (late Feb 2026), recovery from 3-decade low. OPEC+ Sept 39.07M bpd, up ~900k from Aug. Overall down 3.69M bpd or 9% pre-war. Saudi Aramco ramping loadings Gulf terminals (exports partial recovery). OPEC+ Nov quotas unchanged (maintain Sept levels). OPEC DEMAND REVISION: 2026 global demand growth cut to 180k bpd (major cut from 1.4M earlier, 71% reduction). 2027 demand raised 2.55M bpd (pent-up demand materialization). Rationale: weak 2026 demand, inventory rebuild needed. GEOPOLITICAL: US-Iran conflict 7-8 months ongoing since late Feb 2026. Trump stated no major US attacks Iran before Nov 3 midterms, "productive talks." Iran/IRGC warn post-election escalation risks. Iran uses Hormuz leverage. Inventories drawing, amplifying supply concerns. Brent persistently >$100 (recently $104-105+) geopolitical premium despite recovery. Houthi attacks Saudi facilities. NATURAL GAS: Henry Hub ~$3.187/MMBtu close, down 2.56-3.23% from Oct 13 settlement ($3.283). Intraday range ~$3.166-$3.334. NYMEX Nov ~$3.17-$3.20. Oct YTD avg ~$3.141 (range $2.967-$3.220). 52-week low $2.523 (Apr 2026), high $7.460 (Jan 2026). CONTEXT: Storage building Oct forecast 328 Bcf, end-Oct ~3,850 Bcf (2% above 5-yr avg). Heating mild HDD ~3,150 (3% below 10-yr avg). Production strong ~112.2 Bcf/d, LNG exports ~17.6-18 Bcf/d. POSITIONING: OIL: WTI near $95 consolidating above $90 uptrend, triangle breakout now materializing (testing $94-95). Resistance $96-97.41. Fundamental: Strait escalation supporting, Saudi recovery suggesting resilience, OPEC demand revision (down 2026/up 2027) moderating ahead. Inventory draws Q4/tightening Q1 2027. Tactical short-covering near $95 resistance. Longer positioning (accumulate $85-88) for upside targeting $105+. Caution midterm volatility (Nov 3). SL discipline essential. GAS: Henry Hub near $3 consolidating. Oct dip $3.18 support test. Oscillators oversold (RSI 40-55), bounce risk. Fundamental: Storage ample build, heating mild HDD 3,150 (3% below), production strong 112.2 Bcf/d, LNG 17.6-18 Bcf/d. Tactical short bias (sell $3.30 target $3). Longer downtrend Jan $7.72 peak YTD -13% intact. Winter mild keeps downside. Bounce risk $3.20-30 oversold, no conviction rally above Dec $3.51 without supply shock (weather flip/arctic outbreak). SUMMARY: WTI surged $91.85→$95.05 (+$3.20, +3.5% week). Strait escalation 15+ attacks, flows collapsed 2.9M (lowest month), 4 AIS transits (vs 85 normal). Iran surveillance/blockade (zero exports Sept). Saudi 8.372M bpd (+2.13M recovery). OPEC+ 39.07M down 9% pre-war. OPEC 2026 demand forecast slashed 180k bpd, 2027 raised 2.55M. Geopolitical premium intact. Henry Hub -3% to $3.187, consolidating oversold. Storage ample, heating mild YTD -13% longer downtrend. Oil volatility geopolitical midterms (Nov 3). Gas neutral consolidation winter mild. | 3m 44s | ||||||
| 10/13/26 | Technicals: Week 41 | Tuesday, October 13, 2026. CRUDE OIL TECHNICALS. WTI Oct 12-13: Range $91.30-$93.68 (intraday ~2% volatility), close ~$91.85. SUPPORT: $90 (critical uptrend/psychological), $88.77-$88.75, $86.30-$86.89, ~$85. RESISTANCE: $91.18-$93.61 (immediate testing), $93.54-$95, $96-$97.41. PATTERNS: Triangle compression near $91.40, breakout potential higher. Short-term mixed-downtrend (sellers at resistance), broader uptrend intact. Elliott Wave bullish structure above $86.20 targeting $105+. MA: Bullish (price above 5/10/20/50/100/200-day). RSI: 53-70 neutral-overbought, buys present. MACD: Positive/Buy. Stochastic/Williams %R: Overbought spots, reversal risk if extended. Overall: Strong buy/neutral bullish pressure. FUNDAMENTALS: Gulf of Mexico hurricane supply impacts persisting (hundreds rigs offline, partial recovery). Strait of Hormuz AIS transits ~9/day vs 85 pre-crisis (geopolitical risk premium intact). Refinery crude inputs rose to ~16.5M bbl/d (92.7% utilization, up 223k bpd). SETUP: Short bias sell near $91-$93 targeting lower supports, SL $92+. Long bias buy breaks above resistance or holds above $90 uptrend, target $105+ if support holds, SL below $85. Volatility from overnight/tanker attacks/US-Iran/US midterms (Nov 13). NATURAL GAS TECHNICALS. Henry Hub Oct 12: Spot ~$3.145/MMBtu (intraday ~$3.16-$3.20 range). NYMEX Nov 2026 contract ~$3.17-$3.20. SUPPORT: $3.00 (key round), $2.90-$2.95, $2.80, ~$2.60 (Apr 2026 low). RESISTANCE: $3.20-$3.30, $3.40-$3.50, ~$3.90 (Dec 2026 futures). FUTURES CURVE: Oct spot ~$3.15, Nov ~$3.17-$3.20, Dec ~$3.51, Winter strip ~$3.39 (slight contango, modest winter premium). TREND: Consolidation at $3 level neutral. Longer-term downtrend from Jan peak $7.72 intact, YTD down ~13%. MA: Mixed (above 5/10-day, testing 20/50-day). Intermediate weakness, support holding, momentum waning. RSI: 40-55 neutral-slightly oversold. MACD: Flattening-slightly negative. Stochastic: Oversold spots, bounce risk. Overall: Neutral-slightly bearish, bounce potential. FUNDAMENTALS: Storage build continuing. Oct forecast ~328 Bcf build. End-Oct storage ~3,850 Bcf (2% above 5-yr avg). Heating mild: HDD forecast ~3,150 (3% below 10-yr avg), low heating demand. Production strong: US dry gas ~112.2 Bcf/d, LNG exports ~17.6-18 Bcf/d. SETUP: Short bias sell near $3.30 targeting $3, SL $3.50. Long bias buy bounces $2.90-$3.00 on oversold, target $3.30, SL $2.80. Volatility low, mild winter reduces seasonal spike. WEEK 41 SUMMARY: WTI $91.85 (Oct 12), support $90 critical/$88.75/$86.30, resistance $91.18-$93.61/$93.54-$95/$96-$97.41. Triangle compression near $91.40, upside breakout potential. Short-term mixed, broader uptrend intact. Elliott bullish $86.20+ target $105+. MA bullish, RSI 53-70 overbought spots, MACD positive, oscillators overbought (reversal risk extended). Strong buy/neutral. Gulf supply impacts, Strait risk premium. Henry Hub $3.145, support $3/$2.90-$2.95/$2.80, resistance $3.20-$3.30/$3.40-$3.50. Consolidation neutral, longer-term downtrend Jan $7.72 peak YTD -13% intact. MA mixed, RSI 40-55 oversold, MACD negative, stochastic oversold (bounce risk). Neutral-slightly bearish. Storage building 328 Bcf Oct, ~3,850 Bcf end-Oct (2% above avg). Heating mild HDD ~3,150. Production strong 112.2 Bcf/d, LNG 17.6-18 Bcf/d. Oil supported Gulf supply/geopolitical risk, gas weak mild weather/ample storage. Watch Strait Hormuz oil support/breakout. Monitor US midterms Nov 13 crude premium risk. Winter weather Dec key gas upside. No peak demand Q4 forecast. | 3m 37s | ||||||
| 10/12/26 | Strategic Positioning: Week 41 | Monday, October 12, 2026. CRUDE OIL UPDATE. WTI trading mid-ninety range consolidating near $92.41/bbl (Oct 11 intraday $91.89-$92.48). Month-to-date up $3-4 from early Oct lows near $88. YTD up ~47-50%. Support $88-$89, resistance $94-$95. Brent elevated $104-$105/bbl (bullish consolidation). Support $103, resistance $106-$107. YTD up ~50-52%. WTI-Brent spread $12-$13 (maritime risk premium). HORMUZ CRISIS: Day 226 (Feb 28 start). Throughput ~1% normal (~1 vessel/day vs 85 typical). War-risk insurance 40x pre-crisis (~$10M per VLCC). Tanker backlog increasing. Shipping severely disrupted. OPEC PRODUCTION: Oct quotas unchanged. OPEC-7 target 31.01M bpd (Saudi 10.478M bpd). Sept actual ~30.24M bpd (4.21M bpd deficit). Saudi actual ~8.55M bpd (highest since war Argus). Iran ~1.95M bpd (declining). 2B barrels lost first 7 months (~5M bpd deficit). OPEC policy: Unchanged quotas, monthly reviews continuing. Actual output hamstrung by Hormuz closure/infrastructure damage. EIA OUTLOOK: Brent forecast 2026 avg ~$96/bbl, Q4 ~$105/bbl (updated upward). WTI discount $10-14/bbl. Analyst consensus $89 Brent/$84 WTI full-year (up from prior). NATURAL GAS: Henry Hub spot ~$2.90-$3.05/MMBtu (Oct 6 $3.03, Sept 30 $3.02). Nov futures ~$3.20-$3.22/MMBtu. Sept avg $2.95/MMBtu. YTD avg $3.48/MMBtu. Stable mid-$3 range. WEEK 41 POSITIONING: WTI $92 consolidation (critical $88-$89, resistance $94-$95). Brent $104-$105 bullish consolidation. Spread $12-$13 maritime premium. Henry Hub steady mid-$3. Risk-off sentiment Hormuz persistent. OPEC unchanged. Capital preservation paramount. Data-driven positioning. Geopolitical hedges essential. Trade data not headlines. | 2m 32s | ||||||
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| 10/11/26 | 2026 Year-in-Review and Q4 2026 Outlook | 2026 YEAR-IN-REVIEW AND Q4 2026 OUTLOOK. CRUDE OIL: WTI 2026 YTD average $84.01/bbl (range $55.99-$112.95), up 68% from Jan start (~$57 to ~$96 Sep). Q1 ~$72.13, Q2 ~$95.76, Q3 ~$86.94. vs 2025 avg $64.94 (up $29/bbl, +45%). Brent 2026 YTD $93.81/bbl (range $61-$138), up 84% from Jan (~$62 to ~$114 Sep). Q1 ~$66.60, Q2 ~$117.30, Q3 ~$92.40. vs 2025 avg $69.14 (up $24.87, +36%). Recent Oct: WTI ~$91.85, Brent ~$125.44. NATURAL GAS: Henry Hub 2026 YTD average $3.48/MMBtu. Monthly range Jan $4.144, Feb $3.148, Mar $3.036, Apr $2.683, May $2.938, Jun $3.206, Jul $2.963, Aug $2.766, Sep $2.954. Q1 ~$3.45, Q2 ~$2.94, Q3 ~$2.90. vs 2025 avg ~$3.52 (relatively flat YoY). Recent Oct ~$3.03. CRUDE PRODUCTION: US 2026 proj 13.9M bbl/d (2025 actual 13.7). Global 2026 proj 101.1M bbl/d (2025 actual 106.3, major decline Strait disruptions). OPEC 2026 proj 23.9M, non-OPEC 77.2M. Nov 2026 quotas unchanged (Saudi 10.478M, Russia 9.949M, Iraq 4.431M, Kuwait 2.676M, Kazakhstan 1.628M, Algeria 1.007M, Oman 0.841M). Q4 assumes ~4.5M bbl/d shut-ins, Brent $105 avg. STRAIT OF HORMUZ 2026 CRISIS: Pre-crisis baseline ~17-21M bbl/d crude/refined products. Current ~80-85% (late Sep), dropping 40-80% (early Oct). AIS transits ~1-10% normal (~85/day pre-crisis, now single-digit). Cumulative loss 2B barrels first 7 months. Peak disruption 14% global combined oil/gas supply. Largest modern disruption (2x 1970s shocks, 6x Russia-Ukraine). Tanker attacks surge Sep/Oct (9-12+ incidents/week). War-risk ~30x pre-crisis. Buffers (Saudi/UAE bypass pipelines 3.5-5.5M bpl usable, inventory/demand compression) containing gap. NATURAL GAS 2026: US consumption proj 92.37 Bcf/d. Production proj 112.20 Bcf/d. LNG exports ~17.6-18 Bcf/d. Storage Oct 30-forecast ~3,850 Bcf (2% above 5-yr avg), build ~328 Bcf Oct. INVENTORY: US crude commercial (ex-SPR) late Sep 427.3M bbl (2% above 5-yr avg). SPR historic low 284.6M bbl (down 30% YoY, lowest since late 1982). Gasoline 6-7% below avg, distillate 12-14% below avg. Q4 2026 & 2027 FORECASTS: Brent 2026 annual avg $96/bbl (EIA, raised from $91), Q4 $105 (raised $14 due ME constraints, shut-ins, draws, diesel tightness). 2027 avg $84. WTI 2026 ~$88, 2027 ~$80. Global inventory Q3 draw 1.9M bpl, Q4 draw 0.7M bpd, 2027 builds. Henry Hub 2026 annual avg $3.48/MMBtu, 2027 avg $3.16 (down 9%, ~$0.32 lower). Jan 2027 no spike (vs Jan 2026 storm spike $7.72). 2027 monthly range low ~$2.60 (Apr/May) to high ~$3.90 (Dec). US dry gas prod 2026 proj 112.20 Bcf/d, 2027 proj 116.13. LNG exports 2026 ~17.6-18 Bcf/d, 2027 ~18.6-19. HEATING SEASON 2026-27: Residential heating consumption flat nationally vs prior winter. HDD ~3,150 (3% below 10-yr avg), slightly warmer normal. Q4 weather milder than avg (Nov-Dec ~1,430 HDD, slightly below avg). Heating expenditures ~9% lower than prior winter (lower prices + weather), Northeast down 14%. GEOPOLITICAL: US-Iran conflict ongoing since Feb 28, 2026 (7-8 months Oct 2026). Shut-ins avg several M bpd, peak 5-10+ M bpd. Key variables: US/Israeli strikes potential, proxy actions, full Hormuz blockage (+$4/bbl per M lost, prices could spike $100-150 severe). US midterms Nov 2026. Diplomacy fragile/stalled. Scenarios: gradual normalization (prices $70-90), prolonged standoff/escalation (elevated/spike further), knock-on global inflation/growth. SUMMARY: WTI 2026 YTD $84.01 (up 68%), Brent $93.81 (up 84%). Q4 Brent EIA $105, 2027 $84 Brent/$80 WTI. Henry Hub $3.48 YTD, 2027 $3.16 (down 9%). US prod 13.9M bpd, global 101.1M (Strait impact). OPEC Nov quotas unchanged (supply tight). Strait Day 247 crisis, flows 80-85% late Sep dropping 40-80% early Oct, 2B barrels lost 7 months, 14% global disruption peak. US crude 427M bbl (2% above avg), SPR historic low 284M (30% down YoY). Q4 Brent $105 EIA, WTI $88. Gas $3.48 avg, 2027 $3.16 down. Heating mild. LNG rising. Geopolitical elevated. Recovery 2027 supports price declines. ME constraint Q4 key risk. Winter mild/low heating. No peak demand. Supply resilience/buffers contain volatility. Downside if escalation eases, upside if tensions rise. Data-driven: fundamentals support 2027 moderation. | 4m 56s | ||||||
| 10/9/26 | Geographic Feature: Turkey | Friday, October 9, 2026. TURKEY ENERGY OVERVIEW. Strategic hub, modest domestic oil/gas, rapidly expanding LNG, multiple pipelines, self-sufficiency policy. NATURAL GAS PRODUCTION: Jul 2026 ~128.34M cubic meters monthly (down). Sakarya Black Sea ~109M cubic meters (84.6% onshore), TPAO ~96.5%. Declining (maturing fields, maintenance). NATURAL GAS IMPORTS: Jul ~3.063B cubic meters. Pipeline ~2.869B (Azerbaijan 1.001-1.011B TANAP/BTE, Russia ~948M TurkStream/Blue Stream, Iran ~919M). LNG ~194M (Algeria). Consumption ~2.648B (industrial ~1.114B, power ~770M, residential ~376M). Exports ~197.61M (Syria ~145.4M, Bulgaria ~49.1M). Storage ~5.638B (~5.413B underground, ~225M LNG). LIQUIFIED NATURAL GAS: ~10 contracts (BP 1.6 bcm/yr, Cheniere 1.2 bcm, Shell 0.8 bcm, Mercuria 4 bcm, Equinor, JERA, others). Jan-May 2026 ~6.9M metric tons. Forecasts 2026 ~16.6 bcm, 2027 ~17.95 bcm, 2028 ~18.88 bcm. Diversification, hub ambitions, re-exports Central/E Europe/Balkans. PIPELINES: Russia ~21.75 bcm/yr (renewed), Iran ~10 bcm/yr (renewal negotiating), Turkmenistan 2026 resume, Azerbaijan TANAP/BTE (ongoing). MEDITERRANEAN: 2 FSRUs (Dörtyol double capacity, Gazipasha-Anamur). Target ~200M cubic meters/day seaborne 2 years. Existing Marmara, Aliağa, FSRUs Dörtyol/Saros. TURKEY-TRNC PIPELINE: ~101 km (~97 km offshore, Anamur-Teknecik). Oruc Reis survey early Oct. MOU Jul. 2028 target. ~3.1 bcm/yr capacity. CRUDE OIL: Jun 2026 ~127K bbl/d (stable), TPAO combined ~350K boe/d, target 550-600K by 2028. SAKARYA BLACK SEA: Phase 1 ~9.5M cubic meters/d (operational), Phase 2 Osman Gazi late 2026 target ~20M cubic meters/d, total reserves ~92.4B cubic meters. TRANSIT: Iraq oil avg 2.65M bpd, ~250K bpd via Ceyhan. BOTAŞ LNG charter 940 days. IMPORT COSTS: Aug 2026 ~$6.46B (up 33.8% YoY). Diversifying U.S. LNG. POLICY: Non-discriminatory (Russia/Azerbaijan/Turkmenistan/U.S./Algeria). SUMMARY: Hub. Crude ~127K bbl/d, TPAO 350K boe/d, target 550-600K by 2028. Sakarya Phase 1 9.5M, Phase 2 late 2026 ~20M, reserves 92.4B. Gas production 128.34M (Jul, declining), Sakarya 109M. Imports 3.063B (pipeline 2.869B, LNG 194M). Consumption 2.648B. Exports 197.61M. Storage 5.638B. LNG 10 contracts, forecasts 2026 16.6 bcm, 2028 18.88 bcm. Pipelines Russia 21.75 bcm (renewed), Iran 10 bcm (renewal). Mediterranean 2 FSRUs, target 200M cubic meters/d. Turkey-TRNC 3.1 bcm/yr. Iraq transit 250K bpd. Imports Aug $6.46B. Import-dependent, LNG expansion, hub development, Sakarya growth, self-sufficiency 2028. | 2m 29s | ||||||
| 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 | ||||||
| 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 | ||||||
| 9/11/26 | 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.