Energy Markets Daily

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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 intelligence, and the geopolitical developments that drive billion-dollar energy decisions. Providing superior energy market intelligence sourced from the same trading floors, boardrooms, and energy desks where your competition operates. Essential listening for oil & gas executives, energy investors, and institutional capital allocating $100M+ in the energy sector. Contact: energymarkets@protonmail.com Disclaimer: This podcast is powered by Daily Dominance and utilizes artificial intelligence technology for content creation and production. The views and opinions expressed in this show are those of the hosts and guests and do not necessarily reflect the official policy or position of Daily Dominance. All content is generated with the intent to provide informative and engaging material; however, the accuracy and reliability of the information presented may vary. Listeners are encouraged to conduct their own research and consult with professionals before making any decisions based on the content of this podcast. By listening to this podcast, you acknowledge and agree to these terms.

  1. 2d ago

    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.

  2. 3d ago

    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.

  3. 4d ago

    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.

  4. 5d ago

    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.

  5. 6d ago

    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.

  6. Oct 11

    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.

  7. Oct 9

    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.

  8. Oct 8

    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.

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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 intelligence, and the geopolitical developments that drive billion-dollar energy decisions. Providing superior energy market intelligence sourced from the same trading floors, boardrooms, and energy desks where your competition operates. Essential listening for oil & gas executives, energy investors, and institutional capital allocating $100M+ in the energy sector. Contact: energymarkets@protonmail.com Disclaimer: This podcast is powered by Daily Dominance and utilizes artificial intelligence technology for content creation and production. The views and opinions expressed in this show are those of the hosts and guests and do not necessarily reflect the official policy or position of Daily Dominance. All content is generated with the intent to provide informative and engaging material; however, the accuracy and reliability of the information presented may vary. Listeners are encouraged to conduct their own research and consult with professionals before making any decisions based on the content of this podcast. By listening to this podcast, you acknowledge and agree to these terms.

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  • Creator
    EMD
  • Years Active
    2025 - 2026
  • Episodes
    286
  • Rating
    Clean
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    © 2026 EMD

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