Tuesday, August 25, 2026. CRUDE OIL TECHNICALS: Current price context Latest ~$85.62 (down ~1.65% on day); intraday range ~$84.71-$86.56; Aug 24 reference/closing levels around $85.23. RSI(14) 46.691 — Neutral (neither overbought >70 nor oversold <30). MACD(12,26) -0.25 — Sell signal (negative, indicating bearish momentum). MA5 (Simple) $85.41 — Buy. MA5 (Exponential) $85.47 — Buy. MA10 (Simple) $85.41 — Buy. MA10 (Exponential) $85.53 — Buy. MA20 (Simple) $85.83 — Sell. MA20 (Exponential) $85.71 — Sell. MA50 (Simple) $86.25 — Sell. MA50 (Exponential) $85.83 — Sell. MA100 (Simple) $85.45 — Buy. MA100 (Exponential) $85.31 — Buy. MA200 (Simple) $83.95 — Buy. MA200 (Exponential) $84.08 — Buy. Overall summary Mixed/neutral bias — Moving averages lean Buy (8 buy vs. 4 sell), while technical indicators lean Sell/neutral (mixed oscillator signals). Recent context Day of downside pressure; recent closes/levels around $84.8-$86 range. NATURAL GAS TECHNICALS: Current price context Trading near $2.76-$2.81/MMBtu amid well-supplied market and seasonal shoulder-period dynamics. Key Support Levels: $2.50 Major/multiyear structural support; tested multiple times without sustained break; aligns with longer-term lows and analyst targets for September contract. $2.56-$2.563 Lower 20-day Bollinger Band area (noted in July 2026 analysis for September contract; relevant near rollover). $2.68-$2.70s Near-term range lows and technical thresholds. $2.71-$2.74 Recent intraday lows and pivot-derived supports (e.g., Classic S3 around 2.74-2.746). $2.756-$2.761 Classic/Fibonacci pivot supports (S2/S1 levels from recent technical summaries). $2.763-$2.77 Camarilla/near-term daily supports and moving average clusters. Key Resistance Levels: $2.78-$2.79 Immediate pivot R1/R2 and recent highs in $2.70s-$2.80s consolidation zone. $2.99-$3.00 Initial/strong resistance (middle Bollinger Band area); psychological round-number level and noted ceiling for near-term contracts. $3.14-$3.35 Broader resistance zone tied to moving averages, forecasts, and prior trading ranges. $3.44-$3.50 Higher structural/psychological resistance; aligns with some longer-term forecasts and round numbers. Additional Context: Pivot points Recent Investing.com data for Micro/Natural Gas futures cluster tightly around 2.75-2.78, reflecting current low-volatility range. Range-bound theme Much of recent action confined between roughly $2.60-$2.80, with oversold momentum indicators suggesting limited follow-through on breakdowns. Psychological/round-number levels $2.00, $2.50, $3.00, $3.50 often act as magnets or barriers in NG trading. Technical bias Leaned neutral-to-bearish short-term due to supply but with potential upside from demand or momentum shifts. EIA PETROLEUM STATUS REPORT (Week Ending Aug 14, Released Aug 19): U.S. commercial crude oil inventories (excluding SPR) Rose by 4.4 million barrels week-over-week to 428.8 million barrels. Five-year average comparison This inventory level matches five-year average for time of year. Crude oil refinery inputs Averaged 17.4 million barrels per day (up 215,000 bpd from prior week), with refineries operating at ~97.2% of operable capacity. Total commercial petroleum inventories Increased by 8.8 million barrels. Motor gasoline inventories Rose by 0.7 million barrels and stood 5% below five-year average. Distillate fuel inventories Fell by 1.5 million barrels and were about 13% below five-year average. Propane/propylene inventories Increased by 2.0 million barrels and were 31% above five-year average. U.S. crude oil imports Averaged 6.6 million barrels per day (down 746,000 bpd from prior week). WTI crude oil spot price (Cushing) $83.99 per barrel. Motor gasoline supplied (4-week average) 8.9 million barrels per day (down 0.9% year-over-year). Distillate supplied (4-week average) 3.7 million barrels per day (down 0.8% y/y). Next report For week ending Aug 21, scheduled for release Aug 26, 2026. THE READ: Crude technicals Latest $85.62, down 1.65% on day, intraday range $84.71-$86.56, Aug 24 reference/closing $85.23; RSI 14 46.691 neutral, neither overbought nor oversold; MACD 12/26 -0.25 sell signal, negative, bearish momentum; MA5 simple $85.41 buy, exponential $85.47 buy; MA10 simple $85.41 buy, exponential $85.53 buy; MA20 simple $85.83 sell, exponential $85.71 sell; MA50 simple $86.25 sell, exponential $85.83 sell; MA100 simple $85.45 buy, exponential $85.31 buy; MA200 simple $83.95 buy, exponential $84.08 buy; overall mixed/neutral bias, moving averages lean buy 8 vs. 4 sell, technical indicators lean sell/neutral, mixed oscillator signals; day downside pressure, recent closes/levels $84.8-$86. Gas technicals Trading $2.76-$2.81/MMBtu, well-supplied market, seasonal shoulder-period dynamics; support $2.50 major/multiyear structural, tested multiple times without sustained break, longer-term lows and analyst targets September contract; $2.56-$2.563 lower 20-day Bollinger Band, July 2026 analysis September contract, re...

Monday, August 24, 2026. WEEK 34 OPENS. CRUDE OIL UPDATE: WTI at $85.42-$85.66 as of Aug 24 (intraday or close); one live update $84.97 spot with range $84.89-$86.15. Aug 21 futures close ~$87.06; spot/futures references ~$86.34-$86.76 (one source lists $86.66-$86.76). Aug 20 futures close ~$86.83; other references ~$85.97-$87.83. Aug 23 ~$85.79-$86.02 (daily range examples: low ~$85.78, high ~$86.14 or $86.56). Aug 19 ~$84.08-$84.39. Aug 18 ~$84.06-$84.38. Aug 17 ~$84.01-$84.50. Aug 14 ~$81.53-$82.40. GuruFocus oil price (WTI futures proxy) on/around Aug 21 $86.76 (down ~1.22% from prior day). YCharts WTI spot (Aug 20) $89.75 (noted as potentially higher/outlier vs. other benchmarks). Twelve Data WTI/USD (Aug 24 close example) ~$84.97. FRED/EIA WTI spot references (weekly/daily, e.g., around mid-August) ~$83.99-$86.48. Broader trend Prices notably higher than year-ago levels (~+35% YoY in some reports). General trend Futures closes tended to be in high $86s earlier in period before easing; spot prices often bit lower. NATURAL GAS UPDATE: Aug 18 (latest available daily spot) $2.82. Aug 17 $2.77. Aug 14 $2.79. Aug 13 $2.82. Aug 12 $2.82. CME Henry Hub Natural Gas futures (e.g., prompt-month contracts) around Aug 21-23, 2026 Settlements or last prices in ~$2.75-$2.76 range, with modest daily changes. Broader 2026 forecasts (EIA STEO) Project annual average around $3.44/MMBtu, with Q3 2026 averaging near $2.87. Note EIA releases daily spot price data with lag (typically updated mid-week for prior period); next release expected around Aug 26; no trading on weekends. STRAIT OF HORMUZ SHIPPING: Aug 21 US officials reported ~40 oil tankers carrying ~16 million barrels of crude transited southern channel. Aug 21-22 overnight Windward intelligence noted 9 vessels transited southern corridor "dark" (7 inbound, 2 outbound)—largest single-night count on record at time. Aug 21 Windward recorded 5 vessels transiting (including Panama-flagged product tanker, sanctioned LPG carrier, others; mix of AIS-visible and dark). Aug 22 One analysis contrasted ~36 vessels (per broader or prior-day data) with sharp drop next day. Aug 23 Commercial AIS data showed only 7 total vessels entering or exiting (4 inbound, 3 outbound), with no dedicated oil tankers among them—mostly general cargo, bulk carriers, tugs, Iranian "other" vessels (specific examples RAMA 3, AL WATHBA, AL DAHABI, smaller Iranian craft). Broader early-to-mid August context (Aug 1-19) 236 total ships transited (~12 per day vs. ~130 pre-war norm); 112 were oil/gas tankers, with most using unconfirmed/dark routes. US military "stealth" operations (ongoing into August) Reportedly enabled 15-20 tankers per night via southern channel in recent weeks, supporting millions of barrels oil movement despite restrictions. Overall August trend Volumes remained low (e.g., month-to-date averages around 12 or fewer commodity vessels/day per Kpler; further drops noted mid-month due to tensions). Live trackers (as of ~Aug 23-24) Some dashboards showed strait effectively closed or at 0.4-1.7% of normal throughput (e.g., 1 ship or minimal DWT in 24h periods), with heavy reliance on facilitated or dark movements. Persistent factors High war-risk insurance, attacks/incidents, Iranian threats, competing US/Iran claims over control continued to suppress open commercial tanker traffic. Pre-crisis baseline Roughly 60-140 vessels per day. THE READ: Crude WTI $85.42-$85.66 Aug 24, intraday or close, live update $84.97 spot, range $84.89-$86.15; Aug 21 futures close $87.06, spot/futures $86.34-$86.76; Aug 20 futures $86.83, references $85.97-$87.83; Aug 23 $85.79-$86.02, low $85.78, high $86.14 or $86.56; Aug 19 $84.08-$84.39; Aug 18 $84.06-$84.38; Aug 17 $84.01-$84.50; Aug 14 $81.53-$82.40; GuruFocus $86.76 down 1.22%; YCharts $89.75 potentially higher/outlier; Twelve Data $84.97; FRED EIA $83.99-$86.48; notably higher year-ago, +35% YoY; futures high $86s earlier, easing, spot often lower. Gas Aug 18 $2.82, Aug 17 $2.77, Aug 14 $2.79, Aug 13 $2.82, Aug 12 $2.82; CME Henry Hub futures Aug 21-23 $2.75-$2.76, modest daily changes; EIA STEO annual average $3.44/MMBtu, Q3 2026 near $2.87; EIA releases daily spot data with lag, typically mid-week, next around Aug 26, no weekend trading. Hormuz Aug 21 US officials 40 oil tankers, 16M barrels crude, southern channel; Aug 21-22 overnight Windward 9 vessels southern corridor dark, 7 inbound 2 outbound, largest single-night record; Aug 21 Windward 5 vessels, Panama-flagged product tanker, sanctioned LPG carrier, others, AIS-visible and dark; Aug 22 36 vessels prior-day data, sharp drop next day; Aug 23 commercial AIS 7 total vessels, 4 inbound 3 outbound, no dedicated oil tankers, general cargo bulk carriers tugs Iranian other, RAMA 3, AL WATHBA, AL DAHABI, smaller Iranian; Aug 1-19 236 total ships, 12 per day vs. 130 pre-war, 112 oil/gas tankers, unconfirmed/dark routes; US military stealth operations 15-20 tankers per night southern channel recent w...

Friday, August 21, 2026. SRI LANKA ENERGY PROFILE: Sri Lanka is actively advancing oil and gas exploration (primarily in Mannar Basin) while pursuing critical minerals development (notably graphite and mineral sands) and renewable energy goals, with 2025-2026 marking renewed licensing and investment efforts. MANNAR BASIN OIL/GAS LICENSING: Licensing round (Sri Lanka plans to invite international bids in August 2026 for upstream petroleum development, exploration and extraction of gas and oil, in four blocks of Mannar Basin). Past discoveries and reserves (Cairn Lanka, Indian subsidiary, drilled wells in 2011 confirming natural gas in Barracuda and Dorado fields in Mannar Basin; overall offshore basins—Mannar, Cauvery, Lanka—hold petroleum potential estimated at ~$250-267 billion). Licensing process updates (2025) (in mid-2025, Cabinet approved selection of marketing consultant for new Mannar Basin licensing round; PDASL closed its RFP in September 2025, with plans to launch EOIs once consultant selected). Natural gas confirmation (natural gas confirmed in Mannar Basin, with estimates around 350 billion cubic feet cited in some reports; CPC preparing to call for investors). REFINERY MODERNIZATION: Sapugaskanda refinery (Sri Lanka's refinery, operated by CPC, undergoing expansion plans via BOT to increase capacity from ~50,000 to 100,000 barrels per day; EOIs invited in 2025 with shortlisted companies). RENEWABLES TARGETS: Energy goals (government aims for 70% of energy requirements from renewable sources by 2030, alongside broader energy transition efforts). CRITICAL MINERALS POLICY: National minerals policy (Sri Lanka approved its first national minerals policy since 1999 in February 2026, supporting mining development). Graphite investment call (2026) (official calls for investment in integrated mine development and value-added graphite projects, e.g., at Kahatagaha, targeting graphene, advanced carbon materials, and lithium-ion battery components under 30-year frameworks). Mineral sands project (Capital Metals Taprobane) (high-grade project advancing with two mining licenses secured; construction targeted for Q4 2026, pending final approvals, low capex, strong projected IRR). Critical minerals focus (Sri Lanka's resources include graphite, phosphorus, titanium, and zirconium relevant to clean energy/battery tech; limited public emphasis on lithium deposits specifically). OFFSHORE ENERGY INVESTOR INTEREST: Basin modelling (recent basin modelling and studies attracting renewed investor conversations for Sri Lanka's offshore potential as of early 2026). ENERGY MIX CONTEXT: Primary energy supply (relies heavily on coal and imports, with ~23% from modern renewables; efforts ongoing to diversify including via domestic fossil resources). EXPLORATION HISTORY: Timeline (exploration dates to 1960s; past progress stalled due to costs and instability, but renewed push in 2025-2026). MARKET REPORTS: 2026 analyses (dedicated 2026 Sri Lanka oil & gas market analyses cover field output, LNG/refinery profiles, and competitive landscape). BROADER CRITICAL MINERALS OUTLOOK: Global context (global reports, e.g., IEA 2026, note volatility in lithium and other battery metals, but Sri Lanka-specific activity centers more on graphite and mineral sands than lithium mining). THE READ: Sri Lanka actively advancing oil and gas exploration, Mannar Basin, critical minerals development, graphite and mineral sands, renewable energy goals, 2025-2026 renewed licensing and investment efforts; Mannar Basin licensing round, international bids August 2026, upstream petroleum development, exploration and extraction gas and oil, four blocks Mannar Basin; Cairn Lanka, Indian subsidiary, drilled wells 2011, natural gas confirmed, Barracuda and Dorado fields, Mannar Basin; offshore basins Mannar, Cauvery, Lanka, petroleum potential ~$250-267 billion; mid-2025 Cabinet approved marketing consultant selection, new Mannar Basin licensing round; PDASL closed RFP September 2025, plans launch EOIs consultant selected; natural gas confirmed Mannar Basin, estimates 350 billion cubic feet, CPC preparing call investors; Sapugaskanda refinery, operated CPC, expansion plans BOT, capacity 50,000 to 100,000 barrels per day, EOIs invited 2025, shortlisted companies; government aims 70% energy requirements renewable sources 2030, broader energy transition efforts; first national minerals policy since 1999 February 2026, supporting mining development; official calls investment integrated mine development, value-added graphite projects, Kahatagaha, graphene, advanced carbon materials, lithium-ion battery components, 30-year frameworks; Capital Metals Taprobane, high-grade project, two mining licenses secured, construction Q4 2026, pending final approvals, low capex, strong projected IRR; graphite, phosphorus, titanium, zirconium, clean energy and battery tech, limited public emphasis lithium deposits specifically; recent basin modelling and studies, renewed inves...

Thursday, August 20, 2026. ARIZONA ENERGY PROFILE: Arizona has negligible oil and natural gas production, with no significant proved reserves and output that is minimal or often zero in recent monthly data. CRUDE OIL PRODUCTION: Production levels (EIA monthly data shows Arizona field production typically at 0-1 thousand barrels per month in 2024-2026; e.g., 2024 and 2025 mostly 0-1; early 2026: Jan/Feb/May 0, Mar/Apr 1; annual totals in low thousands of barrels or less). Historical context (main producing area is Dineh-bi-Keyah field, Apache County, on Navajo Nation land, produced ~19 million barrels total since 1967, peak output far higher than current levels, now around 12,000 barrels/year or less; other wells contribute minimally). NATURAL GAS: Production (data largely NA/withheld or indicates no meaningful production; Arizona is not a notable gas-producing state). RESERVES & GEOLOGY: Reserves (EIA and other sources state Arizona has no significant proved crude oil or natural gas reserves; geology in most of state not conducive to commercial hydrocarbons). LEASE ACTIVITY (2026): BLM proposed sale (BLM proposed December 2026 oil and gas lease sale covering ~40 parcels and 78,708 acres in northwest Arizona, near Grand Canyon-Parashant National Monument/Littlefield area; first such sale since 2018; scoping occurred in 2026, does not reflect current production). OVERALL RANKING & SCALE: National ranking (Arizona ranked ~30th nationally for crude oil in older data, e.g., 2014, but produces tiny fraction of U.S. totals; production almost entirely from tribal lands). Supporting context (EIA state profiles and historical series confirm minimal output; articles note reliance on imports, pipelines from CA/TX/NM for petroleum products, no refineries in-state). ENERGY PROFILE: Energy mix (emphasizes consumption: natural gas ~43-46% of electricity generation, plus nuclear and growing solar, rather than local fossil fuel extraction). No major production increases (no major production increases or new fields indicated for 2026 beyond potential lease sale). THE READ: Arizona negligible oil and natural gas production, no significant proved reserves, output minimal or often zero recent monthly data; EIA monthly data 0-1 thousand barrels per month 2024-2026, 2024 and 2025 mostly 0-1, early 2026 January/February/May 0, March/April 1, annual totals low thousands barrels or less; Dineh-bi-Keyah field, Apache County, Navajo Nation land, ~19 million barrels total since 1967, peak output far higher, now 12,000 barrels/year or less, other wells minimally; natural gas data NA/withheld or no meaningful production, not notable gas-producing state; no significant proved crude oil or natural gas reserves, geology most state not conducive commercial hydrocarbons; BLM proposed December 2026 oil and gas lease sale, ~40 parcels, 78,708 acres, northwest Arizona, Grand Canyon-Parashant National Monument, Littlefield area, first sale since 2018, scoping 2026, does not reflect current production; ranked ~30th nationally crude oil older data 2014, tiny fraction U.S. totals, production almost entirely tribal lands; EIA state profiles historical series confirm minimal output, articles reliance on imports, pipelines California/Texas/New Mexico petroleum products, no refineries in-state; emphasizes consumption, natural gas ~43-46% electricity generation, plus nuclear and growing solar, rather than local fossil fuel extraction; no major production increases or new fields indicated 2026 beyond potential lease sale. Capital preservation first. Trade the data, not the headlines.

Wednesday, August 19, 2026. URUGUAY ENERGY PROFILE: Uruguay has negligible domestic oil and natural gas production as of 2025-2026 and relies almost entirely on imports for fossil fuels. Exploratory drilling for offshore oil and gas is scheduled to begin in 2026, but commercial production is not expected in the near term (likely years away even with discoveries). CURRENT PRODUCTION: Oil production about 1,411.6 barrels per day of oil and petroleum liquids in 2025 (down 1.8% YoY), ranking #104 globally; essentially no crude oil production (0 bpd reported). No proven oil reserves (Worldometers and other trackers report no proven oil reserves for Uruguay). No natural gas production (Uruguay produces no natural gas domestically and has no proven reserves; imports via pipelines from Argentina). Oil consumption context (consumption declined to around 45,000-49,800 bpd recently, down from over 65,000 bpd in 2012, supported by strong renewables). OFFSHORE EXPLORATION RAMP-UP: Offshore blocks (ANCAP licensed seven offshore blocks; seismic acquisition started in 2025, exploratory drilling planned for 2026, first deepwater well in ~a decade by APA in H2 2026). Major companies involved (partners include Shell, QatarEnergy, Chevron, and APA; YPF Argentina expressed interest in nearby blocks). Geological potential (similarities to Namibia's discoveries; ANCAP estimates 3-23% probability of oil/gas in offshore areas, speculative potential up to 30 billion barrels). Exploration timeline (contracts cover all ~120,000 sq km of offshore acreage; drilling phase expected to last at least 4 years, possibly extendable). Investment and activity (over $200 million in commitments; first significant offshore test well in a decade set for 2026). ENERGY INDEPENDENCE HOPES: Strategic goal (successful discoveries could eventually meet domestic oil needs and enable exports, complementing Uruguay's renewable leadership: wind, solar, hydro). Natural gas exploration included (offshore blocks target both oil and gas; no near-term domestic production expected). REFINING & BROADER CONTEXT: Refining (La Teja refinery, only one in country, processes imported crude for domestic needs). Broader energy context (oil and gas sector underdeveloped; focus remains on renewables while testing offshore hydrocarbons). No 2026 production forecast (exploration phase means any commercial output would be post-2026 at earliest; current "production" figures reflect minor/non-crude liquids or statistical artifacts). Recent policy/activity (government authorized seismic projects in 2025; ongoing interest despite renewable focus). THE READ: Uruguay negligible domestic oil and natural gas production 2025-2026, relies almost entirely on imports, exploratory drilling scheduled 2026, commercial production not expected near term, years away even with discoveries; oil production 1,411.6 bpd 2025, down 1.8% YoY, ranking #104 globally, essentially no crude oil production, zero bpd; no proven oil reserves; no natural gas production domestically, no proven reserves, imports via pipelines from Argentina; oil consumption 45,000-49,800 bpd recently, down from 65,000+ 2012, strong renewables; ANCAP licensed seven offshore blocks, seismic acquisition started 2025, exploratory drilling planned 2026, first deepwater well ~a decade by APA H2 2026; partners Shell, QatarEnergy, Chevron, APA, YPF Argentina interested nearby blocks; similarities Namibia discoveries, ANCAP 3-23% probability oil/gas offshore, speculative potential 30 billion barrels; contracts ~120,000 sq km offshore acreage, drilling phase 4+ years; over $200 million commitments, first significant offshore test well a decade 2026; successful discoveries could meet domestic oil needs and enable exports, complementing renewable leadership, wind, solar, hydro; offshore blocks target oil and gas, no near-term domestic production; La Teja refinery, only one, imported crude domestic needs; oil and gas sector underdeveloped, focus renewables, testing offshore hydrocarbons; exploration phase post-2026 earliest, current production minor/non-crude liquids or statistical artifacts; government authorized seismic projects 2025, ongoing interest despite renewable focus. Capital preservation first. Trade the data, not the headlines.

Tuesday, August 18, 2026. CRUDE OIL TECHNICALS: Investing.com (Aug 18 update) Overall Strong Buy signal; moving averages showed 11 Buy vs. 1 Sell; technical indicators unanimously Strong Buy (8/0). Barchart (Aug 17 technical analysis for Sep '26) Price closed higher (~84.61, +2.21 or +2.68% intraday in one snapshot); 5-day average ~82.90; 20-day ~82.53, with positive momentum noted. Economies.com (Aug 17 analyses) Crude oil fluctuated but held early gains with positive support from trading above key levels; preparation to resume upward moves on strong technical support after minor intraday dips. OneUpTrader (Aug 17 analysis) WTI erased early-August declines and returned to recurring 82-83 pivot zone; key resistance at 83.04 (session high/pivot); support at 81.50 (session low) and faster MA near 78.75; bullish continuation possible above 83.04 toward 87-88. FXStreet (recent hourly/daily bias) Mildly bearish near-term bias below 100-hour SMA (~81.18) but holding above 200-hour SMA and $80 support; RSI neutral/slightly downside; resistances at ~81.94, 83.57, 84.50. LiteFinance (Aug 17-18 update) USCrude around $84.14 as of Aug 18; expected consolidation on Aug 18; weekly range outlook ~67.93-97.41. Barchart (Aug '26 contract snapshot) Buy signal with strong strength; key turning points included resistance near 86.39-89.94 and support at 82.84-80.77. CME Group / market data (Aug 17-18) WTI last ~84.85 (+0.35); September contract active with positive daily closes reported around 84-85. Oilprice.com / Yahoo Finance snapshots Sep 2026 futures ~84.50-85.14 range on Aug 17-18, with day ranges like 84.62-85.37 and modest positive closes. FX Empire / YouTube forecasts (mid-Aug context) Bullish signals from falling wedge breakouts earlier in month, targeting higher levels (e.g., $94 area) if supports like ~82.50 held; recent videos noted extensions of gains. Additional context Earlier August saw sharp moves (e.g., breakdown tests near $74-77), with recovery into 80s by mid-month. Overall tone Constructive/bullish on Aug 17-18, driven by price action reclaiming moving averages and pivots near 82-83; some noted near-term consolidation risks or overhead resistance; geopolitical factors (Hormuz/Middle East) referenced as potential drivers but secondary to chart levels; prices showed +2%+ daily gains on Aug 17 in multiple reports. NATURAL GAS TECHNICALS: Front-month contracts (NGQ26/Aug '26 or NGU26/Sep '26) Trading near $2.67-$2.73/MMBtu, with recent spot prices around $2.79. Shriram Insight pivots for Henry Hub Sep-26 contract (as of Aug 17, 2026; close 2.733) S3 2.628, S2 2.669, S1 2.701, Pivot 2.742, R1 2.774, R2 2.815, R3 2.847. Barchart key turning points for NGQ26 (Aug '26; last ~2.725) 3rd resistance 2.942, 2nd resistance 2.856, 1st resistance 2.791; 1st support 2.640, 2nd support 2.554, 3rd support 2.489. Multiyear lows Tested near $2.50-$2.56 (e.g., Bollinger Band support mentioned in July 2026 commentary). Broader range references Support near $2.65 and resistance in $3.30 area (medium-term views). Recent daily closes/levels Hovered around $2.67-$2.79, with volatility tied to storage, supply, and weather. EIA PETROLEUM STATUS REPORT (Week Ending Aug 7, Released Aug 12): U.S. commercial crude oil inventories (excluding SPR) Rose sharply by 17.4 million barrels in week ending Aug 7, 2026, reaching 424.4 million barrels. Prior week Smaller increase of 2.479 million barrels (week ending July 31), bringing stocks to approximately 407 million barrels. Five-year average comparison Crude oil inventories stood about 6% below five-year average for time of year. Refinery crude runs Averaged 17.2 million barrels per day in week ending Aug 7 (down 183,000 bpd from prior week), with operable capacity utilization at 96.5%. Total commercial petroleum inventories Increased by 11.6 million barrels in earlier comparable week. Gasoline inventories Rose modestly in recent weeks (e.g., +0.8 million barrels in one period) but remained ~7% below five-year average. Distillate inventories Mixed changes, with builds or draws of 1-3+ million barrels in recent weeks and levels ~10% below average. Cushing hub Crude stocks rose notably in prior weeks (e.g., +2.356 million barrels). Net U.S. crude imports Increased in recent reporting periods (e.g., +297,000 bpd in one week). SPR (Strategic Petroleum Reserve) Total holdings in ~300+ million barrel range across sites as of early Aug 2026, distinct from commercial inventories. Next report For week ending Aug 14, scheduled for release Aug 19, 2026. THE READ: Crude technicals Investing.com Strong Buy, 11 Buy vs. 1 Sell, 8 to 0 Strong Buy; Barchart 84.61 +2.21 or +2.68%, 5-day 82.90, 20-day 82.53, positive momentum; Economies.com held early gains, positive support, upward moves, strong technical support; OneUpTrader 82-83 pivot, 83.04 resistance, 81.50 support, 78.75 MA, bullish above 83.04 toward 87-88; FXStreet mildly bearish below 100-hour SMA 81.18, above 200-hour SMA and $80, RSI neutral, re...

Monday, August 17, 2026. WEEK 33 OPENS. CRUDE OIL UPDATE: WTI at $82.09, down 0.38% from prior day per CFD/benchmark report; another note indicated rise toward $82.44 amid market movements. Aug 16 around $82.08 (delayed quote/settlement reference); one historical table listed 81.52 with -1.07% change; intraday trading referenced opens near $82.53 and ranges in low $82s. Aug 14 settlement $82.40 (up 1.42%). Aug 13 $81.25 settlement (down 2.43%). Front-month WTI futures CLU26 Sep 2026 traded on NYMEX. NATURAL GAS UPDATE: Aug 11 spot (latest reported) $2.79 (up from $2.72 on Aug 10). Earlier Aug: Aug 7 ~$2.56; Aug 6/5 ~$2.60; Aug 4 ~$2.74. CME Henry Hub futures (mid-Aug 2026) trading around $2.66-$2.72 on Aug 16, 2026, with daily changes roughly -0.4% to -2.7%. Broader natural gas (CFD tracking Henry Hub) around $2.66-$2.73 on Aug 16-17, 2026, reflecting downward pressure. EIA Q3 2026 expectations around $2.87 in some outlooks. 2026 averages low-to-mid $3 range. STRAIT OF HORMUZ SHIPPING: Aug 14 (Friday) only 2 vessels transited (one grain carrier entering Iranian waters, one empty dry bulk carrier exiting); separately empty LPG tanker noted heading through; no crude oil cargoes observed (Kpler analysis); nine vessels passed prior Thursday; five on Wednesday. Aug 13 13 confirmed Strait of Hormuz crossings (MarineTraffic data: 7 entering Gulf, 6 exiting; mix of vessel types including some sanctioned/shadow vessels). Aug 13/14 context Hormuz shipping traffic shows no sign of recovery (per gCaptain reports citing trade data); PortWatch recorded just 1 transit on Aug 9 against pre-crisis baseline of ~73 per day. Aug 10 (Monday) traffic fell to 6 vessels (vs. 10-day average of ~11); included 4 commodity vessels entering (two empty oil product tankers) and 2 exiting (one small LPG tanker, one with residual fuels) (Kpler/Reuters). Around Aug 11-12 5-day average of ~13 transits (all ship types), near three-month low and ~90% below pre-war levels (Kpler data via CNBC analysis). Aug 5 8 vessels transited (including 5 tankers and 3 bulk carriers; Kpler data). Aug 15 (or recent daily snapshot) 16 vessels recorded transiting (mix including dry bulk carriers, chemical tanker, oil tanker). Mid-Aug daily example (Windward data, ~Aug 15 context) 13 total crossings (4 inbound, 9 outbound), with several running AIS-dark for extended periods; composition included tankers, bulk carriers, cargo vessels. Broader Aug trend traffic remains well below pre-crisis norms; reports of attacks on vessels (including ADNOC-linked tankers) contributing to caution; some sources note Iranian-linked or shadow fleet activity and limited commercial flows. Overall context cumulative effects from crisis (including prior attacks, threats, stalled diplomacy) kept flows suppressed since spring/summer; occasional slight rebounds but no sustained recovery to normal levels as of mid-Aug. Pre-crisis baselines consistently cited as much higher (often 100+ daily). THE READ: Crude WTI $82.09 down 0.38%; Aug 16 $82.08; Aug 14 settlement $82.40 up 1.42%; Aug 13 $81.25 down 2.43%; front-month CLU26 Sep 2026 NYMEX. Gas Aug 11 spot $2.79 up from $2.72 Aug 10; earlier Aug 7 $2.56, Aug 6/5 $2.60, Aug 4 $2.74; CME Henry Hub futures mid-Aug $2.66-$2.72 Aug 16, daily changes -0.4% to -2.7%; broader natural gas CFD $2.66-$2.73 Aug 16-17, downward pressure; EIA Q3 2026 $2.87; 2026 averages low-to-mid $3. Hormuz Aug 14 only 2 vessels, grain carrier Iranian waters, empty dry bulk exiting, empty LPG heading through, no crude oil, Kpler, nine prior Thursday, five Wednesday; Aug 13 13 crossings, MarineTraffic 7 entering 6 exiting, sanctioned/shadow vessels, no recovery, gCaptain, PortWatch 1 transit Aug 9 vs. 73 pre-crisis; Aug 10 6 vessels vs. 10-day average 11, 4 commodity entering, 2 empty oil product tankers, 2 exiting, 1 small LPG, 1 residual fuels, Kpler Reuters; Aug 11-12 5-day average 13 transits, three-month low, 90% below pre-war, Kpler CNBC; Aug 5 8 vessels, 5 tankers 3 bulk; Aug 15 16 vessels, dry bulk, chemical tanker, oil tanker; mid-Aug Windward 13 crossings, 4 inbound 9 outbound, AIS-dark, tankers bulk cargo; Aug trend well below pre-crisis, attacks ADNOC tankers, Iranian-linked shadow fleet, limited flows; crisis cumulative effects, attacks threats stalled diplomacy, suppressed since spring/summer, occasional rebounds, no sustained recovery mid-Aug; pre-crisis 100+ daily. Capital preservation first. Trade the data, not the headlines.

Friday, August 15, 2026. ZIMBABWE ENERGY PROFILE: Zimbabwe's 2026 developments in energy, oil/gas, mining, and lithium focus on a lithium export and processing boom alongside early-stage oil/gas exploration, supported by policy shifts toward local beneficiation and foreign (especially Chinese) investment. LITHIUM BOOM: Export earnings $782 million in first six months of 2026 (more than triple the $237 million from prior comparable period). Global position: Accounted for nearly 10% of global lithium production in 2025; leads African output. Major operations: Bikita Minerals (Sinomine), Arcadia (Huayou Cobalt/Prospect Lithium), Kamativi (Yahua), Sabi Star, Sandawana; Chinese firms invested over $1 billion since 2021. Processing plants: Huayou's lithium sulphate production at Arcadia (early 2026 start); $500 million Goromonzi facility (Africa's first, world's third such plant, targeting 60,000 tonnes capacity). Export controls: Feb 2026 government ban on exports of raw mineral ore and lithium concentrates to enforce local processing and value addition. INVESTMENT & POLICY: Record approvals: $1.59 billion in new projects approved in Q2 2026; mining/manufacturing ~80% (~$768.5 million for mining focused on gold, platinum, lithium). Critical minerals: Nickel, copper, lithium declared critical minerals alongside oil/gas, coal, gold. Mining sector weight: 14% of GDP, 75% of export earnings, 20% of government revenues in 2024. Beneficiation focus: Multiple processing/refining initiatives and state equity stakes to capture more value domestically. OIL & GAS EXPLORATION: Cabora Bassa Basin project (Invictus Energy): Largest oil/gas exploration effort; targeting ~1.2 trillion cubic feet of gas and 73 million barrels of condensate; Musuma-1 well spud planned for November 2026. Landmark deal: Gas production deal signed in 2026 for Cabora Bassa project, advancing commercialization with international partnerships. Broader push: Zimbabwe seeking partnerships for oil/gas development amid regional Southern/East African momentum; confirmed viable gas/oil via advanced tech. AFRICA-WIDE CONTEXT: Regional output: Zimbabwe drives much of continent's lithium output (part of 124k+ tons LCE regionally); costs competitive with growing state participation mandates. Export controls impact: Zimbabwe's restrictions (alongside others) noted in 2026 critical minerals outlooks as tightening supply chains for battery metals. THE READ: Zimbabwe lithium export earnings $782M first six months 2026, triple prior period; nearly 10% global lithium production 2025; leads African output; major operations Bikita Minerals, Arcadia, Kamativi, Sabi Star, Sandawana; Chinese firms over $1B since 2021; Huayou lithium sulphate Arcadia early 2026; $500M Goromonzi facility, Africa's first, world's third, 60k tonnes capacity; Feb 2026 ban raw mineral ore/lithium concentrates, local processing/value addition; record approvals $1.59B Q2 2026, mining/manufacturing 80%, $768.5M mining, gold/platinum/lithium; nickel/copper/lithium critical minerals; mining 14% GDP, 75% export earnings, 20% government revenues 2024; processing/refining initiatives, state equity stakes; Cabora Bassa Basin Invictus Energy, largest oil/gas exploration, 1.2T cubic feet gas, 73M barrels condensate, Musuma-1 well spud Nov 2026; gas production deal 2026, commercialization, international partnerships; regional Southern/East African momentum, confirmed viable gas/oil; Zimbabwe drives continent's lithium output, 124k+ tons LCE regionally, competitive costs, state participation mandates; export controls tightening supply chains battery metals. Capital preservation first. Trade the data, not the headlines.

Thursday, August 14, 2026. WASHINGTON STATE ENERGY PROFILE: Washington state has no meaningful in-state crude oil or natural gas production. No crude oil production: Zero commercial production since early 1960s; exploration dating back to 1900 yielded only negligible amounts. No natural gas production: State produces none; nearly all natural gas consumed is imported, primarily from Canada. Refining capacity: Fifth-largest crude oil refining capacity in U.S. (five refineries processing ~650,000 barrels per day), but all crude is imported (historically from Alaska, now increasingly via pipeline from Canada or rail from other U.S. regions). Natural gas consumption: Mainly for power generation, heating, and industry; Canada is dominant supplier; electric power sector use has grown since ~2013. Policy context: Natural gas faces regulation under Climate Commitment Act (emissions cap-and-trade) and related decarbonization efforts, though it remains in use for reliability amid growing electricity demand. Broader energy profile: Net energy importer overall; hydropower dominates electricity generation; natural gas is secondary source (~16% of in-state generation in recent data); oil and gas production plays no role. No 2026 shifts: Official sources consistently describe zero or negligible activity; no projections indicate shift toward in-state fossil fuel production. THE READ: Washington state zero crude oil production since early 1960s; zero natural gas production; imports nearly all natural gas from Canada; fifth-largest U.S. refining capacity 650,000 barrels per day; all crude imported from Alaska, Canada, or other U.S. regions; natural gas for power generation, heating, industry; Canada dominant supplier; electric power sector use growing since 2013; Climate Commitment Act regulation; emissions cap-and-trade; decarbonization efforts; reliability concerns amid growing electricity demand; net energy importer; hydropower dominates generation; natural gas 16% of in-state generation; oil and gas production zero; no 2026 shifts; official sources zero or negligible activity; no projections indicate shift toward in-state fossil fuel production. Capital preservation first. Trade the data, not the headlines.

Wednesday, August 13, 2026. CRUDE OIL UPDATE: WTI Sep 2026 futures trading $82.10-$83.38; recent trade $83.10 +0.97 on Aug 11 data; settlement/open levels $82.25-$82.88; up ~1%+ intraday in some sessions. WTI Aug 2026 futures ~$84.91. Oct 2026 ~$81.06-$81.52. Nov 2026 ~$79.76. Recent spot/WTI prices (early Aug 2026) around $78-$82 range; examples include ~$81.96 on Aug 3; ~$78.16-$78.78 in early/mid-August; decline to ~$77.11 on Aug 4. EIA Short-Term Energy Outlook (Aug 2026): Brent spot forecast averaging ~$85/bbl in Q3 2026 (WTI typically trades at discount to Brent); 2027 average ~$69. Bloomberg energy snapshot (Aug 11): WTI ~$83.05-$83.45 (Aug/Sep 2026 contracts); Brent ~$88.71 (Sep 2026). Recent opens/closes: WTI futures opened ~$78.31 on Aug 7; ~$77.74 on Aug 10; recent closes/settlements in low-to-mid $82 area on Aug 10-11. NATURAL GAS UPDATE: Aug 3 spot (latest reported) $2.81/MMBtu. Sep 2026 futures (NGU26) $2.77-$2.79/MMBtu (recent trades around $2.754-$2.789). Oct 2026 (NGV26) ~$2.835/MMBtu. Recent spot prices (early Aug 2026) low-to-mid $2.60s-$2.80s range. EIA forecast Q3 2026 average around $2.87/MMBtu; prices expected to stay below $3.00/MMBtu through much of period due to high storage and production. 2026 annual average forecasts $2.89-$3.50 range depending on source/timing. OPEC+ PRODUCTION: August 2026 quota increase +188,000 bpd (effective from start of month). Core countries: Saudi Arabia, Russia, Iraq, Kuwait, Kazakhstan, Algeria, Oman. Cumulative increase (Apr-Aug 2026) 958,000 bpd total. Trend: Fifth consecutive monthly hike; further similar increases expected (e.g., another ~188,000 bpd potentially for September). Context: Phased unwinding of earlier voluntary production cuts (originally from 2023). Note on actual vs. target: Announced quotas reflect targets amid ongoing market reviews (e.g., post-Iran conflict dynamics affecting shipping in Strait of Hormuz). Physical output may lag due to logistical/geopolitical factors; some reports noting subdued tanker activity despite quota hikes. OPEC+ crude output reached approximately 43.05 million bpd in September 2025; 2026 demand for OPEC+ crude projected around 43.1 million bpd. 2026 global oil demand growth: OPEC raising forecast to ~1.4 million bpd growth. OPEC MONTHLY OIL MARKET REPORT: Release date August 12, 2026. Includes detailed supply/demand data and actual production estimates. Latest available July 2026 edition. THE READ: Crude WTI Sep 2026 $82.10-$83.38; recent trade $83.10 +0.97; settlement/open $82.25-$82.88; up ~1%+; WTI Aug 2026 $84.91; Oct 2026 $81.06-$81.52; Nov 2026 $79.76; recent spot/WTI early Aug $78-$82 range; $81.96 Aug 3; $78.16-$78.78 early/mid-Aug; decline to $77.11 Aug 4; EIA STEO Aug 2026 Brent $85/bbl Q3; WTI discount to Brent; 2027 average $69; Bloomberg Aug 11 WTI $83.05-$83.45 Aug/Sep 2026; Brent $88.71 Sep 2026; recent opens/closes WTI Aug 7 $78.31; Aug 10 $77.74; recent closes/settlements low-to-mid $82 Aug 10-11. Gas: Aug 3 spot $2.81; Sep 2026 NGU26 $2.77-$2.79; recent trades $2.754-$2.789; Oct 2026 NGV26 $2.835; recent spot early Aug low-to-mid $2.60s-$2.80s; EIA Q3 2026 average $2.87; prices below $3.00 through much of period; high storage/production; 2026 annual average $2.89-$3.50. OPEC+: Aug 2026 quota +188,000 bpd; core countries Saudi Arabia, Russia, Iraq, Kuwait, Kazakhstan, Algeria, Oman; cumulative Apr-Aug 2026 958,000 bpd; fifth consecutive monthly hike; further similar increases expected; another 188,000 potentially September; phased unwinding earlier voluntary production cuts from 2023; announced quotas reflect targets amid ongoing market reviews; post-Iran conflict dynamics affecting Strait of Hormuz shipping; physical output may lag; subdued tanker activity despite quota hikes; OPEC+ output Sept 2025 43.05 million bpd; 2026 demand OPEC+ crude 43.1 million bpd; 2026 global oil demand growth OPEC raising forecast 1.4 million bpd. OPEC MOMR: Aug 12 2026 release; detailed supply/demand data and actual production estimates; latest available July 2026 edition. Capital preservation first. Trade the data, not the headlines.