πŸ›’οΈ North America Oil & Gas Weekly Briefing

Supply / Demand Fundamentals Β· CFTC Positioning Β· Rig Activity
Report Generated: September 4, 2026
Primary Data Week: Week Ending August 28, 2026 (EIA WPSR/WNGSR)
CFTC As-Of: September 1, 2026 (WTI legs confirmed β€” see Positioning tab)
πŸ“‹ Data: EIA Weekly Petroleum Status Report β€” Week Ending August 28, 2026 (Released September 2, 2026). All KPIs below β€” including crude field production and crude exports β€” independently confirmed via the EIA API v2 this run.
Crude Stocks
424.5
β–Ό -4.45 mb w/w
mln bbls | ~0.8% above 5yr avg
Cushing, OK
22.51
β–² +0.08 mb w/w
mln bbls WTI hub
US Production
13.86
β–² +0.02 mb/d w/w
mb/d (EIA WCRFPUS2, confirmed)
Refinery Inputs
17.50
β–² +0.10 mb/d w/w
mb/d crude throughput
Utilization Rate
98.0%
β–² +0.6 ppt w/w
% operable capacity
Crude Imports
6.77
β–² +0.61 mb/d w/w
mb/d
Crude Exports
4.48
β–² +0.69 mb/d w/w
mb/d (confirmed via EIA API)
WTI Prompt Spread
+$2.97
β–² widened; still Oct26-Nov26 (from +$1.59)
M1–M2 $/bbl (Oct26–Nov26) Β· confirmed Sep 4, CME Globex
SPR Stocks
286.60
β–Ό -3.12 mb w/w
mln bbls | fresh multi-decade low
Supply / Demand Balance Week Ending August 28, 2026 | mb/d
DEMAND (Disposition)
Refinery Throughput (Crude Inputs)17.50
Crude Exports4.48
Total Crude Disposition~21.98
SUPPLY
US Field Production13.86
Crude Imports6.77
SPR Release (WCSSTUS1 draw)+3.12
Condensate & NGL (est.)~0.50
Total Supply~24.25
Net Implied Balance (Actual EIA Stock Chg.)-4.45 mb (draw)
Product StocksCurrent (mb)W/W Chgvs 5yr Avg
Crude Oil (excl. SPR)424.5-4.5+0.8%
Cushing, OK (WTI hub)22.51+0.08β€”
Motor Gasoline (Total)~205.7-1.2est.
Distillate Fuel Oil~104.2+0.8est.
Propane/Propyleneβ€”-2.1est.
Refinery Throughput17.50 mb/d+0.10β€”
Utilization Rate98.0%+0.6 pptβ€”
βœ… Note: Confirmed from EIA API v2 (WPSR release, September 2, 2026) for week ending August 28, 2026: crude stocks (WCESTUS1) 424.46 mb, -4.45 mb w/w (a return to draws after last week's flat print), ~0.8% above the 5-yr seasonal average (avg computed from confirmed WCESTUS1 history, 2021-2025: 421.1 mb for this ISO week); Cushing (W_EPC0_SAX_YCUOK_MBBL) 22.51 mb, +0.08 mb w/w; SPR (WCSSTUS1) 286.60 mb, -3.12 mb w/w (fresh multi-decade low, continuing to decline); refinery inputs (WCRRIUS2) 17.50 mb/d (+0.10 mb/d w/w); utilization (WPULEUS3) 98.0% (+0.6 ppt); crude imports (WCRIMUS2) 6.77 mb/d (+0.61 mb/d); crude exports (WCREXUS2) 4.48 mb/d (+0.69 mb/d); crude field production (WCRFPUS2) 13.86 mb/d, up modestly (+0.019 mb/d w/w). All series independently confirmed via EIA API v2 this run β€” no estimates. Gasoline (WGTSTUS1) -1.17 mb w/w; distillate (WDISTUS1) +0.80 mb w/w; propane/propylene (WPRSTUS1) -2.07 mb w/w β€” all three independently confirmed via EIA API v2 this run (5-yr avg comparison not recomputed for these three products this run β€” vs-5yr columns marked "est." pending recomputation). WTI prompt spread reconfirmed this run directly from CME Globex delayed quotes (Oct26 CLV6 $91.39, Nov26 CLX6 $88.42 as of 4 Sep 2026 14:39 CT): M1-M2 = +$2.97/bbl β€” no contract roll this week, same Oct26-Nov26 pair as last week (was +$1.59, a substantial widening) β€” not an EIA series, sourced from cmegroup.com.
Crude Oil Commercial Inventory Trend Million Barrels | Recent Weeks
US Commercial Crude Inventories vs 5-Year Average
Most recent confirmed: 424.5 mb (August 28, 2026), ~0.8% above 5-yr seasonal average. Shaded band = actual 5-yr seasonal min/max envelope (weekly high/low, 2021–2025). Weeks 1–16 from prior reporting; weeks 17–35 confirmed from EIA WCESTUS1 API. Source: EIA WPSR.
πŸ“‹ Data: EIA Weekly Natural Gas Storage Report β€” Week Ending August 28, 2026 (Released September 3, 2026). National total independently confirmed via EIA API v2. 5-yr average and year-ago comparison independently computed from confirmed EIA history (nearest-date match per year, 2021-2025). Regional breakdown estimated pro-rata from the confirmed national total β€” not independently reconfirmed by region this run. HH Summer–Winter spread reconfirmed this run directly from live CME Globex Henry Hub futures quotes (not an EIA series, sourced from cmegroup.com, as of 4 Sep 2026 14:39 CT): the Sep26 contract remains expired, so the "summer" leg is still just the single Oct26 month ($2.942/MMBtu: NGV26) vs. the Nov26–Mar27 5-month winter strip average ($3.375/MMBtu: NGX26 $3.061, NGZ26 $3.501, NGF27 $3.874, NGG27 $3.548, NGH27 $2.891) = -$0.43/MMBtu, vs. -$0.52 last confirmed Aug 28, 2026 (unchanged contract composition β€” no roll this week; spread narrowed as the Oct26 front month firmed relative to the winter strip).
Working Gas in Storage
3,214
β–² +30 Bcf w/w
Bcf | Week ending Aug 28
W/W Injection
+30
β–Ό Slightly below 5yr avg (+34 Bcf, computed)
Bcf | 5yr avg level: ~3,047 Bcf
vs 5-Year Average
+167
β–Ό Above 5yr avg (narrowed further w/w)
Bcf above 5yr avg (~3,047 Bcf, computed)
vs Year Ago
-48
Deficit widened further this week
Bcf vs Aug 29, 2025 (computed)
Dry Gas Production
~111
Near record high (carried forward, 7 wks stale)
Bcf/d (EIA STEO Jun 2026 est., carried forward)
LNG Exports
~17.2
2026 annual avg (carried forward, 7 wks stale)
Bcf/d (2026 avg, EIA STEO Jun 2026)
Season Start Storage
1,829
Injection season
Bcf (late March 2026)
Sep 4 Wk Estimate
~+50
5yr avg injection (computed, nearest-date)
Bcf (ISO wk 36 seasonal avg, computed)
HH Summer–Winter
-$0.43
β–² narrowed from -$0.52 (Aug 28)
O26(Oct)–W26/27(Nov-Mar) $/MMBtu Β· confirmed Sep 4, CME Globex
Storage Trend & Regional Breakdown
US Natural Gas Storage ~12 Weeks
Most recent confirmed national total: 3,214 Bcf (August 28, 2026), confirmed via EIA API v2 (NW2_EPG0_SWO_R48_BCF). 5-yr avg (~3,047 Bcf) and 5-yr high/low band independently computed this run from confirmed EIA history (nearest-date match per year, 2021-2025). 2-year view: last week-ending of each month from EIA β€” August 2026 now complete and appended this run. Source: EIA WNGSR.
Storage RegionAug 28 (Bcf, est.)W/W Chg (est.)vs 5yr Avg
East~646~+6N/A
Midwest~786~+7N/A
Mountain~252~+2N/A
Pacific~343~+3N/A
South Central~1,187~+12N/A
Total US3,214+30+167
⚠️ National total (3,214 Bcf, +30 Bcf w/w) confirmed from EIA API; regional breakdown above is estimated pro-rata, scaled from the prior week's regional table (East 640 + Midwest 779 + Mountain 250 + Pacific 340 + South Central 1,175 = 3,184, week ending August 21) and should be treated as indicative only until independently reconfirmed by region.
Production & LNG Flow
Dry Gas Production (est.)~111 Bcf/d
LNG Exports (2026 avg, STEO Jun)~17.2 Bcf/d
Pipeline Exports to Mexico6.35 Bcf/d
Pipeline Exports to Canada3.88 Bcf/d
EIA N9132MX2 / N9132CN2 Β· Mar 2026 (carried forward)
Fcst Incremental LNG 20260.00 Bcf/d
Fcst Incremental LNG 2027+1.40 Bcf/d
STEO NGEXPUS_LNG Β· 2026 avg 17.2, 2027 avg 18.6 Bcf/d
πŸ“‹ Data: Statistics Canada (production & exports: June 2026, released August 31, 2026 β€” newly confirmed and published this run, replacing the carried-forward May 2026 production and April 2026 export figures; production via Table 25-10-0063-01, natural gas via new Table 25-10-0086-01, both confirmed directly via StatCan's WDS API) Β· Baker Hughes Rig Count (Week Ending September 4, 2026, released September 4, 2026, sourced directly from rigcount.bakerhughes.com β€” the dashboard's local Rig Counts sync folder had not yet received the September 4, 2026 workbook at the time of this run, latest local file week ending August 21, 2026) Β· CER Market Snapshot (May 13, 2026 release β€” western Canada gas storage, carried forward, no newer snapshot found this run) Β· CAPP industry overview Β· AESO Connection Project List (September 2026 list, updated 2026-09-01, downloaded directly this run). Canadian production/export volume data is monthly β€” periods clearly labeled. AECO basis carried forward β€” no newer weekly gas market data confirmed this run (now seven weeks stale).
Crude Oil Production
~5.37
β–² +3.1% YoY
mb/d | June 2026 (monthly, StatsCan, newly confirmed)
Crude Exports
~4.35
β–² +6.4% YoY (June 2026, newly confirmed)
mb/d | June 2026 StatsCan release (confirmed)
Rig Count (Oil)
140
β–Ό -4 w/w
rigs | Week Ending September 4, 2026
Rig Count (Gas)
62
β–Ό -1 w/w
rigs | Week Ending September 4, 2026
LNG Overseas Exports
~1.84 Bcf/d
β–² up from ~1.45 (May 2026, newly confirmed)
June 2026 Β· 58.3M GJ Β· StatsCan Aug 31, 2026
Gas Exports to US
~7.89 Bcf/d
β–Ό -7.9% YoY (June 2026, newly confirmed)
June 2026 Β· 250.2M GJ Β· StatsCan Aug 31, 2026
AECO Fwd Basis
-$1.87
(carried forward, 5 wks stale)
Aug-26 fwd vs HH Β· 0.706 CAD/USD Β· gasalberta.com
Canadian Natural Gas & Large Load Tracker Natural gas: June 2026 (StatsCan/CER) | Large load: AESO Connection List, Sep 2026
Natural Gas & LNGValueNotes
Marketable Gas Production~22.1 Bcf/dJune 2026, StatsCan (newly confirmed, +7.9% YoY)
LNG Canada Phase 1~1.8 Bcf/dOperational since Jul 2025, Kitimat BC
LNG Export DestinationAsia-PacificJapan, Korea, China primary
Storage (Western Canada)~602 BcfEnd-Mar 2026; 22% above 5-yr avg (CER)
AECO Hub Price (est.)~1.52 CAD/GJJul-26 fwd (~$1.13 USD/MMBtu) Β· gasalberta.com
Alberta Large Load (Data Centre) Tracker
Requested (Data Load projects)21,310 MW42 projects
Phase 1 Allocated1,200 MWFully allocated
Remaining in Queue (est.)~20,110 MW~94% of requested
Stage 1 (Early Study)7,676 MW16 projects
Stage 2 (Advanced Study)13,634 MW26 projects
Large Load Connection Queue & Natural Gas Storage AESO Connection Project List Sep 2026 Β· CER Western Canada Gas Storage
Data Load Connection Queue β€” Requests to Study Stage
LARGE LOAD REQUESTS 21.3 GW 42 projects Β· AESO Connection List, Sep 2026 1.2 GW Phase 1 Β· fully allocated STILL IN QUEUE 20.1 GW ~94% of requested Β· 42 projects 7.7 GW Stage 1 Β· 16 projects 13.6 GW Stage 2 Β· 26 projects
Source: AESO Connection Project List, September 2026 (aeso.ca/grid/transmission-projects/connection-project-reporting; list and map dated 2026-09-01, downloaded directly from AESO's site this run β€” updated from the August 2026 list used previously). Filtered to MW Type = "Data Load" (45 total rows; 42 active/under-review projects, 21,310 MW total β€” sum of all disclosed energization-stage MW per project β€” excluding the same 3 recently-cancelled Data Load projects still listed, totaling 840 MW: Alsike, Lone Pine, and Myers Energy Park MPC, 280 MW each). Phase 1 Large Load Integration allocation (1,200 MW, fully allocated per AESO's Nov 2025 announcement β€” executed load contracts, unchanged and still fully subscribed; Phase 2's long-term framework remains under consultation with no new allocation published as of this run) is tracked via a separate AESO process and is not a column in this list; "Still in Queue" nets it against the September 2026 requested total as an approximation. Remaining queue is broken down by AESO study Stage (1 = Early Study, 2 = Advanced Study); no Data Load projects have reached Stage 3+ as of this release. Full project-level detail: AESO Connection Project Dashboard.
Western Canada Natural Gas Inventories vs Historical Range
Source: Canada Energy Regulator (CER) Market Snapshot (released 2026-05-13; carried forward this run β€” no newer CER snapshot found). Western Canada holds ~88% of national gas storage. National storage ended March 2026 at 684 Bcf β€” 4% above end-March 2025 and 22% above the 5-yr average β€” implying ~602 Bcf in western Canada specifically (2026 series shown here). The withdrawal season began from a record national high of 1,098 Bcf on November 7, 2025 (2% above the prior 2024 record), driven by record monthly marketable gas production of 20.04 Bcf/d that same month β€” over 99.9% of it from western Canada. Shaded band = 5-yr seasonal range (2020–2024). See: CER Market Snapshot, May 13, 2026.
πŸ“‹ Data: Baker Hughes Weekly Rig Count β€” Week Ending September 4, 2026 (released September 4, 2026), sourced from the local Rig Counts sync folder workbook (arrived after this week's initial compile, confirmed against and matching the rigcount.bakerhughes.com web fallback figures already on file).
US Total Rigs
588
β€” flat w/w
Week Ending Sep 4 | vs prior week 588
US Oil Rigs
449
β–² +2 w/w
Up from 447
US Gas Rigs
130
β–Ό -2 w/w
Natural gas-directed
Gulf of Mexico
6
β–Ό -1 w/w
Offshore/misc rigs
Canada Total
204
β–Ό -7 w/w
Extending pullback from prior multi-month high
Canada Oil Rigs
140
β–Ό -4 w/w
Oil-directed
Canada Gas Rigs
62
β–Ό -1 w/w
Gas-directed
NA Total
792
β–Ό -7 w/w
North America combined
Rig Count Detail & Breakdown
CategoryCountW/W ChgYoY Chg
United States
  Oil Rigs449+2414
  Gas Rigs130-2118
  Gulf of Mexico / Misc6-110
Major Basins (US)
  Permian268+1254
  Haynesville56-139
  Eagle Ford50039
  Williston27029
  US Total5880537
Canada
  Oil Rigs140-4123
  Gas Rigs62-158
  Misc2-20
  Canada Total204-7181
North America Total792-7718
Rig Count by Category β€” Week Ending September 4, 2026
Source: Baker Hughes North America Rig Count. Weekly release every Friday.
πŸ“‹ Data: NYMEX WTI Physical and WTI Financial (ICE Europe) β€” both genuine Managed Money, confirmed as of September 1, 2026, pulled directly from cftc.gov/dea/futures/petroleum_sf.htm (released September 4, 2026; `curl -I` Last-Modified header showed 19:27 GMT β‰ˆ 3:27 PM ET, right on the normal Friday release window). ICE Brent Crude financial positioning has been removed from this tab (as of the September 4, 2026 run) β€” this page now tracks WTI-only Managed Money positioning (NYMEX Physical + ICE Europe Financial). CFTC reports Tuesday positions, released the following Friday.
NYMEX WTI Physical Net
+94.3k
contracts (net long; confirmed Sep 1)
β–² +10.3k w/w β€” long-buying + short-covering
ICE Europe WTI Financial Net
-10.7k
contracts (net short; confirmed Sep 1)
β–Ό -0.4k w/w β€” drifted slightly further short
Combined WTI (NYMEX + ICE Europe)
+83.5k
contracts (net long; both legs confirmed Sep 1)
β–² +9.9k w/w β€” NYMEX rebuilt on long-buying + short-covering
WTI NYMEX Long / Short Ratio
1.85x
longs vs shorts (Managed Money)
L 205k vs S 111k (Sep 1, 2026)
Market Signal
πŸ“ˆ NYMEX Rebuilds on Long-Buying & Short-Covering; ICE Europe Slips Slightly Further Short
NYMEX Physical net long jumped +10.3k via a bullish combination β€” longs added (+8.4k) while shorts were covered (-1.8k) β€” even as WTI spot fell to $84.62. ICE Europe drifted marginally deeper net-short (-0.4k w/w) to -10.7k.
RWTC spot down $2.73/bbl w/w to $84.62 even as NYMEX length rebuilt β€” a notable divergence
Managed Money Positioning β€” WTI (NYMEX + ICE Europe) Thousands of contracts | Jan 2021 – Sep 2026
Weekly. EIA series RWTC (Cushing, OK WTI spot price FOB, US$/bbl). Each point is the week-ending Friday price preceding the corresponding CFTC report date. Shares the x-axis of the positioning chart above.
WTI Short WTI Long Net
Values in thousands of contracts. WTI Physical from CFTC Disaggregated COT (NYMEX; managed money) β€” confirmed genuine Managed Money through Sep 1, 2026 (Long 205.3k / Short 111.0k / Net +94.3k), up from +84.0k the prior week. Source: CFTC Disaggregated COT (publicreporting.cftc.gov, cftc.gov/dea/futures/petroleum_sf.htm). ICE Brent Crude financial positioning was removed from this chart and this tab as of the September 4, 2026 run β€” the historical brentL/brentS series is no longer plotted or tracked.
βœ… Methodology note: This chart plots WTI Physical (NYMEX) Managed Money β€” CFTC's single largest WTI contract β€” as the stacked Long/Short area with a Net line overlay. The smaller ICE Europe WTI Financial contract (OI 767.4k) is tracked separately in the KPI cards and the detailed positions table below, and combined into the "Combined WTI (NYMEX + ICE Europe)" figures, but is not separately plotted on this chart. ICE Brent Crude (ICE Futures Europe's own Commitments of Traders Report, published separately from CFTC) has been removed from this dashboard as of Sep 4, 2026.
Detailed Positions Table As of Sep 1, 2026 | CFTC Disaggregated COT
Contract / Exchange MM Longs MM Shorts Net Position W/W Longs W/W Shorts W/W Net Ξ” Open Interest Signal
WTI Physical (NYMEX) Managed Money 205,300 111,019 +94,281 +8,418 -1,843 +10,261 1,921,085 Net Long β€” Building (Long-Led)
WTI Financial (ICE Europe) Managed Money 13,651 24,398 -10,747 -573 -185 -388 767,357 Net Short β€” Widening Slightly
Combined WTI (NYMEX + ICE Europe, Managed Money) 218,951 135,417 +83,534 +7,845 -2,028 +9,873 β€” Net Long β€” Building (NYMEX-Led)
Positioning Context & Interpretation

Overall Stance: NYMEX WTI Rebuilds on Long-Buying and Short-Covering; ICE Europe Slips Slightly Further Net Short

This week's CFTC Disaggregated COT report (positions as of Tuesday, September 1, 2026, released Friday September 4 and pulled directly from cftc.gov/dea/futures/petroleum_sf.htm β€” the `curl -I` Last-Modified check showed the page updated at 19:27 GMT, β‰ˆ3:27 PM ET, right at the normal release window) shows a solid week-over-week rebuild in the WTI physical contract, reversing last week's short-building-driven easing. NYMEX WTI Physical managed money net long rose to +94,281 contracts (Long 205,300 / Short 111,019), up +10,261 from +84,020 the prior week β€” this time driven by a bullish combination of longs added (+8,418) and shorts covered (-1,843), the classic long-buying/short-covering pattern rather than the short-building composition seen last week.

ICE Europe WTI Financial drifted slightly further net short: managed money longs fell 573 to 13,651, while shorts fell less, 185, to 24,398, widening the net short position to -10,747 contracts from -10,359 the prior week β€” a modest -388 move that erases the small improvement posted last week, leaving the leg deeply net short. Blending both confirmed NYMEX and ICE Europe Managed Money readings gives a combined WTI net long of +83,534 contracts, up +9,873 (+13.4%) w/w. This is a notable divergence from the price action: EIA's WTI spot price (RWTC) fell -$2.73/bbl to $84.62 for the week ending August 28, even as the dominant NYMEX leg of positioning rebuilt meaningfully β€” length adding into a falling tape rather than confirming it.

Note on scope: as of the September 4, 2026 run, this dashboard tracks WTI-only Managed Money positioning (NYMEX Physical + ICE Europe Financial). ICE Brent Crude's own Commitments of Traders Report (published separately by ICE Futures Europe, not CFTC) has been removed from this tab, its chart, KPI cards, and detailed positions table β€” the "Combined WTI + Brent" metric no longer appears anywhere on this dashboard.

Context: This week's positioning shift is notable for its composition: the dominant NYMEX physical contract rebuilt via long-buying and short-covering together β€” a combination that typically signals fresh bullish conviction rather than short covering alone β€” while the smaller ICE Europe leg slipped modestly further into net-short territory. This occurred even as WTI spot fell for the week, a divergence worth watching next week: either positioning is leading price lower risk into a subsequent reversal, or the market is pricing in factors not yet reflected in Tuesday's positioning snapshot. The WTI NYMEX long/short ratio widened to 1.85x (from 1.74x the prior week), recovering more than the prior week's pullback.