Gulf South Pipeline has issued a second consecutive Over-Under Performance notice (new ID 5038899) for Loc 24329 Stratton Ridge to Freeport LNG, covering Gas Day 10/21/2026 and until further notice -- an exact reissuance of yesterday's notice (GSPL-5038892) shifted forward one gas day. The customer continues to fail to take confirmed quantities at the Stratton Ridge delivery point, and Gulf South will reduce scheduling for remaining nomination cycles based on Projected Daily Quantities. Pre-event scheduled flow at Loc 24329 was 1.43 Bcf/d median (range 1.02-1.46 Bcf/d over the prior seven days), against 1.78 Bcf/d operating capacity; no explicit new cap or volume cut is stated in this notice.
Freeport LNG feed gas curtailment at Stratton Ridge (Loc 24329) now extends a second consecutive gas day (10/21/2026 UFN); pre-event scheduled flow was ~1.43 Bcf/d median (1.02-1.46 range) vs 1.78 Bcf/d operating capacity, with displaced volumes remaining in the domestic Gulf Coast pool -- bearish Henry Hub regional proxy as long as the under-take persists.
Reroute: None: Stratton Ridge is the dedicated Gulf South delivery point feeding Freeport LNG; displaced feed gas volumes have no alternate export outlet and remain in the domestic market.
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Transwestern Pipeline
[Transwestern Pipeline] [Capacity Constraint] ATOKA 2 POINT GROUP
SEV 4/5
Force Majeure1 Days
Transwestern Pipeline has declared force majeure on the ATOKA 2 POINT GROUP, effective Oct 20 2026 9:00AM through Oct 21 2026 8:59AM. This is a third administrative repost of the same event (prior notices TW-121418 and predecessor), with only the notice ID and posting timestamp changed -- no new operational content. Pre-event scheduled flow at both identified Atoka receipt meters (ATOKA PECOS DIAMOND PL 8 INCH and AGAVE ATOKA #3 STA) was 0.00 Bcf/d throughout the prior week, so the physical cut is currently unquantifiable from flow data alone.
TW force majeure on ATOKA 2 POINT GROUP is a third administrative repost with no new operational content; pre-event flow at both Atoka receipt meters (loc_id 9168 and 500305) was 0.00 Bcf/d so the physical cut is currently unquantifiable, but minimum severity 4 applies given the active force majeure declaration -- split-direction signal: bearish Waha/Permian as TW takeaway is restricted, bullish SoCal Border and Arizona if volumes were scheduled.
Reroute: Moderate: EPNG serves the same SoCal border and Arizona delivery markets as Transwestern and could absorb some displaced volumes, but given the Atoka meters showed zero scheduled flow pre-event, immediate market impact appears minimal.
Transwestern Pipeline has declared a force majeure on the ATOKA 2 POINT GROUP effective October 20, 2026 at 9:00 AM through October 21, 2026 at 8:59 AM. This is a second administrative repost (TW-121418 follows TW-121409 which followed TW-121397), with only the notice ID and posting timestamp changed -- no new operational content. Pre-event scheduled quantities at both identified Atoka receipt meters (ATOKA PECOS DIAMOND PL 8 INCH, loc_id 9168; AGAVE ATOKA #3 STA, loc_id 500305) were 0.00 Bcf/d, so the physical volume impact remains unquantifiable from available data.
TW force majeure on ATOKA 2 POINT GROUP is a second administrative repost with no new operational content; pre-event flow at both Atoka receipt meters was 0.00 Bcf/d so the physical cut is currently unquantifiable, but minimum severity 4 applies given the active force majeure declaration -- split-direction signal applies: bearish Waha/Permian as basin takeaway is curtailed, bullish SoCal Border and Arizona delivery points.
Reroute: Moderate: EPNG serves overlapping SoCal border and Arizona delivery markets and may absorb displaced volumes, but a simultaneous EPNG constraint would leave no California reroute alternative.
Force Majeure0.061 Bcf/d cut (capped at 0.447 Bcf/d)7 Days
Southern Natural Gas has escalated planned SESH maintenance at the Delhi and Gwinville Compressor Stations to a force majeure event affecting SNG-SESH capacity on Segment 380. Normal capacity of 507,689 Dth/d (0.508 Bcf/d) is reduced on six specific gas days between October 20-29, with the largest single-day reduction occurring October 28 when capacity falls to 447,000 Dth/d (a cut of ~60,689 Dth/d or ~0.061 Bcf/d). Out-of-Path and In-Path services are at risk based on current nominations.
SNG Segment 380 force majeure cuts SNG-SESH interconnect capacity by up to 0.061 Bcf/d on the worst day (Oct 28, restricted to 0.447 Bcf/d), with curtailments on six days through Oct 29; expect mild bullish pressure on Southern Natural La. and Southeast basis as out-of-path and in-path services face curtailment risk.
Reroute: Moderate: Gulf South and Transco serve overlapping Southeast markets and may absorb some displaced volumes; however, SNG is the dominant Southeast pipeline and SESH is a primary Gulf Coast interconnect, so full reroute is unlikely to offset all affected nominations on constrained days.
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Transwestern Pipeline
[Transwestern Pipeline] [Capacity Constraint] ATOKA 2 POINT GROUP
SEV 4/5
Force Majeure1 Days
Transwestern Pipeline has declared a force majeure on the ATOKA 2 POINT GROUP, effective October 20 at 9:00 AM through October 21 at 8:59 AM. This is an administrative repost of TW-121397 (itself a repost of TW-121388) with only the notice ID and posting timestamp changed -- no new operational content. Pre-event scheduled flow at both identifiable Atoka receipt meters (ATOKA PECOS DIAMOND PL 8 INCH and AGAVE ATOKA #3 STA) was 0.00 Bcf/d across the prior week, so the physical volume impact is currently unquantifiable.
TW force majeure on ATOKA 2 POINT GROUP is a same-day administrative repost of TW-121397 with no new operational content; pre-event flow at both Atoka receipt meters was 0.00 Bcf/d, so the physical cut is currently unquantifiable, but minimum severity 4 applies given the active force majeure declaration -- split direction: bearish Waha/Permian as TW takeaway is constrained, bullish SoCal Border and Arizona delivery points.
Reroute: Moderate: EPNG serves overlapping SoCal border and Arizona markets and is the primary alternative to Transwestern; however, if EPNG is simultaneously constrained, no California reroute exists.
Maintenance0.100 Bcf/d cut (capped at 0.700 Bcf/d)2 Days
CGT is conducting planned maintenance at Lake Arthur Compressor Station on October 27-28, 2026, which will reduce delivery capacity at Cameron LNG (loc 4246) from its design capacity of 0.800 Bcf/d to 0.700 Bcf/d (Primary Only), a reduction of 0.100 Bcf/d. CGT explicitly warns that this restriction may result in curtailments to Interruptible, Secondary Firm, and Primary Firm services. Live capacity data for Cameron LNG (loc 4246) shows the point currently running at 0.696 Bcf/d scheduled against 0.800 Bcf/d operating capacity, confirming the new 0.700 Bcf/d cap is effectively at or just above current flows but Primary Firm curtailment risk makes this actionable.
CGT maintenance cuts Cameron LNG feed gas delivery cap by 0.100 Bcf/d (0.800 to 0.700 Bcf/d) on Oct 27-28 with explicit Primary Firm curtailment risk; gas that cannot be exported stays domestic, bearish for Henry Hub and Gulf Coast basis over the two-day window.
Reroute: Limited: Cameron LNG feed gas can only arrive via pipelines serving that terminal; no alternative LNG export outlet exists for these specific curtailed volumes, so the gas remains in the domestic market.
Gulf South Pipeline issued a Critical Over-Under Performance notice on Gas Day 10/20/2026 for Loc 24329 (Stratton Ridge to Freeport LNG), citing a customer's failure to take confirmed quantities and triggering scheduling reductions for remaining nomination cycles through at least Gas Day 10/21/2026. This is a recurrence of the same event posted on 10/17/2026 (GSPL-5038889). The live evening-cycle reading at Loc 24329 shows 1.45 Bcf/d scheduled against 1.78 Bcf/d operating capacity (81.5% utilized, 18.5% headroom), compared to a pre-event 7-day median of 1.43 Bcf/d (range 1.11-1.46 Bcf/d); no explicit volume cut is stated, but scheduling reductions are anticipated and the UFN language keeps the event open-ended.
Gulf South curtailment at Stratton Ridge (Loc 24329) again reduces Freeport LNG feed gas on Gas Day 10/20/2026 -- pre-event baseline was 1.43 Bcf/d median (range 1.11-1.46), live evening cycle shows 1.45 Bcf/d scheduled vs 1.78 Bcf/d operating capacity with no explicit cut volume stated; displaced gas stays in the domestic Gulf Coast pool, bearish Gulf Coast/Henry Hub basis; this is a repeat occurrence from 10/17 and remains UFN.
Reroute: None: Freeport LNG feed gas delivered via this specific lateral cannot be rerouted to the terminal through an alternative path; any curtailed volume remains in the domestic pipeline system.
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Transwestern Pipeline
[Transwestern Pipeline] [Capacity Constraint] ATOKA 2 POINT GROUP
SEV 4/5
Force Majeure1 Days
Transwestern Pipeline has declared force majeure on the ATOKA 2 POINT GROUP, effective Oct 20 2026 9:00AM through Oct 21 2026 8:59AM -- a roughly 24-hour window. This posting (TW-121397) is an administrative repost of TW-121388 filed earlier the same day with no operational changes. Pre-event scheduled quantities at the two identified Atoka receipt meters (loc_id 9168 and 500305) were 0.00 Bcf/d throughout the prior seven gas days, so the immediate physical supply reduction appears negligible based on recent flow.
TW force majeure on ATOKA 2 POINT GROUP is a same-day administrative repost of TW-121388 with no new operational content; pre-event flow at both Atoka receipt meters was 0.00 Bcf/d, so the physical cut is currently unquantifiable but minimum severity 4 applies given force majeure declaration -- split-direction signal remains bearish Transwestern Permian/Waha basis and mildly bullish SoCal Border and Arizona delivery points.
Reroute: Moderate: EPNG serves overlapping SoCal border and Arizona delivery markets and can partially offset Transwestern constraints; however, if EPNG is simultaneously constrained, California reroute options are effectively eliminated.
Transwestern Pipeline has declared a force majeure on the ATOKA 2 POINT GROUP, effective October 20 at 9:00 AM through October 21 at 8:59 AM -- approximately one gas day. No specific capacity volume is stated in the notice. Pre-event flow data for the two named Atoka-area receipt points (ATOKA PECOS DIAMOND PL 8 INCH, loc_id 9168; AGAVE ATOKA #3 STA, loc_id 500305) shows zero scheduled quantities over the prior seven days, suggesting this is a small receipt-point group with minimal throughput ahead of the event.
TW force majeure on ATOKA 2 POINT GROUP applies split-direction pressure: bearish Waha and Transwestern Permian basis as any constrained receipts back up at the basin, and mildly bullish SoCal Border and Arizona delivery points; pre-event flow at the two identified Atoka receipt meters was 0.00 Bcf/d across the prior week, so immediate market impact is likely negligible in volume terms despite the FM declaration.
Reroute: Moderate: EPNG serves overlapping Permian-to-California and Permian-to-Arizona corridors and can absorb marginal volumes if needed; however, given near-zero pre-event flows at the identified Atoka meters, reroute need appears minimal.
Force Majeure0.205 Bcf/d cut (capped at 0.180 Bcf/d)Until Further Notice25 Days
Southern Star has declared a force majeure at the Saginaw Compressor Station (Jasper County, MO) due to a mechanical failure of the Saginaw Turbine, reducing capacity by 180,000 Dth/d (0.180 Bcf/d) at Saginaw CS and 25,000 Dth/d (0.025 Bcf/d) at Empire Energy Center, totaling 0.205 Bcf/d. This update (superseding #11240) pushes the in-service date back to November 2, 2026, extending the outage that began ID2 cycle October 9. Live capacity data for Saginaw CS Area Deliveries (loc_id 444550) shows operating capacity at 0.180 Bcf/d with 0.143 Bcf/d scheduled, corroborating the reduced operating cap stated in the notice.
Southern Star force majeure at Saginaw CS removes 0.205 Bcf/d of Midcontinent/Missouri delivery capacity through Nov 2; timeline extension is bearish for update direction but the sustained capacity loss is bullish for Southern Star basis -- watch for tightening in Kansas/Missouri LDC markets with limited reroute via ANR, PEPL, or Southern Star alternatives.
Reroute: Moderate: ANR and Panhandle Eastern (PEPL) serve overlapping Midcontinent and Midwest corridors and may absorb some volumes, but Southern Star serves specific Kansas/Missouri local markets that have limited direct bypass options.
Force Majeure0.040 Bcf/d cut (capped at 0.035 Bcf/d)1 Days
Transwestern Pipeline has declared a force majeure at Atoka 2 Compressor Station (Artesia area, NM) due to mechanical failure, effective Gas Day October 20, 2026. Total station capacity will be reduced from 75,000 MMBtu/d (0.075 Bcf/d) to approximately 35,000 MMBtu/d (0.035 Bcf/d), a reduction of ~0.040 Bcf/d, affecting receipt volumes from DCP Artesia Plant (POI 10703) and Dagger Draw Plant (POI 56339). Transwestern states capacity will return to 75,000 MMBtu/d on Gas Day October 21, making this a single-day event.
TW force majeure removes ~0.040 Bcf/d of Artesia-area Permian receipt capacity for Gas Day Oct 20 only; pre-event DCP Artesia (loc 10703) was scheduling ~0.031 Bcf/d against 0.038 Bcf/d operating capacity and Dagger Draw (loc 56339) was scheduling ~0.050 Bcf/d, so the combined receipts at risk broadly align with the stated cut -- expect modest bearish pressure at Waha/Permian basis with negligible downstream SoCal Border impact given the small aggregate volume and single-day duration.
Reroute: Limited: Transwestern and EPNG both serve the SoCal border from Permian receipt points; EPNG could absorb marginal volumes from Artesia-area producers, but at 0.040 Bcf/d the cut is small enough that system-wide reroute impact is minimal. The one-day duration further limits market significance.
Gulf South Pipeline issued a Critical Over-Under Performance notice for Gas Day 10/17/2026, citing the customer's failure to take confirmed quantities at Loc 24329 Stratton Ridge to Freeport LNG. Gulf South is implementing scheduling reductions for remaining nomination cycles on 10/17 and until further notice. Live capacity data shows Stratton Ridge (Loc 24329) running at 1.46 Bcf/d scheduled against 1.78 Bcf/d operating capacity (82.2% utilization, 0.317 Bcf/d headroom) as of the evening cycle; the pre-event baseline median was 1.43 Bcf/d over the prior seven gas days, so the posted evening reading is consistent with a partial reduction already in progress with no stated volume for the cut.
Gulf South curtailment at Stratton Ridge (Loc 24329) reduces Freeport LNG feed gas on Gas Day 10/17/2026 -- pre-event baseline was 1.43 Bcf/d (flat over the prior week), live evening cycle shows 1.46 Bcf/d scheduled against 1.78 Bcf/d operating capacity with no explicit cut volume stated; gas displaced from LNG export remains in the domestic Gulf Coast market, bearish for Henry Hub-area pricing.
Reroute: None: this notice directly curtails feed gas deliveries to Freeport LNG at the terminal delivery meter; there is no alternative pipeline pathway that replaces LNG offtake once the customer fails to take at the terminal.
Force Majeure0.395 Bcf/d cut (capped at 0.930 Bcf/d)Until Further Notice29 Days
ANR Pipeline has extended its Force Majeure at St. John Eastbound (LOC #FPSTJNEB) on the Michigan Leg South through October 31, 2026, pushed back from the prior end date of October 19. The FM was originally declared on October 3 due to an anomaly between MLV 56 and MLV 57, reducing eastbound capacity by 395 MMcf/d (0.395 Bcf/d), leaving 930 MMcf/d available. Firm Primary curtailments of approximately 34% of contracted MDQ remain in effect, with RCC eligibility active under ANR Tariff Section 6.36.
ANR FM at St. John Eastbound removes 0.395 Bcf/d of Michigan Leg South eastbound capacity through Oct 31 (extended from Oct 19); live data shows 0.977 Bcf/d operating capacity with 0.642 Bcf/d scheduled on TD1 against the 0.930 Bcf/d post-FM ceiling, consistent with the stated constraint, and pre-event flow averaged ~0.67 Bcf/d (0.60-0.77 range) on TD1 -- the 0.930 Bcf/d cap sits above recent scheduled flow but well below normal operating capacity, with firm primary shippers taking a ~34% MDQ curtailment signaling real tightness at ANR ML 7 Michigan delivery points.
Reroute: Limited: TETCO, TGT, and PEPL serve overlapping Midwest/Michigan markets but ANR Michigan Leg South is a specific geographic corridor; partial reroute may be possible via TETCO or PEPL for some Michigan deliveries but full offset is unlikely given the firm primary curtailment level.
TCO has issued a revision to its October 14, 2026 force majeure on MXP Line-100 in West Virginia, originally triggered by a detected leak near the Saunders Creek Regulator Station (a separate event from the September 24 force majeure on the same line). As of this update, MXPSEG remains at zero total capacity, with firm service impact estimated at 1.9 MMDth/day; TCO is estimating a return to service for Gas Day Saturday October 17, 2026, though the timeline is subject to change and Timely/Evening Cycle nominations for October 17 are likely to be impacted. The force majeure and capacity elimination remain fully in effect, and RCC eligibility requires 10 or more consecutive days of firm curtailment.
TCO force majeure on MXPSEG remains at zero total capacity with 1.9 Bcf/d of estimated firm service impact; targeted return is October 17 but is not guaranteed, keeping bearish pressure on Columbia Appalachia basis and mildly bearish pressure on Dominion South and TETCO M2 through at least the weekend gas days.
Reroute: Limited to moderate: TETCO (monitored) and Equitrans serve overlapping Appalachian markets, but TCO MXPSEG is very high capacity and 1.9 Bcf/d of stranded firm volumes cannot be fully absorbed by competing pipes without significant basis pressure at Columbia Appalachia pool.
Maintenance0.400 Bcf/d cut (capped at 1.530 Bcf/d)Until Further Notice6 Days
CTPL 2026 Q4 maintenance summary (updated 10/15/26) bundles two jobs at Gillis Compressor Station. The highest-impact job is Job 2026115, a 6-day Station Upgrade (11/12-11/18/2026) that reduces available capacity to zero transport impact (0 Dths transport impact) with available capacity of 1,530,000 Dths and a TETCO (CT109413) meter capacity limit set to 0, effectively cutting one feed interconnect entirely. The lesser job, 2026114, is a 15-hour compressor maintenance event (11/17/2026) with a 400,000 Dth/day transport impact and 1,130,000 Dths available capacity.
Job 2026115 Station Upgrade at Gillis Compressor Station (11/12-11/18, 6 days) sets TETCO CT109413 meter limit to zero and posts zero transport impact Dths with 1.530 Bcf/d available capacity, reducing feedgas flexibility at Sabine Pass LNG and applying bearish pressure on Henry Hub as export throughput is constrained during the upgrade window.
Reroute: None: Sabine Pass LNG is the delivery endpoint; no alternative pipeline can substitute for LNG feedgas curtailed at the Gillis terminal interconnect during the station upgrade.
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Florida Gas Transmission
[Florida Gas Transmission] [Planned Service Outage] NOVEMBER 2026 --- FGT WESTERN DIVISION AND MARKET AREA MAINTENANCE
Capacity Constraintcapped at 0.805 Bcf/d, cut unknown
Ruby Pipeline is issuing Update #3 to the Roberson Compressor Station operational issue first posted October 14, 2025 (Notice ID 13046). Effective Evening Cycle Gas Day October 19 and ID3 cycle October 19, 2026, and until further notice, Ruby will schedule Segment 20 to a cap of 0.805 Bcf/d. At this cap level, secondary firm and ITS/AOR service classes are at risk of not being scheduled.
Ruby Seg 20 capped at 0.805 Bcf/d UFN with secondary firm and ITS/AOR at risk; bullish SoCal Border and Pacific Northwest as Opal-to-Malin westbound capacity remains constrained with no reroute alternative for California-bound volumes.
Reroute: Limited: Northwest Pipeline provides some alternative for Pacific Northwest deliveries, but no comparable westbound Rockies-to-California alternative exists to replace Ruby volumes; EPNG and Kern River serve California from the south/east but do not substitute for Opal-originating supply on the same path.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Tennessee Gas Pipeline (TGP)
FORCE MAJEURE MLV 313 (HC LINE) RESOLVED
SEV 1/5
lifted ✓Restoration10 Days
Tennessee Gas Pipeline has resolved the force majeure declared October 6, 2026 on the HC Line between valve sections MLV 313A-403 and 313A-404 just south of Avoca, New York (Segment 399 FH, Zone 4 End). Repairs to the discovered anomaly are complete and the area is returning to normal operations effective Timely Cycle for gas day October 16, 2026. Meters 412803 TGP Gravel Run and 421068 TGP Wyckoff Storage will also accept nominations up to meter capacity; this is the final update for the outage.
TGP HC Line force majeure south of Avoca, NY is fully resolved as of October 16 gas day Timely Cycle -- no capacity constraint remains and any Zone 4 Northeast basis premium attributable to this event should unwind.
Reroute: High: constraint is resolved; no reroute analysis required. Prior to resolution, limited reroute existed given TGP and Transco are the two dominant Northeast pipes, but that is now moot.
