Every notice, by week
The month’s most market-relevant notices, highest severity first. Routine postings (severity 1–3) are on the week pages.
Columbia Gas Transmission (TCO)
UPDATE: Force Majeure – MXP Line
SEV 5/5
Force Majeure
1.800 Bcf/d
Until Further Notice
TCO declared force majeure on MXP Line-100 in West Virginia following detection of a gas leak at the Saunders Creek Regulator Station on September 24, 2026. As of September 25, 2026, MXPSEG MA42 is reduced to zero total capacity, eliminating an estimated 1.8 Bcf/d of firm service through this internal constraint; the outage is expected to persist at minimum through the weekend gas days September 26-28, with restoration timing still 'until further notice.' Live capacity data confirms TM MXP MA42 (loc_id TMMXP) is posting 0 Bcf/d scheduled against 0.500 Bcf/d operating capacity, consistent with the constraint being upstream of that delivery metering point, though the notice-stated firm impact of 1.8 Bcf/d is the controlling figure.
TCO force majeure on MXP Line-100 eliminates 1.8 Bcf/d of firm throughput through MXPSEG with no firm restoration date; expect significant bullish pressure on Dominion South and TETCO M2 basis as Appalachian supply is stranded, with downstream Mid-Atlantic and Midwest markets tightening -- Columbia Gas Appalachian basis was already at -0.795 vs HH on 2026-09-24 and is likely to narrow sharply or flip positive given the scale of firm curtailment.
Reroute: Limited: TETCO (monitored) and TCO itself are the primary Appalachian corridor pipes; at 1.8 Bcf/d of firm curtailment, competing capacity on TETCO M2 and Rover is unlikely to absorb the full volume, and any available headroom will clear at a premium basis.
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Columbia Gas Transmission (TCO)
SEV 5/5
Force Majeure
1.800 Bcf/d
Until Further Notice
TCO has declared a Force Majeure on MXP Line-100 in West Virginia following detection of a leak at the Saunders Creek Regulator Station on September 24, 2026. Effective the Timely Cycle for Gas Day September 25, 2026, MXPSEG is reduced to zero total capacity with an estimated firm service impact of 1.8 MMDth/d (1.8 Bcf/d); the Force Majeure remains in effect until further notice with no restoration timeline provided. This is Revision 1 (superseding prior notice 26276009), but it meets escalation trigger criteria -- force majeure active, firm service eliminated at 1.8 Bcf/d scale, and 'until further notice' duration -- and must be scored as a fresh high-severity event.
TCO force majeure eliminates 1.800 Bcf/d of MXPSEG firm capacity until further notice; live capacity data confirms MXPSEG MA42 (loc MXPSEG) posted at 0 Bcf/d operating capacity with 1.84 Bcf/d scheduled and flagged NON-FIRM-RESTRICTED as of the timely cycle 2026-09-24, fully corroborating the notice -- expect sharp bullish pressure at Dominion South and Columbia Gas Appalachia basis (most recently -1.505 vs HH on 2026-09-23, likely to tighten significantly) and spillover bullish pressure at TETCO M2 and Transco Zone 4 as Appalachian supply backs out of downstream Mid-Atlantic and Midwest markets.
Reroute: Limited to moderate: TETCO (monitored) and Equitrans serve overlapping Appalachian markets and provide some partial reroute potential, but TCO is a very high-capacity system and a 1.8 Bcf/d firm-service loss at a single internal constraint is extremely difficult to fully offset; no restoration timeline increases the duration risk significantly.
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TransColorado Gas Transmission
SEV 4/5
Force Majeure
0.080 Bcf/d
TransColorado Gas Transmission has declared a force majeure on Segment 310 at the Blanco Compressor Station effective September 30, 2026 Cycle 5 (Intraday 3), following a jacket water coupling failure on Unit #2. Operational capacity through the Segment 310_BLANCO_COMPRESSOR_BH TD2 constraint is reduced from 260,000 Dth/d to 180,000 Dth/d (a loss of 80,000 Dth/d, or 0.080 Bcf/d), with restoration until further notice. TC has indicated it will post an updated maintenance notice reflecting the total impact.
Force majeure removes 0.080 Bcf/d of TransColorado takeaway capacity from the San Juan/Piceance Basin with no restoration timeline; expect mild bearish pressure at CIG/Rockies and White River Hub regional basis, which was already averaging -0.609 vs Henry Hub over the five trading days ended 2026-09-25 (most recently -0.720 on September 25) -- the notice effective date falls after that pricing window so traders should monitor for further basis softening.
Reroute: Limited: Colorado Interstate Gas (CIG) and Wyoming Interstate (WICD) serve overlapping Rockies areas and provide some alternative egress from the Piceance and San Juan basins, but spare capacity availability is uncertain and cannot fully offset a UFN force majeure constraint.
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Force Majeure
Until Further Notice
5 Days
Transco declared a Force Majeure event on 9/28/2026 due to integrity concerns on piping at the Guillory M3681 Meter Station (loc 9013263, Receipt, MP 473.5). The location was immediately restricted to zero scheduled capacity effective ID3 gas day 9/28/2026, with anticipated return to service October 3, 2026 -- a five-day outage. This is a revision superseding prior notice 17328542, with the key new information being the October 3 anticipated return-to-service date.
Transco FM at Guillory M3681 receipt meter eliminates scheduling capacity at this Gulf Coast receipt point through October 2; live capacity data confirms 0 Bcf/d operating and scheduled at loc 9013263 (evening cycle 9/30), corroborating the outage, with bullish implications for Transco Zone 4 basis as Gulf Coast receipt supply is curtailed; no volume stated in the notice so system-wide impact depends on typical throughput at this meter.
Reroute: Limited to moderate: Transco is the dominant Southeast-to-Northeast pipeline and producers with access to alternative interconnects (Gulf South, CGT, TETCO) may be able to reroute volumes, but the specific meter restriction at Guillory M3681 eliminates that receipt point entirely for its contracted shippers.
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Compressor Issue
1.094 Bcf/d
REX Update #18 confirms Segment 250 (West-to-East) remains restricted to 1.094 Bcf/d at Bertrand Compressor Station effective Gas Day October 1, 2026, until further notice. At this restriction level, primary firm, secondary firm, and ITS/AOR quantities are all at risk of not being scheduled. No restoration timeline has been provided across 18 updates, and this is a fresh notice (Revision 1) posted September 30, 2026.
REX Segment 250 W-to-E cap of 1.094 Bcf/d with primary firm at risk is a sustained, material Rockies-to-Midwest constraint; expect bullish pressure at Lebanon Hub and Midwest delivery points, and note that Trailblazer shares Bertrand CS and cannot serve as an independent reroute, leaving no effective bypass for the affected volumes.
Reroute: None: REX and Trailblazer share Bertrand Compressor Station -- both are simultaneously constrained by the same facility, so Trailblazer cannot serve as an independent reroute for REX Segment 250 flows.
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Force Majeure
0.236 Bcf/d
Until Further Notice
Transco declared force majeure on 9/28/2026 due to a Variable Frequency Drive failure on Main Unit 9 at Compressor Station 50 (MP 517.23), restricting south-to-north mainline flows effective timely gas day 9/29/2026. The TSB at MP 517 shows design capacity of 1.536 Bcf/d with total available quantity of 1.300 Bcf/d, representing a 0.236 Bcf/d reduction (approximately 15% of design capacity) with 5-12% cuts to primary firm service. Repairs are underway and expected to be completed by end of week, but no firm restoration date is given and duration remains UFN.
Transco Station 50 force majeure removes approximately 0.236 Bcf/d of south-to-north mainline capacity with 5-12% primary firm cuts, supportive of Transco Zone 4 and downstream zone basis widening vs Henry Hub; monitor CS 60 (already at 100% utilization per live data) and CS 65 South (81.5% loaded) as downstream choke points that could amplify impact if repairs extend beyond week-end.
Reroute: Limited: Transco is the dominant pipeline in the Southeast-to-Northeast corridor; Southern Natural Gas provides partial real-world alternative capacity in the Southeast but is unmonitored and cannot be confirmed available. Tennessee Gas Pipeline serves overlapping Northeast markets but cannot fully offset a Transco mainline constraint at this scale.
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Transco
Update - Notice of Force Majeure Event - Unplanned Outage – Guillory M3681 Meter Station 2026
SEV 4/5
Force Majeure
Until Further Notice
Transco declared a force majeure on 9/28/2026 due to integrity concerns on piping at the Guillory M3681 Meter Station (loc 9013263, receipt point, MP 473.5), effective ID3 gas day 9/28. Total available capacity at this receipt point has been zeroed out (EPSQ/0), and the location is unavailable for scheduling or flow until further notice. Repair work is underway with no restoration timeline posted; an updated timeline will follow when available.
Transco receipt FM at Guillory M3681 removes this Gulf Coast receipt point from scheduling UFN with zero available capacity confirmed in live data (loc 9013263 showing 0 Bcf/d operating capacity, 0.015 Bcf/d still scheduled vs-design flag); with Zone 4, Zone 5, and Zone 6 segment headroom already at 0% in today's intraday cycle, any reduction in Gulf Coast receipts adds incremental bullish pressure to Transco Zone 4 and downstream Southeast basis.
Reroute: Moderate: Transco serves Gulf Coast-to-Southeast flows alongside Southern Natural Gas (SNG, unmonitored) and Tennessee Gas Pipeline; shippers at this specific receipt meter have no bypass at this location, but alternative receipt points on Transco and competing pipes may partially offset lost supply. However, with Zone 4 and Zone 5 segment headroom already at 0% today, absorbing rerouted volumes on Transco itself is constrained.
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Force Majeure
0.321 Bcf/d
Until Further Notice
Transco has declared a force majeure event at the Guillory M3681 Receipt Meter Station (Location ID 9013263, MP 473.5) effective ID3 gas day 9/28/2026 through at least the Evening cycle of 9/29/2026 due to equipment failure. The station is unavailable for scheduling or flow until further notice, with no restoration date provided. Live capacity data from intraday 2 on 9/28 showed 0.321 Bcf/d scheduled at this receipt point against 1.03 Bcf/d operating capacity, so the curtailed volume is approximately 0.321 Bcf/d; however, that reading predates the event and current scheduled quantities are now effectively zero per the notice.
Transco force majeure at Guillory M3681 (MP 473.5, Zone 4 corridor) removes approximately 0.321 Bcf/d of receipt capacity until further notice -- expect mild bullish pressure at Transco Zone 4 basis, with limited broader HH signal given the localized receipt-point nature of the outage; mainline segments remain largely unconstrained at this time but the UFN duration warrants monitoring.
Reroute: Limited: as a receipt meter station on Transco, the reroute option is for upstream shippers to redirect gas to alternative Transco receipt points or competing pipelines (Gulf South, CGT) serving this Louisiana corridor, but those arrangements require operational changes and may not fully replace scheduled quantities on short notice.
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Columbia Gulf Transmission (CGT)
SEV 4/5
Maintenance
0.100 Bcf/d
4 Days
CGT has notified customers of planned maintenance at Lake Arthur Compressor Station from October 6-9, 2026, which will reduce backhaul delivery capacity at location 4246 (Cameron LNG) from 800,000 Dth/d (design) to 700,000 Dth/d -- a restriction of 100,000 Dth/d (0.100 Bcf/d). CGT explicitly warns that curtailments to Interruptible, Secondary Firm, and Primary Firm services are anticipated, and RCC provisions have been triggered. The four-day event directly reduces feed gas deliveries to Cameron LNG, an active LNG export terminal.
CGT maintenance at Lake Arthur restricts Cameron LNG feed gas deliveries by 0.100 Bcf/d (from 0.800 to 0.700 Bcf/d) across Oct 6-9; live capacity data confirms Cameron LNG (loc 4246, BD:DPQ:FTS-1) currently scheduled at 0.669 Bcf/d against 0.800 Bcf/d operating capacity, consistent with the constraint -- reduced LNG export pull is bearish Henry Hub and Columbia Gulf mainline basis, which has most recently traded at -0.475 vs HH (2026-09-25).
Reroute: Limited: Cameron LNG feed gas supply is delivered via CGT's backhaul path and there are no immediate pipeline alternatives that can directly substitute for the curtailed CGT delivery into this terminal; partial offsetting supply may be available from other feed gas pipelines interconnecting Cameron LNG, but the firm service curtailment risk limits full reroute.
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Natural Gas Pipeline (NGPL)
SEV 4/5
Force Majeure
NGPL has declared a force majeure due to a unit outage at Compressor Station 302 (CS 302) in Montgomery County, Texas, on Segment 25 of the Texok Zone. Effective the evening cycle of September 29, 2026, and continuing until further notice, eastbound capacity through CS 302 is reduced, limiting throughput from Segments 26 and 22 into Segment 25. Primary Firm and Secondary in-path Firm transports will be scheduled to no less than 80% of contract MDQ; AOR/ITS and Secondary out-of-path Firm are eliminated for the duration.
NGPL CS 302 force majeure curtails eastbound Texok Zone capacity to 80% of contracted MDQ (with out-of-path firm eliminated entirely) effective Sep 29 evening cycle until further notice -- expect bullish pressure at Chicago Citygate and widening NGPL Midcontinent basis, which most recently traded at -0.645 vs Henry Hub on Sep 25; the no-restoration-timeline and firm-service impact support continued basis widening.
Reroute: Moderate: ANR, PEPL, and TETCO serve overlapping Gulf Coast-to-Midwest corridors and could absorb some displaced volumes, but NGPL is one of the highest-throughput Midwest pipelines and a sustained eastbound constraint here is difficult to fully offset across competing systems.
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Columbia Gulf Transmission (CGT)
SEV 4/5
Maintenance
0.345 Bcf/d
14 Days
CGT has issued a critical maintenance notice for Mainline 100, effective October 6-19, 2026 (14 days). Backhaul capacity through ClemSEG will be reduced to 1,950,000-2,050,000 Dth/day against a design capacity of 2,344,656 Dth/day, a reduction of approximately 295,000-395,000 Dth/day (~0.295-0.395 Bcf/d). Separately, the Tetco/Adair Co., Ky receipt interconnect (MS 3194) will be reduced to 0-50,000 Dth/day against a design of 207,517 Dth/day, representing a near-complete curtailment of that interconnect. CGT explicitly warns of potential curtailments to Interruptible, Secondary Firm, and Primary Firm services.
CGT Mainline 100 maintenance removes up to ~0.345 Bcf/d of backhaul capacity through ClemSEG (currently running at 83.9% utilization, 1.97 Bcf/d scheduled of 2.34 Bcf/d operating capacity per timely cycle 2026-09-28) and effectively zeros the Tetco/Adair Ky receipt (3194, currently 96.4% utilized at 0.200 Bcf/d), with primary firm curtailments explicitly at risk -- expect bullish pressure on Transco Zone 4 and CGT mainline basis vs Henry Hub; Columbia Gulf mainline basis most recently -0.475 vs HH on 2026-09-25, with a 5-day average of -0.347, and this constraint should narrow that discount.
Reroute: Moderate: TETCO and Trunkline (TGC) serve overlapping Gulf Coast northbound corridors, but with the Tetco/Adair Ky receipt effectively curtailed, TETCO's own receipt capacity from CGT at that interconnect is simultaneously impacted, limiting the typical reroute option at that junction. Partial reroute via ANR and CGT alternate paths may absorb some volume but is unlikely to fully offset primary firm curtailments.
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Force Majeure
0.236 Bcf/d
Until Further Notice
Transco has declared a force majeure event due to an unplanned equipment failure on Main Unit 9 at Compressor Station 50 (MP 517.23), effective timely gas day 9/29/2026 with no end date provided. The outage restricts south-to-north mainline flows through the TSB at MP 517, reducing total available capacity from 1,536 Mdt/d design capacity to 1,300 Mdt/d available -- a loss of approximately 236 MMdt/d (0.236 Bcf/d) -- with primary firm shippers facing potential cuts of 5-12% based on historical utilization. An updated posting with an estimated return-to-service date is expected no later than September 30, 2026.
Transco CS 50 force majeure removes approximately 0.236 Bcf/d of south-to-north mainline capacity effective 9/29 UFN, expect bullish pressure at Transco Zone 4 and Zone 5/6 as northbound supply tightens, with primary firm shippers at 5-12% cut risk and no restoration timeline yet available.
Reroute: Limited: Transco is the dominant south-to-north mainline in this corridor; Southern Natural Gas (not monitored for live conditions) provides partial Southeast alternative capacity but cannot fully replace Transco mainline throughput for Mid-Atlantic and Northeast deliveries. Tennessee Gas Pipeline offers some competing capacity for Northeast markets but is unlikely to absorb the full constraint volume.
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El Paso Natural Gas (EPNG)
SEV 4/5
Force Majeure
0.171 Bcf/d
1 Days
EPNG has declared force majeure at Seligman C Compressor Station in Yavapai County, Arizona, following a dry seal failure that has taken the station offline pending repairs. Operational capacity through the NORTH ML constraint is reduced by an additional 170,521 Dth/d (0.171 Bcf/d) effective September 27, 2026 Intraday 1 Cycle (Cycle 3). EPNG will issue an updated maintenance notice to reflect the total combined impact at the NORTH ML constraint; the stated end date is September 28, 2026 at 9:00 AM, though repair timeline remains uncertain.
EPNG force majeure at Seligman C removes an additional 0.171 Bcf/d of westbound NORTH ML capacity; expect bearish pressure at Waha as Permian takeaway tightens further, with corresponding bullish pressure at SoCal Border and Arizona delivery points -- note EPNG has flagged a forthcoming updated maintenance notice that may quantify a larger total NORTH ML impact.
Reroute: Moderate: Transwestern Pipeline (TW) is the primary competing pipeline for SoCal border deliveries and provides the main alternative westbound corridor; however, any pre-existing TW constraints would eliminate reroute options entirely for California-bound volumes.
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Columbia Gas Transmission (TCO)
SEV 4/5
lifted ✓
Restoration
1.800 Bcf/d
Until Further Notice
3 Days
TCO has lifted the Force Majeure on MXP Line-100 in West Virginia, effective Intraday 1 Cycle for Gas Day September 27, 2026 (with Timely Cycle restoration for September 28, 2026), reinstating full capacity through the MXPSEG MA42 internal constraint. The original force majeure was declared September 24, 2026 following detection of a leak at the Saunders Creek Regulator Station, which had reduced MXPSEG to zero total capacity and impacted an estimated 1.8 MMDth/day of firm service. The FM was active for approximately three gas days (September 24-27) before being lifted.
Restoration of 1.8 Bcf/d of MXPSEG capacity is bearish for Appalachian basis -- Columbia Gas Appalachia basis was trading at -1.060 vs Henry Hub as of September 25; expect that discount to widen modestly as previously backed-up Appalachian supply is released back into TCO downstream markets including TETCO M2 and Mid-Atlantic points.
Reroute: Moderate: Texas Eastern (TETCO, monitored) and Equitrans serve overlapping Appalachian markets; Transco provides partial Mid-Atlantic alternative. The original 1.8 Bcf/d firm impact was too large to fully offset on alternatives, so the restoration is fully market-moving.
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Force Majeure
0.186 Bcf/d
Until Further Notice
10 Days
ANR Pipeline has declared a Force Majeure event on the Southwest Mainline Northbound due to a pipeline leak between MLV 22-23 just downstream of Havensville Compressor Station in Pottawatomie County, Kansas. Effective 9/26 intraday with no incremental volumes scheduled, and from 9/27 through 10/5 the SWML Northbound (LOC #226630) is limited to 520 MMcf/d (0.520 Bcf/d), reducing capacity by 186 MMcf/d (0.186 Bcf/d). ANR anticipates Firm Primary curtailments of approximately 6% of current net nominations and 31% of contracted MDQ.
ANR SWML Northbound force majeure removes 0.186 Bcf/d of northbound Gulf Coast-to-Midwest capacity through 10/5, with firm primary curtailments confirmed at up to 31% of contracted MDQ; expect bullish pressure at ANR ML 7 and Midwest delivery points versus Henry Hub, with the live SWML Northbound reading (0.553 Bcf/d scheduled against 0.615 Bcf/d operating capacity, 10.1% headroom) likely to tighten further as the restriction takes full effect.
Reroute: Moderate: TETCO, Trunkline (TGC), and Southern Natural (EGT) serve overlapping Gulf Coast-to-Midwest corridors and may absorb some displaced volumes, but with DEFIANCE WESTBOUND and LAGRANGE WESTBOUND already flagged OVER on the ANR system today, downstream congestion limits the effective reroute offset.
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Capacity Constraint
Until Further Notice
Cove Point LNG (CPL) has posted a critical capacity constraint notice effective 2026-09-26 at 23:00, classified as a PPO (Periodic Pressure Obligation) restriction. No specific volume impact is stated in the notice text. Live capacity data shows COVE POINT PLANT (SI:SIQ) at only 0.015 Bcf/d scheduled against 1.80 Bcf/d operating capacity, indicating feed gas nominations are already extremely depressed -- well below normal LNG export operating rates. The effective date is current so this is not a legacy repost.
Cove Point LNG restrictions remove feed gas demand from Appalachian supply; bearish for Appalachian/Mid-Atlantic basis -- Eastern Gas South regional proxy has averaged -1.775 vs HH over the five trading days ended 2026-09-25, most recently -2.485 on 2026-09-25, and curtailed LNG export demand will pressure this spread further; no specific curtailed volume stated but COVE POINT PLANT (loc 10001, SI:SIQ) shows only 0.015 Bcf/d scheduled against 1.80 Bcf/d capacity as of 2026-09-26 evening cycle.
Reroute: Not applicable -- this is an LNG export terminal restriction, not a pipeline constraint; gas that cannot be exported remains in the domestic Appalachian/Mid-Atlantic market, adding supply rather than requiring reroute.
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El Paso Natural Gas (EPNG)
SEV 4/5
Force Majeure
0.313 Bcf/d
1 Days
EPNG has declared Force Majeure at El Paso C Compressor Station in El Paso County, Texas, due to a high bearing vibration issue. This Update #1 (superseding Notice 629747) escalates the total operational capacity reduction to 312,889 Dth/d (0.313 Bcf/d) effective September 26, 2026 Timely Cycle, an increase of 106,417 Dth/d from the prior notice. The force majeure is expected to remain in effect through September 26, 2026 at 9:00 AM, with repairs ongoing.
EPNG FM at El Paso C Station escalates total westbound capacity reduction to 0.313 Bcf/d; expect bearish pressure at Waha as Permian takeaway is further curtailed, with bullish pressure at SoCal Border and Arizona delivery points where westbound supply tightens.
Reroute: Moderate: Transwestern Pipeline (TW) is the primary competing pipeline serving SoCal border and Arizona delivery points; however, depending on TW utilization, partial reroute may be available but is unlikely to fully offset 0.313 Bcf/d of westbound EPNG capacity loss.
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Force Majeure
1.403 Bcf/d
Until Further Notice
10 Days
ANR Pipeline has declared a Force Majeure at Patterson Compressor Station (Unit 1) in Jefferson Parish, Louisiana due to an unexpected equipment failure, effective September 25, 2026 through October 4, 2026. The outage reduces capacity across multiple interconnects including Shadyside/TGP (443 MMcf/d curtailed, leaving 30 MMcf/d), Weeks ISLA/LIG PL (260 MMcf/d curtailed), Patterson to Col Gulf (143 MMcf/d curtailed, leaving 0 MMcf/d), Shadyside/Sonat (281 MMcf/d curtailed), and others, totaling approximately 1.403 Bcf/d of combined capacity reductions across listed locations. ANR has flagged RCC eligibility per Tariff Section 6.36 if primary firm service cannot be scheduled.
ANR Patterson FM removes approximately 1.403 Bcf/d of aggregate Gulf Coast northbound/interconnect capacity through Oct 4, with Patterson to Col Gulf reduced to zero and Shadyside/TGP slashed from ~473 to 30 MMcf/d; expect bullish pressure at ANR La. and Midwest delivery basis while Henry Hub and Gulf Coast onshore basis softens as northbound takeaway tightens.
Reroute: Moderate: TETCO (monitored), Trunkline/TGC (monitored), and CGT (monitored) serve overlapping Gulf Coast northbound corridors, but the scale of reductions across multiple interconnects -- particularly Patterson to Col Gulf zeroed out and Shadyside/TGP cut to 30 MMcf/d -- will stress available alternative capacity and may not fully offset firm service impacts.
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Northern Border Pipeline (NBPL)
SEV 4/5
Force Majeure
0.378 Bcf/d
Until Further Notice
Northern Border Pipeline declared force majeure effective September 26, 2026 due to an unplanned equipment failure at Compressor Station 11 (CS11) near Estelline. As a result, NBPL is restricting nominated volumes for Flow Past Glen Ullin (GlenSEG) to 2,152 MMcf/d (2.152 Bcf/d) effective timely September 26, continuing until further notice. Prior to the restriction, GlenSEG was running at 99.8% utilization (2.52 Bcf/d scheduled against 2.53 Bcf/d operating capacity), implying a capacity reduction of approximately 0.378 Bcf/d from current scheduled flows.
NBPL force majeure at CS11 imposes a 2.152 Bcf/d cap at GlenSEG -- cutting roughly 0.378 Bcf/d from current timely-cycle nominations of 2.52 Bcf/d -- with no restoration timeline; expect bullish pressure at Northern Border Ventura TP (most recently -0.435 vs Henry Hub on 2026-09-24, trailing 5-day average -0.476) and at Chicago Citygate as Canadian/Bakken supply into the Midwest is curtailed.
Reroute: Limited: Alliance Pipeline (not monitored) provides an alternative Canadian import corridor into Chicago, but volumes are typically fully subscribed and cannot be expected to absorb a sudden 0.378 Bcf/d diversion; no other large-diameter pipe replicates NBPL's Western Canada/Bakken-to-Midwest flow path.
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Columbia Gas Transmission (TCO)
SEV 4/5
Force Majeure
0.550 Bcf/d
Until Further Notice
DT Midstream (DTM) has declared a Force Majeure at the Stonewall Gas Gathering (SGG) TCO West Braxton delivery meter (#842867), which feeds Columbia Gas Transmission (TCO). Effective 9/26/2026 Timely cycle, DTM is revising the FM upward: maximum capacity at the meter increases from 400,000 Dth/d to 550,000 Dth/d (0.550 Bcf/d), until further notice, with no estimated return to full normal capacity. The prior restriction beginning 9/23/2026 had reduced the meter to 400,000 Dth/d; this revision partially restores but does not eliminate the constraint.
DTM FM at Braxton (meter 842867) restricts TCO receipts to 0.550 Bcf/d until further notice -- live data shows the meter operating at 1.50 Bcf/d capacity with only 0.400 Bcf/d scheduled as of 9/25 Timely, but the new FM cap of 0.550 Bcf/d limits upside; Columbia Gas Appalachia basis, recently at -0.795 vs HH (most recent day 2026-09-24), faces upward pressure as Appalachian supply into TCO remains force-majeure constrained with no restoration timeline.
Reroute: Moderate: TCO interconnects with TETCO (monitored) and Equitrans (not monitored) in Appalachia, offering partial alternative routing for Marcellus/Utica producers, but the constraint is at the gathering level (DTM Stonewall SGG) and cannot be bypassed by upstream producers without alternative gathering infrastructure.
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El Paso Natural Gas (EPNG)
SEV 4/5
Force Majeure
0.206 Bcf/d
1 Days
EPNG has declared force majeure at the El Paso C Compressor Station in El Paso County, Texas, due to a high bearing vibration issue requiring repairs. Operational capacity through the ELPASO C and associated constraints is reduced by 206,472 Dth/d (0.206 Bcf/d) effective September 25, 2026 Timely Cycle. The outage window runs through September 25 at 9:00 AM, though EPNG notes it is evaluating repair options and will post an updated maintenance notice reflecting the full impact.
EPNG force majeure at El Paso C removes 0.206 Bcf/d of westbound throughput capacity; expect bearish pressure at Waha/Permian as basin takeaway tightens and mild bullish pressure at SoCal Border and Arizona delivery points, with the short stated duration (sub-24 hours) limiting broader market impact unless repairs extend beyond the September 25 restoration window.
Reroute: Moderate: Transwestern Pipeline (TW) serves overlapping SoCal border and Arizona markets and may absorb some displaced volumes, though simultaneous TW constraints would eliminate this option entirely.
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Capacity Constraint
Until Further Notice
Cove Point LNG (CPL) has posted a Critical capacity constraint notice titled 'Cove Point Restrictions Update' effective 2026-09-24, classified as a PPO (Planned Partial Outage) under the pipeline's own notice taxonomy. No specific capacity volume or duration is stated in the notice text. Live capacity data for gas day 2026-09-24 (evening cycle) shows Cove Point Plant feed gas receipts (SI:SIQ, loc 10001) scheduled at only 0.015 Bcf/d against 1.80 Bcf/d operating capacity -- a near-total curtailment of LNG feedgas relative to design throughput. The LNG feedgas severity floor applies as this is a named Cove Point LNG terminal notice.
Cove Point LNG feedgas is running at approximately 0.015 Bcf/d versus a 1.80 Bcf/d operating capacity as of the 2026-09-24 evening cycle, indicating a near-complete feedgas curtailment that removes up to ~1.8 Bcf/d of LNG export demand from the Appalachian supply stack -- bearish for Appalachian basis (Eastern Gas South regional proxy most recently at -1.580 vs HH on 2026-09-23) and bearish for the LNG export arbitrage, as stranded volumes remain in the domestic market.
Reroute: Not applicable -- Cove Point is an LNG export terminal; gas that cannot be liquefied stays in the domestic pipeline system and increases onshore supply rather than being rerouted.
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Columbia Gas Transmission (TCO)
SEV 4/5
Force Majeure
1.800 Bcf/d
Until Further Notice
TCO has declared a Force Majeure effective Gas Day September 24, 2026 (Intraday 1 cycle) due to an unexpected mechanical issue on MXP Line-100 between Mt. Olive Compressor Station and Saunders Creek Regulator Station in West Virginia. Effective the Timely Cycle for September 25, 2026, and until further notice, the MXPSEG MA42 internal constraint is reduced to zero total capacity, with estimated firm service impact of 1.8 MMDth/day. TCO targets an update by Friday morning, September 25, with no restoration timeline currently committed.
TCO force majeure on MXPSEG MA42 eliminates 1.8 Bcf/d of scheduled firm capacity from Gas Day September 25 until further notice; the live capacity table confirms MXPSEG (loc_id MXPSEG) is already posted at 0 Bcf/d operating capacity with 1.84 Bcf/d scheduled and flagged NON-FIRM-RESTRICTED, corroborating the impact; Columbia Gas Appalachia basis has been running at approximately -1.505 vs Henry Hub (as of 2026-09-23) and is likely to tighten sharply as Marcellus/Utica supply is stranded within the MA42 market area until the line is restored.
Reroute: Limited: TCO is a high-capacity Appalachian system and TETCO M2, TCO, and Equitrans serve overlapping markets, but the 1.8 Bcf/d firm impact on an internal constraint (MXPSEG MA42) is large relative to available spare capacity on competing pipes; partial reroute via TETCO (monitored) is possible but unlikely to absorb the full volume on short notice.
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Operational Alert
0.180 Bcf/d
Until Further Notice
Northwest Pipeline has issued an OFO Recall Advisory and Operational Flow Order at the Chehalis compressor effective Gas Day September 24, 2026, and until further notice. Southbound operationally available capacity is constrained to 492,000 Dth/d (0.492 Bcf/d) versus design capacity of 672,000 Dth/d (0.672 Bcf/d), a reduction of approximately 0.180 Bcf/d. Live capacity data confirms the Chehalis Compressor DECREASING point is flagged OVER at 132.9% utilization (0.654 Bcf/d scheduled against 0.492 Bcf/d operating capacity), corroborating the constraint in real time.
NWP OFO at Chehalis reduces southbound operationally available capacity by 0.180 Bcf/d (to 0.492 Bcf/d) until further notice, with the point already oversubscribed at 132.9% utilization per current EBB data; expect bullish pressure at Sumas basis, which has already softened to -0.425 vs Henry Hub most recently (5-day average -0.234), and tightening in Pacific Northwest gas markets as deficiency cuts are enforced during evening scheduling.
Reroute: Limited: Ruby Pipeline provides partial Rockies egress alternative but does not serve the same Pacific Northwest downstream markets; no pipeline directly replaces NWP southbound capacity into Washington and Oregon markets.
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El Paso Natural Gas (EPNG)
SEV 4/5
Force Majeure
8 Days
EPNG has declared force majeure at Caprock Compressor Station Unit #2 in Lea County, New Mexico, due to a second stage nozzle system cooling blockage, originally posted June 9, 2026 (Notice 628635). This is Update #2, superseding Notice 629669, with repairs ongoing and an anticipated return to service on or before October 1, 2026. The event has been active since June 9 and continues to restrict westbound Permian takeaway capacity.
Active EPNG force majeure at Caprock Unit #2 restricts Permian westbound takeaway; expect continued bearish pressure at Waha as basin gas backs up, with bullish pressure at SoCal Border and Arizona delivery points -- no concrete capacity figure stated in the notice, but the MAPL/EPNG CAPROCK PUMP delivery point (loc_id 344251) shows zero scheduled volumes against 0.005 Bcf/d operating capacity, consistent with the unit being offline.
Reroute: Moderate: Transwestern Pipeline (TW) is the primary competing pipeline for SoCal border deliveries and can absorb some displaced Permian volumes, but a simultaneous TW constraint would eliminate California reroute entirely; no alternative route exists for Waha-origin volumes needing westbound egress other than TW and EPNG.
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Maintenance
Until Further Notice
Golden Pass Pipeline LLC has posted its Annual Planned Maintenance 2025-2026 Rev 36, covering planned outages on the Sabine Pass TX to Starks LA corridor serving up to 2.6 Bcf/d of LNG export feed gas capacity. This is filed as Revision Number 1 (first issuance), posted September 22, 2026. No specific per-job capacity impact figures or individual outage durations are stated in the notice text; the actual maintenance schedule details are not provided in the available text.
Golden Pass Pipeline planned maintenance reduces LNG export feed gas availability on a system capable of up to 2.6 Bcf/d; absent per-job figures, impact is unquantified but any curtailment of Golden Pass feed gas keeps supply in the domestic market, bearish for Houston Ship Channel regional basis (most recently -0.410 vs Henry Hub as of 2026-09-21) and mildly bearish Henry Hub -- monitor GasNom EBB for per-job schedule and specific capacity restrictions.
Reroute: None: Golden Pass Pipeline is a dedicated LNG export feed gas lateral; gas not delivered to the terminal has no alternative export outlet on this system and remains in the domestic market.
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Columbia Gas Transmission (TCO)
SEV 4/5
Force Majeure
0.400 Bcf/d
Until Further Notice
DT Midstream Stonewall Gas Gathering has declared a Force Majeure at the TCO West Braxton delivery meter (842867), effective 9/23/2026 ID1 cycle, reducing maximum capacity at that meter to 400,000 Dth/d (0.400 Bcf/d) until further notice with no estimated return to normal capacity. TCO is coordinating with DTM but cannot provide a restoration timeline. The live capacity table shows Braxton (loc 842867) was posting 1.50 Bcf/d operating capacity with 0.981 Bcf/d scheduled as of the timely cycle on 9/23/2026, confirming a material reduction from the pre-event operating level to the FM-capped 0.400 Bcf/d ceiling.
DT Midstream FM at Braxton (842867) cuts TCO receipt capacity by approximately 1.1 Bcf/d from the timely-cycle scheduled level to a 0.400 Bcf/d cap with no return date; Columbia Gas Appalachia basis was already trading at -1.500 vs Henry Hub on 2026-09-21 (five-day average -1.384), and this unresolved FM curtailment of Appalachian supply into TCO is supportive of a tightening (less negative) Columbia Gas App basis, with neutral-to-mildly-bearish signal for Henry Hub as downstream Mid-Atlantic and Midwest markets lose Appalachian supply.
Reroute: Limited: TCO is a dominant Appalachian transmission system; TETCO (monitored) and Equitrans serve overlapping Appalachian markets and may absorb some displaced volume, but the 'until further notice' duration and scale of the FM at Braxton -- one of the larger receipt points on the system -- limits full offset, and no single alternative gathering system replaces Stonewall Gas Gathering's Braxton feed.
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Maintenance
0.500 Bcf/d
Until Further Notice
28 Days
Southern Star has scheduled station maintenance at Blackwell CS (loc 445511) beginning September 23, 2026 and running through October 21, 2026 -- approximately 28 days. The notice states 500,000 Dth/d (0.500 Bcf/d) of throughput at this location will be affected. Live capacity data for the evening cycle on 2026-09-22 shows Blackwell CS (loc_id 445511, R:MLQ) operating at 0.670 Bcf/d with 0.454 Bcf/d scheduled and 0.215 Bcf/d of headroom, meaning the outage represents roughly 75% of currently scheduled flow through this compressor.
Southern Star Blackwell CS maintenance removes 0.500 Bcf/d of Midcontinent throughput capacity from September 23 through October 21; Southern Star basis has been running at -0.540 vs Henry Hub most recently (2026-09-21), and this constraint on a key compressor station should pressure Midcontinent supply and support a narrowing of the Southern Star discount or shift volumes to PEPL and ANR alternatives.
Reroute: Moderate: ANR (monitored), PEPL (monitored), and TIGT (monitored) serve overlapping Midcontinent markets and can absorb some diverted Anadarko/Hugoton supply, though a 0.500 Bcf/d constraint over 28 days will likely saturate available alternate capacity on at least some days.
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Maintenance
Until Further Notice
Golden Pass Pipeline has posted its Annual Planned Maintenance 2025-2026 Rev 34 (Revision Number listed as 1, treated as a fresh notice) covering the Sabine Pass TX to Starks LA corridor, which feeds up to 2.6 Bcf/d of LNG export capacity. No specific per-job schedule, individual outage dates, capacity restriction volumes, or duration details are provided in the notice text -- the posting references planned outages without quantifying individual maintenance impacts. The LNG feedgas severity floor applies given the delivery point is Golden Pass LNG.
Golden Pass Pipeline planned maintenance affecting up to 2.6 Bcf/d of LNG export feed gas is bearish for Gulf Coast and Henry Hub as constrained LNG exports keep gas onshore; regional proxy at Houston Ship Channel has been trading at a discount to Henry Hub (most recently -0.410 on 2026-09-21, five-day average -0.428), and any reduction in Golden Pass feed gas nominations would deepen that bearish pressure on the Gulf Coast supply balance -- specific per-outage capacity impacts are unquantified in this notice.
Reroute: None: Golden Pass Pipeline is the dedicated feed gas lateral serving Golden Pass LNG at Sabine Pass, TX; there is no alternative routing for LNG export volumes at this terminal, and any maintenance-driven curtailment directly reduces feed gas available to the liquefaction trains.
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El Paso Natural Gas (EPNG)
SEV 4/5
Force Majeure
0.107 Bcf/d
1 Days
EPNG has declared force majeure at its Roswell Compressor Station in Chaves County, New Mexico following a fuel system failure. The outage reduces operational capacity through the CAPROCK N constraint by an additional 106,848 Dth/d (0.107 Bcf/d) effective September 19, 2026 Intraday 1 cycle, with restoration targeted by 9:00 AM September 20. EPNG noted this FM stacks on top of an existing maintenance constraint at CAPROCK N and will post an updated maintenance notice reflecting the total combined impact.
EPNG FM at Roswell CS removes an incremental 0.107 Bcf/d through the CAPROCK N constraint, compounding an existing maintenance restriction on the same bottleneck; expect bearish pressure at Waha as Permian/San Juan takeaway tightens further, with bullish pressure at SoCal Border and Arizona delivery points -- the short 24-hour window limits multi-day basis impact but intraday tightness at downstream points is real.
Reroute: Moderate: Transwestern Pipeline (TW) provides competing westbound capacity from the Permian and San Juan basins to SoCal border and Arizona, but cannot fully replace EPNG CAPROCK N segment capacity if the existing maintenance restriction plus this FM materially reduce total throughput; simultaneous TW constraints would eliminate reroute entirely.
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Force Majeure
1 Days
Transwestern Pipeline declared force majeure at the P-3 Compressor Station effective September 19, 2026 at 9:00 AM through September 20, 2026 at 8:59 AM -- a roughly 24-hour window. No capacity volume is stated in the notice, but TW is a primary westbound pipeline from the Permian and San Juan basins to SoCal border and Arizona markets. The force majeure designation triggers a minimum severity of 4 regardless of stated volume.
TW force majeure at P-3 Comp Sta tightens westbound takeaway from Permian and San Juan; expect bearish pressure at Waha and San Juan basis as basin gas backs up, with bullish pressure at SoCal Border and Arizona delivery points for the roughly 24-hour event window -- no capacity figure posted, so magnitude is unquantified but reroute to EPNG is the only alternative.
Reroute: Moderate: El Paso Natural Gas (EPNG) is the primary competing pipeline serving SoCal border and Arizona from the Permian Basin and can absorb some displaced volumes, but EPNG spare capacity as of the evening cycle on 2026-09-19 shows SOCAL NEEDLES at 72.3% utilized with 27.7% headroom (0.235 Bcf/d OAC), suggesting partial but not full reroute is feasible; any simultaneous EPNG constraint would eliminate California reroute entirely.
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Maintenance
Until Further Notice
Cove Point LNG is entering its annual planned maintenance outage effective 2026-09-19 at 14:00. The notice is classified as a Capacity Constraint / Critical notice by the operator but provides no specific duration or volume impact. As an LNG export terminal, any feedgas curtailment at Cove Point removes export demand from the domestic market, which is directionally bullish for Appalachian supply basis.
Cove Point annual maintenance removes LNG export demand from the Appalachian supply basin; gas that would have fed the terminal stays domestic, bearish the LNG export arb and bullish Appalachian regional basis -- the Eastern Gas South regional proxy has been trading at approximately -1.270 vs HH as of 2026-09-17 (5-day trailing average -1.317), and reduced feedgas pull from Cove Point is expected to widen that discount further; COVE POINT PLANT delivery meter (loc 10001, D:DPQ) was running at 94.4% utilization (0.868 Bcf/d scheduled against 0.920 Bcf/d operating capacity) in the 2026-09-18 evening cycle, indicating pre-maintenance throughput was near-full and the maintenance impact on nominations could be material.
Reroute: None: Cove Point is the sole LNG export terminal served by this system; there is no alternate delivery point for LNG export volumes, though gas volumes displaced from feedgas can be absorbed by the broader Appalachian/Mid-Atlantic grid via EGTS, Transco, and TCO interconnects.
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Force Majeure
0.088 Bcf/d
4 Days
Transwestern Pipeline declared force majeure on the Panhandle Lateral due to compressor station mechanical failure, effective September 17, 2026. This Revision 1 extends the event through September 20, 2026 (4 days total), reducing Panhandle Lateral Receipt and Delivery capacity from 0.263 Bcf/d to 0.175 Bcf/d -- a loss of 0.088 Bcf/d. Capacity is expected to return to normal on September 21, 2026 at 9:00 AM.
TW Panhandle Lateral FM removes 0.088 Bcf/d of receipt/delivery capacity through 9/20/26; expect mild bullish pressure at SoCal Border and Arizona delivery points as westbound supply tightens, with offsetting bearish pressure at Permian/San Juan basin as lateral gas cannot move westbound at full volume.
Reroute: Moderate: EPNG serves overlapping SoCal Border and Arizona markets and may absorb some displaced volumes, but if EPNG is simultaneously constrained, no California reroute remains. The Panhandle Lateral itself is a discrete lateral with no direct bypass.
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Operational Alert
Until Further Notice
On September 18, 2026, Texas Gas Transmission reported a pipeline release and fire on its 16-inch line southwest of Jennings, LA. The pipeline was shut in and the fire has been extinguished with no injuries. No restoration timeline has been provided and TGT has indicated it will update as more information becomes available.
TGT 16-inch line shut-in southwest of Jennings with no restoration timeline removes northbound Louisiana receipt capacity of unknown volume; expect bullish pressure on Texas Gas Zone 1 basis (most recently -0.245 vs HH on 2026-09-17) and Midwest delivery markets as Gulf Coast supply into the system is curtailed until further notice.
Reroute: Moderate: ANR, TETCO, and Gulf South serve overlapping Gulf Coast-to-Midwest corridors and may absorb some displaced volumes, but TGT's specific Louisiana receipt infrastructure at this location has limited immediate bypass; full offset is unlikely until the shut-in segment is restored.
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El Paso Natural Gas (EPNG)
SEV 4/5
Force Majeure
0.100 Bcf/d
1 Days
EPNG has declared force majeure at Caprock Compressor Station Unit #2 in Lea County, New Mexico, due to a second-stage nozzle system cooling blockage. The CAPROCK N constraint remains reduced by 68,380 Dth/d (0.068 Bcf/d), and effective September 18 Timely Cycle, the LUSK constraint will be additionally reduced by 9,542 Dth/d (0.010 Bcf/d), bringing total combined reductions to approximately 100,272 Dth/d (0.100 Bcf/d). The force majeure end date is currently posted as September 18, 2026 at 9:00 AM, though an updated maintenance notice is pending.
EPNG force majeure at Caprock Unit #2 removes a combined 0.100 Bcf/d across CAPROCK N and LUSK constraints; expect modest bearish pressure at Waha/Permian as New Mexico takeaway is reduced, with correspondingly mild bullish pressure at SoCal Border and Arizona delivery points -- impact is small relative to system scale but force majeure status and pending LUSK expansion warrant close monitoring into the September 18 Timely Cycle.
Reroute: Moderate: Transwestern Pipeline (TW) serves overlapping SoCal border and Arizona markets and provides partial alternative routing for westbound Permian volumes; however, the combined constraint volume of 0.100 Bcf/d is modest and reroute via TW is likely feasible at comparable cost.
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Operational Alert
Until Further Notice
1 Days
Gulf South Pipeline issued a Critical Over-Under Performance notice on 2026-09-17 for Loc 24329 Stratton Ridge to Freeport LNG, citing the customer's failure to take confirmed delivery quantities. Gulf South is reducing scheduling for remaining nomination cycles for Gas Day 9/17/2026 and until further notice. The LNG feedgas severity floor applies -- this is a direct curtailment of feed gas deliveries to Freeport LNG.
Gulf South curtailment at Stratton Ridge (Loc 24329) reduces Freeport LNG feed gas; live capacity data shows 1.47 Bcf/d scheduled against 1.78 Bcf/d operating capacity at 82.6% utilization as of the evening cycle on 2026-09-17, with no stated volume of the reduction -- gas displaced from LNG export stays in the domestic market, bearish near-term for Henry Hub (regional proxy at 3.010 on 2026-09-16) and Gulf Coast basis.
Reroute: None: Freeport LNG feed gas delivered via the Stratton Ridge lateral has no alternative pipeline path -- curtailed volumes cannot be rerouted to the terminal; instead, displaced supply increases domestic onshore availability.
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Capacity Constraint
Until Further Notice
Cove Point LNG (CPL) has posted a Critical capacity constraint notice effective 2026-09-19 at 14:00, classified as a PPO (Planned Partial Outage). No specific capacity reduction volume is stated in the notice text. Live EBB data as of the 2026-09-16 evening cycle shows COVE POINT PLANT (loc 10001, D:DPQ) running at 94.5% utilization with only 0.051 Bcf/d of headroom against 0.920 Bcf/d operating capacity, indicating the terminal is already near full throughput before the restriction takes effect. The restriction is set to begin September 19, approximately 3 days after posting.
CPL PPO effective 2026-09-19 removes LNG export demand at Cove Point, bearish for Appalachian/Mid-Atlantic supply balance; Eastern Gas South regional basis most recently printed at -1.420 vs HH (2026-09-15) against a 5-day average of -1.273, and any further feedgas displacement into a region already trading deep negative to Henry Hub will pressure that spread wider to the bearish side.
Reroute: None applicable from an LNG export perspective -- Cove Point is the only LNG export terminal on the East Coast, and displaced feedgas volumes have no alternative LNG outlet; gas backing into the Appalachian/Mid-Atlantic system may find limited domestic absorption given shoulder-season demand.
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Maintenance
Until Further Notice
Golden Pass Pipeline has posted its Annual Planned Maintenance 2025-2026 Rev 32, covering the Sabine Pass TX to Starks LA corridor with up to 2.6 Bcf/d of LNG export feed gas capacity at risk. This is listed as Revision Number 1 (not a revision of a prior posting), indicating a fresh or newly re-labeled filing as of September 15-16, 2026. No specific per-job schedule, individual outage dates, or discrete capacity impact figures are provided in the notice text; the 2.6 Bcf/d figure represents the system's full feed gas capacity ceiling, not a stated curtailment volume.
Golden Pass Pipeline planned maintenance threatens feed gas deliveries to the Golden Pass LNG export terminal (up to 2.6 Bcf/d system capacity); any realized curtailment is bearish Gulf Coast basis as unexported gas stays domestic -- Houston Ship Channel regional basis has already softened to -0.455 vs Henry Hub as of 2026-09-15 (5-day average -0.287), and further feed gas disruptions would pressure that spread wider on the downside.
Reroute: None: Golden Pass Pipeline is a dedicated LNG export feed gas pipeline serving only the Golden Pass LNG terminal; curtailed feed gas volumes have no alternative export outlet and instead back into the Gulf Coast domestic market.
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Operational Alert
2.600 Bcf/d
Until Further Notice
Golden Pass Pipeline has posted a critical ACA (Authorized Contract Authority) change effective October 1, 2026, affecting up to 2.6 Bcf/d of LNG export feed gas capacity on the Sabine Pass TX to Starks LA corridor. The nature of the change (reduction, reallocation, or scheduling adjustment) is not specified in the notice text. Because this directly involves LNG export feed gas nominations at Golden Pass LNG, the LNG feedgas severity floor of 4 applies regardless of the notice's informational framing.
ACA change at Golden Pass Pipeline effective October 1, 2026 places up to 2.6 Bcf/d of LNG export feed gas nominations at risk; if feed gas deliveries are curtailed or reduced, gas remains onshore and is bearish for Henry Hub and Gulf Coast basis -- regional Houston Ship Channel basis was most recently -0.455 vs Henry Hub on 2026-09-15 (trailing 5-day average -0.287), with the October 1 effective date falling outside this pricing window; watch for follow-on nominations notices confirming actual curtailment volumes.
Reroute: None: Golden Pass Pipeline is the dedicated feed gas supply line to Golden Pass LNG at Sabine Pass, TX; no alternative pipeline replaces this function for this terminal. Any reduction in ACA capacity directly curtails LNG export throughput with no bypass.
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Force Majeure
0.088 Bcf/d
2 Days
Transwestern Pipeline declared force majeure on the Panhandle Lateral due to a compressor station mechanical failure. Receipt and delivery capacity on the Panhandle Lateral is reduced from 0.263 Bcf/d to 0.175 Bcf/d (a loss of 0.088 Bcf/d) effective September 17, 2026 through September 19, 2026 at 8:59 AM -- a two-day event. Full capacity of 0.263 Bcf/d is expected to be restored on September 19.
TW Panhandle Lateral FM removes 0.088 Bcf/d of receipt and delivery capacity for two days; expect mild bearish pressure at Permian/San Juan basin points (Waha, TW Permian) and modest bullish support at SoCal Border and Arizona delivery points, though the relatively small volume limits the broader market impact.
Reroute: Moderate: EPNG serves overlapping SoCal border and Arizona markets and likely has spare capacity to absorb some displaced volumes; however, a simultaneous EPNG constraint would eliminate this option entirely.
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Tennessee Gas Pipeline (TGP)
SEV 4/5
Force Majeure
0.590 Bcf/d
Until Further Notice
4 Days
Tennessee Gas Pipeline has declared a force majeure on the HC Line between valve sections 313A-403 and 313A-404, just south of Avoca, New York, effective September 16, 2026. An anomaly requiring immediate repair was discovered, with TGP personnel on site and repair work estimated to last approximately 4 days. The event threatens up to 0.590 Bcf/d of Primary In the Path capacity at MLV 313 HC Zone 4 End (Segment 399 FH), with impact possible as early as the Timely Cycle for Gas Day September 16.
TGP force majeure on the HC Line near Avoca, NY threatens up to 0.590 Bcf/d of Zone 4 primary firm capacity starting September 16 for an estimated 4 days; expect bullish pressure on Tennessee Zone 4-300 leg basis (most recently -1.440 vs HH) and downstream Algonquin Citygate and New England basis as Appalachian/Northeast supply tightens with limited reroute via Transco.
Reroute: Limited: Transco is the primary competing pipeline for Northeast deliveries from this corridor, but Transco Zone 5 and Northeast segments frequently run near capacity; TGP and Transco together dominate this market, so a 0.590 Bcf/d Zone 4 firm curtailment has limited practical reroute relief for affected Northeast shippers.
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Force Majeure
0.250 Bcf/d
2 Days
Transwestern Pipeline declared force majeure at the GCX Waha interconnect (POI 100744) effective September 11, 2026 at 4:02 PM, reducing delivery capacity from 0.250 Bcf/d to zero due to emergency valve repair. Restoration to full 0.250 Bcf/d capacity is scheduled for September 13, 2026 at 8:59 AM, yielding approximately two gas days of curtailment. Live capacity data for GD 9/11 id3 confirms GCX WAHA (loc 100744) posted operating capacity of 0 with scheduled volumes of 0.027 Bcf/d, consistent with the force majeure declaration -- the data predates full reflection of the event but already shows the constraint.
TW force majeure eliminates 0.250 Bcf/d of Permian takeaway at GCX Waha through 9/13 morning; expect bearish Waha basis pressure as Permian supply backs up, with modest bullish signal at SoCal Border and Arizona delivery points where TW volumes are reduced.
Reroute: Moderate: EPNG serves overlapping Permian-to-SoCal/Arizona corridors and is the primary reroute alternative for westbound volumes displaced from TW at Waha; however, if EPNG is simultaneously constrained, no California reroute exists. The GCX Waha point is a specific Permian Basin interconnect and producers may need to redirect onto EPNG or other Permian takeaway pipes.
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Force Majeure
0.027 Bcf/d
1 Days
Transwestern Pipeline declared force majeure at the GCX WAHA interconnect (loc 100744) effective Sep 12, 2026 9:00AM through Sep 13, 2026 8:59AM -- a one-day event. The capacity table for the prior gas day (Sep 11) shows GCX WAHA posting zero operating capacity against 0.027 Bcf/d scheduled (vs-design flag), consistent with the constraint already affecting nominations before the FM was formally declared. The stated capacity impact is limited to the scheduled volume at that point (~0.027 Bcf/d), though the force majeure floor sets minimum severity at 4 regardless.
Transwestern FM at GCX WAHA removes approximately 0.027 Bcf/d of Permian takeaway at this interconnect for one day; expect bearish pressure at Waha/Permian basis as basin gas backs up, with mild bullish pressure at SoCal Border and Arizona delivery points -- volumes are small relative to TW system scale but force majeure status warrants monitoring for any scope expansion.
Reroute: Moderate: EPNG serves overlapping Permian-to-SoCal/Arizona corridors and is the primary reroute alternative; however, if EPNG is simultaneously constrained, no California reroute exists. Volumes affected at this single interconnect are small (~0.027 Bcf/d), limiting market impact absent escalation.
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Operational Alert
Until Further Notice
1 Days
Gulf South Pipeline issued a Critical Over-Under Performance notice on 9/11/2026 for Loc 24329 (Stratton Ridge to Freeport LNG), citing the customer's failure to take confirmed quantities. Gulf South is reducing scheduling for remaining nomination cycles on Gas Day 9/11/2026 and until further notice. The affected location is the dedicated lateral delivering feed gas to Freeport LNG, making this an LNG feedgas disruption event; no specific curtailed volume is stated in the notice.
Freeport LNG feed gas under-performance at Stratton Ridge (Loc 24329) reduces LNG export pull from the Gulf Coast domestic gas market, bearish for Henry Hub regional pricing; live capacity data shows the point running at 1.46 Bcf/d scheduled against 1.78 Bcf/d operating capacity (82% utilized, 0.318 Bcf/d headroom) in the td3 cycle -- the magnitude of the actual curtailment below scheduled is unquantified in the notice text but the 'until further notice' language keeps the downside risk open beyond Gas Day 9/11.
Reroute: None: Freeport LNG is a single-customer export facility served by this dedicated lateral -- there is no alternative route for the feed gas to reach the terminal, and the curtailment keeps gas onshore rather than rerouting it.
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Northern Border Pipeline (NBPL)
SEV 4/5
Force Majeure
2.160 Bcf/d
Until Further Notice
NBPL has declared a Force Majeure effective evening September 11, 2026 due to an unplanned equipment failure at Compressor Station 07 (CS07) near St. Anthony, ND. As a result, nominated volumes past Glen Ullin (GlenSEG) are restricted to 2,160 MMcf/d (2.160 Bcf/d) until further notice. Pre-event capacity data from the prior gas day (September 10) shows GlenSEG already running at 99.4% utilization (2.52 Bcf/d scheduled against 2.53 Bcf/d operating capacity), meaning the new 2.160 Bcf/d cap represents a reduction of approximately 0.37 Bcf/d from already near-full flow; note the capacity table predates the FM by one gas day and does not yet reflect the restriction.
NBPL FM at CS07 caps GlenSEG flows at 2.160 Bcf/d until further notice, cutting roughly 0.37 Bcf/d of Canadian/Bakken supply into the Midwest; expect bullish pressure at Chicago Citygate and Northern Border Ventura TP basis, which was last quoted at -0.205 vs Henry Hub on 2026-09-09 and is likely to tighten further once the evening-cycle restriction takes effect.
Reroute: Limited: Alliance Pipeline provides an alternative Canadian supply route into Chicago but volumes are typically fully subscribed, leaving minimal spare capacity to absorb displaced NBPL volumes; no other pipeline replicates NBPL's specific Canadian border crossing and Midwest delivery corridor.
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Force Majeure
0.900 Bcf/d
Until Further Notice
1 Days
Gulf Run Transmission has declared a Force Majeure at its Panola Compressor Station in Panola County, Texas (Zone 1), effective September 15, 2026 at 09:00, with anticipated restoration by September 16, 2026 at 09:00 -- approximately one calendar day. During this period, throughput capacity at Panola is limited to 0.900 Bcf/d, with upstream point operators warned of elevated pressures and shippers directed to nominate from contractual MRO to MDO locations to minimize scheduling reductions. Pre-event capacity data (gas day 2026-09-09) shows Gemini Panola GR receipt at 0.437 Bcf/d scheduled against 0.800 Bcf/d operating capacity, so the 0.900 Bcf/d throughput cap itself may not immediately bind at current scheduled levels -- but the Force Majeure designation and unplanned nature of the event warrant elevated caution ahead of the effective date.
Gulf Run FM at Panola CS caps throughput at 0.900 Bcf/d on Sept 15; this system is built to serve Golden Pass LNG, so any binding curtailment reduces Haynesville-origin feed gas to the LNG corridor and keeps supply in the domestic market, mildly bearish Henry Hub regionally -- watch Golden Pass nominations on Sept 15 for confirmation of actual feed gas impact.
Reroute: Moderate: Gulf South and Kinder Morgan assets serve the Haynesville corridor and could absorb some displaced Haynesville supply, but Gulf Run is the primary purpose-built conduit to Golden Pass LNG and no direct replacement pipeline exists for that specific LNG delivery path.
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Columbia Gulf Transmission (CGT)
SEV 4/5
Maintenance
0.075 Bcf/d
4 Days
CGT has notified customers of planned maintenance at both Golden Meadow and Centerville Compressor Stations from September 15-18, 2026, reducing backhaul capacity on EL300SEG to 350,000-500,000 Dth/day against a design capacity of 575,000 Dth/day -- a restriction of up to 225,000 Dth/day (0.225 Bcf/d). CGT explicitly warns that curtailments to Interruptible, Secondary Firm, and Primary Firm services are anticipated, a significant escalation beyond typical interruptible-only curtailment language. Live capacity data confirms EL300SEG is already at 100% utilization (0.575 Bcf/d scheduled against 0.575 Bcf/d operating capacity) as of the September 8 timely cycle, corroborating the tightness described in the notice.
CGT maintenance on EL300SEG cuts backhaul capacity by up to 0.225 Bcf/d (midpoint ~0.113 Bcf/d restriction at the 500k Dth floor) for four days starting September 15, with primary firm curtailments explicitly at risk; Columbia Gulf mainline basis, which has traded at an average of -0.247 vs Henry Hub over the five trading days ended September 4 (most recently -0.215 on September 4), is likely to widen further as southbound backhaul tightens and Transco Zone 4 Southeast basis firms in sympathy.
Reroute: Moderate: Texas Eastern (TETCO) and Trunkline (TGC) serve overlapping Gulf Coast northbound corridors and could absorb some displaced volumes, but the explicit primary firm curtailment risk on a Critical notice suggests CGT does not anticipate sufficient system-level flexibility to avoid firm impacts.
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Force Majeure
2.772 Bcf/d
REX declared force majeure at Chandlersville Compressor Station (Segment 380) on September 7, 2026, limiting eastbound-to-westbound capacity to 2,835 MDth/d (2.835 Bcf/d) for the ID3 cycle on Gas Day September 7, and 2,772 MDth/d (2.772 Bcf/d) from the Evening Cycle of Gas Day September 8 until further notice. Primary firm, secondary firm, and AOR/ITS service are all explicitly at risk of not being scheduled, indicating curtailments across all service classes. No restoration timeline has been provided.
REX force majeure at Chandlersville CS (Seg 380) limits east-to-west capacity to 2.772 Bcf/d until further notice with all firm service classes at risk; REX Zone 3 basis was -0.250 vs Henry Hub as of 2026-09-04 and is subject to further pressure as westbound Appalachian-origin receipts back up at the Lebanon Hub while downstream Midwest and Ohio Valley markets tighten -- expect bullish Zone 3 and Lebanon Hub basis and bearish pressure on any westbound receipt points unable to schedule.
Reroute: Moderate: REX Zone 3 westbound Appalachian volumes have partial alternatives via Rover Pipeline, TETCO M2, and TCO for Midwest and Ohio Valley markets, but these pipes serve different downstream points and cannot fully replace REX westbound throughput at this scale; no single alternative approaches 2.772 Bcf/d of replacement capacity on short notice.
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Nautilus Pipeline Company
SEV 4/5
Force Majeure
Nautilus Pipeline has declared force majeure following an unplanned outage at the Enterprise Neptune offshore processing plant, effective September 3, 2026. The plant continues troubleshooting with no estimated restart timeline, and Nautilus is reducing all scheduled quantities to EPSQ (Elapsed Prorata Scheduled Quantity) for the Intraday 3 cycle on the September 3 gas day. No restoration ETA has been provided, and the notice end date extends to December 2, 2026, suggesting a potentially prolonged constraint.
Nautilus force majeure with no restart ETA removes offshore GoM supply volumes from the onshore market indefinitely; bullish for Henry Hub spot and Gulf Coast basis with duration risk extending into Q4 2026.
Reroute: None: Nautilus is an offshore gathering pipeline serving the Enterprise Neptune plant directly; there is no alternative routing for production shut in at this offshore facility.
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Capacity Constraint
Until Further Notice
CPL has posted a Critical PPO (Planned Planned Outage) notice effective 2026-09-19 14:00 flagging anticipated restrictions at the Cove Point LNG export terminal in Maryland. No specific capacity volume or restoration date is stated in the notice text. As of the 2026-09-03 gas day (one day lag), COVE POINT PLANT delivery was running at 94.5% utilization (0.869 Bcf/d scheduled against 0.920 Bcf/d operating capacity), leaving only 0.051 Bcf/d of headroom -- confirming the system is already running tight ahead of the restriction.
Cove Point LNG feedgas restriction beginning 2026-09-19 removes demand from the Appalachian supply stack, bearish for Appalachian basin basis -- Eastern Gas South regional proxy was most recently -1.265 vs Henry Hub (2026-09-03) and has averaged -1.130 over the prior five trading days; further softening in that regional read and the export arb is likely if the restriction proves material, with no offsetting bullish signal for Henry Hub.
Reroute: None: Cove Point LNG is the sole LNG export terminal served by CPL; feedgas volumes that cannot be nominated to the plant have no alternative export outlet and will back into the Appalachian pipeline network.
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Columbia Gulf Transmission (CGT)
SEV 4/5
Maintenance
0.391 Bcf/d
Until Further Notice
77 Days
CGT has updated its Hampshire Compressor Station maintenance notice, revising the lower bound of the backhaul capacity restriction downward to 2,150,000 Dth/d (from the prior 2,200,000 Dth/d floor), against a design capacity of 2,540,656 Dth/d -- a reduction of up to 0.391 Bcf/d versus design. The maintenance window remains September 9 through November 25, 2026 (77 days). Critically, the prior posting explicitly warned of potential curtailments to Interruptible, Secondary Firm, and Primary Firm services, an escalation trigger that elevates severity; the updated notice widens the capacity reduction range modestly on the downside and removes the explicit firm-service curtailment language, but the prior notice established that risk and it has not been formally withdrawn. Live capacity data for HampSEG (TD4 cycle, timely) shows 2.15 Bcf/d scheduled against 2.54 Bcf/d operating capacity at 84.8% utilization today, consistent with pre-event conditions ahead of the September 9 effective date.
CGT Hampshire maintenance removes up to 0.391 Bcf/d of backhaul capacity on HampSEG from September 9 through November 25, representing roughly 15% of the segment's design capacity; with Columbia Gulf mainline basis most recently at -0.215 vs Henry Hub (2026-09-03) against a 5-day trailing average of -0.254, expect this basis to tighten (move less negative or flip positive) as northbound backhaul tightens through Kentucky and into TETCO/Adair Co. interconnects, which is already showing only 3.6% headroom at 0.200 Bcf/d scheduled.
Reroute: Moderate: Texas Eastern (TETCO) and Trunkline (TGC) serve overlapping Gulf Coast northbound corridors and provide partial reroute options, but the multi-month duration and the prior notice's warning of firm service curtailments suggest the constraint exceeds what parallel capacity can fully absorb without basis widening.
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El Paso Natural Gas (EPNG)
SEV 4/5
Force Majeure
0.159 Bcf/d
1 Days
EPNG has declared force majeure on Line No. 1103 between Pecos River and Guadalupe in Culberson County, Texas, following discovery of safety and integrity anomalies downstream of Pecos River Compressor Station. Effective September 5, 2026 Timely Cycle, operational capacity through the PECOS constraint is reduced by 0.159 Bcf/d and through the GUADLUP constraint by 0.136 Bcf/d, with a pressure restriction and isolation required to facilitate repairs. The stated end date is September 5, 2026 at 9:00 AM, making this a short-duration but formally declared force majeure event on a key Permian outbound segment.
EPNG force majeure on Line 1103 removes up to 0.159 Bcf/d of Permian outbound takeaway capacity; expect bearish pressure at Waha as basin gas backs up, with mild bullish pressure at SoCal Border and Arizona delivery points -- though the one-day duration limits sustained market impact.
Reroute: Moderate: Transwestern Pipeline (TW) serves overlapping SoCal border and Arizona markets and is the primary alternative to EPNG for westbound Permian volumes; however, available TW spare capacity on any given day is uncertain and partial reroute is the realistic outcome for the affected 0.159 Bcf/d.
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Tallgrass Energy
[Tallgrass Interstate Gas Transmission (TIGT)] [OPERATIONAL ALERT] SEGMENT 520 OPERATIONAL ISSUE
SEV 4/5
Capacity Constraint
TIGT has declared an operational alert on Segment 520 from Otis to Stockton due to an ongoing pipeline integrity issue requiring section replacement, effective Gas Day August 25, 2026 (ID1 Cycle), and the outage is expected to last longer than originally anticipated with no restoration date given. Primary firm, secondary firm, and interruptible/as-available service quantities are all at risk of not being scheduled on this segment. TIGT is working with affected customers on alternative connections but cannot guarantee full scheduling of nominations.
TIGT Segment 520 (Otis to Stockton) is offline indefinitely with firm service at risk; Cheyenne Hub regional basis has averaged -0.442 vs Henry Hub over the five trading days ended 2026-09-02 (most recently -0.410 on 2026-09-02) and further bearish pressure on Rockies/Midcontinent regional basis is likely until a restoration timeline is established -- no capacity volume is quantified in the notice.
Reroute: Limited: TIGT serves the Rockies-to-Midcontinent corridor, and while PEPL and Southern Star serve overlapping Midcontinent markets, the integrity-driven segment outage with no restoration timeline makes full volume displacement uncertain; affected customers are being worked individually for alternative connections per the notice.
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Trunkline Gas Company
[Trunkline Gas Company] [Force Majeure] TGC Force Majeure REINSTATED: Kountze Station Additional Power Outages
SEV 4/5
Force Majeure
Until Further Notice
Trunkline Gas Company has reinstated a force majeure at Kountze Compressor Station (MP -73.7) due to continued unexpected power outages caused by the landfall of Tropical Storm Edouard. The prior notification lifting the force majeure was rescinded effective immediately on 2026-09-03. Scheduling reductions are in effect with no end date specified, and updates will be posted as conditions develop.
TGC force majeure reinstatement at Kountze CS eliminates any relief priced into the prior FM lift notice -- expect bullish pressure at Trunkline ELA and tightening Gulf Coast-to-Midwest basis with no restoration timeline disclosed; no specific capacity volume stated but compressor outage on a major Gulf Coast northbound corridor carries meaningful flow reduction risk.
Reroute: Moderate: TETCO, ANR, and Southern Natural serve overlapping Gulf Coast-to-Midwest corridors and can absorb some displaced TGC volumes, though simultaneous storm-related stress on Gulf Coast infrastructure may limit available spare capacity on competing pipes.
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Force Majeure
0.008 Bcf/d
Trailblazer Pipeline declared a force majeure at its Heartwell Location (Location 60487) on Gas Day September 2, 2026, caused by electrical storms. Effective the ID2 cycle on September 2 and the Timely cycle on September 3, operating capacity at Heartwell is scheduled to 0 MDth/d until further notice. Primary and secondary firm quantities as well as ITS/AOR are explicitly stated to be at risk of not being scheduled.
Trailblazer FM at Heartwell zeros 0.008 Bcf/d of local capacity at Location 60487 with firm service at risk and no restoration timeline; while the isolated location impact is small, the force majeure declaration with 'until further notice' duration and primary firm curtailment language warrants monitoring -- Cheyenne Hub regional basis was already at -0.465 vs HH as of 2026-09-01 and any escalation to mainline throughput would pressure that spread further.
Reroute: None: Trailblazer shares Bertrand Compressor Station with REX, making REX a correlated rather than independent reroute option; the specific Heartwell location serves local delivery points with no identified bypass.
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Columbia Gulf Transmission (CGT)
SEV 4/5
Maintenance
0.340 Bcf/d
78 Days
CGT is scheduling maintenance at Hampshire Compressor Station (HampSEG) from September 9 through November 25, 2026 -- 78 calendar days. Backhaul capacity through HampSEG will be restricted to 2.200-2.350 Bcf/d against a design capacity of 2.541 Bcf/d, a reduction of approximately 0.190-0.340 Bcf/d (87-92% of design). CGT explicitly warns that Primary Firm, Secondary Firm, and Interruptible services are all at risk of curtailment, and Reservation Charge Credits have been triggered -- a firm-service curtailment notice, not merely an informational posting.
CGT HampSEG maintenance removes up to 0.340 Bcf/d of backhaul capacity from September 9 through November 25, with explicit risk of Primary Firm curtailments; Columbia Gulf mainline basis has been trading near -0.285 to -0.288 vs Henry Hub as of September 1 -- expect that spread to widen further as northbound backhaul capacity is squeezed during the shoulder/early-winter period, with modest bullish support for Transco Zone 4 and Gulf Coast downstream markets receiving less northbound competition for Gulf Coast gas.
Reroute: Moderate: Texas Eastern (TETCO) and Trunkline (TGC) serve overlapping Gulf Coast northbound corridors and provide partial backhaul alternatives; however, the 78-day duration and explicit firm curtailment risk mean alternative paths may face significant competition for remaining capacity, limiting full offset.
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Force Majeure
Until Further Notice
Trunkline Gas Company declared force majeure effective 2026-09-02 due to an unexpected power outage at the Kountze Compressor Station (MP -73.7) caused by Tropical Storm Edouard landfall. Scheduling reductions are being implemented immediately to reduce imbalances and maintain system integrity. No end date has been provided; duration is indeterminate pending power restoration.
TGC force majeure at Kountze CS removes northbound Gulf Coast-to-Midwest capacity with no stated restoration timeline; expect bullish pressure at Trunkline ELA and Henry Hub with possible widening at downstream Midwest delivery points as scheduled volumes are cut, with no concrete capacity figure available to quantify the reduction.
Reroute: Moderate: Texas Eastern (TETCO), Southern Natural (EGT), and ANR serve overlapping Gulf Coast northbound corridors, but tropical storm-related conditions affecting the broader Gulf Coast region may simultaneously limit alternative pipeline headroom.
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Capacity Constraint
1.085 Bcf/d
Rockies Express is restricting Segment 250 capacity to 1.085 Bcf/d westbound-to-eastbound (West to East direction) effective timely cycle Gas Day September 3, 2026, until further notice, due to an ongoing operational issue at Bertrand Compressor Station (Update #17). At this restriction level, primary firm, secondary firm, and ITS/AOR service classes are all explicitly at risk of curtailment. No restoration timeline has been provided.
REX Segment 250 restricted to 1.085 Bcf/d eastbound with primary firm at risk -- a multi-week unresolved constraint with no end date; REX Zone 3 delivered basis has averaged -0.313 vs HH over the five trading days ended 2026-09-01 (most recently -0.285 on 2026-09-01) and should widen further bearish as eastbound throughput remains capped, while Rockies/Cheyenne Hub faces bearish pressure from trapped westbound supply; Trailblazer shares Bertrand CS and is not an independent reroute.
Reroute: None: Trailblazer Pipeline (TPC) shares Bertrand Compressor Station with REX and is simultaneously constrained by the same facility -- the two are not independent reroutes for each other. The REX/TPC SALINE and TPC/REX LONE TREE WELD REC interconnects are both shown at 100% utilization (0.642 Bcf/d and 0.579 Bcf/d respectively, zero headroom) in current capacity data, corroborating the constraint.
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