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.
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.
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.
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.
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.
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.
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.
lifted ✓Restoration1.800 Bcf/dUntil Further Notice3 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.
Force Majeure0.186 Bcf/dUntil Further Notice10 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.
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.
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.
Force Majeure1.403 Bcf/dUntil Further Notice10 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.
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.
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.
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.
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.
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.
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.
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.
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.
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.
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.
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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Golden Pass Pipeline
Annual Planned Maintenance 2025- 2026 Rev 36
SEV 3/5
MaintenanceUntil Further Notice
Golden Pass Pipeline has posted Rev 37 of its Annual Planned Maintenance 2025-2026 notice (logged here as Rev 36/Revision 2), covering planned outage windows on the Golden Pass Pipeline LLC system running from Sabine Pass, TX to Starks, LA, which feeds the Golden Pass LNG export terminal with up to 2.6 Bcf/d of capacity. This is a revision to an ongoing annual maintenance schedule; no specific per-job capacity impact figures or individual outage dates are stated in the notice text. The LNG feedgas severity floor applies given the terminal served, but no concrete volume or duration data is available to quantify the specific impact.
Planned maintenance on Golden Pass Pipeline reduces available LNG feedgas capacity on a system rated up to 2.6 Bcf/d; without specific job-level capacity figures, the magnitude of this revision is unquantified, but any confirmed feedgas curtailment at Golden Pass LNG is bearish for Gulf Coast spot prices as volumes stay in the domestic market -- Houston Ship Channel regional basis most recently -0.525 vs Henry Hub as of 2026-09-25.
Reroute: Limited: Golden Pass Pipeline is the dedicated feed gas lateral for the Golden Pass LNG terminal; no alternate routing exists for LNG export volumes at this terminal, though curtailed feedgas volumes simply remain in the domestic Gulf Coast supply pool.
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Columbia Gulf Transmission (CGT)
Mainline 100 Pigging (HampSEG), Effective October 7 – 14, 2026
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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MountainWest (multi-pipeline)
[MountainWest Pipeline (MWP)] [OPERATIONAL FLOW ORDER IMBALANCE RESTRICTION AND CLAY BASIN RESERVOIR TEST REMINDER] OPERATIONAL FLOW ORDER IMBALANCE RESTRICTION AND CLAY BASIN RESERVOIR TEST REMINDER
UNSCORED
Informational
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El Paso Natural Gas (EPNG)
[MAINTENANCE] Updated Prelim October 2026 Maintenance
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Southern Natural Gas
[MAINTENANCE] TGP Outage Impact Report
SEV 1/5
Informational
Not scored -- external_id 'SNGD-404461' shares its numeric ID and exact title with 'TGP-404461' under a different pipeline code. Very likely the same underlying notice scraped twice under two different labels (see kindermorgan.py v19 changelog / audit_km_contamination.py) rather than two independent events. No Claude API call was made for this notice. Needs manual review to confirm which pipeline (if either) is correct before it's trusted.
Not scored -- suspected cross-pipeline duplicate, needs manual review.
Reroute: Not assessed.
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Tennessee Gas Pipeline (TGP)
TGP Outage Impact Report
SEV 1/5
Informational
Not scored -- external_id 'TGP-404461' shares its numeric ID and exact title with 'SNGD-404461' under a different pipeline code. Very likely the same underlying notice scraped twice under two different labels (see kindermorgan.py v19 changelog / audit_km_contamination.py) rather than two independent events. No Claude API call was made for this notice. Needs manual review to confirm which pipeline (if either) is correct before it's trusted.
Not scored -- suspected cross-pipeline duplicate, needs manual review.
