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)
SEV 5/5
Force Majeure
1.900 Bcf/d
Until Further Notice
TCO has declared a new Force Majeure effective Gas Day October 14, 2026, due to a detected leak near the Saunders Creek Regulator Station in West Virginia on MXP Line-100 -- explicitly separate from the September 24 FM (Notice 26276009). Effective the Evening Cycle of October 15 and until further notice, scheduled volumes through the MXPSEG MA42 internal constraint are reduced to zero total capacity, with estimated firm service impact of 1.9 MMDth/d (1.9 Bcf/d). Live capacity data at MXPSEG (loc_id MXPSEG, dir TD1:SGQ:FTS) already shows NON-FIRM-RESTRICTED with zero operating capacity posted against 1.85 Bcf/d scheduled as of the timely cycle on Oct 14, corroborating the constraint. TCO will provide an update by Friday morning October 16.
New TCO force majeure on MXP Line-100 eliminates 1.9 Bcf/d of Appalachian firm transport capacity to zero effective Oct 15 evening cycle (MXPSEG already NON-FIRM-RESTRICTED at 1.85 Bcf/d scheduled vs zero operating capacity in the Oct 14 timely cycle); expect significant bullish pressure on Dominion South, TETCO M2, and downstream Mid-Atlantic basis, with bearish pressure at Appalachian receipt points where gas backs up in-basin -- this is a second, independent TCO FM active simultaneously with the Sep 24 event.
Reroute: Limited to moderate: TETCO (monitored) and Equitrans serve overlapping Appalachian markets and provide partial reroute, but with 1.9 Bcf/d of firm capacity offline and a simultaneous active TCO force majeure from September 24 still in effect, the combined system stress severely limits practical bypass options for affected shippers.
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Force Majeure
1 Days
Transwestern Pipeline has declared a force majeure on the East Mainline effective Gas Day Oct 27 2026 at 9:00 AM, expiring Oct 28 2026 at 8:59 AM -- a single-day event. No specific capacity reduction figure is stated in the notice. The East Mainline carries Permian and San Juan Basin gas westbound toward SoCal and Arizona delivery points.
TW East Mainline force majeure on Oct 27 produces split-direction signal: bearish Waha/Permian as westbound takeaway is cut, bullish SoCal Border and Arizona delivery points as westbound supply is reduced; no capacity volume stated so exact cut is unquantified but duration is short at one gas day.
Reroute: Moderate: EPNG is the primary competing pipeline serving SoCal border and Arizona from the Permian Basin; if EPNG has available capacity, partial reroute is possible, but any simultaneous EPNG constraint would eliminate California reroute entirely.
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Force Majeure
≈0.890 Bcf/d est. cut vs recent flow (capped at 0.220 Bcf/d)
Until Further Notice
36 Days
ANR Pipeline has declared a force majeure at Greenville Compressor Station Unit #7 in Washington County, Mississippi, due to unexpected equipment failure, curtailing capacity on the Southeast Mainline at Delhi Southbound (LOC FPDELHSB). On 10/26, no incremental volumes will be scheduled; from 10/27-10/31 and 11/1-11/30, capacity is reduced by 220 MMcf/d leaving 994 MMcf/d and 1,027 MMcf/d respectively. Pre-event flow at DELHI SOUTHBOUND TD2 was running at a median of 1.11 Bcf/d, implying a net cut of approximately 0.89 Bcf/d against the 0.220 Bcf/d cap, with firm primary service estimated at 16% impact through October and 13% in November.
ANR force majeure at Greenville CS Unit 7 cuts Delhi Southbound from a pre-event median of ~1.11 Bcf/d to a 0.220 Bcf/d cap, a net reduction of ~0.89 Bcf/d, with primary firm curtailments of 13-16% -- expect bullish pressure on ANR ML 7 and Midwest/Michigan basis as southbound Gulf Coast throughput is materially reduced through November 30.
Reroute: Moderate: Texas Eastern (TETCO), Trunkline (TGC), and Columbia Gulf Transmission (CGT) serve overlapping Gulf Coast northbound corridors, but with ANR running tight systemwide (multiple OVER and zero-headroom points visible in live data), full reroute of 0.89 Bcf/d displaced volume is unlikely without basis widening.
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Operational Alert
≈1.430 Bcf/d est.
Until Further Notice
1 Days
Gulf South Pipeline has implemented a System Management Plan at Location SLN 024329 Stratton Ridge (to Freeport LNG) effective 08:30 AM on October 26, 2026, reducing scheduled quantities to 0 Dth/d until further notice through at least October 27 at 09:00 AM. The curtailment was triggered by the customer's (Freeport LNG's) failure to take confirmed quantities, forcing Gulf South to balance nominations to zero. Pre-event flow at this location had been running at a median of 1.43 Bcf/d (range 1.02-1.46 Bcf/d over the prior 7 days), meaning approximately 1.43 Bcf/d of LNG feed gas has been zeroed out.
Gulf South SMP cuts Freeport LNG feed gas at Stratton Ridge (loc 24329) to 0 Dth/d from a pre-event median of 1.43 Bcf/d (range 1.02-1.46), stranding ~1.43 Bcf/d onshore and applying bearish pressure on Henry Hub and Gulf Coast basis until Freeport resumes taking nominations.
Reroute: None: this is a demand-side curtailment -- Freeport LNG is not taking gas, so the volume backs up onshore regardless of pipeline alternatives; no reroute to another LNG terminal is implied by this notice.
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Transwestern Pipeline
[Transwestern Pipeline] [Capacity Constraint] M/L THOREAU WEST SYSTEM
SEV 4/5
Force Majeure
1 Days
Transwestern Pipeline declared a force majeure on the M/L Thoreau West System effective October 25, 2026 at 9:00 AM, with a stated end of October 26 at 8:59 AM -- a single gas day. No specific capacity volume is stated in the notice, but pre-event flow context shows the Thoreau West mainline (measured past Station 3 at Leupp, AZ) was moving a median of 1.11 Bcf/d westbound (range 1.04-1.26 Bcf/d) in the seven days prior. The prior posting TW-121544 was scored below threshold as informational; this notice explicitly designates Reason: Force Majeure and is treated as the first actionable event.
TW force majeure on the Thoreau West mainline removes an unquantified portion of ~1.11 Bcf/d of pre-event westbound flow; expect bullish pressure at SoCal Border and Arizona delivery points and bearish pressure at San Juan and Waha basis as westbound takeaway is disrupted, with limited reroute relief given current EPNG loading.
Reroute: Moderate but constrained: EPNG is the primary competing pipeline for SoCal border deliveries, but PHP TW Waha is already running at 100% utilization (0.025 Bcf/d scheduled against 0.025 Bcf/d operating capacity as of Oct 25 id2 cycle), indicating tight conditions at Permian interconnects; SOCAL NEEDLES on TW itself shows 36.6% headroom, suggesting some throughput remains on the western delivery end.
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Transwestern Pipeline
[Transwestern Pipeline] [Capacity Constraint] M/L THOREAU WEST SYSTEM
SEV 4/5
Force Majeure
1 Days
Transwestern Pipeline has extended a force majeure on the Thoreau West mainline by one gas day, now covering Oct 26 9:00 AM through Oct 27 8:59 AM (previously Oct 25-26). The notice states no specific capacity volume, but pre-event flow data shows the Thoreau West mainline was moving a median of approximately 1.11 Bcf/d westbound (range 1.04-1.26 Bcf/d over the prior week). No new cap is stated, so the net reduction remains unquantified but reflects a full or substantial interruption of that flow.
TW force majeure on Thoreau West mainline extended to gas day Oct 26-27, tightening westbound San Juan/Permian-to-California capacity for a second consecutive day; pre-event throughput past Station 3 (Leupp, AZ) was approximately 1.11 Bcf/d westbound -- expect continued bullish pressure at SoCal Border and Arizona delivery points, with bearish pressure at Transwestern Permian and San Juan basis, and note EPNG is the only reroute alternative for California-bound volumes.
Reroute: Moderate: El Paso Natural Gas (EPNG) is the primary competing pipeline for SoCal border deliveries; however, EPNG is the sole realistic alternative and may lack sufficient spare capacity to fully absorb a mainline Thoreau West constraint. A simultaneous EPNG constraint would leave California with no reroute.
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Transwestern Pipeline
[Transwestern Pipeline] [Capacity Constraint] M/L THOREAU WEST SYSTEM
SEV 4/5
Force Majeure
1 Days
Transwestern Pipeline has declared a force majeure on the M/L Thoreau West System, effective Oct 25 at 9:00 AM through Oct 26 at 8:59 AM (one gas day). This is a repost of the same event originally filed as TW-121527 on Oct 24; no operational changes are evident. Pre-event throughput past Station 3 (Leupp, AZ) was running at a median of approximately 1.11 Bcf/d westbound (range 1.04-1.26 Bcf/d), but no specific capacity cap is stated in this notice.
TW force majeure on the Thoreau West mainline cuts unquantified westbound capacity on the San Juan/Permian-to-California corridor for one gas day (Oct 25-26); expect bullish pressure at SoCal Border and Arizona delivery points, with offsetting bearish pressure at Waha/San Juan basis -- pre-event throughput was ~1.11 Bcf/d westbound, actual cut unquantified.
Reroute: Moderate: EPNG serves overlapping SoCal border and Arizona markets and is the primary alternative, but any simultaneous EPNG constraint would eliminate California reroute entirely.
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Force Majeure
1 Days
Transwestern Pipeline has declared a force majeure on the M/L Thoreau West System effective Oct 25 9:00 AM through Oct 26 8:59 AM (one gas day). This is a revision of prior notice TW-121532 (same event, same location), sliding the effective window forward by one day; no capacity figures are stated in either notice. Pre-event flow past Station 3 (Leupp, AZ) had been running at a median of approximately 1.11 Bcf/d westbound (range 1.02-1.26 Bcf/d over Oct 18-24), but the notice provides no cap or stated reduction, so net cut is unquantified.
TW force majeure on the Thoreau West mainline (pre-event ~1.11 Bcf/d westbound) cuts unquantified capacity on the San Juan/Permian-to-California corridor for one gas day (Oct 25-26); expect bullish pressure at SoCal Border and Arizona delivery points, with offsetting bearish pressure at Waha/San Juan as westbound takeaway is impaired -- update_direction is bearish because the prior notice (TW-121532) already covered Oct 24-25 and this posting simply shifts the FM window one day forward with no new operational escalation.
Reroute: Moderate: EPNG serves the same SoCal border market and provides a partial alternative, but if EPNG is simultaneously constrained no California reroute exists; check EPNG conditions before assuming full offset.
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Transwestern Pipeline
[Transwestern Pipeline] [Force Majeure] Force Majeure - Station 3 (Leupp, AZ.) - Compressor Station mechanical Failure - Gas Day 10/24/26 (Until Further Notice)
SEV 4/5
Force Majeure
capped at 1.100 Bcf/d, cut unknown
Transwestern Pipeline declared force majeure at Station 3 (Leupp, AZ) due to a compressor station mechanical failure, effective Gas Day October 24, 2026 until further notice. The Mainline Thoreau West System capacity is restricted to approximately 1.1 Bcf/d with no stated restoration timeline. No pre-event baseline is available in the notice itself to quantify the net reduction, but the 1.1 Bcf/d ceiling on a major westbound segment represents a material capacity constraint on Permian/San Juan outbound flows toward SoCal and Arizona.
TW force majeure at Station 3 caps Mainline Thoreau West at 1.1 Bcf/d UFN; expect bearish pressure at Waha/Permian as westbound takeaway tightens, with bullish pressure at SoCal Border and Arizona delivery points -- EPNG is the only remaining major California-bound alternative.
Reroute: Moderate: EPNG serves the same SoCal border and Arizona markets and is the primary competing pipeline, but a simultaneous EPNG constraint would leave California with no reroute option. At current TW capacity restriction levels, some westbound reroute via EPNG is possible but may not fully offset the constrained volumes.
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Force Majeure
capped at 1.100 Bcf/d, cut unknown
9 Days
Transwestern Pipeline has declared a Force Majeure effective Gas Day October 24, 2026 due to a compressor station mechanical failure at Station 3 in Leupp, AZ. The Mainline Thoreau West System capacity is reduced to approximately 1.1 Bcf/d until further notice, with a currently stated end date of November 2, 2026. This is an unplanned event on a major westbound supply artery serving Arizona and California SoCal border markets.
Transwestern FM at Station 3 (Leupp, AZ) caps Thoreau West System at 1.1 Bcf/d; expect bullish pressure at SoCal Border and Arizona delivery points as westbound capacity is constrained, while Permian/Waha and San Juan basin points face bearish pressure from backed-up supply -- no pre-event baseline available to quantify the net reduction from the stated 1.1 Bcf/d ceiling, and EPNG is the only partial reroute for California markets.
Reroute: Moderate: EPNG serves overlapping SoCal border and Arizona markets and is the primary competing pipeline; however, if EPNG is simultaneously constrained, California supply reroute drops to none. TW and EPNG together represent the two dominant westbound arteries from the Permian and San Juan basins.
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Operational Alert
Until Further Notice
1 Days
Gulf South Pipeline has issued a second consecutive Over-Under Performance notice (new ID 5038899) for Loc 24329 Stratton Ridge to Freeport LNG, covering Gas Day 10/21/2026 and until further notice -- an exact reissuance of yesterday's notice (GSPL-5038892) shifted forward one gas day. The customer continues to fail to take confirmed quantities at the Stratton Ridge delivery point, and Gulf South will reduce scheduling for remaining nomination cycles based on Projected Daily Quantities. Pre-event scheduled flow at Loc 24329 was 1.43 Bcf/d median (range 1.02-1.46 Bcf/d over the prior seven days), against 1.78 Bcf/d operating capacity; no explicit new cap or volume cut is stated in this notice.
Freeport LNG feed gas curtailment at Stratton Ridge (Loc 24329) now extends a second consecutive gas day (10/21/2026 UFN); pre-event scheduled flow was ~1.43 Bcf/d median (1.02-1.46 range) vs 1.78 Bcf/d operating capacity, with displaced volumes remaining in the domestic Gulf Coast pool -- bearish Henry Hub regional proxy as long as the under-take persists.
Reroute: None: Stratton Ridge is the dedicated Gulf South delivery point feeding Freeport LNG; displaced feed gas volumes have no alternate export outlet and remain in the domestic market.
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Transwestern Pipeline
[Transwestern Pipeline] [Capacity Constraint] ATOKA 2 POINT GROUP
SEV 4/5
Force Majeure
1 Days
Transwestern Pipeline has declared force majeure on the ATOKA 2 POINT GROUP, effective Oct 20 2026 9:00AM through Oct 21 2026 8:59AM. This is a third administrative repost of the same event (prior notices TW-121418 and predecessor), with only the notice ID and posting timestamp changed -- no new operational content. Pre-event scheduled flow at both identified Atoka receipt meters (ATOKA PECOS DIAMOND PL 8 INCH and AGAVE ATOKA #3 STA) was 0.00 Bcf/d throughout the prior week, so the physical cut is currently unquantifiable from flow data alone.
TW force majeure on ATOKA 2 POINT GROUP is a third administrative repost with no new operational content; pre-event flow at both Atoka receipt meters (loc_id 9168 and 500305) was 0.00 Bcf/d so the physical cut is currently unquantifiable, but minimum severity 4 applies given the active force majeure declaration -- split-direction signal: bearish Waha/Permian as TW takeaway is restricted, bullish SoCal Border and Arizona if volumes were scheduled.
Reroute: Moderate: EPNG serves the same SoCal border and Arizona delivery markets as Transwestern and could absorb some displaced volumes, but given the Atoka meters showed zero scheduled flow pre-event, immediate market impact appears minimal.
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Force Majeure
1 Days
Transwestern Pipeline has declared a force majeure on the ATOKA 2 POINT GROUP effective October 20, 2026 at 9:00 AM through October 21, 2026 at 8:59 AM. This is a second administrative repost (TW-121418 follows TW-121409 which followed TW-121397), with only the notice ID and posting timestamp changed -- no new operational content. Pre-event scheduled quantities at both identified Atoka receipt meters (ATOKA PECOS DIAMOND PL 8 INCH, loc_id 9168; AGAVE ATOKA #3 STA, loc_id 500305) were 0.00 Bcf/d, so the physical volume impact remains unquantifiable from available data.
TW force majeure on ATOKA 2 POINT GROUP is a second administrative repost with no new operational content; pre-event flow at both Atoka receipt meters was 0.00 Bcf/d so the physical cut is currently unquantifiable, but minimum severity 4 applies given the active force majeure declaration -- split-direction signal applies: bearish Waha/Permian as basin takeaway is curtailed, bullish SoCal Border and Arizona delivery points.
Reroute: Moderate: EPNG serves overlapping SoCal border and Arizona delivery markets and may absorb displaced volumes, but a simultaneous EPNG constraint would leave no California reroute alternative.
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Force Majeure
0.061 Bcf/d cut (capped at 0.447 Bcf/d)
7 Days
Southern Natural Gas has escalated planned SESH maintenance at the Delhi and Gwinville Compressor Stations to a force majeure event affecting SNG-SESH capacity on Segment 380. Normal capacity of 507,689 Dth/d (0.508 Bcf/d) is reduced on six specific gas days between October 20-29, with the largest single-day reduction occurring October 28 when capacity falls to 447,000 Dth/d (a cut of ~60,689 Dth/d or ~0.061 Bcf/d). Out-of-Path and In-Path services are at risk based on current nominations.
SNG Segment 380 force majeure cuts SNG-SESH interconnect capacity by up to 0.061 Bcf/d on the worst day (Oct 28, restricted to 0.447 Bcf/d), with curtailments on six days through Oct 29; expect mild bullish pressure on Southern Natural La. and Southeast basis as out-of-path and in-path services face curtailment risk.
Reroute: Moderate: Gulf South and Transco serve overlapping Southeast markets and may absorb some displaced volumes; however, SNG is the dominant Southeast pipeline and SESH is a primary Gulf Coast interconnect, so full reroute is unlikely to offset all affected nominations on constrained days.
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Transwestern Pipeline
[Transwestern Pipeline] [Capacity Constraint] ATOKA 2 POINT GROUP
SEV 4/5
Force Majeure
1 Days
Transwestern Pipeline has declared a force majeure on the ATOKA 2 POINT GROUP, effective October 20 at 9:00 AM through October 21 at 8:59 AM. This is an administrative repost of TW-121397 (itself a repost of TW-121388) with only the notice ID and posting timestamp changed -- no new operational content. Pre-event scheduled flow at both identifiable Atoka receipt meters (ATOKA PECOS DIAMOND PL 8 INCH and AGAVE ATOKA #3 STA) was 0.00 Bcf/d across the prior week, so the physical volume impact is currently unquantifiable.
TW force majeure on ATOKA 2 POINT GROUP is a same-day administrative repost of TW-121397 with no new operational content; pre-event flow at both Atoka receipt meters was 0.00 Bcf/d, so the physical cut is currently unquantifiable, but minimum severity 4 applies given the active force majeure declaration -- split direction: bearish Waha/Permian as TW takeaway is constrained, bullish SoCal Border and Arizona delivery points.
Reroute: Moderate: EPNG serves overlapping SoCal border and Arizona markets and is the primary alternative to Transwestern; however, if EPNG is simultaneously constrained, no California reroute exists.
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Columbia Gulf Transmission (CGT)
SEV 4/5
Maintenance
0.100 Bcf/d cut (capped at 0.700 Bcf/d)
2 Days
CGT is conducting planned maintenance at Lake Arthur Compressor Station on October 27-28, 2026, which will reduce delivery capacity at Cameron LNG (loc 4246) from its design capacity of 0.800 Bcf/d to 0.700 Bcf/d (Primary Only), a reduction of 0.100 Bcf/d. CGT explicitly warns that this restriction may result in curtailments to Interruptible, Secondary Firm, and Primary Firm services. Live capacity data for Cameron LNG (loc 4246) shows the point currently running at 0.696 Bcf/d scheduled against 0.800 Bcf/d operating capacity, confirming the new 0.700 Bcf/d cap is effectively at or just above current flows but Primary Firm curtailment risk makes this actionable.
CGT maintenance cuts Cameron LNG feed gas delivery cap by 0.100 Bcf/d (0.800 to 0.700 Bcf/d) on Oct 27-28 with explicit Primary Firm curtailment risk; gas that cannot be exported stays domestic, bearish for Henry Hub and Gulf Coast basis over the two-day window.
Reroute: Limited: Cameron LNG feed gas can only arrive via pipelines serving that terminal; no alternative LNG export outlet exists for these specific curtailed volumes, so the gas remains in the domestic market.
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Operational Alert
Until Further Notice
1 Days
Gulf South Pipeline issued a Critical Over-Under Performance notice on Gas Day 10/20/2026 for Loc 24329 (Stratton Ridge to Freeport LNG), citing a customer's failure to take confirmed quantities and triggering scheduling reductions for remaining nomination cycles through at least Gas Day 10/21/2026. This is a recurrence of the same event posted on 10/17/2026 (GSPL-5038889). The live evening-cycle reading at Loc 24329 shows 1.45 Bcf/d scheduled against 1.78 Bcf/d operating capacity (81.5% utilized, 18.5% headroom), compared to a pre-event 7-day median of 1.43 Bcf/d (range 1.11-1.46 Bcf/d); no explicit volume cut is stated, but scheduling reductions are anticipated and the UFN language keeps the event open-ended.
Gulf South curtailment at Stratton Ridge (Loc 24329) again reduces Freeport LNG feed gas on Gas Day 10/20/2026 -- pre-event baseline was 1.43 Bcf/d median (range 1.11-1.46), live evening cycle shows 1.45 Bcf/d scheduled vs 1.78 Bcf/d operating capacity with no explicit cut volume stated; displaced gas stays in the domestic Gulf Coast pool, bearish Gulf Coast/Henry Hub basis; this is a repeat occurrence from 10/17 and remains UFN.
Reroute: None: Freeport LNG feed gas delivered via this specific lateral cannot be rerouted to the terminal through an alternative path; any curtailed volume remains in the domestic pipeline system.
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Transwestern Pipeline
[Transwestern Pipeline] [Capacity Constraint] ATOKA 2 POINT GROUP
SEV 4/5
Force Majeure
1 Days
Transwestern Pipeline has declared force majeure on the ATOKA 2 POINT GROUP, effective Oct 20 2026 9:00AM through Oct 21 2026 8:59AM -- a roughly 24-hour window. This posting (TW-121397) is an administrative repost of TW-121388 filed earlier the same day with no operational changes. Pre-event scheduled quantities at the two identified Atoka receipt meters (loc_id 9168 and 500305) were 0.00 Bcf/d throughout the prior seven gas days, so the immediate physical supply reduction appears negligible based on recent flow.
TW force majeure on ATOKA 2 POINT GROUP is a same-day administrative repost of TW-121388 with no new operational content; pre-event flow at both Atoka receipt meters was 0.00 Bcf/d, so the physical cut is currently unquantifiable but minimum severity 4 applies given force majeure declaration -- split-direction signal remains bearish Transwestern Permian/Waha basis and mildly bullish SoCal Border and Arizona delivery points.
Reroute: Moderate: EPNG serves overlapping SoCal border and Arizona delivery markets and can partially offset Transwestern constraints; however, if EPNG is simultaneously constrained, California reroute options are effectively eliminated.
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Force Majeure
1 Days
Transwestern Pipeline has declared a force majeure on the ATOKA 2 POINT GROUP, effective October 20 at 9:00 AM through October 21 at 8:59 AM -- approximately one gas day. No specific capacity volume is stated in the notice. Pre-event flow data for the two named Atoka-area receipt points (ATOKA PECOS DIAMOND PL 8 INCH, loc_id 9168; AGAVE ATOKA #3 STA, loc_id 500305) shows zero scheduled quantities over the prior seven days, suggesting this is a small receipt-point group with minimal throughput ahead of the event.
TW force majeure on ATOKA 2 POINT GROUP applies split-direction pressure: bearish Waha and Transwestern Permian basis as any constrained receipts back up at the basin, and mildly bullish SoCal Border and Arizona delivery points; pre-event flow at the two identified Atoka receipt meters was 0.00 Bcf/d across the prior week, so immediate market impact is likely negligible in volume terms despite the FM declaration.
Reroute: Moderate: EPNG serves overlapping Permian-to-California and Permian-to-Arizona corridors and can absorb marginal volumes if needed; however, given near-zero pre-event flows at the identified Atoka meters, reroute need appears minimal.
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Force Majeure
0.205 Bcf/d cut (capped at 0.180 Bcf/d)
Until Further Notice
25 Days
Southern Star has declared a force majeure at the Saginaw Compressor Station (Jasper County, MO) due to a mechanical failure of the Saginaw Turbine, reducing capacity by 180,000 Dth/d (0.180 Bcf/d) at Saginaw CS and 25,000 Dth/d (0.025 Bcf/d) at Empire Energy Center, totaling 0.205 Bcf/d. This update (superseding #11240) pushes the in-service date back to November 2, 2026, extending the outage that began ID2 cycle October 9. Live capacity data for Saginaw CS Area Deliveries (loc_id 444550) shows operating capacity at 0.180 Bcf/d with 0.143 Bcf/d scheduled, corroborating the reduced operating cap stated in the notice.
Southern Star force majeure at Saginaw CS removes 0.205 Bcf/d of Midcontinent/Missouri delivery capacity through Nov 2; timeline extension is bearish for update direction but the sustained capacity loss is bullish for Southern Star basis -- watch for tightening in Kansas/Missouri LDC markets with limited reroute via ANR, PEPL, or Southern Star alternatives.
Reroute: Moderate: ANR and Panhandle Eastern (PEPL) serve overlapping Midcontinent and Midwest corridors and may absorb some volumes, but Southern Star serves specific Kansas/Missouri local markets that have limited direct bypass options.
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Force Majeure
0.040 Bcf/d cut (capped at 0.035 Bcf/d)
1 Days
Transwestern Pipeline has declared a force majeure at Atoka 2 Compressor Station (Artesia area, NM) due to mechanical failure, effective Gas Day October 20, 2026. Total station capacity will be reduced from 75,000 MMBtu/d (0.075 Bcf/d) to approximately 35,000 MMBtu/d (0.035 Bcf/d), a reduction of ~0.040 Bcf/d, affecting receipt volumes from DCP Artesia Plant (POI 10703) and Dagger Draw Plant (POI 56339). Transwestern states capacity will return to 75,000 MMBtu/d on Gas Day October 21, making this a single-day event.
TW force majeure removes ~0.040 Bcf/d of Artesia-area Permian receipt capacity for Gas Day Oct 20 only; pre-event DCP Artesia (loc 10703) was scheduling ~0.031 Bcf/d against 0.038 Bcf/d operating capacity and Dagger Draw (loc 56339) was scheduling ~0.050 Bcf/d, so the combined receipts at risk broadly align with the stated cut -- expect modest bearish pressure at Waha/Permian basis with negligible downstream SoCal Border impact given the small aggregate volume and single-day duration.
Reroute: Limited: Transwestern and EPNG both serve the SoCal border from Permian receipt points; EPNG could absorb marginal volumes from Artesia-area producers, but at 0.040 Bcf/d the cut is small enough that system-wide reroute impact is minimal. The one-day duration further limits market significance.
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Operational Alert
Until Further Notice
1 Days
Gulf South Pipeline issued a Critical Over-Under Performance notice for Gas Day 10/17/2026, citing the customer's failure to take confirmed quantities at Loc 24329 Stratton Ridge to Freeport LNG. Gulf South is implementing scheduling reductions for remaining nomination cycles on 10/17 and until further notice. Live capacity data shows Stratton Ridge (Loc 24329) running at 1.46 Bcf/d scheduled against 1.78 Bcf/d operating capacity (82.2% utilization, 0.317 Bcf/d headroom) as of the evening cycle; the pre-event baseline median was 1.43 Bcf/d over the prior seven gas days, so the posted evening reading is consistent with a partial reduction already in progress with no stated volume for the cut.
Gulf South curtailment at Stratton Ridge (Loc 24329) reduces Freeport LNG feed gas on Gas Day 10/17/2026 -- pre-event baseline was 1.43 Bcf/d (flat over the prior week), live evening cycle shows 1.46 Bcf/d scheduled against 1.78 Bcf/d operating capacity with no explicit cut volume stated; gas displaced from LNG export remains in the domestic Gulf Coast market, bearish for Henry Hub-area pricing.
Reroute: None: this notice directly curtails feed gas deliveries to Freeport LNG at the terminal delivery meter; there is no alternative pipeline pathway that replaces LNG offtake once the customer fails to take at the terminal.
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Force Majeure
0.395 Bcf/d cut (capped at 0.930 Bcf/d)
Until Further Notice
29 Days
ANR Pipeline has extended its Force Majeure at St. John Eastbound (LOC #FPSTJNEB) on the Michigan Leg South through October 31, 2026, pushed back from the prior end date of October 19. The FM was originally declared on October 3 due to an anomaly between MLV 56 and MLV 57, reducing eastbound capacity by 395 MMcf/d (0.395 Bcf/d), leaving 930 MMcf/d available. Firm Primary curtailments of approximately 34% of contracted MDQ remain in effect, with RCC eligibility active under ANR Tariff Section 6.36.
ANR FM at St. John Eastbound removes 0.395 Bcf/d of Michigan Leg South eastbound capacity through Oct 31 (extended from Oct 19); live data shows 0.977 Bcf/d operating capacity with 0.642 Bcf/d scheduled on TD1 against the 0.930 Bcf/d post-FM ceiling, consistent with the stated constraint, and pre-event flow averaged ~0.67 Bcf/d (0.60-0.77 range) on TD1 -- the 0.930 Bcf/d cap sits above recent scheduled flow but well below normal operating capacity, with firm primary shippers taking a ~34% MDQ curtailment signaling real tightness at ANR ML 7 Michigan delivery points.
Reroute: Limited: TETCO, TGT, and PEPL serve overlapping Midwest/Michigan markets but ANR Michigan Leg South is a specific geographic corridor; partial reroute may be possible via TETCO or PEPL for some Michigan deliveries but full offset is unlikely given the firm primary curtailment level.
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Columbia Gas Transmission (TCO)
SEV 4/5
Force Majeure
1.900 Bcf/d
Until Further Notice
TCO has issued a revision to its October 14, 2026 force majeure on MXP Line-100 in West Virginia, originally triggered by a detected leak near the Saunders Creek Regulator Station (a separate event from the September 24 force majeure on the same line). As of this update, MXPSEG remains at zero total capacity, with firm service impact estimated at 1.9 MMDth/day; TCO is estimating a return to service for Gas Day Saturday October 17, 2026, though the timeline is subject to change and Timely/Evening Cycle nominations for October 17 are likely to be impacted. The force majeure and capacity elimination remain fully in effect, and RCC eligibility requires 10 or more consecutive days of firm curtailment.
TCO force majeure on MXPSEG remains at zero total capacity with 1.9 Bcf/d of estimated firm service impact; targeted return is October 17 but is not guaranteed, keeping bearish pressure on Columbia Appalachia basis and mildly bearish pressure on Dominion South and TETCO M2 through at least the weekend gas days.
Reroute: Limited to moderate: TETCO (monitored) and Equitrans serve overlapping Appalachian markets, but TCO MXPSEG is very high capacity and 1.9 Bcf/d of stranded firm volumes cannot be fully absorbed by competing pipes without significant basis pressure at Columbia Appalachia pool.
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Maintenance
0.400 Bcf/d cut (capped at 1.530 Bcf/d)
Until Further Notice
6 Days
CTPL 2026 Q4 maintenance summary (updated 10/15/26) bundles two jobs at Gillis Compressor Station. The highest-impact job is Job 2026115, a 6-day Station Upgrade (11/12-11/18/2026) that reduces available capacity to zero transport impact (0 Dths transport impact) with available capacity of 1,530,000 Dths and a TETCO (CT109413) meter capacity limit set to 0, effectively cutting one feed interconnect entirely. The lesser job, 2026114, is a 15-hour compressor maintenance event (11/17/2026) with a 400,000 Dth/day transport impact and 1,130,000 Dths available capacity.
Job 2026115 Station Upgrade at Gillis Compressor Station (11/12-11/18, 6 days) sets TETCO CT109413 meter limit to zero and posts zero transport impact Dths with 1.530 Bcf/d available capacity, reducing feedgas flexibility at Sabine Pass LNG and applying bearish pressure on Henry Hub as export throughput is constrained during the upgrade window.
Reroute: None: Sabine Pass LNG is the delivery endpoint; no alternative pipeline can substitute for LNG feedgas curtailed at the Gillis terminal interconnect during the station upgrade.
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Force Majeure
0.205 Bcf/d
Until Further Notice
14 Days
Southern Star declared force majeure on Line Segment 455 due to a mechanical turbine failure at Saginaw Compressor Station in Jasper County, Missouri, effective October 9, 2026 (ID2 cycle). Capacity reductions total 205,000 Dth/d (0.205 Bcf/d): 180,000 Dth/d at Saginaw CS (Location ID 444550) and 25,000 Dth/d at Empire Energy Center (Location ID 378502). This notice (11240) supersedes 11238 and adds a repair timeline -- contractors are scheduled to complete turbine repairs by October 26, 2026, approximately two weeks from the notice date.
Southern Star force majeure removes 0.205 Bcf/d of Midcontinent/Kansas-Missouri capacity through approximately October 26; expect mild bullish pressure on Southern Star basis and Kansas-Missouri delivery markets, with tightening most acute at points downstream of Saginaw CS -- live data shows Saginaw CS Area Deliveries (loc 444550) running at 83.9% utilization with only 16.1% headroom, consistent with the stated constraint.
Reroute: Moderate: ANR, PEPL, and Southern Natural (EGT) serve overlapping Midcontinent and Kansas-Missouri markets, though Southern Star serves specific local delivery points in Missouri that may have limited bypass. PEPL Princeton Receipt (loc 17131) is posting 74.5% utilization with 25.5% headroom, suggesting some alternative capacity exists.
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Force Majeure
0.205 Bcf/d
Until Further Notice
Southern Star declared force majeure effective October 9, 2026 due to a mechanical failure at Saginaw Compressor Station in Jasper County, Missouri. The event reduces capacity by 180,000 Dth/d (0.180 Bcf/d) at Saginaw CS (Location ID 444550) and 25,000 Dth/d (0.025 Bcf/d) at Empire Energy Center (Location ID 378502), for a combined 0.205 Bcf/d reduction on Line Segment 455. No restoration timeline has been given; Southern Star will post updates as available.
Southern Star force majeure removes 0.205 Bcf/d of Midcontinent throughput capacity on Line Segment 455 with no restoration timeline; expect bullish pressure on Southern Star / Midcontinent Kansas-Missouri basis with tightening likely to spill into Oneok Oklahoma pricing and modest supportive signal at Henry Hub if Midwest pull-back reduces southbound displacement.
Reroute: Moderate: ANR, PEPL, and TIGT serve overlapping Midcontinent and Kansas/Missouri markets and could absorb a portion of the displaced volumes, but Southern Star Line Segment 455 serves specific local and downstream Missouri delivery points that may have limited bypass options.
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Force Majeure
0.395 Bcf/d cut (capped at 0.930 Bcf/d)
Until Further Notice
17 Days
ANR Pipeline has declared a force majeure on the Michigan Leg South at St. John Eastbound (LOC #FPSTJNEB) due to an anomaly discovered between MLV 56 and MLV 57, restricting capacity by 395 MMcf/d (0.395 Bcf/d) and leaving only 930 MMcf/d available. The constraint, originally set to run from 10/3 through 10/12, has now been extended through 10/19, a total of 17 days. ANR anticipates firm primary curtailments of approximately 34% of contracted MDQ, with firm secondary and interruptible services also affected.
ANR force majeure removes 0.395 Bcf/d of Michigan Leg South eastbound capacity through 10/19; pre-event flow at St. John Eastbound (FPSTJNEB TD1) was running at a median 0.67 Bcf/d (range 0.59-0.75) against the now-constrained 0.977 Bcf/d operating capacity, with the new 0.930 Bcf/d cap implying a modest physical cut relative to recent scheduled flows of ~0.593 Bcf/d currently posted, but firm primary curtailments at 34% of MDQ signal tightening at ANR ML 7 Michigan/Wisconsin delivery markets.
Reroute: Limited: ANR is one of the primary pipelines serving Michigan and Wisconsin markets; NGPL, PEPL, and ANR's own alternative segments provide partial relief but cannot fully replace constrained Michigan Leg South eastbound capacity, particularly for firm primary shippers already facing 34% MDQ curtailments.
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Tennessee Gas Pipeline (TGP)
SEV 4/5
Force Majeure
Until Further Notice
Tennessee Gas Pipeline has declared a force majeure on its Muskrat Line (Segments 509, 515, 516, 523, and 524) effective Gas Day October 9, 2026 and until further notice, due to evacuations in the Cocodrie, Louisiana area driven by the projected path and landfall of Hurricane Isaias. Primary In the Path capacity at Segment 524 FH may be impacted as early as the Timely Cycle for October 9. No specific capacity volume is stated; duration is indeterminate (UFN).
TGP Muskrat Line force majeure effective 10-9-26 UFN removes Gulf Coast zone supply with no stated capacity figure but hurricane-driven evacuations at Cocodrie create immediate risk to primary firm service on Segments 509-524; expect bullish pressure on Tennessee Zone 0/1 downstream basis and potential widening at Transco Zone 4 as Gulf Coast TGP supply is at risk.
Reroute: Limited: Gulf South (monitored) and Columbia Gulf Transmission serve overlapping Gulf Coast corridors, but hurricane evacuation conditions affecting the Cocodrie area may simultaneously constrain other Gulf Coast infrastructure; reroute cannot be assumed reliable while Isaias threatens landfall.
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Force Majeure
2.274 Bcf/d
REX declared a force majeure at Hamilton Compressor Station effective ID1 cycle Gas Day October 7, 2026, and until further notice. Segment 360 eastbound capacity is restricted to 2.274 Bcf/d, with upstream segments 370 and 380 also curtailed to 2.657 and 2.692 Bcf/d respectively. Primary firm, secondary firm, and AOR/ITS quantities are all at risk of not being scheduled.
REX Hamilton FM caps Seg 360 E-to-W flow at 2.274 Bcf/d with firm and secondary firm service at risk; expect bullish pressure at Lebanon Hub and Midwest delivery points as westbound throughput tightens, with no clear HH directional signal given REX's Midwest-facing flow path.
Reroute: Limited: Trailblazer Pipeline (TPC) is the primary Rockies eastbound alternative, but REX and Trailblazer share Bertrand Compressor Station -- they are not independent reroutes for one another, limiting offset capacity. Zone 3 Appalachian westbound reversals on REX may partially compensate for Midwest demand, but firm service curtailment risk leaves limited near-term relief.
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Restoration
Until Further Notice
Cove Point LNG is terminating a previously active capacity restriction (PPO) effective 2026-10-07 at 03:00. This restoration notice signals that prior feedgas delivery constraints at Cove Point are being lifted, restoring normal LNG export operations. No specific capacity figure is stated in the notice.
Restoration of Cove Point LNG feedgas capacity removes a prior bearish domestic supply overhang; resumption of LNG exports is bullish for Henry Hub and tightens Appalachian/Mid-Atlantic basis (Eastern Gas South and Transco Zone 5), as gas previously retained onshore will now flow to the export terminal -- live capacity at COVE POINT PLANT (loc 10001, SI:SIQ) shows 0.013 Bcf/d currently scheduled against 1.80 Bcf/d operating capacity, confirming the terminal was running near zero under the prior restriction.
Reroute: Not applicable -- this is a restoration event lifting a prior restriction at Cove Point LNG; no reroute assessment required.
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Maintenance
0.400 Bcf/d
Until Further Notice
1 Days
This is a bundled CTPL 2026 Planned Outage and Maintenance Summary covering two independent jobs. The most impactful single job is Job 2026114 (Q4): a 15-hour compressor maintenance window at Gillis Compressor Station on 11/17/2026 (3:00 a.m. to 6:00 p.m.), with a transport impact of 400,000 Dths (0.400 Bcf/d) and available capacity reduced to 1,130,000 Dths. Job 2026112 (Q3, 9/29-10/2, 4 days) is a LEAP Meter Station upgrade with zero transport impact and should not be treated as a capacity-affecting event.
Job 2026114 removes 0.400 Bcf/d of Sabine Pass LNG feedgas capacity for ~15 hours on 11/17/2026, reducing available CTPL throughput to 1.130 Bcf/d; LNG feedgas curtailment keeps that volume in the domestic market, bearish Henry Hub for that gas day, with the Gillis-LEAP interconnect (CT109461) currently scheduled at 0.735 Bcf/d against 1.00 Bcf/d operating capacity providing partial buffer.
Reroute: Limited: CTPL is the dedicated feed gas pipeline for Sabine Pass LNG; no alternative pipeline directly replaces CTPL feedgas supply to the terminal, though Cheniere may partially offset the 15-hour window through storage or scheduling adjustments.
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Tennessee Gas Pipeline (TGP)
SEV 4/5
Force Majeure
0.580 Bcf/d
Until Further Notice
Tennessee Gas Pipeline declared a force majeure on October 2, 2026 between valve sections 313A-403 to 313A-404 on the HC Line just south of Avoca, New York, following discovery of an anomaly requiring immediate repair. This is Revision 3, issued as a reminder that repair work is scheduled to begin on October 6, 2026, with primary firm capacity at MLV 313 HC Zone 4 End (Segment 399 FH) at risk for up to 0.580 Bcf/d; meters 412803 (TGP Gravel Run) and 421068 (TGP Wyckoff Storage) are being physically shut in for the duration of work, with all secondary receipts and deliveries restricted. No restoration timeline has been provided.
TGP HC Line force majeure threatens up to 0.580 Bcf/d of primary firm capacity at MLV 313 Zone 4 End with no restoration timeline; expect bullish pressure on Tennessee Zone 4-300 and Zone 6 New England basis as Appalachian corridor flows through this segment are curtailed, with Wyckoff Storage shut in compounding supply tightness for downstream Northeast markets.
Reroute: Limited: Transco is the primary competing pipeline for Northeast deliveries, and while it serves overlapping markets, TGP's HC Line serves specific Appalachian Zone 4 segments with limited bypass; partial reroute via Transco and TETCO is possible but unlikely to fully offset 0.580 Bcf/d of primary firm curtailment given current system loadings.
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Gas Transmission Northwest
SEV 4/5
Force Majeure
2.096 Bcf/d
10 Days
GTN has declared a Force Majeure following an unexpected equipment failure at Sandpoint Compressor Station Unit A, restricting capacity at Flow Past Kingsgate (LOC #3500) to 2.096 Bcf/d from October 6 through October 15, 2026. No incremental volumes will be scheduled on the intraday of October 5. GTN anticipates Firm Primary, Firm Secondary, and Interruptible curtailments, including previously scheduled volumes for the October 6 Evening Cycle, with the Reservation Charge Crediting Mechanism activated.
GTN force majeure at Sandpoint CS Unit A restricts Flow Past Kingsgate to 2.096 Bcf/d through Oct 15, tightening Western Canada/WCSB import flow into the Pacific Northwest and California; expect bullish pressure at Sumas, PG&E Malin, and Stanfield basis points -- the GTN Kingsgate basis had already averaged -1.609 vs HH over the five trading days ended Sep 25 (most recently -1.755 on Sep 25), but those figures predate this FM declaration and do not reflect the now-constrained flow environment.
Reroute: Limited: GTN is the primary Western Canada-to-Pacific Northwest import corridor; Northwest Pipeline (NWP) provides some Pacific Northwest alternative capacity, but cannot fully replace WCSB volumes moving through Kingsgate, and Ruby Pipeline serves a different upstream basin (Rockies/Opal) with no direct Canadian supply substitution.
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Force Majeure
0.395 Bcf/d
Until Further Notice
10 Days
ANR Pipeline declared force majeure on its Michigan Leg South system effective October 3, 2026, due to an anomaly discovered between MLV 56 and MLV 57. Eastbound capacity at St. John (LOC #FPSTJNEB) is reduced by 395 MMcf/d (0.395 Bcf/d), leaving 930 MMcf/d available, with the constraint expected to run through October 12. ANR warns of firm primary (estimated 34% of contracted MDQ), firm secondary, and interruptible curtailments, with RCCs to be issued per Tariff Section 6.36 if primary firm scheduled quantities cannot be met.
ANR force majeure removes 0.395 Bcf/d of eastbound Michigan Leg South capacity through Oct 12, with 34% of contracted firm primary MDQ at risk; expect bullish pressure on ANR ML 7 and Michigan/Wisconsin basis versus Henry Hub as Midwest supply tightens.
Reroute: Limited: TETCO (monitored), TGT (monitored), and PEPL (monitored) serve overlapping Gulf Coast-to-Midwest corridors but cannot fully replace Michigan-specific ANR Michigan Leg South deliveries; downstream Michigan LDC customers in particular have few practical bypass options.
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Tennessee Gas Pipeline (TGP)
SEV 4/5
Force Majeure
0.580 Bcf/d
Until Further Notice
Tennessee Gas Pipeline has declared a Force Majeure between valve sections 313A-403 and 313A-404 on the HC Line just south of Avoca, New York, effective October 6, 2026 starting with the Timely Cycle. An anomaly requiring immediate repair was discovered; repair work begins October 6 with no stated end date. Up to 0.580 Bcf/d of Primary In the Path capacity at MLV 313 HC Zone 4 End (Segment 399 FH) is at risk, and meters 412803 (TGP Gravel Run) and 421068 (TGP Wyckoff Storage) will be physically shut in for the duration.
TGP HC Line force majeure removes up to 0.580 Bcf/d of Zone 4 primary firm capacity effective Oct 6 with no restoration timeline; expect bullish pressure on Tennessee Zone 4 and Zone 6 Northeast/New England basis with Wyckoff Storage shut in compounding supply tightness into the region.
Reroute: Limited: Transco is the primary competing Northeast pipeline and serves overlapping Zone 4/6 markets, but TGP and Transco together are the two dominant Northeast corridors, so a TGP constraint of this size cannot be fully offset without knowing Transco's available capacity; no same-corridor single alternative exists for direct HC Line Zone 4 deliveries north of the constraint point.
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Great Lakes Gas Transmission
SEV 4/5
Compressor Issue
0.504 Bcf/d
Great Lakes Gas Transmission declared unplanned maintenance at Rapid River Compressor Station 9 effective October 1, 2026, with a critical capacity reduction taking effect October 2 until further notice. Eastbound capacity at Crystal Falls CS (LOC #3911656) will be reduced by 504 MMcf/d (0.504 Bcf/d), leaving only 1,210 MMcf/d (1.210 Bcf/d) of eastbound capacity. GLGT explicitly warns this may result in Firm Primary curtailments, estimating 22% impact to Firm Primary service, with Reservation Charge Crediting triggered under Section 6.10.3(d).
Unplanned GLGT compressor outage removes 0.504 Bcf/d of eastbound capacity until further notice with confirmed 22% Firm Primary impact; expect bullish pressure at Chicago Citygate, Emerson/Viking GL, and Dawn Ontario basis as Western Canadian supply routed through GLGT is curtailed, with the no-restoration-timeline and firm service curtailment language supporting a sustained tightness signal in Upper Midwest markets.
Reroute: Limited: GLGT is a primary Western Canadian import path into the Upper Midwest and Michigan; while ANR and TransCanada Mainline interconnect with the system, the constraint is on GLGT's own mainline eastbound segment and volumes scheduled on this path have limited immediate alternatives at comparable cost or capacity.
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