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.
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.
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.
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.
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.
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 MajeureUntil 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.
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.
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.
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.
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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NEXUS Gas Transmission (U.S.)
09/07/2026- NEXUS Pipeline Conditions for 09/08/2026
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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El Paso Natural Gas (EPNG)
[OPERATIONAL FLOW ORDER] SOC Declaration - System Wide DRAFT
SEV 3/5
Operational Alert
EPNG has declared a system-wide Strained Operating Condition (SOC) effective September 5, 2026 with duration 'Until Further Notice,' citing linepack at 7,377 MMcf -- a 14 MMcf draw driven by deliveries exceeding scheduled volumes. EPNG has activated Washington Ranch storage withdrawal, suspended imbalance payback and IHSW service, and imposed a 5% imbalance tolerance. No specific capacity volume is quantified in the notice.
EPNG delivery-end SOC tightens westbound delivery schedules toward SoCal Border and Arizona, bullish those basis points; Waha/Permian is neutral as Permian receipts are unaffected and Washington Ranch withdrawal is adding system supply to offset the linepack deficit.
Reroute: Moderate: Transwestern Pipeline (TW) serves overlapping SoCal border and Arizona markets as the primary competing alternative to EPNG, though a simultaneous TW constraint would eliminate California reroute options entirely.
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Transwestern Pipeline
[Transwestern Pipeline] [Operational Alert] CRITICAL NOTICE - SAME DAY - OVERAGE ALERT - PHOENIX AREA
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Panhandle Eastern Pipe Line
[Panhandle Eastern Pipe Line] [Maintenance] PEPL Sooner Line Outage
SEV 3/5
MaintenanceUntil Further Notice
Panhandle Eastern posted a Critical maintenance notice on 2026-09-04 for an outage on the PEPL Sooner Line, affecting seven Oklahoma receipt locations including Dover Hennessey Gas Plant, OGT Hennesey, Lincoln Plant, Reeding Plant, Chisholm Plant, DCP Kingfisher, and Taggart Greenhouse. No end date is specified in the notice (nominal end date of 2200-01-01 indicates open-ended duration), meaning the outage timeline is indeterminate. No specific capacity volume is stated, but the affected meters collectively represent meaningful Midcontinent/Oklahoma receipt points on PEPL.
Open-ended Sooner Line outage restricts Oklahoma receipt volumes on PEPL; Panhandle Tx.-Okla. basis was -0.380 on 2026-09-04 (most recently) and averaged -0.414 over the prior five trading days -- watch for further weakening at that hub vs Henry Hub if the outage duration extends, with mild bullish bias for downstream Midwest markets (Indiana, Michigan) as throughput from affected Oklahoma plants is reduced.
Reroute: Moderate: ANR, TGT, and Southern Star Central serve overlapping Midcontinent/Oklahoma supply corridors and may absorb some stranded volumes, though the Sooner Line serves specific Oklahoma gathering plant receipt points that may have limited physical alternatives at the plant level.
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Nautilus Pipeline Company
09/03/2026- Nautilus - Unplanned Outage at Enterprise Neptune plant
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Columbia Gas Transmission (TCO)
OFO – Receipt Points in Market Areas 26, 30, 35, 41, 42, Effective September 5, 2026
SEV 3/5
Operational AlertUntil Further Notice
TCO has issued a formal OFO effective Gas Day September 5, 2026, requiring shippers with receipts in Market Areas 26, 30, 35, 41, and 42 to align physical receipts at or below scheduled quantities. The OFO is driven by mild weather, reduced market demand, and elevated storage and linepack levels causing excess Appalachian production to threaten system integrity. The order runs until further notice, with penalties up to three times the Columbia Gas Appalachia spot price for non-compliant shippers.
TCO receipt-side OFO across five Appalachian market areas caps physical injections and forces upstream producers to curtail flows into the basin, adding bearish pressure to Columbia Gas Appalachia basis, which was already at -1.265 vs Henry Hub on 2026-09-03 (five-day average -1.122); no volume cap is stated, but the open-ended duration and system-wide geographic scope across MAs 26, 30, 35, 41, and 42 keeps downward pressure on Dominion South and TETCO M2 as excess supply is trapped in the Appalachian basin.
Reroute: Limited: the OFO restricts the receipt side of TCO's Appalachian network; affected producers have few near-term alternatives as TETCO (monitored) and TCO are the two dominant Appalachian takeaway pipes, and any TCO receipt constraint that backs gas up in the basin similarly pressures available TETCO capacity at M2 points. Some modest diversion to Rover or REX Zone 3 is possible but unlikely to absorb material volumes given the broad market-area scope of the OFO.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Columbia Gulf Transmission (CGT)
Hartsville Compressor Station Maintenance (HartSEG), September 9-30, 2026
SEV 3/5
Maintenance0.245 Bcf/d22 Days
CGT has issued a planned maintenance notice for Hartsville Compressor Station (HartSEG) from September 9 through September 30, 2026, reducing backhaul capacity to 2,300,000-2,400,000 Dth/d versus the design capacity of 2,544,656 Dth/d -- a restriction of roughly 144,656-244,656 Dth/d (0.145-0.245 Bcf/d). CGT explicitly warns this may result in curtailments to Interruptible, Secondary Firm, and Primary Firm services. The HartSEG capacity table as of the 2026-09-02 timely cycle shows the segment running at approximately 84.6% utilization at 2.15 Bcf/d scheduled against 2.54 Bcf/d operating capacity, suggesting the upcoming restriction will bite into current headroom and create genuine firm-service curtailment risk.
CGT HartSEG planned maintenance removes approximately 0.145-0.245 Bcf/d of backhaul capacity starting September 9, elevating firm curtailment risk on a corridor that was already at ~85% utilization as of the 2026-09-02 timely cycle; Columbia Gulf mainline basis has been trading around -0.285 to -0.288 vs Henry Hub over the five trading days ended 2026-09-01, and tighter backhaul capacity through HartSEG is bullish for Transco Zone 4 and downstream Southeast markets while adding marginal bearish pressure to Gulf Coast/Haynesville supply points that rely on CGT northbound flow.
Reroute: Moderate: Texas Eastern (TETCO), Trunkline (TGC), and ANR serve overlapping Gulf Coast northbound corridors, but the explicit firm-service curtailment warning from CGT suggests HartSEG is already a critical constraint point with limited slack; affected shippers should pursue alternate paths early as September 9 approaches.
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Gulf South Pipeline
Gulf South Inability to Take Confirmed Quantities on Index 296
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Florida Gas Transmission
[Florida Gas Transmission] [Operational Alert] Overage Alert Day 15% Tolerance
SEV 3/5
Operational Alert1 Days
FGT has declared an Overage Alert Day at 15% tolerance for gas day September 2, 2026, effective 9:00 AM through September 3, 2026 9:00 AM. The notice cites 90-degree temperatures forecast across Florida over the next several days with FGT linepack already below target levels, creating demand-side pressure on the system. FGT will not interrupt previously scheduled Market Area ITS-1 service below elapsed prorated scheduled quantities but is warning customers to closely monitor actual burn versus scheduled volumes.
FGT overage alert tightens Florida supply with linepack below target during a heat event; Florida Gas Zone 3 basis was already at +2.315 vs Henry Hub on 2026-09-01 (trailing 5-day avg +2.013), and sustained 90-degree Florida temperatures with sub-target linepack create further upside basis risk with no reroute available to offset any supply shortfall.
Reroute: None: FGT is the sole large-diameter interstate pipeline serving the Florida peninsula; no bypass exists and no alternative pipeline can replace FGT deliveries into the Florida market.
