Every notice, by week
The month’s most market-relevant notices, highest severity first. Routine postings (severity 1–3) are on the week pages.
Iroquois Gas Transmission
SEV 4/5
Operational Alert
Until Further Notice
Iroquois Gas Transmission has declared an Operational Flow Order (OFO) effective January 15 gas day, in effect until further notice, for all points south of MLV-12, citing expected high volumes and adverse weather. All point operators must adhere strictly to scheduled volumes to maintain pipeline pressure; no unscheduled OBA gas is available, and Flow Control will be activated if necessary. The OFO has no stated end date and directly restricts flexibility for power plants and distribution customers in the New York and southern New England service area.
Iroquois OFO south of MLV-12 with no restoration timeline restricts delivery flexibility into the NYC metro and southern New England market; Iroquois Zone 2 basis has been running at -0.140 vs Henry Hub as of 2026-08-27 but expect significant bullish pressure on Zone 2 and Algonquin Citygate as the OFO tightens operational flexibility during a high-demand weather event with zero unscheduled gas available.
Reroute: Limited to none: Algonquin Gas Transmission serves overlapping southern New England and Connecticut markets, but if Algonquin is simultaneously stressed during the same weather event, there is effectively no reroute for affected Iroquois delivery points south of MLV-12, including Long Island and NYC metro customers.
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Iroquois Gas Transmission
Operational Flow Order
SEV 4/5
Operational Alert
Until Further Notice
Iroquois Gas Transmission has declared an Operational Flow Order (OFO) effective February 23rd gas day, valid until further notice, for all points south of MLV-12. The OFO is driven by expected high volumes and forecasted weather conditions, requiring all point operators to adhere strictly to scheduled volumes to maintain pipeline pressures; OBA gas is suspended and Flow Control may be activated. No end date has been specified, introducing sustained supply risk for New York and New England markets downstream of the affected segment.
Iroquois OFO south of MLV-12 with no restoration timeline tightens deliveries into New York and New England; Iroquois Zone 2 basis was -0.140 vs Henry Hub on 2026-08-27 (five-day average -0.190), and this open-ended OFO with weather-driven demand pressure is bullish for Zone 2 and Algonquin Citygate -- expect basis to widen further as unscheduled flexibility is eliminated and power plant burn nominations are constrained.
Reroute: Limited to none: Algonquin Gas Transmission provides partial alternative supply into New England and New York markets, but Algonquin and Iroquois are the two dominant pipes serving these markets and Algonquin is frequently simultaneously constrained during high-demand weather events, leaving minimal reroute headroom for volumes south of MLV-12.
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Texas Eastern Transmission (TETCO)
SEV 4/5
Compressor Issue
0.579 Bcf/d
TETCO has experienced an unplanned outage at its Lebanon, Ohio compressor station, reducing east-to-west capacity through Berne, Sarahsville, and Somerset to approximately 0.579 Bcf/d and Five Points/Lebanon to 0.676-0.678 Bcf/d. Non-primary nominations at Sarahsville, Five Points, and Lebanon will be restricted beginning Gas Day August 28, 2026, with no firm end date provided. Restoration timeline is unknown; TETCO states updates will follow as repairs progress.
Unplanned Lebanon CS outage cuts TETCO eastbound capacity to 0.579 Bcf/d at the tightest point (Berne/Sarahsville/Somerset) effective August 28; with TETCO M-3 basis already at -1.160 vs Henry Hub as of 2026-08-26, further Mid-Atlantic tightening is likely while Appalachian M-2 supply backs up west of the outage.
Reroute: Limited: Transco (monitored) is the primary competing Mid-Atlantic pipeline and provides partial alternative capacity, but cannot fully replace TETCO M-3 deliveries at comparable volumes; TCO and EGTS serve overlapping Appalachian markets but do not replicate TETCO's Mid-Atlantic reach.
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El Paso Natural Gas (EPNG)
SEV 4/5
Operational Alert
EPNG has declared a system-wide Strained Operating Condition (SOC) effective August 27, 2026, due to linepack falling to 7,530 MMcf following a 105 MMcf draw on Gas Day August 26, driven by deliveries exceeding scheduled volumes. The SOC is in effect until further notice, with EPNG suspending IHSW service, denying imbalance paybacks, and placing Washington Ranch storage on withdrawal. Customers are required to balance deliveries to scheduled supplies immediately.
System-wide EPNG SOC with no stated restoration timeline tightens Permian/San Juan takeaway capacity; Waha basis, already at -1.050 on 2026-08-26 (trailing 5-day average -0.880 vs Henry Hub), faces additional bearish pressure from potential scheduling curtailments, while SoCal Border and Arizona delivery points face bullish pressure from reduced westbound throughput reliability -- monitor for escalation to OFO or firm curtailments.
Reroute: Moderate: Transwestern Pipeline (TW) serves overlapping SoCal border and Arizona markets and provides a partial alternative for westbound Permian flows; however, a simultaneous TW constraint would eliminate California reroute options entirely.
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El Paso Natural Gas (EPNG)
SEV 4/5
Operational Alert
EPNG has declared a system-wide Strained Operating Condition (SOC) effective August 25, 2026, with duration listed as 'until further notice.' Linepack fell to 7,444 MMcf as of the Gas Day August 25 start -- down 291 MMcf from the prior day -- driven by deliveries in excess of scheduled volumes and supply underperformance in the Permian Basin. In response, EPNG has activated Washington Ranch storage withdrawal, suspended IHSW service, and is denying imbalance payback from the system; customers are required to balance deliveries with scheduled supplies.
System-wide SOC with no restoration timeline on EPNG tightens Permian takeaway and pressures linepack; Waha basis, already at -0.870 vs Henry Hub as of 2026-08-24 (5-day average -0.822), faces further bearish pressure as Permian supply backs up, while SoCal Border and Arizona delivery points face reduced supply and bullish basis pressure until the SOC is lifted.
Reroute: Moderate: Transwestern Pipeline (TW) serves overlapping SoCal border and Arizona markets and provides a partial alternative for westbound Permian volumes, though available spare TW capacity is unknown and may not fully offset EPNG throughput constraints during an active SOC.
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El Paso Natural Gas (EPNG)
SEV 4/5
Force Majeure
0.144 Bcf/d
1 Days
EPNG has declared force majeure following a dry seal failure at the Seligman 'C' Compressor Station in Yavapai County, Arizona. The outage reduces operational capacity through the NORTH ML constraint by an additional 144,220 Dth/d (0.144 Bcf/d) effective August 25, 2026 Intraday 1 Cycle, with a stated end date of August 26, 2026 9:00 AM. Repair timeline is uncertain; EPNG has noted it is evaluating options and will post an updated maintenance notice reflecting the total NORTH ML impact.
EPNG force majeure at Seligman 'C' removes an additional 0.144 Bcf/d of westbound NORTH ML capacity; expect bearish pressure at Waha -- already at -0.870 vs Henry Hub as of 2026-08-24 and averaging -0.822 over the prior five trading days -- as Permian basin gas backs up further, with incremental bullish pressure at SoCal Border and Arizona delivery points as westbound supply is further tightened.
Reroute: Moderate: Transwestern Pipeline (TW) serves overlapping SoCal Border and Arizona markets and provides a partial alternative for westbound volumes; however, TW capacity availability is unconfirmed and may not fully absorb the constrained volumes, particularly given ongoing NORTH ML aggregate restrictions.
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Tennessee Gas Pipeline (TGP)
SEV 4/5
Force Majeure
0.280 Bcf/d
Until Further Notice
Tennessee Gas Pipeline has declared a Force Majeure at Station 542 near DeKalb, Mississippi, effective August 25, 2026 and until further notice, after discovering a failure requiring immediate repairs on Unit 1. Units 2 and 3 at the same station have been out of service since March and April 2026 respectively, meaning all three compressor units are now offline simultaneously. Tennessee estimates the capacity impact at up to 0.280 Bcf/d, with Primary In the Path nominations on Segment 539 BH at risk of curtailment as early as the Timely Cycle for August 26, 2026.
TGP force majeure at STA 542 removes up to 0.280 Bcf/d of northbound capacity on Segment 539 BH; with all three compressor units now offline and no restoration timeline, expect bullish pressure on Tennessee Zone 4/500 Leg basis vs Henry Hub -- Tennessee Zone 4-300 leg was already trading at a -1.360 basis vs HH as of 2026-08-24 and the loss of primary firm capacity eligibility beginning August 26 Timely Cycle could drive further widening in Southeast and downstream Northeast zones.
Reroute: Moderate: Southern Natural Gas (not live-monitored) and Gulf South serve overlapping Gulf Coast-to-Southeast corridors and may absorb some displaced volumes, though SNG real-time capacity is unverified and neither pipe fully replicates TGP's northbound reach into the Northeast.
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Maintenance
Until Further Notice
Trunkline Gas Company has posted a Critical maintenance notice effective 2026-08-24 for a high-pressure outage at the Henry Hub (loc 80721). The notice carries no end date (end date is effectively open-ended at 2200-01-01), meaning the constraint is 'until further notice.' Live capacity data for the prior gas day shows HENRY HUB HIGH PRESSURE - TGC - SA running at only 7% utilization on the delivery side (0.035 Bcf/d scheduled against 0.500 Bcf/d operating capacity), consistent with a facility that is largely offline or severely restricted. Because this is the physical Henry Hub high-pressure header, even a partial outage carries outsized price signal importance beyond the raw volume removed.
TGC high-pressure outage at the physical Henry Hub with no restoration timeline is bullish for Henry Hub and Trunkline ELA spot prices; the prior gas day's delivery scheduling at this location collapsed to 0.035 Bcf/d against 0.500 Bcf/d operating capacity (93% headroom, consistent with near-full curtailment), and with no end date this constraint must be traded as open-ended until a restoration notice is posted.
Reroute: Moderate: TETCO (monitored), CGT (monitored), and Gulf South (monitored) all have interconnects in the Henry Hub area and can absorb some diverted volumes, but the Henry Hub itself is a pooling and pricing node -- physical access constraints at the hub itself affect settlement and basis pricing beyond simple volume rerouting.
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Maintenance
0.480 Bcf/d
Until Further Notice
6 Days
ANR Pipeline has posted a planned maintenance outage at the Wheeler Hidetown meter station (Loc #523099) in Wheeler County, Texas, scheduled September 13-18, 2026 (6 days). Capacity at this location will be reduced from 480 MMcf/d to zero, with ANR explicitly warning of 100% curtailments to Firm Primary service based on both current nominations and contracted MDQ. This is a full capacity elimination at a Southwest Area receipt/delivery point affecting all service classes.
ANR Wheeler Hidetown maintenance removes 0.480 Bcf/d of Southwest Area capacity on September 13-18, with 100% Firm Primary curtailments anticipated; expect tightening at ANR ML 7 (Michigan/Wisconsin) delivery basis and modest bearish pressure at Gulf Coast receipt points as northbound takeaway is reduced, with any unaffected competing pipes (TETCO, TGC) as partial mitigation.
Reroute: Moderate: TETCO (monitored), Trunkline/TGC (monitored), and Southern Star (monitored) serve overlapping Gulf Coast-to-Midwest corridors and may absorb displaced volumes, but the 0.480 Bcf/d full curtailment with advance notice gives shippers time to arrange alternatives before the September 13 effective date.
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Gas Transmission Northwest
SEV 4/5
Maintenance
2.550 Bcf/d
10 Days
Gas Transmission Northwest (GTN) has declared an unplanned maintenance outage at Unit 5D affecting Flow Past Kingsgate (LOC #3500), effective 8/26 through 9/4/2026. Available capacity is reduced to 2,550 MMcf/d (2.550 Bcf/d) for the duration. GTN explicitly warns that Firm Primary, Firm Secondary, and Interruptible curtailments are anticipated, and the Reservation Charge Crediting Mechanism has been activated.
GTN unplanned outage at Kingsgate restricts 2.550 Bcf/d of Western Canada/PNW corridor capacity through 9/4; with Firm Primary curtailments possible and GTN Kingsgate basis already deeply negative (most recently -1.710 vs HH as of 2026-08-21), expect the constraint to tighten PG&E Malin and downstream California basis materially over the 8/26-9/4 window.
Reroute: Limited: GTN is the primary Western Canada-to-Pacific Northwest corridor feeding California via Malin; Ruby Pipeline (monitored) and Northwest Pipeline (monitored) provide partial Rockies-origin alternatives but cannot replace WCSB volumes at equivalent scale, and simultaneous system stress on any of these pipes would further limit relief.
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El Paso Natural Gas (EPNG)
SEV 4/5
Force Majeure
0.068 Bcf/d
1 Days
EPNG declared force majeure at Gresham Compressor Station in Culberson County, Texas, due to a failed compressor seal requiring immediate repairs. The station is currently unavailable, reducing operational capacity through the WA2CORN constraint and associated points by 67,738 Dth/d (0.068 Bcf/d) effective August 24, 2026 Evening Cycle (Cycle 2). EPNG has indicated a separate updated maintenance notice will follow to reflect total impact, and the stated end date is August 24, 2026 at 9:00 AM, suggesting a short-duration event.
EPNG force majeure at Gresham Station removes 0.068 Bcf/d of Permian outbound capacity via WA2CORN; expect mild additional bearish pressure at Waha, which was already trading at a -0.815 basis vs Henry Hub as of 2026-08-21 (5-day average -0.825), with a corresponding small bullish signal at SoCal Border and Arizona delivery points -- magnitude is modest relative to system scale but force majeure status and promise of a follow-on notice warrant monitoring for escalation.
Reroute: Moderate: Transwestern Pipeline (TW) serves overlapping SoCal Border and Arizona markets and may absorb some displaced volumes; however, the Culberson County location and WA2CORN constraint are specific to EPNG's Permian mainline corridor, and if TW is simultaneously tight, reroute options diminish.
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Maintenance
0.728 Bcf/d
Until Further Notice
3 Days
ANR Pipeline has planned maintenance at Mermentau Compressor Station in Jefferson Parish, Louisiana, reducing Lake Arthur Southbound (LOC #FPLKARSB) capacity by 0.728 Bcf/d from approximately 1.078 Bcf/d to 0.350 Bcf/d during September 22-24 (3 days). ANR explicitly warns this will likely cause curtailments to Firm Primary (estimated 65-67% based on current nominations/contracted MDQ), Firm Secondary, and Interruptible service, triggering reservation charge credit provisions.
ANR Mermentau CS maintenance removes 0.728 Bcf/d of Lake Arthur Southbound capacity (leaving only 0.350 Bcf/d) Sept 22-24, with 65-67% Firm Primary curtailments expected; live capacity data shows FPLKARSB already running at 93.2% utilization with only 0.078 Bcf/d headroom, confirming the segment is tight pre-event and leaving virtually no buffer to absorb the restriction -- expect significant widening of ANR, La. basis and upward pressure on Midwest/Michigan delivery prices.
Reroute: Moderate: Texas Eastern (TETCO), Columbia Gulf (CGT), and Trunkline (TGC) serve overlapping Gulf Coast northbound corridors and could absorb some displaced volumes, but the scale of firm curtailments (65-67% of primary firm) suggests these alternatives will face strong incremental demand and may lack sufficient spare capacity to fully offset the loss.
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Columbia Gulf Transmission (CGT)
SEV 4/5
Maintenance
0.395 Bcf/d
8 Days
CGT is performing a valve replacement at Means, Kentucky from August 27 through September 3, 2026 (8 days), reducing backhaul capacity on StanSEG to between 1.95 and 2.20 Bcf/d against a design capacity of 2.345 Bcf/d -- a reduction of approximately 0.14 to 0.40 Bcf/d. CGT explicitly warns of potential curtailments to Interruptible, Secondary Firm, and Primary Firm services, meeting the escalation threshold for a severity 4 rating on a planned event. The current live reading shows StanSEG already running at 90.2% utilization (2.12 Bcf/d scheduled of 2.34 Bcf/d operating capacity) on today's timely cycle, meaning the capacity ceiling will drop below current scheduled volumes once the restriction takes effect.
CGT valve maintenance at Means, KY cuts StanSEG backhaul to 1.95-2.20 Bcf/d (down from 2.34 Bcf/d design, a maximum reduction of ~0.395 Bcf/d) and explicitly risks Primary Firm curtailments; Columbia Gulf mainline basis, which has averaged -0.406 vs HH over the five trading days ended 2026-08-19 (most recently -0.420 on 2026-08-19), should widen further bearish as northbound backhaul is constrained and Gulf Coast gas backs up, with bullish pressure at downstream Appalachian and Mid-Atlantic delivery points served by CGT northward flows.
Reroute: Moderate: Texas Eastern (TETCO) and Trunkline (TGC) serve overlapping Gulf Coast northbound corridors and can absorb some diverted volumes, but the live capacity data shows HartSEG and CorinSEG already running at near-zero headroom (2.5% and 0.0% respectively), suggesting the broader CGT mainline system is already tight and reroute capacity may be limited in practice.
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Columbia Gulf Transmission (CGT)
SEV 4/5
Maintenance
0.190 Bcf/d
11 Days
Columbia Gulf Transmission is reducing backhaul capacity on Mainline-200 at BannSEG from August 27 through September 6, 2026 (11 days) for pipeline maintenance. The restriction sets operating capacity at 2.300-2.350 Bcf/d against a design capacity of 2.540 Bcf/d, representing a reduction of approximately 0.190-0.240 Bcf/d (91-93% of design). CGT explicitly warns that Interruptible, Secondary Firm, and Primary Firm services are all at risk of curtailment -- a significant escalation beyond typical non-firm notices.
CGT Mainline-200 BannSEG maintenance removes approximately 0.190-0.240 Bcf/d of northbound backhaul capacity beginning August 27; with Primary Firm at risk and BannSEG currently running at 87.7-94.3% utilization in recent cycles (2.23-2.39 Bcf/d scheduled vs. 2.54 Bcf/d operating capacity), expect bullish pressure on Columbia Gulf mainline basis -- most recently trading at -0.420 vs. Henry Hub as of 2026-08-19 -- with tightening likely as the constraint date approaches and firm curtailment risk narrows scheduling flexibility at Transco Zone 4 and TETCO M3 downstream interconnects.
Reroute: Moderate: Texas Eastern (TETCO) and Trunkline (TGC) serve overlapping Gulf Coast northbound corridors and may absorb some displaced volumes, though both systems carry their own utilization loads and cannot be assumed to have spare capacity without live confirmation. The firm curtailment risk elevates the difficulty of full reroute.
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Capacity Constraint
Until Further Notice
Cove Point LNG (Lusby, MD) has posted a Critical PPO notice effective 2026-09-19 14:00 ET flagging anticipated capacity restrictions at the terminal. No specific capacity volume or restoration date is stated in the notice text. As an LNG export terminal, any feedgas curtailment at Cove Point removes export demand from the domestic Appalachian supply balance, leaving gas onshore.
Anticipated Cove Point restrictions starting 2026-09-19 are bearish for Appalachian and Mid-Atlantic basis -- the Eastern Gas South regional proxy was trading at -1.105 vs Henry Hub as of 2026-08-19 (5-day average -1.019), and reduced LNG export pull will pressure that spread wider; no concrete capacity volume is stated in this notice, so magnitude of feedgas reduction remains unquantified until a follow-up posting.
Reroute: None: Cove Point LNG is a single-terminal LNG export facility with no alternative export outlet; volumes that cannot be liquefied and exported remain in the domestic pipeline system rather than being rerouted to another export point.
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Great Lakes Gas Transmission
SEV 4/5
Maintenance
1.276 Bcf/d
36 Days
Great Lakes Gas Transmission declared unplanned maintenance at Shelvin Compressor Station 3, reducing Emerson Eastbound (LOC #3833975) available capacity to 1.276 Bcf/d effective 08/21/2026 09:00 through 09/25/2026 09:00 -- a 36-day outage. GLGT explicitly warns this may result in Firm Primary (estimated 23% impact), Firm Secondary, and Interruptible curtailments, triggering the Reservation Charge Crediting Mechanism under Section 6.10.3(d). The live EMERSON RECEIPT meter (loc 33975) posted operating capacity of 2.34 Bcf/d on the evening cycle of 2026-08-20 with 1.35 Bcf/d scheduled, indicating the restriction will materially cut into currently flowing volumes.
Unplanned GLGT constraint reduces Emerson Eastbound to 1.276 Bcf/d with 23% firm primary curtailment risk, tightening Western Canadian supply into the Upper Midwest; Emerson/Viking GL basis was already deeply negative at -1.655 vs HH on 2026-08-19 (5-day average -1.562), and this outage is bullish for Chicago citygate and Dawn Ontario as Canadian throughput to those markets is squeezed for 36 days starting 08/21.
Reroute: Limited: GLGT is the primary Western Canadian import path into Minnesota, Wisconsin, and Michigan; ANR and other Gulf/Midcontinent-sourced pipes serve overlapping Midwest markets but cannot directly replace WCSB volumes entering at Emerson, and the scale of firm curtailments (23% of primary firm) limits full offset.
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Natural Gas Pipeline (NGPL)
SEV 4/5
Force Majeure
Until Further Notice
1 Days
NGPL has declared a force majeure at Compressor Station 168 in Bailey County, Texas (Segment 8, Permian Zone), effective gas day August 20, 2026 Intraday 1 and continuing until further notice. A unit outage requires NGPL to reduce maximum operating capacity northbound from Segment 9 into Segment 8, with the scheduling constraint applied at CS 167. Primary Firm and Secondary in-path Firm transports will be scheduled to no less than 86% of contract MDQ through CS 167; AOR/ITS and Secondary out-of-path Firm transports are suspended for the duration.
NGPL force majeure on Permian Zone northbound capacity (CS 168/167 constraint) cuts firm transport to 86% of MDQ through CS 167, tightening supply flow toward Chicago and Midwest delivery markets; NGPL Midcontinent basis was already at -0.450 vs Henry Hub on 2026-08-19 (5-day average -0.359), and this restriction should narrow that discount as northbound throughput is reduced -- watch for bullish pressure at Chicago Citygate and NGPL Midcontinent basis.
Reroute: Limited: NGPL is one of the highest-capacity Gulf Coast-to-Chicago pipelines, and while ANR, PEPL, and REX Zone 3 serve overlapping Midwest corridors, NGPL's Permian Zone is a major northbound artery and a full-volume reroute at short notice is unlikely; Permian/Amarillo receipt shippers may also face congestion on Transwestern and EPNG as alternatives.
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Gas Transmission Northwest
SEV 4/5
Capacity Constraint
1.796 Bcf/d
8 Days
Gas Transmission Northwest (GTN) is restricting capacity at Flow Past Kingsgate (Loc #3500) from 8/21 to 8/28 to protect pipeline integrity, limiting available capacity to 1.796 Bcf/d for eight days. GTN explicitly warns that Firm Primary, Firm Secondary, and Interruptible curtailments are anticipated, triggering the Reservation Charge Crediting Mechanism. This is a critical, planned maintenance event with confirmed multi-tier curtailment exposure.
GTN restricts Flow Past Kingsgate to 1.796 Bcf/d through 8/28, with Firm Primary curtailments explicitly anticipated; GTN Kingsgate basis was most recently -1.790 vs Henry Hub on 2026-08-19 (5-day average -1.638) and is likely to tighten sharply as the constraint squeezes Western Canada/PNW import flow, with bullish pressure at Stanfield, Sumas, and PG&E Malin.
Reroute: Limited: Northwest Pipeline (NWP) provides some Pacific Northwest market access but does not replicate Kingsgate border crossing volumes; Ruby Pipeline offers a Rockies-origin westbound alternative for California but cannot replace Western Canada supply flowing via GTN-Kingsgate. Full reroute offset is unlikely given the multi-tier curtailment language.
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Transco
Unplanned Maintenance Compressor Station 517 MU5 Outage - Notice of Force Majeure Event
SEV 4/5
Force Majeure
2.375 Bcf/d
Until Further Notice
Transco declared force majeure at Compressor Station 517 Main Unit 5 (Leidy Line, MP 127.96) due to equipment failure, limiting primary firm transportation west-to-east through Station 517 effective December 14, 2025 ID2 cycle. Available primary firm capacity is restricted to 2,375 MDth/d (2.375 Bcf/d), representing 30-40% potential cuts to primary firm shippers based on historical utilization. Estimated return to full service was December 24, 2025 to January 1, 2026, with no confirmed end date posted; this is Revision 3 of a notice originally posted December 14, 2025, and the event dates are approximately 8 months prior to the Last Updated timestamp of August 20, 2026, suggesting this is a legacy repost or administrative revision of an event that resolved in late 2025.
Legacy repost or administrative revision of a December 2025 force majeure event -- Transco CS 517 MU5 restricted 2.375 Bcf/d of primary firm west-to-east capacity with 30-40% firm cuts; market impact was priced at the original December 14, 2025 effective date and no new trading signal applies.
Reroute: Limited: Transco is the dominant Southeast-to-Northeast pipeline and Southern Natural Gas (unmonitored) provides partial alternative capacity in overlapping Southeast corridors, but cannot fully offset primary firm curtailments of this magnitude; Tennessee Gas Pipeline (TGP) serves similar Northeast markets but competing capacity may have been tight during the December 2025 winter period.
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Transwestern Pipeline
[Transwestern Pipeline] [Capacity Constraint] EAST MAINLINE
SEV 4/5
Force Majeure
1 Days
Transwestern Pipeline declared a force majeure capacity constraint on the East Mainline effective Aug 19, 2026 at 9:00 AM through Aug 20, 2026 at 8:59 AM -- a roughly 24-hour event. The East Mainline is the outbound corridor moving Permian and San Juan Basin gas westward toward Arizona and the SoCal border. No specific capacity volume is stated in the notice.
TW East Mainline force majeure (no stated volume) traps Permian/San Juan gas upstream -- expect bearish pressure at Transwestern Permian basis, which has already averaged -0.856 vs HH over the five trading days ended 2026-08-18 (most recently -0.815 on 2026-08-18), with bullish pressure at SoCal Gas border and Arizona delivery points; if EPNG is simultaneously constrained, no California reroute exists.
Reroute: Moderate in isolation: EPNG is the primary competing pipeline for SoCal border and Arizona deliveries. However, if EPNG faces simultaneous constraints, no California reroute exists and the bullish SoCal signal intensifies sharply.
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Operational Alert
Until Further Notice
Gulf South Pipeline has declared a Critical Period across all four of its operating areas (1, 2, 3, and 4) effective 2026-08-19 10:40 AM CT, citing constrained operating conditions and limited operational flexibility to manage shipper imbalances. Shippers are required to balance receipts and deliveries at a Uniform Hourly Rate of Flow, with OFO issuance explicitly threatened if compliance is not achieved. No end time has been posted, and no specific capacity volume has been quantified, but a system-wide Critical Period declaration covering all areas is the broadest possible precursor to a formal OFO on Gulf South.
System-wide Gulf South Critical Period covering all four areas -- the broadest possible pre-OFO alert on this Louisiana/Gulf Coast collector -- signals meaningful supply tightness along the Haynesville and Gulf Coast onshore corridor; the Perryville Transportation Point was already running OVER capacity (scheduled 1.76 Bcf/d vs. 1.10 Bcf/d operating capacity, 159.7% utilization) as of the 2026-08-18 gas day (one day prior to this notice), corroborating the declared system stress; watch for Henry Hub (regional proxy, most recently 2.825 on 2026-08-18) and Transco Zone 4 basis to firm if a formal OFO follows.
Reroute: Moderate: Southern Natural Gas (SNG, unmonitored), Transco (monitored), and Tennessee Gas Pipeline (monitored) serve overlapping Gulf Coast and Southeast markets, providing partial alternative routing for shippers able to redirect volumes; however, a system-wide Gulf South Critical Period affecting all four areas limits the volume that can realistically shift and SNG real-time conditions are unverified.
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Capacity Constraint
Until Further Notice
1 Days
Gulf South Pipeline posted a Critical Over-Under Performance notice on 8/19/2026 citing the customer's failure to take confirmed quantities at Location SLN 24329 (Stratton Ridge to Freeport LNG) in Area 25. Gulf South is reducing confirmations for all remaining nomination cycles for Gas Day 8/19/2026 and until further notice. The prior gas day (8/18) capacity table shows this delivery point with an operating capacity of 1.78 Bcf/d and a scheduled quantity of 0.780 Bcf/d at 43.8% utilization, though those figures predate the event by one gas day and do not reflect the current curtailment.
Freeport LNG feed gas curtailment via Gulf South Stratton Ridge (loc 24329) reduces LNG export offtake and returns gas to the domestic market, applying bearish pressure on Henry Hub and Gulf Coast regional basis; the prior-day table shows up to 0.780 Bcf/d was scheduled at this point, suggesting material volumes are at risk, but the actual curtailed volume is unquantified in this notice.
Reroute: Limited: Freeport LNG feed gas arrives via dedicated laterals and the customer's own receipt infrastructure; Gulf South cannot redirect volumes away from the terminal if the LNG facility is not taking gas, so the domestic supply overhang stands until Freeport LNG resumes normal offtake.
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Operational Alert
Until Further Notice
Cove Point LNG (CPL) has issued an Operational Flow Order (OFO) classified as Critical, effective July 1, 2026 at 14:00. This is Revision 2 of the notice originally posted June 30, 2026. No specific capacity volume is stated in the notice text, and the notice predates the live capacity data window (which reflects August 18, 2026); the COVE POINT PLANT delivery point shows 0.747 Bcf/d scheduled against 0.920 Bcf/d operating capacity (81.2% utilized, 18.8% headroom) as of August 18 -- but this reading postdates the OFO effective date by nearly 7 weeks and cannot be treated as representative of conditions at the time of the OFO. As an LNG export terminal, any OFO at Cove Point carries minimum severity 4.
Cove Point LNG OFO removes or curtails feedgas demand at the terminal, keeping Appalachian supply onshore and pressuring Appalachian/Mid-Atlantic basis bearish; Eastern Gas South regional proxy most recently at -1.005 vs Henry Hub (hub ~1.820, HH ~2.825 as of 2026-08-18), though those prices postdate the July 1 OFO effective date and may not reflect conditions at issuance.
Reroute: Not applicable -- Cove Point LNG is a demand sink (LNG export terminal), not a supply pipeline; an OFO restricts feedgas nominations into the terminal, with no reroute concept applicable to a curtailed LNG export facility.
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CPL
Cove Point Restrictions Revision
SEV 4/5
Capacity Constraint
Until Further Notice
Cove Point LNG (CPL) has posted a Revision 2 to its Cove Point Restrictions notice, originally filed 2026-07-20, designating it as a Critical capacity constraint. No specific restriction volumes or restoration timeline are stated in the notice text. As an LNG export terminal, any feedgas curtailment at Cove Point removes export demand from the domestic Appalachian supply balance, keeping gas onshore and pressuring regional basis bearishly. Live capacity data (gas day 2026-08-18, one day behind) shows the Cove Point Plant delivery point running at 81.2% utilization (0.747 Bcf/d scheduled against 0.920 Bcf/d operating capacity), with 0.173 Bcf/d of headroom; the storage injection point shows an INCONSISTENT flag, so its utilization figures are unreliable.
Cove Point LNG feedgas restriction applies the minimum severity-4 LNG floor; no specific curtailment volume is stated in the notice, but live data (2026-08-18, one day lag) shows the plant delivery point at 81.2% utilization with 0.173 Bcf/d of remaining headroom -- any tightening of that headroom would suppress Appalachian export demand and pressure Eastern Gas South (regional proxy) basis, which most recently printed at -1.005 vs Henry Hub as of 2026-08-18, bearish for Transco Zone 5 delivery points.
Reroute: None: Cove Point is a fixed LNG export terminal; feedgas that cannot be delivered to the liquefaction facility cannot be rerouted to an equivalent export outlet and instead remains in the domestic Appalachian/Mid-Atlantic supply balance.
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Capacity Constraint
Until Further Notice
Cove Point LNG (CPL) has posted a Revision 2 to its Pipeline Conditions / Capacity Constraint critical notice originally filed 2026-07-23, with no additional operational detail or capacity figures provided in the notice text. The notice is a revision with no new quantified impact, but the LNG feedgas severity floor applies because the affected facility is Cove Point LNG export terminal. Live capacity data (gas day 2026-08-18, approximately 1 day lag) shows COVE POINT PLANT operating at 81.2% utilization on the delivery side (0.747 Bcf/d scheduled against 0.920 Bcf/d operating capacity), with 0.173 Bcf/d of remaining headroom; the SI direction is flagged INCONSISTENT and cannot be used for ratio analysis.
Cove Point LNG feedgas constraint minimum severity 4 applies regardless of the absence of a stated volume; the live reading for 2026-08-18 shows the plant delivery point at 81.2% utilization (0.747 Bcf/d scheduled, 0.173 Bcf/d headroom remaining), with the Eastern Gas South regional proxy basis averaging -0.993 vs Henry Hub over the five trading days ended 2026-08-18 (most recently -1.005 on 2026-08-18) -- any escalation of this constraint that further curtails feedgas deliveries would be bearish for Appalachian/Mid-Atlantic basis and bearish for the LNG export arb.
Reroute: None: Cove Point LNG is a fixed-location export terminal; feedgas restrictions cannot be physically rerouted to an alternative facility. Gas displaced from LNG export returns to the domestic Appalachian/Mid-Atlantic supply pool.
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Force Majeure
1 Days
Transwestern Pipeline declared force majeure on its East Mainline, effective Aug 19 2026 9:00AM through Aug 20 2026 8:59AM -- a roughly 24-hour window. The East Mainline is the outbound corridor carrying Permian and San Juan Basin gas westward toward SoCal/Arizona delivery points. No specific capacity volume is stated in the notice.
TW East Mainline force majeure creates a split-direction signal: expect bearish pressure at Transwestern Permian basis (most recently -0.815 vs HH on 2026-08-18, five-day average -0.856) and Waha as basin gas is trapped, with bullish pressure at SoCal Gas border as westbound supply is reduced; EPNG is the only remaining reroute path to California, so SoCal basis spike risk is elevated for the Aug 19 gas day.
Reroute: Moderate: EPNG is the primary competing pipeline for SoCal border deliveries and remains the sole alternative while TW East Mainline is under force majeure; however, EPNG alone cannot fully replace TW volumes if it is operating near capacity, and any simultaneous EPNG constraint would leave California with zero reroute.
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Gas Transmission Northwest
SEV 4/5
Capacity Constraint
1.550 Bcf/d
10 Days
Gas Transmission Northwest has updated the capacity restriction at Station 6 CFTP (Loc #954690) associated with the Starbuck Outage and Bypass Installation, reducing available capacity to 1,550 MMcf/d (1.550 Bcf/d), down from the previously posted 1,600 MMcf/d. The restriction is in effect from 08/18/2026 through 08/29/2026 and GTN has flagged it as Critical with anticipated Firm Primary, Firm Secondary, and Interruptible curtailments. This is a first-time initiation notice (Revision 1, not a stale revision), reflecting an update to the capacity figure that accompanies the original outage posting.
GTN Station 6 CFTP constraint at 1.550 Bcf/d through 08/29 with firm curtailment exposure; GTN Kingsgate basis has averaged -1.585 vs Henry Hub over the five trading days ended 2026-08-17 (most recently -1.565 on 2026-08-17), and further tightening of this Western Canada/PNW import corridor should pressure Kingsgate and PG&E Malin basis higher as downstream California supply diminishes.
Reroute: Limited: GTN is the primary Western Canada-to-Pacific Northwest corridor; Northwest Pipeline (NWP) provides partial Pacific Northwest alternative but does not fully replicate Canadian supply volumes into California, and Ruby Pipeline serves a different Rockies-to-Malin path that may absorb some displaced demand at premium.
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Transwestern Pipeline
[Transwestern Pipeline] [Capacity Constraint] EAST MAINLINE
SEV 4/5
Force Majeure
1 Days
Transwestern Pipeline declared force majeure on its East Mainline effective August 18, 2026 at 9:00 AM through August 19, 2026 at 8:59 AM -- a roughly 24-hour event. The East Mainline is Transwestern's outbound corridor carrying Permian and San Juan Basin gas westward toward SoCal and Arizona markets. No specific capacity volume is stated in the notice, but the force majeure designation triggers the minimum severity floor regardless of stated magnitude.
TW East Mainline force majeure traps Permian/San Juan gas in basin -- expect bearish pressure at Transwestern Permian basis (most recently -0.855 vs HH as of 2026-08-17, already deeply negative) and bullish pressure at SoCal Border and Arizona delivery points; reroute onto EPNG is the only alternative for California-bound volumes.
Reroute: Moderate: EPNG is the primary competing pipeline for SoCal border and Arizona deliveries and provides the only realistic reroute option; however, if EPNG is simultaneously constrained or running near capacity, California supply relief would be severely limited.
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Transwestern Pipeline
[Transwestern Pipeline] [Capacity Constraint] EAST MAINLINE
SEV 4/5
Force Majeure
1 Days
Transwestern Pipeline declared a force majeure on its East Mainline, effective August 19 2026 at 9:00 AM through August 20 2026 at 8:59 AM -- a one-day constraint. The East Mainline is Transwestern's outbound corridor carrying Permian and San Juan Basin gas westward toward SoCal and Arizona delivery points. No specific capacity volume is stated in the notice.
TW East Mainline force majeure (1 day) reduces westbound Permian and San Juan takeaway: expect bearish pressure at Transwestern Permian basis (most recently -0.855 vs HH as of 2026-08-17, trailing 5-day avg -0.809) as basin gas backs up, with bullish pressure at SoCal Border and Arizona delivery points; EPNG is the primary reroute alternative but may lack full offsetting capacity.
Reroute: Moderate: EPNG is the primary competing pipeline serving SoCal border and Arizona from Permian Basin origins, but a simultaneous EPNG constraint would eliminate California reroute entirely; current EPNG conditions are not confirmed here.
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Force Majeure
1.403 Bcf/d
Until Further Notice
10 Days
ANR Pipeline has declared a Force Majeure at Patterson Compressor Station (Southeast Area) due to an unexpected Unit 2 equipment failure, effective 8/18/2026 intraday through 8/27/2026. Eight interconnect locations face curtailed capacity ranging from full elimination (Patterson to Col Gulf, leaving 0 MMcf/d) to partial reductions across Shadyside/TGP, Weeks ISLA, Shadyside/Sonat, and Avalon delivery points. Aggregate stated capacity reductions across the listed locations total approximately 1,403 MMcf/d (1.403 Bcf/d) removed from scheduling, with the Shadyside/TGP (Del) cut of 443 MMcf/d and Weeks ISLA/LIG PL cut of 260 MMcf/d being the largest individual impacts.
ANR Patterson FM removes approximately 1.403 Bcf/d of combined Southeast-area scheduling capacity through 8/27; expect bullish pressure on ANR Louisiana basis and Transco Zone 4 as Gulf Coast northbound flows are curtailed, with the Patterson-to-Col Gulf location going to zero delivery capacity and Shadyside/TGP delivery cut from 473 to 30 MMcf/d -- tightest signal at Southeast and Midwest interconnects receiving from ANR's Louisiana mainline.
Reroute: Moderate: Texas Eastern (TETCO), Trunkline (TGC), and Columbia Gulf Transmission (CGT) serve overlapping Gulf Coast northbound corridors, but the scale of reductions across multiple interconnects -- including a full cut to the Col Gulf interconnect -- limits the ability of any single alternative to absorb displaced volumes. Partial reroute is possible but full offset is unlikely over the 10-day FM window.
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Transwestern Pipeline
[Transwestern Pipeline] [Capacity Constraint] EAST MAINLINE
SEV 4/5
Force Majeure
1 Days
Transwestern Pipeline declared force majeure on its East Mainline effective August 18, 2026 at 9:00 AM through August 19, 2026 at 8:59 AM -- a roughly 24-hour event. The East Mainline is the primary Permian/San Juan Basin outbound segment moving gas westward toward Arizona and California (SoCal border). No specific capacity volume is stated in the notice, and no capacity table row directly corresponds to a mainline segment label, so no volume figure can be confirmed.
TW East Mainline force majeure produces a split signal: expect bearish pressure at Transwestern Permian basis (most recently -0.855 vs HH as of 2026-08-17, already reflecting structural weakness) as Permian/San Juan basin gas is further stranded, and bullish pressure at SoCal Gas and Arizona delivery points where westbound supply is reduced; EPNG is the only reroute option for California volumes and its spare capacity will determine the extent of the SoCal basis spike.
Reroute: Moderate: El Paso Natural Gas (EPNG) is the primary competing pipeline serving the SoCal border and Arizona markets; however, EPNG's available capacity at the time of this force majeure is unknown from this data set, and any simultaneous EPNG constraint would leave California with zero reroute option.
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Transwestern Pipeline
[Transwestern Pipeline] [Capacity Constraint] EAST MAINLINE
SEV 4/5
Force Majeure
1 Days
Transwestern Pipeline declared force majeure on its East Mainline effective Aug 18, 2026 at 9:00AM through Aug 19, 2026 at 8:59AM -- a one-day constraint. No specific capacity volume is stated in the notice. The East Mainline carries Permian and San Juan Basin gas westbound toward SoCal border and Arizona delivery points, producing opposite directional signals at the basin and delivery ends.
TW East Mainline force majeure tightens Permian/San Juan westbound takeaway: expect bearish pressure at Transwestern Permian basis (most recently -0.855 vs HH on 2026-08-17, 5-day avg -0.809) as basin gas backs up at Waha, with bullish pressure at SoCal Border and Arizona delivery points as westbound supply is cut; no capacity volume stated but the force majeure floor and split-direction signal are in effect for the Aug 18-19 gas day.
Reroute: Moderate: EPNG is the primary competing pipeline for SoCal border and Arizona deliveries and provides the main reroute option, but any simultaneous EPNG constraint would eliminate California reroute entirely and leave no alternative supply path to the SoCal border.
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Force Majeure
1 Days
Transwestern Pipeline declared force majeure on the East Mainline effective Aug 18 2026 at 9:00 AM through Aug 19 2026 at 8:59 AM -- a roughly 24-hour outage window. The East Mainline carries Permian and San Juan Basin gas westbound toward SoCal and Arizona delivery points. No specific capacity volume is stated in the notice.
TW East Mainline force majeure removes westbound Permian/San Juan takeaway capacity for approximately one gas day; expect bearish pressure at Transwestern Permian basis (most recently -0.855 vs HH on 2026-08-17, 5-day average -0.809) and Waha as basin gas backs up, with bullish pressure at SoCal Gas and Arizona delivery points -- EPNG is the only remaining California alternative and may lack sufficient spare capacity to fully absorb displaced volumes.
Reroute: Limited: EPNG is the primary competing pipeline for SoCal border and Arizona deliveries, but a simultaneous EPNG constraint would eliminate all California reroute; even absent a concurrent EPNG event, EPNG spare capacity may be insufficient to absorb full East Mainline volumes on short notice.
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Force Majeure
0.150 Bcf/d
2 Days
Transwestern Pipeline declared force majeure at Station 8 Compressor Station in Corona, NM due to mechanical failure, effective August 18 at 9:00 AM through August 20 at 8:59 AM. The failure reduces westbound receipt capacity at Station 9 (Roswell, NM) from 0.750 Bcf/d to 0.600 Bcf/d, a loss of 0.150 Bcf/d on the West Texas and Panhandle Laterals westbound flow path. Capacity is expected to restore to 0.750 Bcf/d on Gas Day August 20.
TW force majeure removes 0.150 Bcf/d of westbound Permian/West Texas takeaway capacity through August 20; expect bearish pressure at Transwestern Permian basis (already trading at -1.030 vs HH as of 2026-08-14, well below the 5-day average of -0.754) as basin gas backs up, with offsetting bullish pressure at SoCal Border and Arizona delivery points -- EPNG capacity should be checked for simultaneous constraint before assuming full SoCal reroute is available.
Reroute: Moderate: EPNG is the primary competing pipeline serving the SoCal border and Arizona markets from the Permian Basin and could absorb some diverted volume; however, if EPNG is simultaneously constrained, no California reroute exists and severity would escalate.
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Northern Border Pipeline (NBPL)
SEV 4/5
Force Majeure
2.145 Bcf/d
Until Further Notice
NBPL has declared force majeure at Trimont Compressor Station 13 (CS13) in Minnesota due to an unplanned equipment failure, effective Gas Day August 18, 2026, continuing until further notice. As a result, NBPL is restricting nominated volumes on the GlenSEG (Flow Past Glen Ullin) segment to 2,145 MMcf/d (2.145 Bcf/d), down from the current scheduled 2.55 Bcf/d -- a reduction of approximately 0.405 Bcf/d of southbound Canadian/Bakken supply. The restriction has no defined end date, adding upward price pressure risk for Midwest and Chicago markets.
NBPL force majeure at Trimont CS13 cuts GlenSEG flow cap to 2.145 Bcf/d from a currently fully-subscribed 2.55 Bcf/d (0.0% headroom confirmed in live data), implying a real-time curtailment of roughly 0.405 Bcf/d of southbound supply; Northern Bdr./Ventura TP basis was already -0.280 vs Henry Hub as of 2026-08-14 and the duration is open-ended, expect bullish pressure at Chicago Citygate and widening Northern Border/Ventura TP basis versus Henry Hub.
Reroute: Limited: Alliance Pipeline (not monitored) is the primary competing Canadian supply route into Chicago, but its capacity is typically fully subscribed; no confirmed spare capacity exists to absorb 0.405 Bcf/d of diverted NBPL volumes, and the open-ended timeline limits confidence in a near-term full offset.
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Columbia Gulf Transmission (CGT)
CAPACITY POSTING - TIM for August 15-17, 2026
SEV 4/5
Force Majeure
2.350 Bcf/d
Until Further Notice
Columbia Gulf Transmission declares a capacity constraint notice for August 15-17, 2026, with an active force majeure at Corinth Compressor Station Unit 505 that has been in effect since June 19, 2026. The CorinSEG is restricted to 2,350,000 Dth/d (2.350 Bcf/d) in the net backhaul direction, while all other segments are listed at total capacity. No OFO has been declared, but Due Shipper service is unavailable. Several point constraints show zero availability (CROSSTEX-GIBSON, TRANSCO/TERREBONNE, SEA ROBIN-ERATH, BURLINGTON-TERREBONNE, SOUTHEASTERN SUPPLY HEADER, Texas Gas Isola), indicating meaningful localized tightness alongside the mainline FM.
Active CGT force majeure at Corinth CS Unit 505 restricts CorinSEG backhaul to 2.350 Bcf/d with no restoration date; CGT mainline basis has recently traded at -0.300 vs Henry Hub (2026-08-12), and continued FM with no timeline raises risk of widening at Columbia Gulf mainline and supportive pressure at Henry Hub as northbound backhaul throughput remains constrained -- watch Transco Zone 4 for downstream tightening.
Reroute: Moderate: Texas Eastern (TETCO) and Trunkline (TGC) serve overlapping Gulf Coast northbound corridors and provide partial reroute options, but the CGT FM has been active since June 19 with no restoration timeline, limiting the market's ability to fully offset the constraint through alternatives.
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Columbia Gulf Transmission (CGT)
SEV 4/5
Force Majeure
2.350 Bcf/d
Until Further Notice
CGT declares a Critical capacity constraint notice for August 14, 2026 reflecting an active force majeure at Corinth Compressor Station Unit 505 originally declared June 19, 2026, with no restoration date provided. CorinSEG is capped at 2.350 Bcf/d on the backhaul (net backhaul), and InvrnSEG is capped at 2.325 Bcf/d. A single point change from the prior posting restricts MidWestern Pipeline deliveries (Loc 4197) to 50,000 Dth/d effective ID1 for 8/13/2026. Due Shipper service is not available, indicating system tightness; no OFO has been declared.
Active CGT force majeure limits CorinSEG backhaul to 2.350 Bcf/d and InvrnSEG to 2.325 Bcf/d on an unresolved 'until further notice' basis since June 19; Columbia Gulf mainline basis was -0.300 as of 2026-08-12 (5-day average -0.278 vs Henry Hub), and continued force majeure with no restoration timeline supports widening of Southeast delivery basis at Transco Zone 4 and TETCO M3 versus CGT mainline as northbound backhaul capacity remains constrained.
Reroute: Moderate: Texas Eastern (TETCO) and Trunkline (TGC) serve overlapping Gulf Coast northbound corridors and can absorb some volumes, but both are fully subscribed segments of a tight Gulf Coast system; the multi-month duration of this force majeure means alternative paths are likely already being utilized, limiting incremental reroute relief.
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El Paso Natural Gas (EPNG)
SEV 4/5
Force Majeure
0.059 Bcf/d
1 Days
EPNG declared force majeure on El Paso D Compressor Station Unit 4 in El Paso County, Texas, effective August 12, 2026 evening cycle, due to damaged fuel nozzles requiring immediate repairs. The outage reduces operational capacity through the ELPASO E and associated constraints by 59,292 Dth/d (0.059 Bcf/d). The stated end date is August 13, 2026 at 9:00 AM, making this a very short-duration event of approximately one day; EPNG has flagged that an updated maintenance notice will follow to reflect total impact.
EPNG force majeure removes 0.059 Bcf/d of westbound Permian takeaway capacity through ELPASO E constraints; expect mild bearish pressure at Waha -- which has already been averaging -0.629 vs Henry Hub over the five trading days ended 2026-08-11 (most recently -0.610 on 2026-08-11) -- and modest bullish pressure at SoCal Border and Arizona delivery points, though the volume is small relative to system scale and the duration is sub-24 hours.
Reroute: Moderate: Transwestern Pipeline (TW) serves overlapping SoCal Border and Arizona markets from the Permian and San Juan basins and can absorb a portion of the 0.059 Bcf/d displacement; the small volume relative to TW and EPNG combined capacity makes full reroute likely achievable at comparable cost.
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Maintenance
2.600 Bcf/d
Until Further Notice
Golden Pass Pipeline has posted its Annual Planned Maintenance notice for 2025-2026 (Rev 31), covering up to 2.6 Bcf/d of LNG export feed gas capacity on the Sabine Pass TX to Starks LA corridor. This is a planned outage notice filed under the GasNom EBB; specific maintenance windows and curtailment depths within the 2.6 Bcf/d ceiling are not detailed in this posting. Golden Pass Pipeline is an LNG export terminal feed gas system, triggering the LNG feedgas severity floor regardless of the planned nature of the event.
Planned maintenance on Golden Pass Pipeline threatens up to 2.6 Bcf/d of LNG export feed gas capacity; gas displaced from export remains in the domestic market, applying bearish pressure at Gulf Coast points -- the Houston Ship Channel regional proxy basis averaged -0.347 vs Henry Hub over the five trading days ended 2026-08-11, most recently -0.420 on 2026-08-11, and further widening is possible on days when feed gas nominations are curtailed.
Reroute: None: LNG export feed gas displaced by maintenance cannot be rerouted to an alternative export terminal -- curtailed volumes remain in the domestic pipeline system and pressure Gulf Coast supply balances.
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Great Lakes Gas Transmission
SEV 4/5
Maintenance
1.326 Bcf/d
28 Days
Great Lakes Gas Transmission is extending maintenance at Thief River Falls Unit 201, which was previously scheduled to end 8/21/2026 but is now extended through 9/8/2026. The constraint at Emerson Eastbound (LOC #3833975) limits available capacity to 1.326 Bcf/d and has been in effect since 7/17/2026. GLGT explicitly warns that this may result in Firm Primary (estimated 21% impact), Firm Secondary, and Interruptible curtailments -- a significant escalation of service class impact.
GLGT maintenance extending to 9/8 caps Emerson Eastbound at 1.326 Bcf/d with Firm Primary curtailments estimated at 21%, tightening Western Canadian supply into Minnesota/Wisconsin/Michigan; Chicago city-gates basis has already weakened to -0.190 vs Henry Hub as of 2026-08-11 but the extension through September adds duration risk and pressure on Upper Midwest and Dawn interconnect pricing into the remainder of injection season.
Reroute: Limited: GLGT is the primary Western Canadian import corridor into the Upper Midwest via Emerson; ANR serves overlapping Midwest markets from Gulf Coast and Midcontinent origins but cannot replicate Canadian supply volumes or fully substitute for the geographic basis differential. Dawn Hub deliveries via the TransCanada Mainline interconnect have no direct pipeline bypass.
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Texas Eastern Transmission (TETCO)
SEV 4/5
Compressor Issue
0.424 Bcf/d
TETCO experienced an unplanned outage at its Lebanon, Ohio compressor station on August 11, 2026, reducing east-to-west nomination capacity to approximately 0.424 Bcf/d at Sarahsville, Summerfield, and Somerset, and 0.523 Bcf/d at Five Points and Lebanon, effective Gas Day August 12, 2026. Downstream operators west of Lebanon may see reduced pressures. No restoration timeline has been provided -- TE will post updates as they become available.
Unplanned TETCO Lebanon CS outage restricts east-to-west capacity to 0.424 Bcf/d on key M-2 segment starting August 12; expect bullish pressure on TETCO M-3, which most recently traded at -0.480 vs HH (hub 2.230 vs HH 2.710 as of 2026-08-10), with potential further widening as reduced westbound flow tightens Mid-Atlantic supply; no restoration date adds a premium.
Reroute: Limited to moderate: Columbia Gas Transmission (TCO) and Equitrans serve overlapping Appalachian corridors and could absorb some displaced volumes, and Transco provides partial Mid-Atlantic alternative, but TETCO is a dominant Mid-Atlantic artery and a compressor constraint of this magnitude on the Ohio segment is difficult to fully offset at comparable cost.
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Texas Eastern Transmission (TETCO)
08/11/2026- TE Force Majeure -- Lebanon Compressor Station
SEV 4/5
Force Majeure
TETCO declared force majeure on August 11, 2026 due to an outage at its Lebanon Compressor Station in Lebanon, Ohio. Restoration timeline is unknown at this time. The station is a critical mid-system compression point on the TETCO mainline connecting Appalachian M-2 receipts to Mid-Atlantic M-3 delivery markets; no specific capacity volume has been stated in this notice.
TETCO force majeure at Lebanon CS with no restoration timeline is a firm directional signal: expect bullish pressure on TETCO M-3 Mid-Atlantic basis (most recently -0.480 vs HH as of 2026-08-10, five-day average -0.511) as downstream Mid-Atlantic deliveries are constrained, and bearish pressure on M-2 Appalachian receipt basis as gas backs up upstream of the failed station.
Reroute: Limited: Transco (monitored) is the primary competing pipeline for Mid-Atlantic deliveries, and Columbia Gas Transmission (TCO, monitored) serves overlapping Appalachian markets, but a TETCO Lebanon CS outage of unknown scope and duration with no timeline constrains a high-capacity mainline segment that alternatives cannot fully replace at short notice.
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Maintenance
Until Further Notice
Trunkline Gas Company posted a Critical maintenance notice on 2026-08-11 for a high-pressure outage at its Henry Hub interconnect. The notice carries no end date (placeholder end date of 2200-01-01), making duration indeterminate -- effectively 'until further notice.' No specific capacity volume is stated in the notice text.
TGC Henry Hub high-pressure outage with no restoration timeline removes an indeterminate volume of throughput at one of the most liquid Gulf Coast pricing hubs; Trunkline ELA basis was already trading at -0.460 vs Henry Hub as of 2026-08-10 (5-day average -0.371), and a sustained outage at this location risks further basis widening and upward pressure on Henry Hub spot as TGC flow through the hub is impaired.
Reroute: Moderate: Texas Eastern (TETCO), Southern Natural (EGT), and ANR serve overlapping Gulf Coast northbound corridors and provide partial reroute alternatives for volumes not able to move through the TGC Henry Hub interconnect, though TGC is a major artery and full offset is unlikely during a sustained high-pressure outage.
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Columbia Gulf Transmission (CGT)
SEV 4/5
Maintenance
0.164 Bcf/d
38 Days
CGT has notified customers that Venice Meter Station (DMS-VENICE PLANT, loc 595) will be reduced to zero total receipt capacity beginning August 18, 2026 through September 24, 2026 -- a 38-day window. Design capacity at this point is 163,500 Dth/d (0.164 Bcf/d). CGT explicitly warns that curtailments to Interruptible, Secondary Firm, AND Primary Firm services are anticipated, which is a significant escalation beyond typical maintenance language.
CGT maintenance zeros out 0.164 Bcf/d at DMS-VENICE PLANT for 38 days starting Aug 18, with explicit primary firm curtailment risk declared -- capacity data confirms the point was running at 0.127 Bcf/d scheduled (77.9% utilized) on Aug 11, consistent with near-full utilization prior to the outage; expect modest bullish pressure at Henry Hub and Transco Zone 4, with Columbia Gulf mainline basis (most recently -0.300 vs HH on 2026-08-10, five-day average -0.296) at risk of widening as Gulf Coast receipt supply tightens.
Reroute: Moderate: CGT interconnects with TETCO, ANR, and Trunkline (TGC) in the Gulf Coast/Louisiana corridor, and some volumes may reroute onto those systems; however, the explicit primary firm curtailment warning and the system's already-tight mainline segments (ClemSEG at 99.6%, East Lateral at 98.8%, East Lateral 300 SEG at 99.9% utilization) suggest limited spare capacity exists on CGT itself to absorb displaced volumes.
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El Paso Natural Gas (EPNG)
SEV 4/5
Force Majeure
0.277 Bcf/d
1 Days
EPNG has declared force majeure on Line No. 1100 between the Florida A Compressor Station (Luna County, NM) and Red Mountain due to anomalies affecting line integrity. A pressure restriction and isolation are required for immediate repairs, reducing operational capacity through the FLORIDA constraint by 0.277 Bcf/d effective August 11, 2026 Timely Cycle. This is Revision 4 of the notice; the end date remains August 11, 2026 at 9:00 AM, indicating a short-duration event with an active force majeure declaration still in place.
EPNG force majeure on the Florida A segment removes 0.277 Bcf/d of Permian outbound takeaway; expect incremental bearish pressure at Waha -- which has already been trading at a steep discount averaging -0.656 vs HH over the five trading days ended 2026-08-07, most recently -0.725 on 2026-08-07 -- and bullish pressure at SoCal Border and Arizona delivery points as westbound supply tightens.
Reroute: Moderate: Transwestern Pipeline (TW) is the primary competing alternative for SoCal border and Arizona deliveries. However, if TW is simultaneously constrained or fully subscribed, California reroute options narrow significantly; shippers should confirm TW availability before assuming full offset.
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Transco
Update - Market and Production Constraints
SEV 4/5
Capacity Constraint
Until Further Notice
1 Days
Transco has posted a system-wide market and production constraint notice effective August 11, 2026, covering multiple throughput section boundaries (TSBs) across Zones 2 through 6. Numerous delivery TSBs are at zero available capacity including SELA (both directions), Central Penn South, NY Bay Lateral, Mainline Milltown, and Rivervale Lateral, with HBLV swing availability also at zero across Zones 2 through 6. An unplanned maintenance constraint is active at Compressor Station 70 MP 662 (Zone 4 receipt, southbound) alongside planned maintenance at CS 160 and ML S35, indicating simultaneous pressure from both unplanned and scheduled events across the system.
Widespread Transco TSB constraints at zero available capacity across Zones 4-6 -- including SELA, Central Penn South, NY Bay Lateral, and Mainline Milltown -- signal a tightly packed system with no swing buffer (HBLV zero Zones 2-6); expect bullish pressure at Transco Zone 4 Southeast and Zone 6 NY basis versus Henry Hub, with highest risk of curtailment at secondary and interruptible service classes on August 11.
Reroute: Limited: Southern Natural Gas (SNG/EGT) provides partial alternative for Southeast Zone 4 volumes, but cannot replace Transco's scale; Tennessee Gas Pipeline offers partial Northeast/Mid-Atlantic reroute but is also frequently constrained in summer peak; no reroute exists for Florida deliveries via FGT if Transco Zone 2 SWLA lateral constraint (40 Mdt/d available) tightens further.
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Iroquois Gas Transmission
Capacity Constraint
SEV 4/5
Capacity Constraint
2 Days
Iroquois Gas Transmission has sealed nominations from all increases at MLV-14 and the Brookfield Interconnect with Algonquin Gas Transmission effective the Timely Cycle for Gas Day August 10, 2026. Interruptible and Extended Receipt/Delivery nominations forward-haul through MLV-14 are reduced 100%, Secondary Out of Path nominations reduced 85%, and Park/Interruptible receipts at Brookfield are reduced 100% with Secondary receipts reduced 98%. Constraint is in effect through 09:00 AM CCT August 11, 2026, a duration of approximately two days.
Iroquois constraint at MLV-14 and the Algonquin Brookfield Interconnect eliminates interruptible and near-eliminates secondary forward-haul capacity, bullish for Algonquin Citygate and Iroquois Zone 2 basis vs Henry Hub through August 11; watch for simultaneous Algonquin constraint given the Brookfield interconnect is directly affected.
Reroute: Limited to none: Algonquin Gas Transmission is the primary competing pipeline for New England and NYC metro deliveries, but this constraint directly involves the Algonquin-Iroquois Brookfield Interconnect, meaning Algonquin supply flowing into Iroquois at this point is also restricted; no meaningful bypass exists for downstream Connecticut and New York deliveries.
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Transco
Notice of Force Majeure Event - Unplanned Outage Station 70 Main Unit 9
SEV 4/5
Force Majeure
0.865 Bcf/d
Until Further Notice
Transco declared force majeure on August 7, 2026 due to an unplanned equipment failure at Compressor Station 70 (MP 662), restricting south-to-north throughput effective ID2 8/7/2026 with no stated return-to-service date. Design capacity at the TSB is 3,344 MDth/d but available primary firm transportation is reduced to 2,479 MDth/d, implying a loss of approximately 865 MDth/d (0.865 Bcf/d) of northbound capacity. Potential shipper cuts of 0-15% on primary firm service are indicated, with major repairs anticipated before full restoration.
Transco FM at Station 70 removes approximately 0.865 Bcf/d of northbound capacity with no restoration timeline; expect bullish pressure on Transco Zone 4 and Zone 5 basis as Southeast and Mid-Atlantic shippers compete for reduced northbound scheduling space, with mild upward bias at Henry Hub given Transco's dominant role in Gulf Coast-to-Northeast flows.
Reroute: Limited: Southern Natural Gas (SNG/EGT) provides partial alternative for Southeast volumes, but SNG capacity is significantly smaller than Transco and cannot absorb a full 0.865 Bcf/d displacement; Tennessee Gas Pipeline serves overlapping Northeast markets but may also face summer throughput constraints, leaving meaningful volumes without viable reroute.
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Algonquin Gas Transmission
08/07/2026- AGT Operational Flow Order -- EFF 8/8
SEV 4/5
Operational Alert
Until Further Notice
Algonquin Gas Transmission has declared a system-wide Operational Flow Order effective August 8, 2026, and lasting until further notice (notice end date listed as 11/05/2026). The OFO prohibits daily pathing exceeding 4% over scheduled quantities (500 MMBtu minimum) for all system customers, with a tighter 2% / 500 MMBtu restriction applied to customer-specific nominations. No restoration timeline is given beyond 'until further notice,' indicating an open-ended supply management event on one of New England's two dominant interstate pipelines.
Algonquin system-wide OFO effective 8/8 with no fixed end date signals tightening New England supply balance; expect bullish pressure at Algonquin Citygate and elevated New England basis vs Henry Hub, with risk of extreme spike if Iroquois faces simultaneous constraint.
Reroute: Limited to none: Algonquin and Iroquois are the two primary pipelines serving New England; if Iroquois is simultaneously constrained, there is zero reroute available and extreme basis spikes are likely at Algonquin Citygate.
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Columbia Gulf Transmission (CGT)
CAPACITY POSTING - TIM for August 8, 2026, through August 10, 2026
SEV 4/5
Force Majeure
2.350 Bcf/d
3 Days
CGT declares a force majeure active since June 19, 2026 at Corinth Compressor Station Unit 505, with this TIM capacity posting covering August 8-10, 2026. The CorinSEG backhaul segment is restricted to 2,350,000 MMBtu/day (2.350 Bcf/d) while all other segments show Total Capacity availability. Multiple point constraints are zeroed out including key interconnects at CROSSTEX-GIBSON, TRANSCO/TERREBONNE, SEA ROBIN-ERATH, BURLINGTON-TERREBONNE, and SOUTHEASTERN SUPPLY HEADER. Due Shipper service is not available.
Active CGT force majeure at Corinth CS restricts backhaul capacity to 2.350 Bcf/d on CorinSEG, tightening Gulf Coast-to-Appalachian northbound flows and supporting bullish pressure at Transco Zone 4 and TETCO M3 versus Henry Hub; multiple zeroed-out interconnect points including Transco/Terrebonne and SESH further constrain routing flexibility.
Reroute: Moderate: Texas Eastern (TETCO) and Trunkline (TGC) serve overlapping Gulf Coast northbound corridors and can absorb some displaced volumes, but the scale of the CorinSEG restriction at 2.350 Bcf/d means partial offset at best, and zeroed SESH and Transco/Terrebonne interconnects further limit reroute optionality.
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Texas Eastern Transmission (TETCO)
08/06/2026- TE Operational Advisory -- UPDATE
SEV 4/5
Operational Alert
Until Further Notice
TETCO has declared an operational advisory effective August 6, 2026, requiring all shippers and point operators in Market Area Zones M2 and M3 to perform to scheduled quantities due to large pipeline imbalances that Texas Eastern cannot manage with existing flexibility. The notice threatens OFOs and underperformance reductions if compliance is not achieved, and remains in effect until further notice with no restoration timeline. This is a first-revision superseding notice (prior notice 181374), indicating an escalation from an earlier advisory.
TETCO M2 and M3 imbalance advisory with OFO threat and no end date tightens Mid-Atlantic and Appalachian supply, expect bullish pressure on TETCO M2, TETCO M3, and Transco Zone 5 basis vs Henry Hub as shipper curtailments and underperformance reductions bite.
Reroute: Limited to moderate: Transco serves overlapping Mid-Atlantic markets and is the primary competing pipeline for M3 deliveries; however, simultaneous demand pressure on both TETCO and Transco in the Mid-Atlantic corridor limits the degree to which volumes can be shifted without further basis widening.
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Columbia Gulf Transmission (CGT)
Clementsville Compressor Station Maintenance (ClemSEG), August 11-12, 2026
SEV 4/5
Maintenance
0.245 Bcf/d
2 Days
CGT has notified customers of planned maintenance at Clementsville Compressor Station on August 11-12, 2026, reducing backhaul capacity through ClemSEG to 2,050,000-2,150,000 Dth/day against a design capacity of 2,344,656 Dth/day -- a reduction of approximately 195,000-295,000 Dth/day (roughly 0.245 Bcf/d at midpoint). The restriction is explicitly noted as potentially curtailing Interruptible, Secondary Firm, and Primary Firm services, making this a significant planned event. Duration is two gas days.
CGT maintenance reduces ClemSEG backhaul capacity by approximately 0.245 Bcf/d on August 11-12; the explicit mention of Primary Firm curtailment risk warrants bullish positioning in Southeast basis (Transco Zone 4) versus Henry Hub during the affected gas days.
Reroute: Moderate: Texas Eastern (TETCO) and Trunkline (TGC) serve overlapping Gulf Coast northbound corridors and may absorb some displaced volumes, but the explicit Primary Firm curtailment language suggests CGT itself has limited operational flexibility to offset the restriction.
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ANR Pipeline (TC Energy)
UPDATED: CAPACITY REDUCTION Michigan Leg North – Rabbit River MS
SEV 4/5
Maintenance
0.083 Bcf/d
Until Further Notice
39 Days
ANR Pipeline has updated the maintenance window for the Rabbit River Meter Station (LOC #523093) in Allegan County, Michigan on the Michigan Leg North. The outage now runs August 11 through September 18, 2026 (shifted from the original August 6 to September 14 window), reducing capacity to zero MMcf/d and eliminating all 83 MMcf/d of throughput. ANR explicitly warns of 100% curtailment impact on Firm Primary service based on both current nominations and contracted MDQ.
ANR Michigan Leg North maintenance eliminates all 0.083 Bcf/d at Rabbit River MS through September 18, with 100% firm primary curtailment confirmed; watch for tightening Michigan/Midwest basis and potential reservation charge credit activity indicating shipper distress.
Reroute: Limited: the Rabbit River MS is a local Michigan delivery point on the Michigan Leg North, a specific lateral with limited bypass options; TETCO, PEPL, and Southern Star do not serve this same downstream Michigan local distribution market, so full reroute is unlikely for customers directly served by this meter station.
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ANR Pipeline (TC Energy)
UPDATED: CAPACITY REDUCTION Michigan Leg North – Rabbit River MS
SEV 4/5
Maintenance
0.083 Bcf/d
Until Further Notice
38 Days
ANR Pipeline has updated maintenance dates for the Michigan Leg North at Rabbit River Meter Station (Allegan County, MI), shifting the window from 8/6-9/14 to 8/11-9/18/2026. Capacity at LOC #523093 is reduced to 0 MMcf/d from 83 MMcf/d for the full duration -- a complete shutoff. ANR explicitly warns of 100% curtailment of Firm Primary nominations and contracted MDQ, making this a full firm curtailment event despite being planned maintenance.
Complete 0.083 Bcf/d firm primary curtailment at Rabbit River MS through 9/18 will tighten Michigan/Midwest local delivery basis; shippers should seek alternative ANR receipt paths or competing pipelines (PEPL, TGT) immediately as 100% of contracted MDQ is at risk.
Reroute: Moderate: ANR serves overlapping Michigan/Midwest markets with PEPL and TGT providing partial alternatives, but Rabbit River MS delivers into a specific Allegan County, MI local distribution area where bypass options may be geographically limited.
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Tennessee Gas Pipeline (TGP)
FORCEMAJEURE AT STA 542 EFFECTIVE 8-4-26
SEV 4/5
Force Majeure
0.280 Bcf/d
Until Further Notice
Tennessee Gas Pipeline has declared a Force Majeure at Station 542 near DeKalb, Mississippi effective August 4, 2026, after discovering an issue with Unit 1 requiring immediate repairs. Units 2 and 3 at the same station have been out of service since late March and early April 2026 respectively, meaning all three units at STA 542 are now offline. The estimated capacity impact is up to 280,000 Dth/day (0.280 Bcf/d), with Primary In the Path nominations through Segment 539 BH at risk beginning Timely Cycle for August 5, and the event is open-ended with no restoration timeline.
TGP force majeure at STA 542 with all three compressor units offline removes up to 0.280 Bcf/d of capacity through the Mississippi corridor; with no restoration timeline and primary firm service at risk starting August 5, expect bullish pressure on Southeast basis points (Tennessee Zone 4, Transco Zone 4) versus Henry Hub.
Reroute: Moderate: Southern Natural Gas (EGT) and Transco serve overlapping Gulf Coast-to-Southeast corridors, but both are significantly smaller than TGP in this segment and may lack spare capacity to fully absorb 0.280 Bcf/d of displaced volumes.
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Gulf South Pipeline
Failure to take confirmed quantities - Loc 24329 Stratton Ridge to Freeport LNG
SEV 4/5
Operational Alert
Until Further Notice
Gulf South Pipeline is notifying customers of a failure to take confirmed quantities at Location SLN 24329 Stratton Ridge (to Freeport LNG) in Area 25, effective Gas Day 8/4/2026. Confirmation reductions are anticipated for all remaining nomination cycles for 8/4/2026 and until further notice. No specific volume is stated, but the delivery point explicitly names Freeport LNG, triggering the LNG feedgas floor.
Freeport LNG is failing to take confirmed feed gas volumes at Stratton Ridge via Gulf South, reducing LNG export pull and leaving gas onshore -- bearish for Henry Hub and Gulf Coast basis until Freeport resumes taking confirmed quantities.
Reroute: Moderate: Gulf South interconnects with Southern Natural (EGT), Transco, and Tennessee Gas Pipeline for Gulf Coast and Southeast markets, but displaced Freeport LNG feed gas volumes have no alternative LNG export outlet in this corridor -- volumes will simply remain in the domestic supply pool.
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Gulf South Pipeline
Failure to take confirmed quantities - Loc 24329 Stratton Ridge to Freeport LNG
SEV 4/5
Operational Alert
Until Further Notice
Gulf South Pipeline has issued a critical Over-Under Performance notice (Notice 5038516) for Location SLN 24329 - Stratton Ridge (to Freeport LNG) in Area 25, effective 08/03/2026 at 3:20 PM CDT. Freeport LNG is failing to take confirmed quantities at this delivery point, and Gulf South is reducing confirmations for remaining nomination cycles for Gas Day 8/3/2026 and until further notice. No specific volume curtailment is stated, but the open-ended 'until further notice' language signals this is an ongoing, unresolved operational issue at the Freeport LNG feed gas lateral.
Freeport LNG feed gas curtailment via Gulf South Stratton Ridge lateral is active until further notice -- gas stays in the domestic market, applying bearish pressure to Henry Hub and Gulf Coast cash basis with no stated restoration timeline.
Reroute: None: this lateral explicitly serves Freeport LNG; if Freeport LNG is not taking gas, no alternative delivery destination replaces LNG export demand, and the curtailed volumes remain in the domestic supply pool.
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Transco
Update - Market and Production Constraints
SEV 4/5
Capacity Constraint
Until Further Notice
1 Days
Transco has posted a critical market and production constraints notice effective August 4, 2026, showing widespread capacity restrictions across multiple zones from the Gulf Coast to the Northeast. Key constraints include SELA laterals (Zone 3) at 0 MDt/d for both directions, SWLA Lat at 40 MDt/d NSRP only, Mainline Milltown (Zone 6) at 0 NSRP, NY Bay Lateral at 0 Secondary, Central Penn South at 0 Secondary, and multiple Zone 5 segment TSBs at 0-200 MDt/d NSRP, indicating severe northbound flow restrictions from the Southeast through the Mid-Atlantic. No end date is specified, suggesting conditions are operationally driven on a daily basis with no defined restoration timeline.
Widespread Transco constraint notice with zero available capacity at multiple key Zone 3, 5, and 6 TSBs signals significant northbound flow restrictions; expect bullish pressure at Transco Zone 4, Zone 5, and Zone 6 basis points versus Henry Hub, with particular tightness in Mid-Atlantic and Northeast delivery markets on August 4.
Reroute: Limited: Southern Natural Gas (SNG/EGT) provides partial alternative for Southeast segment volumes, and Tennessee Gas Pipeline serves overlapping Northeast markets, but Transco's dominant capacity share in the Southeast-to-Northeast corridor means partial reroute at best; Zone 6 Mid-Atlantic and Northeast volumes have minimal viable alternatives.
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