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.
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.
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.
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.
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.
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.
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 Majeure2.375 Bcf/dUntil 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 Majeure1 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.
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.
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.
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.
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 Majeure1 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 Majeure1 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.
Force Majeure1.403 Bcf/dUntil Further Notice10 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 Majeure1 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 Majeure1 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.
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.
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.
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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East Tennessee Natural Gas
08/20/2026- ETNG Pipeline Conditions for 08/21/2026
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Update - Station 35 Tool Runs (Job 134423) 2026 Planned Outage and Maintenance Summary
SEV 3/5
Maintenance0.284 Bcf/d1 Days
Transco is performing inline inspection tool runs (pig runs) between Station 35 and Station 40 on August 25 (HS/Combo Tool) and August 27 (EMAT Tool) as part of Job 134423. Due to operational challenges, the originally anticipated maintenance impact can no longer be achieved within the previously posted restriction, and Transco will restrict scheduled quantities for all transportation priorities moving south to north through TSB location ML S35 S to N MP 327.27 (Location ID 9011644). Available capacity will be reduced to 425,000 Dt/d (0.425 Bcf/d) on August 25 and 480,000 Dt/d (0.480 Bcf/d) on August 27, versus a design capacity of 708,995 Dt/d (0.709 Bcf/d), representing cuts of 10-15% to primary firm shippers on each day.
Transco S-to-N mainline through Station 35 (MP 327.27) will be cut to 0.425 Bcf/d on Aug 25 and 0.480 Bcf/d on Aug 27 (vs 0.709 Bcf/d design), removing up to 0.284 Bcf/d of northbound capacity on the tighter day; expect modest bullish pressure at Transco Zone 4 and downstream Zone 5/6 basis versus Henry Hub on those discrete days.
Reroute: Limited: Transco is the dominant pipeline in this corridor and while SNG provides partial Southeast alternative capacity in principle, SNG is unmonitored and significantly smaller than Transco, meaning full offset of even this partial restriction is unlikely on the affected days.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Gas Transmission Northwest
OFO Watch: GTN Low Inventory (Posted 8/1/26)
SEV 3/5
Operational Alert
GTN has issued an OFO Watch effective 08/21/2026 due to low system inventory, with concerns that continued low inventory may compromise system pressure and operational integrity. The watch remains in effect until further notice through at most 10/01/2026, with GTN warning it may issue a full OFO immediately and without advance notice if shippers do not voluntarily maintain daily balance. No specific capacity volume is stated, but GTN explicitly warns of limited flexibility to manage imbalances.
GTN OFO Watch with no-notice escalation language tightens the Western Canada/PNW import corridor; GTN Kingsgate basis has averaged -1.659 vs Henry Hub over the five trading days ended 2026-08-20 (most recently -1.695 on 08/20), and a full OFO declaration would pressure Pacific Northwest and Malin delivery points bullish while offering no meaningful reroute for California-bound volumes.
Reroute: Limited: GTN is the primary Western Canada import corridor into the Pacific Northwest feeding California via Malin; Northwest Pipeline provides some Pacific Northwest coverage but does not replicate GTN's Canadian supply volumes or Malin delivery path.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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El Paso Natural Gas (EPNG)
[OPERATIONAL FLOW ORDER] SOC Declaration - Loc Specific Draft
SEV 3/5
Operational AlertUntil Further Notice
EPNG has declared a Strained Operating Condition (SOC) effective August 21, 2026, targeting five specific delivery locations: APS Phoenix Maricopa (300777), SRP Phoenix Maricopa (301043), AZ Electric Power Willcox (300754), TEP S78 (301149), and Blythe (314980). System linepack opened the gas day at 7,560 MMcf, down 84 MMcf versus the prior day, with the named locations taking deliveries in excess of scheduled quantities and undermining linepack recovery. EPNG has responded by putting Washington Ranch on withdrawal and suspending IHSW service; the SOC runs until further notice with a 5% imbalance tolerance.
EPNG SOC at Phoenix-area and Blythe delivery points tightens westbound Arizona and SoCal border supply; Waha basis has averaged -0.854 vs HH over the five trading days ended 2026-08-20 (most recently -0.715 on 2026-08-20) and the location-specific curtailment pressure is bullish for Arizona delivery points and the SoCal border while providing modest bearish relief at Waha as system linepack recovers -- no aggregate capacity volume stated so magnitude is unquantified but the 'until further notice' duration adds uncertainty.
Reroute: Limited: Transwestern Pipeline (TW) serves overlapping Arizona and SoCal border points and could partially offset reduced EPNG deliveries at the affected Phoenix-area and Blythe locations, but TW's available capacity is not confirmed and cannot be assumed to be sufficient given the system-wide linepack stress signaled by the SOC declaration.
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Columbia Gulf Transmission (CGT)
CAPACITY POSTING - TIM for August 22, 2026 through August 24, 2026
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Iroquois Gas Transmission
Operational Flow Order
SEV 3/5
Operational AlertUntil Further Notice
Iroquois Gas Transmission has issued a system-wide Operational Flow Order (OFO) effective Gas Day June 10, 2026, due to high linepack conditions, requiring all point operators and shippers to ensure actual deliveries out of the system equal or exceed scheduled deliveries. The OFO remains in effect until further notice with no stated restoration timeline. Capacity data from August 20, 2026 (one day prior to this posting, and more than two months after the OFO effective date) shows Brookfield at 95.2% utilization with only 4.8% headroom and Canajoharie fully subscribed at 100%, consistent with a congested system, though the summer-period readings may not reflect conditions at the June 10 onset.
Iroquois system-wide OFO for high linepack is supply-bearish for New York/New England near-term basis -- Iroquois Zone 2 basis has most recently printed at -0.230 vs Henry Hub (2026-08-20), weaker than the trailing 5-day average of -0.148, suggesting the OFO and associated delivery pressure are already reflected in regional pricing; no specific capacity volume stated.
Reroute: Limited to none for core New York and New England deliveries -- Algonquin Gas Transmission serves overlapping New England markets but is often simultaneously constrained; a high-linepack OFO on Iroquois with no stated end date limits the ability to redirect volumes without exacerbating downstream congestion.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Update - Unplanned Maintenance Station 115 MU3 Planned Outage and Maintenance Summary
SEV 3/5
Maintenance1.074 Bcf/dUntil Further Notice44 Days
Transco is performing unplanned maintenance at Station 115 (MP 1007, South Carolina area) due to equipment failure on Main Unit 3, effective July 29, 2025 through an anticipated September 12, 2025 (TBD). The TSB at Mainline MP 1031 limits southbound-to-northbound capacity to 3,450 Mdt/d (3.450 Bcf/d) against a design capacity of 4,524 Mdt/d (4.524 Bcf/d), a reduction of approximately 1.074 Bcf/d. This is Revision 3 of the notice; impacts to primary firm service remain estimated at 0-5%, with non-primary service (NSRP, secondary FT, IT) significantly curtailed for south-to-north flows.
Transco Station 115 MU3 unplanned outage removes roughly 1.074 Bcf/d of south-to-north non-primary capacity through at least September 12; primary firm cuts remain 0-5% per pipeline guidance, but non-firm and secondary service shippers face real curtailment risk, supporting Transco Zone 4 and Zone 5 basis firming vs Henry Hub -- live capacity data (2026-08-18, 2-day lag) shows MAINLINE MP 1031 TSB S to N at 3.34 Bcf/d scheduled of 4.58 Bcf/d operating (72.9% utilized, 27.1% headroom), which predates the current constraint period and may not reflect actual current conditions.
Reroute: Limited: Southern Natural Gas (SNG) serves overlapping Southeast corridors but is unmonitored with unknown spare capacity, and is significantly smaller than Transco; no fully reliable alternative exists for south-to-north non-primary shippers on this segment.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Operational Flow Order - Imbalance
SEV 3/5
Operational AlertUntil Further Notice
Transco issued an Operational Flow Order for imbalance management effective February 3, 2026 at 9:00 AM CT, directed at Zone 6 shippers with a 'Due From Shipper' imbalance condition lasting until further notice; a prior OFO covering Zones 4, 5, and 6 ran for approximately 4 days beginning January 30. This is Revision 3 of notice 16519969, which supersedes prior notice 16499771. The OFO carries a minimum $50/dt/day penalty for shippers exceeding 5% imbalance tolerance and requires immediate operational response. Live capacity data from 2026-08-18 (2 days behind the current gas day and predating this February 2026 event) shows Zone 6 Segment HB and CS 160 at 0% headroom and CS 60 at 0% headroom, consistent with the tight system conditions that prompted this OFO, though those readings cannot be treated as current.
Transco Zone 6 OFO 'until further notice' with no end date and an active penalty regime signals ongoing line pack stress in the Mid-Atlantic and Northeast; expect bullish pressure at Transco Zone 6 N.Y. and Zone 5 basis vs Henry Hub, with tightening through the Zone 4/5 interface if the broader Zones 4-5-6 OFO from the prior revision remains in effect.
Reroute: Limited: Tennessee Gas Pipeline (TGP) is the primary competing pipeline for Northeast and Mid-Atlantic deliveries, but simultaneous winter system stress often constrains TGP as well; no full reroute exists for Zone 6 New York deliveries.
Transco Revision 3 of its Market and Production Constraints notice (original posted 08/17/2026, effective 08/18/2026) details multiple active TSB constraints across the system. The most binding constraints are Compressor Station 160 (Zone 5, 1,726 Mdt/d available, 0.0% headroom per live data), Central Penn Line South N-to-S MP 1.0 (Zone 6, 2,093 Mdt/d available but live data shows 99.7% utilization at 0.3% headroom), SELA laterals (both directions at 0 available), TSB MP 1412.98 to MP 1369.45 (0 available, 100% utilization), and Compressor Station 60 MP 588.62 (200 Mdt/d NSRP only, 100% utilization on primary). HBLV swing capacity is at 0 or near-0 for Zones 2 through 6, indicating the system has no no-notice swing cushion available. This is a revision with escalation triggers present: Compressor Station 60 and multiple Zone 5/6 TSBs are at 0% headroom with primary firm restricted, and the SELA segment shows zero capacity in both directions at PRIMARY priority.
Transco Zone 5/6 Mid-Atlantic and Northeast capacity is severely constrained with CS 160 at 0.0% headroom (1.73 Bcf/d scheduled against full operating capacity) and Central Penn Line South at 99.7% utilization; simultaneously CS 60 (Zone 3, 1.93 Bcf/d, 100% utilized) restricts southbound Gulf Coast receipts, and SELA laterals show zero PRIMARY capacity in both directions -- expect bullish pressure at Transco Zone 5 and Zone 6 basis versus Henry Hub, with the SELA/Gulf Coast zones facing mild bearish pressure as southbound throughput is saturated and HBLV swing is exhausted across Zones 2-6.
Reroute: Limited: Tennessee Gas Pipeline (TGP) provides partial reroute for Northeast and Southeast volumes, but Transco is the dominant pipeline in these corridors and TGP lacks equivalent capacity in Zone 5/6 markets; Southern Natural Gas (unmonitored) could theoretically absorb some Southeast volumes, but SNG real-time conditions are unknown.
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Transco
Revised- Market and Production Constraints
SEV 3/5
Capacity ConstraintUntil Further Notice
Transco has posted Revision 3 of its Market and Production Constraints notice effective August 19, 2026, listing multiple active TSB and maintenance constraints across the system. The most binding constraints are at Compressor Station 160 (Zone 5, 1,726 Mdt/d available, 0% headroom per live data), Central Penn Line South N-to-S MP 1.0 (Zone 6, 2,093 Mdt/d available, 0.3% headroom), SELA N-to-S and S-to-N MP 85.93/94 (Zone 3, 0 Mdt/d available), and TSB MP 1412.98 to 1369.45 (Zone 5, 0 Mdt/d available, 100% utilized per live data). HBLV swing availability is zero across Zones 2 through 6, signaling system-wide tightness with no operational flexibility for non-firm or interruptible customers in those zones.
Live data corroborates multiple fully saturated northbound and southbound segments on Transco, including CS 160 and TSB MP 1412.98-1369.45 at 100% utilization and CS 60 at 100% utilization (1.93 Bcf/d scheduled); expect widening basis at Transco Zone 5/6 Mid-Atlantic and Northeast delivery points versus Henry Hub, with potential softness in Zone 3/4 Southeast as southbound NSRP and secondary capacity remains constrained at near-zero availability.
Reroute: Limited: Tennessee Gas Pipeline (TGP) provides partial alternative for Northeast and Mid-Atlantic deliveries, but simultaneous tightness across multiple Transco zones and zero HBLV swing in Zones 2-6 means TGP cannot fully absorb displaced volumes. Southern Natural Gas (unmonitored) provides partial Southeast alternative but with unknown current capacity.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transwestern Pipeline
[Transwestern Pipeline] [Operational Alert] CRITICAL NOTICE - SAME DAY - UNDERAGE ALERT - PHOENIX AREA
SEV 3/5
Operational Alert1 Days
Transwestern Pipeline declared a Same Day Underage Alert for the Phoenix Area on August 16, 2026, effective 7:07AM, due to high line pack conditions. Operators delivering into Phoenix Area delivery points whose actual takes fall below scheduled quantities face Alert Day charges under Section 22.4 of Transwestern's FERC Gas Tariff. The condition is expected to persist through the full gas day, with the notice ending August 17 at 8:59AM.
High line pack in the Phoenix Area signals demand underperformance relative to scheduled receipts -- bearish for Transwestern Permian basis, which has already been trading at a steep discount (most recently -1.030 vs Henry Hub as of 2026-08-14, with a 5-day trailing average of -0.754); excess supply backing up at western Arizona delivery points may widen that discount further on the day.
Reroute: Not applicable -- this is a downstream demand-side underage event, not an upstream supply constraint. Gas cannot be physically redirected away from the Phoenix area on same-day basis; Transwestern is the primary interstate serving this zone and EPNG is the only competing option for Arizona delivery points, but rerouting excess supply to EPNG depends on available intrastate and interconnect flexibility that is unlikely to clear same-day.
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Florida Gas Transmission
[Florida Gas Transmission] [Operational Alert] Overage Alert Day 25% Tolerance
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
2026 Major Construction and Maintenance Projects
SEV 2/5
Informational
Transco has updated its 2026 major construction and maintenance schedule, posted as a link on the 1Line portal. The notice supersedes prior notice 17162011 and adds a new tab for Pipeline Inspection (ILI) activities. No specific capacity restrictions are stated in this notice; Transco indicates that individual maintenance activities expected to affect transportation services will receive separate notices prior to commencement.
This is a schedule update only with no quantified capacity impact -- any basis or flow implications will be conveyed in separate notices issued before each individual project begins; no actionable trading signal at this time.
Reroute: Not applicable -- no capacity constraint is declared in this notice. Individual project impacts will be assessed when project-specific notices are issued.
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Northern Border Pipeline (NBPL)
LIFTED for Timely Cycle, August 21-Force Majeure: Trimont Compressor Station 13
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Operational Flow Order Zone 6 - Imbalance
SEV 2/5
Informational
This is Revision 3 of a Transco Zone 6 Imbalance OFO originally posted on October 20, 2023, effective October 21, 2023, with no stated end date. The OFO applied to all deliveries in Zone 6 and required shippers to maintain concurrent balance of receipts and deliveries, with a 10% tolerance and minimum $50/dt/day penalty for violations. No new operational information is contained in this revision relative to the prior filing, and the underlying event is nearly three years old, making this a legacy repost.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; the underlying October 2023 Zone 6 imbalance OFO is a legacy event with no current trading signal.
Reroute: Limited: Transco Zone 6 covers the New York metro and Mid-Atlantic delivery area; Tennessee Gas Pipeline (TGP) provides partial alternative for some Mid-Atlantic volumes, but this OFO is a legacy filing with no active operational constraint to reroute.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Unplanned Outage – Victoria Invista (1006391)
SEV 2/5
Informational0.095 Bcf/d
This is Revision 3 of a notice originally posted 02/02/2024, flagging an unplanned outage at the Victoria Invista delivery meter (loc 1006391, MP 200.1) on Transco with no stated end date. No escalation triggers are present in this revision -- no force majeure declaration, no curtailment of firm service, no new locations added, and no worsened restoration timeline versus prior revisions. The capacity data from 2026-08-18 (2 days prior and not reflecting the 2024 event) shows this meter at 0.095 Bcf/d operating capacity with only 0.017 Bcf/d scheduled, consistent with a long-standing outage already priced by the market.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Not applicable: Victoria Invista is a single industrial end-user delivery point on Transco; the outage affects only that customer's receipts and does not displace mainline volumes to other markets.
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Transco
Updated - Unplanned Outage – Victoria Invista (1006391)
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Unplanned pipeline segment outage in Zone 6
SEV 2/5
Informational2.239 Bcf/d
This is Revision 3 of a February 9, 2024 unplanned pipeline segment outage near Compressor Station 195 (MP 1674) in Transco Zone 6, originally limiting north-to-south primary-firm transportation to 2,239 MDth/d (2.239 Bcf/d) with no restoration timeline. No escalation triggers are present in this revision -- no new locations, no worsening timeline, no force majeure, no OFO, and no curtailment escalation language versus prior revisions. The original event is approximately two and a half years old relative to the Last Updated date of 2026-08-20, making this a legacy repost; live capacity data from 2026-08-18 shows CS 195 at 76.4% utilization with 0.653 Bcf/d of available headroom, consistent with normal operations.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; this is a legacy repost of a February 2024 event with no current trading signal.
Reroute: Limited: Transco is the dominant pipeline in this Zone 6 north-to-south corridor; Tennessee Gas Pipeline (TGP) serves overlapping Northeast markets but cannot fully replace Transco Zone 6 north-to-south capacity for Mid-Atlantic and New York deliveries. However, given this is a stale revision of a 2024 event with live data showing normal CS 195 operations, reroute is moot.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Unplanned pipeline segment outage in Zone 6
SEV 2/5
Informational2.239 Bcf/d7 Days
This is Revision 3 of a February 2024 notice (original post date 02/15/2024, anticipated completion 02/17/2024) describing an unplanned pipeline segment outage near Compressor Station 195 in Transco Zone 6. The notice is a legacy repost -- the event originated over two years before the Last Updated timestamp of 2026-08-20. No new operational information is present in this revision; the outage and its 2,239 MDth/d north-to-south primary-firm capacity constraint were resolved by February 17, 2024 at the latest.
No new market impact -- this is a stale revision of a February 2024 outage that has long since been resolved; market has already priced this constraint and no current trading signal exists.
Reroute: Limited: Transco is the dominant north-to-south pipeline in Zone 6; Southern Natural Gas provides partial real-world alternative but this is a historical event and reroute is moot.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Activating TSB on Transco’s Mainline
SEV 2/5
Informational
This is Revision 3 of a February 28, 2024 critical notice activating a Throughput Section Boundary (TSB) at Zone 2 mainline location ML S35 S-N MP 327.27 (Location ID 9011644) on Transco's mainline, managing south-to-north transportation services. The notice was originally posted over 18 months ago and no restoration end date was ever specified. No escalation triggers are present in this revision -- no new locations added, no force majeure, no curtailment escalation, and no worsened timeline language versus prior revisions.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Limited: Transco is the dominant Southeast-to-Northeast pipeline; Southern Natural Gas (not monitored) provides partial Southeast alternative, and Tennessee Gas Pipeline serves overlapping Northeast markets, but neither fully replicates Transco mainline capacity.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Operational Flow Order - Imbalance
SEV 2/5
Informational
This is Revision 3 of a Transco imbalance OFO originally posted March 12, 2024, effective March 13, 2024, covering Zones 4, 5, and 6 until further notice. No escalation triggers are present in this revision -- no new locations, no force majeure, no capacity volume stated, no worsened timeline, and no firm curtailment language beyond the original imbalance OFO terms. The notice is also a legacy repost, with the original effective date more than two years before this revision's Last Updated timestamp of August 20, 2026.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; legacy OFO from March 2024 carries no fresh trading signal.
Reroute: Moderate: Southern Natural Gas and Tennessee Gas Pipeline serve overlapping Southeast and Mid-Atlantic corridors, though SNG real-time conditions are unmonitored; for Zone 6 Northeast deliveries reroute is limited given Transco and TGP are the two dominant pipes.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Location Confirmations Changed for 04/10/2024 Timely Cycle until further notice
SEV 2/5
Informational0.020 Bcf/d
Transco issued a revision (now Revision 3) to a April 2024 critical notice reducing the confirmation quantity at the Katy-Atmos receipt meter (M3559, Loc 1005518) to 20,000 MMBtu/day (0.020 Bcf/d) effective the Timely cycle for gas day 04/10/2024, continuing until further notice. This is a stale revision reposted in August 2026 for an operational event that originated in April 2024; no new operational information is contained in this revision. The volume involved is immaterial at system scale -- 0.020 Bcf/d against a Transco mainline carrying 3-4+ Bcf/d.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; the 0.020 Bcf/d Katy-Atmos receipt restriction is immaterial to Henry Hub or Transco Zone 4 basis.
Reroute: High: the Katy Hub area is served by numerous Transco receipt interconnects and intrastate pipelines; volumes not confirmed at this meter can readily flow via alternative receipt points with no meaningful supply impact.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Station 60 Update
SEV 2/5
Informational0.775 Bcf/d
This is Revision 3 of a May 2024 critical notice (originally posted 05/10/2024) describing an unplanned incident at Transco Station 60 in East Feliciana Parish, Louisiana that restricted primary south-to-north transportation to 775 MDth/d (0.775 Bcf/d). No escalation triggers are present in this revision -- no new locations, no worsened timeline, no force majeure declaration, no OFO, and no change to the capacity figure. Live capacity data for 2026-08-18 confirms COMPRESSOR STATION 60 MP 588.62 S to N is at 100% utilization with zero headroom (1.93 Bcf/d scheduled against 1.93 Bcf/d operating capacity), consistent with the long-standing TSB constraint. This is a stale revision of an event that originated over two years before the Last Updated date, and the market has long since priced this constraint.
No new market impact -- operational situation unchanged from prior revision, market has already priced this 0.775 Bcf/d south-to-north restriction at Station 60.
Reroute: Limited: Transco is the dominant Southeast-to-Northeast pipeline; Southern Natural Gas (SNG, unmonitored) provides partial alternative capacity in the real world, but SNG is significantly smaller than Transco and its current conditions are not live-verified in this system.
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Transco
Update Washington Storage Semi-Annual Outage: Job #123181 2024 Planned Outage and Maintenance
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Station 60 Update
SEV 2/5
Informational
This is Revision 3 of a maintenance/incident notice originally posted 05/17/2024 regarding an ongoing investigation at Station 60 (MP 588.62) on Transco. No new operational information is provided -- the notice confirms only that operating restrictions remain in effect and federal/agency cooperation continues. No escalation triggers are present: no force majeure declaration, no escalation to firm curtailments, no new locations added, and no worsened restoration timeline beyond the pre-existing open-ended status.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Limited: Transco is the dominant Southeast-to-Northeast pipeline; Southern Natural Gas (SNG, unmonitored) provides partial real-world alternative capacity in the Southeast segment, but SNG live conditions are unverifiable in this system. Station 60 at MP 588.62 sits in Transco Zone 3 (Southeast), and the live capacity table confirms zero headroom at this point (1.93 Bcf/d scheduled against 1.93 Bcf/d operating capacity as of 2026-08-18), consistent with the ongoing restriction being active and binding.
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Transco
Station 535
SEV 2/5
Informational
This is Revision 3 of a May 2024 critical notice regarding an unplanned outage at Transco's Station 535 facility near Wharton, PA, which supports the Wharton Storage Field and Rate Schedule GSS injection services. No escalation triggers are present in this revision -- no force majeure declaration, no firm curtailments, no new affected locations, and no worsened restoration timeline beyond the original 'up to 30% reduction in GSS injection capability' language. The operational situation appears unchanged from prior revisions, and no specific capacity volume or end date is provided.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Limited: Wharton Storage Field supports Transco GSS service in Pennsylvania; no direct physical reroute exists for storage injection capability, though the GSS service impact is limited to a potential 30% reduction in injection flexibility rather than mainline transport curtailment.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Station 80 Update - Unplanned Maintenance
SEV 2/5
Informational2.045 Bcf/d
This is Revision 3 of a June 18, 2024 unplanned maintenance notice for Transco Station 80 (MP 740.50), posted over two years before the current date of August 20, 2026. The original event limited southbound-to-northbound flow through the TSB at MP 740.50 to approximately 2.045 Bcf/d. No escalation triggers are present in this revision -- no new force majeure, no worsened timeline, no new locations added -- making this a stale revision with no new operational information.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; the underlying Station 80 unplanned maintenance event dates to June 2024 and any basis impact at Transco Zone 4 and downstream markets was fully absorbed at that time.
Reroute: Limited: Transco is the dominant Southeast-to-Northeast pipeline; Southern Natural Gas (unmonitored) provides partial Southeast alternative capacity, but this is a legacy event with no current operational relevance.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Sabine River MLB Outage – Unplanned Maintenance
SEV 2/5
Informational0.450 Bcf/d
This is Revision 3 of a September 10, 2024 unplanned maintenance notice for Transco Mainline B near MP 438.84, posted nearly two years before the current date of August 20, 2026. The notice describes isolation of Mainline B between valves 40B30 and 40B40 with south-to-north flow limited to 450 MDth/d (0.450 Bcf/d), with no end date stated and Hurricane Francine cited as a potential delay. No escalation triggers are present in this revision -- the operational situation is unchanged from the prior revision and the market priced this constraint at its September 2024 effective date.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; the underlying event dates to September 10, 2024 and this revision carries no new operational information.
Reroute: Moderate: Southern Natural Gas serves overlapping Gulf Coast-to-Southeast corridors and Transco has multiple south-to-north mainline segments that may carry volumes around the MP 438.84 restriction, though SNG is unmonitored and real-time spare capacity cannot be confirmed.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Update - Sabine River MLB Outage - Unplanned Maintenance
SEV 2/5
Informational0.450 Bcf/d
This is Revision 3 of a September 26, 2024 critical notice regarding an unplanned outage on Transco Mainline B near MP 438.84 (Sabine River area), limiting southbound-to-northbound flow to 450 MDth/d (0.450 Bcf/d). No escalation triggers are present in this revision -- the return-to-service timeline remains 'prior to end of year' (originally stated in September 2024), and no new locations, curtailment escalations, or worsened timelines appear. This notice was last updated August 20, 2026, roughly 23 months after the original effective date of September 26, 2024, making it a legacy repost of a long-resolved or administratively retained event.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; note this is a legacy repost of a September 2024 event now approximately 23 months old with no new trading signal.
Reroute: Limited: Southern Natural Gas provides partial alternative capacity in the Southeast corridor, but SNG is unmonitored and its real-time condition cannot be confirmed; Transco is the dominant Southeast-to-Northeast pipeline and a 0.450 Bcf/d restriction on Mainline B near MP 438.84 would have limited full bypass options at the time of the original event.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
UPDATE 2 - Station 195 (Job 134211) Planned Outage and Maintenance Summary
SEV 2/5
Informational2.265 Bcf/d10 Days
This is Revision 3 of a September 2024 planned maintenance notice for Station 195 (Job 134211) on Transco at mainline milepost 1674, originally posted 09/27/2024 and now reposted with a Last Updated date of 2026-08-20 -- a gap of nearly two years. The maintenance window was September 20-30, 2024, limiting north-to-south primary firm capacity at the Station 195 TSB to 2,265 MDth/d (2.265 Bcf/d). No escalation triggers are present in this revision; the underlying event concluded in late September 2024.
No new market impact -- this is a stale revision of a September 2024 planned outage that has long since concluded; the 2.265 Bcf/d north-to-south constraint at Transco Station 195 was priced at the original effective date and carries no current trading signal.
Reroute: Not applicable -- the underlying event ended in September 2024. At the time, Tennessee Gas Pipeline (TGP) and Southern Natural Gas provided partial southeast-corridor alternatives for north-to-south volumes, but reroute assessment is moot for a concluded outage.
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Transco
UPDATE - Mainline C (Job 880665) 2024 Planned Outage and Maintenance Summary
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Subject: SELA Line A Outage - Unplanned Maintenance
SEV 2/5
Informational
This is Revision 3 of a notice originally posted October 11, 2024 -- nearly 10 months before the Last Updated timestamp of 2026-08-20 -- making this a legacy repost of a historical event. The notice describes an unplanned pressure isolation on a portion of the Southeast Louisiana Lateral (SELA) between valves 62a12 and 62a30 near MP 85.38, cutting off the Larose receipt location (ID 9002040). No escalation triggers are present in this revision: no force majeure, no new locations, no firm curtailment language, and no worsened timeline relative to prior revision.
No new market impact -- this is a legacy repost of an October 2024 SELA outage; the market priced this constraint at the original effective date and the operational situation is unchanged from the prior revision.
Reroute: Moderate: Transco mainline receives Gulf Coast supply from multiple receipt paths and the SELA lateral represents one of several Louisiana gathering interconnects; however, specific reroute capacity at the time of the original October 2024 event cannot be assessed from current data.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Update - Sabine River MLB Outage - Unplanned Maintenance
SEV 2/5
Maintenance
This is Revision 3 of an unplanned outage notice originally posted October 28, 2024, covering a Transco Mainline B failure near milepost 438.84 (Sabine River area). The update states that return-to-service is anticipated February 18, 2025, with no new escalation triggers versus prior revisions. No escalation triggers are present: no new locations added, no force majeure declared, no curtailment of firm service, and the restoration timeline (February 18, 2025) was established in prior revisions. As of the Last Updated date of August 20, 2026, this notice is also a legacy repost of an event that occurred and resolved nearly two years ago.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; note this is also a legacy repost of an October 2024 outage that was anticipated to resolve by February 18, 2025, and any basis signal was priced at the original effective date.
Reroute: Moderate: Transco mainline south-to-north capacity through the Sabine River area could be partially offset via Southern Natural Gas and Tennessee Gas Pipeline for overlapping Southeast corridor volumes, though neither fully replaces Transco's throughput at this segment.
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Transco
UPDATE Location Confirmations Being Reduced for 10/29/2024 Evening Cycle until further notice
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Update - SELA Line A Outage - Unplanned Maintenance
SEV 2/5
Informational34 Days
This is Revision 3 of a Transco critical notice originally posted October 29, 2024, describing an unplanned isolation and pressure reduction on the Southeast Louisiana Lateral (SELA) Line A between the 62A12 and 62A30 valves near MP 85.38, with an anticipated return-to-service date of December 2, 2024. The effective date (October 12, 2024) is nearly two years prior to the Last Updated timestamp (August 20, 2026), confirming this is a legacy repost of a fully resolved historical event. No escalation triggers are present in this revision, and no new operational information is provided relative to prior revisions.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; the underlying SELA Line A outage originated in October 2024 and was anticipated to resolve by December 2, 2024, making this a stale legacy repost with no current trading signal.
Reroute: Not applicable -- this is a legacy event from October 2024 with no current operational relevance. At the time of the original outage, the SELA lateral serves specific Southeast Louisiana receipt points (Larose, loc 9002040); limited reroute options exist via Transco mainline or Gulf South for volumes that were affected.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Location Confirmations being reduced starting ID3 Cycle 11/05/2024
SEV 2/5
Informational
This is Revision 3 of a November 2024 critical notice (original post date 11/05/2024) reporting a reduction in location confirmations at Golden Pass M/L (Location ID 9013124, a receipt point on Transco) starting the ID3 cycle on 11/05/2024. No escalation triggers are present in this revision -- no new locations, no force majeure, no curtailment escalation, no worsened timeline, and no capacity volume is stated. The notice simply repeats the original operational alert with no new information added.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Moderate: Transco is one of the highest-capacity U.S. interstate pipelines with multiple interconnects; no specific volume loss is stated and the notice does not indicate firm service curtailments, limiting reroute assessment.
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Transco
Location Confirmations being reduced starting ID3 Cycle 11/05/2024
SEV 2/5
Informational
This is Revision 3 of a Transco scheduling alert originally posted on 11/05/2024, now being reviewed on 08/20/2026 -- over 21 months after the original event. The notice describes a possible lightning strike at the Golden Pass M/L meter (Location 9013124, a receipt point) that reduced confirmation quantities to zero for Evening cycle starting 11/06/2024. No escalation triggers are present in this revision: no force majeure declaration, no capacity volume stated, no worsened timeline, and no new locations added. This is a stale revision with no new operational information.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Moderate: Transco is a high-capacity system with multiple Gulf Coast and Haynesville receipt points; a single meter reduction at Golden Pass M/L in 2024 would have had limited system-wide impact and alternative receipt paths were available.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Update - Sabine River MLB Outage - Unplanned Maintenance
SEV 2/5
Maintenance0.450 Bcf/d
This is Revision 3 of a November 2024 unplanned outage notice for Transco Mainline B between valves 40B30 and 40B40 near MP 438.84. The TSB at that milepost limits south-to-north flow to 450 MDth/d (0.450 Bcf/d); north-to-south flows are unaffected. The originally anticipated return-to-service date was February 18, 2025, but this notice -- last updated August 20, 2026 -- carries no updated restoration date, and the notice status is listed as Supersede, suggesting this is a legacy administrative repost of an event that has long since resolved or been superseded.
No new market impact -- this is a legacy administrative repost of a November 2024 unplanned Mainline B outage (0.450 Bcf/d south-to-north restriction at MP 438.84) that was anticipated to resolve by February 2025; the market priced this constraint at the original effective date nearly nine months ago.
Reroute: Moderate: during the original event, Southern Natural Gas and Tennessee Gas Pipeline provided partial alternative south-to-north capacity for Southeast and Mid-Atlantic markets, though neither fully replaces Transco mainline B south-to-north throughput at this scale.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Update - SELA Line A Outage - Unplanned Maintenance
SEV 2/5
Informational2 Days
This is Revision 3 of a November 2024 unplanned maintenance notice for the Southeast Louisiana Lateral (SELA) Line A between valves 62A12 and 62A30 near MP 85.38, affecting the Larose receipt location (ID 9002040). The prior revision updated the return-to-service date from December 2, 2024 to November 20, 2024; this revision confirms repairs were completed ahead of schedule. No escalation triggers are present -- no force majeure, no firm curtailments, no worsened timeline, and no new affected locations.
No new market impact -- repairs to SELA Line A were completed ahead of schedule per this revision, situation resolved from prior revision, market has already priced this constraint.
Reroute: Moderate: Transco mainline and other Gulf Coast receipt points provide alternative supply paths into the Southeast; SELA is a lateral, not the mainline, limiting systemic impact.
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Transco
Update-Job 41056 Sta 70 MLD 2024 Planned Outage and Maintenance Summary
SEV 2/5
Informational1.116 Bcf/d4 Days
This is Revision 3 of a November 2024 maintenance notice for Transco Job 41056 at Compressor Station 70 (MP 662, Station 70 TSB), covering planned pipeline inspection and hard spot remediation work scheduled for December 2-5 and December 9-12, 2024. The notice states available capacity would be reduced from 3,466 MDt/d (3.466 Bcf/d) to 2,350 MDt/d (2.350 Bcf/d), a restriction of 1,116 MDt/d (1.116 Bcf/d) on south-to-north flows. The scheduled maintenance dates are now approximately 8 months in the past; no new operational information is present in this revision, and no escalation triggers are present.
No new market impact -- operational situation unchanged from prior revision; the December 2024 maintenance at Compressor Station 70 is long concluded and the market has already priced this constraint.
Reroute: Moderate: Southern Natural Gas (SNG) provides partial alternative capacity in the Southeast corridor, though SNG is not monitored in this system; Tennessee Gas Pipeline (TGP) also serves overlapping markets northward, but neither fully offsets a 1.116 Bcf/d Transco mainline restriction.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Unplanned Anomaly Dig Maintenance Summary
SEV 2/5
Informational
This is Revision 3 of a December 2024 notice (originally posted 12/11/2024) regarding an unplanned anomaly dig on Transco's MLA segment between the Mississippi River and the Amite River, specifically the 65A10-65A20 line segment. The notice identifies two small delivery locations affected -- McComb #4483 and Magnolia UGPL #4150 -- and states Transco is working with those operators to mitigate flow impact. No escalation triggers are present in this revision: no new locations added, no force majeure, no curtailment escalation, no worsened timeline, and no capacity volumes quantified.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Limited: Transco is the dominant Southeast pipeline in this corridor; however, the two affected delivery points (McComb, MS and Magnolia, LA) are small local delivery taps and any volumes curtailed there are unlikely to be material enough to warrant system-level rerouting.
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Transco
Update-Job 41056 Sta 70 MLD 2024 Planned Outage and Maintenance Summary
SEV 2/5
Informational1.116 Bcf/d3 Days
This is Revision 3 of a December 2024 planned maintenance notice (Job 41056) at Transco Station 70 (MP 662), covering pipeline inspection work under the Hard Spot Remediation Program. The maintenance windows were December 10-12 and December 15-17, 2024 -- both dates are approximately eight months in the past relative to the August 2026 Last Updated timestamp. No new operational information is introduced in this revision; the constraint described (3,466 MDth/d design capacity reduced to 2,350 MDth/d available, or approximately 1.116 Bcf/d of restriction, south-to-north) reflects the same figures from prior revisions.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; the underlying December 2024 maintenance at Station 70 is a legacy event and the ~1.116 Bcf/d south-to-north restriction has been resolved for months.
Reroute: Moderate: Southern Natural Gas and Tennessee Gas Pipeline serve overlapping Southeast-to-Northeast corridors and could absorb diverted volumes, though this is moot given the event dates are well in the past.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Update - Sabine River MLB Outage - Unplanned Maintenance
SEV 2/5
Informational0.450 Bcf/d
This is Revision 3 of a January 9, 2025 notice (Notice ID 15286708) regarding an unplanned outage on Transco Mainline B near MP 438.84 at the Sabine River, originally posted over 18 months ago. The notice references an anticipated return-to-service date of March 4, 2025 (with a prior estimate of February 18, 2025), meaning the underlying event is almost certainly fully resolved at this point. The south-to-north capacity constraint of 0.450 Bcf/d at TSB Location ID 9011140 was the operational impact; this revision contains no new operational information relative to the current gas day.
No new market impact -- this is a stale revision of a January 2025 outage with an anticipated return-to-service date of March 4, 2025; the constraint was priced at the original effective date and the underlying event is long resolved.
Reroute: Limited to moderate: Transco is the dominant Southeast-to-Northeast corridor pipeline, though SNG and Tennessee Gas Pipeline serve overlapping Southeast markets; the Mainline B constraint at MP 438.84 limited south-to-north capacity to 0.450 Bcf/d at that location during the original event period, which has since passed.
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Transco
Operational Flow Order - Imbalance
SEV 2/5
Informational
This is Revision 3 of a Transco OFO-Imbalance notice originally posted January 9, 2025 and effective January 11, 2025, covering Zones 4, 5, and 6 until further notice. No escalation triggers are present in this revision -- no new zones added, no force majeure, no firm curtailment language, and no worsened restoration timeline relative to prior revisions. The notice is a superseding administrative update to an OFO that the market priced over 18 months ago.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; live Transco mainline data (2026-08-18, 2-day lag) shows 64.2% average utilization with binding segment CS 84 at 1.0% headroom, consistent with normal summer operations unrelated to this January 2025 OFO filing.
Reroute: Not applicable -- this is a stale administrative revision of a January 2025 OFO with no current operational constraint to reroute. Transco Zones 4-6 alternatives include SNG (unmonitored) and Tennessee Gas Pipeline for Southeast/Mid-Atlantic portions, but no active constraint exists in this notice.
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Transco
Location Confirmations Being Reduced for 01/09/2025 ID1 Cycle - LIFTED
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Compressor Station 190 MLC Unplanned Outage
SEV 2/5
Informational2.684 Bcf/d
Transco posted this notice on 01/14/2025 regarding an unplanned isolation of a portion of Mainline C between the Potomac River and Station 190 near MP 1610, affecting north-to-south flows at TSB MP 1628.78 (design capacity 2.684 Bcf/d). This is Revision 3 of that January 2025 notice, reposted as of 2026-08-20 -- the underlying event originated over 18 months ago, making this a legacy repost. No escalation triggers are present in this revision: no force majeure language, no firm curtailment escalation, no worsened restoration timeline, and no new affected locations are added.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; this is a legacy repost of a January 2025 event and carries no new trading signal.
Reroute: Limited: Transco is the dominant pipeline in this Mid-Atlantic corridor near MP 1628.78; Tennessee Gas Pipeline provides partial northeast market alternative, but for volumes flowing north-to-south toward Southeast markets, Southern Natural Gas (unmonitored) offers the primary partial alternative with significantly smaller capacity than Transco.
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Transco
Job 1088505 MLA near Station 100 Unplanned Maintenance Summary
SEV 2/5
Informational0.675 Bcf/d6 Days
This is Revision 3 of a January 2025 unplanned maintenance notice for Mainline A in the 100A0-100A10 valve segment near Station 100 (MP 890.591). The scheduled maintenance window was January 24-29, 2025 -- a six-day period now approximately 18 months in the past. No escalation triggers are present: no force majeure, no firm curtailments, no worsened restoration timeline, and no new affected locations. The stated constraint was a reduction from 6,147 MDth/d design capacity to 5,472 MDth/d available southbound-to-northbound, implying a restriction of approximately 675 MDth/d (0.675 Bcf/d), with an estimated 0-5% shipper cut based on historical utilization.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; the underlying maintenance window (Jan 24-29, 2025) is approximately 18 months in the past and carries no current trading signal.
Reroute: Limited: Transco is the dominant Southeast-to-Northeast pipeline; Southern Natural Gas (SNG, unmonitored) provides partial real-world alternative for Southeast volumes, but this event is historical and reroute assessment is academic at this stage.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Unplanned Transco’s West End Lateral near MP 1819.17 Outage
SEV 2/5
Informational0.068 Bcf/d
This is Revision 3 of an unplanned outage on Transco's West End Lateral near MP 1819.17, originally posted January 20, 2025 -- a legacy event now over 18 months old relative to the August 2026 last-updated timestamp. The affected location, Kearney - Parkway M6236 (Location ID 9012223), is a single small delivery tap with an operating capacity of approximately 0.068 Bcf/d. No escalation triggers are present in this revision; the notice carries no restoration date and no new operational information beyond the original posting.
No new market impact -- this is a stale revision of a January 2025 outage on a 0.068 Bcf/d delivery tap; the market priced this constraint at original effective date and live capacity data confirms the location is currently showing 98.8% headroom as of the 2026-08-18 gas day, consistent with no ongoing material constraint.
Reroute: Limited: the West End Lateral serves a specific local delivery point with no named alternative; however, at 0.068 Bcf/d maximum operating capacity this tap is immaterial at system scale and reroute assessment is moot.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Operational Flow Order - Imbalance
SEV 2/5
Informational
This is Revision 3 of a Transco Imbalance OFO originally posted January 23, 2025, covering Zones 4, 5, and 6 system-wide. The OFO was initiated due to limited flexibility to manage imbalances and required shippers to maintain concurrent balance of receipts and deliveries; the third phase (beginning January 25, 2025) extended the Due From/Due To Shipper imbalance OFO until further notice. No escalation triggers are present in this revision -- no new locations added, no force majeure, no firm curtailment language, and no worsened restoration timeline relative to prior revisions. The notice is a legacy repost of an event from over 18 months ago.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; this is a legacy repost of a January 2025 OFO and carries no current trading signal.
Reroute: Moderate: Southern Natural Gas and Tennessee Gas Pipeline serve overlapping Southeast and Mid-Atlantic corridors, though SNG real-time conditions are unmonitored; for Northeast Zone 6, reroute options are limited as Algonquin and Iroquois serve distinct but overlapping markets.
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Transco
Update - Unplanned Transco’s West End Lateral near MP 1819.17 Outage
SEV 2/5
Informational0.068 Bcf/d
This is Revision 3 of a January 23, 2025 unplanned outage notice on Transco's West End Lateral near MP 1819.17, affecting the Kearney-Parkway M6236 delivery point (Location ID 9012223). No escalation triggers are present in this revision -- no new locations, no force majeure, no OFO, no worsened restoration timeline, and no curtailment language beyond the original scope. Live capacity data for 2026-08-18 (two days behind current, so predating this notice by over 18 months) shows the Kearney-Parkway M6236 meter at only 0.0008 Bcf/d scheduled against 0.068 Bcf/d operating capacity, confirming this is a small lateral delivery tap with negligible throughput.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; the affected point (Kearney-Parkway M6236, max capacity 0.068 Bcf/d) is immaterially small relative to Transco system flows.
Reroute: Limited: the Kearney-Parkway M6236 is a small lateral delivery point; affected customers may have access to alternative local distribution or other delivery interconnects, but no system-level reroute is relevant at this scale.
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Transco
Unplanned Leidy Line near Station 517 Maintenance January 2025
SEV 2/5
Informational
This is Revision 3 of a January 24, 2025 unplanned maintenance notice for an anomaly on the Leidy Line segment 517B10 to 517B20 near Station 517 (TSB at MP 127.95), posted over 18 months after the original event. No escalation triggers are present in this revision -- no force majeure, no firm curtailments, no capacity figures, and no worsened restoration timeline versus prior revisions. The live capacity data (2026-08-18) shows LEIDY LINE STATION 517 EAST MP 127.95 at 58.3% utilization with 1.87 Bcf/d of headroom, consistent with normal operations, though this reading is from 18 months after the original event and cannot corroborate original conditions. This notice provides no new operational information and appears to be a stale administrative repost of a long-resolved January 2025 event.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Limited: The Leidy Line is a major Appalachian segment of Transco; Tennessee Gas Pipeline (TGP) and Columbia Gas Transmission (TCO) serve overlapping Appalachian and Northeast markets, but the original January 2025 constraint affected only non-primary (non-firm) west-to-east flows and primary service was not interrupted, limiting practical reroute necessity.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Station 80 (Job 1008461) Planned Outage and Maintenance Summary
SEV 2/5
Informational6 Days
This is Revision 3 of a January 2025 planned maintenance notice for Transco Station 80 (Job 1008461) at mainline milepost 740.50, covering Hard Spot Remediation work originally scheduled February 10-15, 2025 -- now more than six months in the past. No pressure limitations or capacity outages were planned, and Transco stated it did not expect any transportation service impacts, though it reserved the right to invoke the TSB at MP 740.50 to manage south-to-north flows if adverse findings warranted it. No escalation triggers are present in this revision; the operational situation is unchanged from prior revisions.
No new market impact -- operational situation unchanged from prior revision, event is months old, and no capacity restriction was ever confirmed; market has already priced any risk associated with this constraint.
Reroute: Not applicable -- no capacity restriction was declared. In the event a future restriction were imposed at Station 80 MP 740.50, moderate reroute options exist via Southern Natural Gas and Tennessee Gas Pipeline for Southeast-bound volumes, though SNG is unmonitored in real time.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Operational Flow Order - Imbalance
SEV 2/5
Informational
This is Revision 3 of a February 6, 2025 Transco OFO covering Zones 5 and 6 (Mid-Atlantic and Northeast), originally posted over 18 months before the Last Updated timestamp of August 20, 2026. The OFO directed shippers to maintain concurrent balance of receipts and deliveries in Zones 5 and 6, with the second phase (Due From Shipper only, 7% tolerance) running until further notice from February 10, 2025. No escalation triggers are present in this revision -- no new locations added, no force majeure, no worsening restoration timeline beyond the original 'until further notice' language already present in prior revisions.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; notice is also a legacy repost of a February 2025 event with no new trading signal for current gas days.
Reroute: Limited: Transco Zones 5 and 6 serve Mid-Atlantic and Northeast markets where Tennessee Gas Pipeline (TGP) is the primary competing pipeline, but this OFO is a stale re-filing from February 2025 and reroute assessment has no current operational relevance.
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Transco
Transco (Job 1077647) 2025 Planned Outage and Maintenance Summary
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
South Virginia Lateral - Mainline A Pressure Reduction
SEV 2/5
Informational
This is Revision 3 of a February 18, 2025 Transco critical notice for a pressure reduction on Mainline A of the South Virginia Lateral due to an unexpected integrity concern. The original event is now approximately 18 months old (effective date 02/18/2025 vs. last updated 2026-08-20), making this a legacy repost. No new operational information, restoration timeline, or capacity figures are provided in this revision. Nine delivery locations in southern Virginia and North Carolina are listed as affected.
No new market impact -- operational situation unchanged from prior revision; this is a legacy repost of a February 2025 event and the market has already priced this constraint.
Reroute: Moderate: Transco is the dominant pipeline in this Southeast corridor, but Southern Natural Gas (SNG) serves overlapping Virginia and Carolina markets; SNG condition is unmonitored so full offset cannot be confirmed.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Update - Sabine River MLB Outage - Unplanned Maintenance
SEV 2/5
Informational0.450 Bcf/d
This is Revision 3 of an unplanned Transco Mainline B outage near MP 438.84 (Sabine River area) originally declared in September 2024. The revision, posted February 25, 2025, updated the return-to-service date from February 18 to March 21, 2025, citing challenging construction site conditions. No new operational information is present beyond a date extension already known to the market; the restoration was anticipated to have occurred by late March 2025, well before this notice was last updated on 2026-08-20.
No new market impact -- this is a stale revision of a February 2025 maintenance update on an outage originating in September 2024, with a stated restoration target of March 21, 2025; the 0.450 Bcf/d south-to-north capacity restriction has long since resolved and the market priced this constraint at the time of original notice.
Reroute: Limited: Transco is the dominant Southeast-to-Northeast pipeline; Southern Natural Gas (unmonitored) provides partial Gulf Coast/Southeast alternative capacity, but is significantly smaller. For the original outage period, capacity constraints were managed within the Transco system via TSB at MP 438.84.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Operational Flow Order - Imbalance
SEV 2/5
Informational3 Days
This is Revision 3 of a Transco Imbalance OFO originally posted February 27, 2025, covering Zones 5 and 6 for three gas days (March 1-4, 2025). The OFO required shippers to maintain concurrent balance of receipts and deliveries with a 10% tolerance, with penalties under Tariff Section 52. No escalation triggers are present in this revision -- no new locations, no force majeure, no worsened timeline, and the event period has long since passed.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Moderate: Tennessee Gas Pipeline (TGP) serves overlapping Northeast markets alongside Transco Zones 5/6; however, this event is from February 2025 and any reroute decisions were made at that time.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Update - Sabine River MLB Outage - Unplanned Maintenance
SEV 2/5
Maintenance0.450 Bcf/d
This is Revision 3 of an unplanned Transco Mainline B outage near MP 438.84 (Sabine River area), originally declared in September 2024. The update moves the anticipated return-to-service date from February 18, 2025 to March 31, 2025, reflecting ongoing challenging site conditions. South-to-north capacity through this location remains limited to 450 MDth/d (0.450 Bcf/d); north-to-south flows are unaffected. No new escalation triggers are present beyond the timeline extension -- the restoration date has worsened, but this is a legacy event originally priced in September 2024 and the market has already absorbed multiple revisions.
No new market impact beyond a further delay in restoration already flagged in prior revisions -- the 0.450 Bcf/d south-to-north cap at Transco MP 438.84 has been the operative constraint since at least September 2024, and any Transco Zone 4 basis widening associated with this outage was priced long ago; the slip to March 31, 2025 extends a known constraint rather than introducing a new one.
Reroute: Limited: Southern Natural Gas serves overlapping Southeast markets and provides partial capacity relief in principle, but SNG is unmonitored and its real-time availability cannot be confirmed; Transco is the dominant Southeast mainline and the 0.450 Bcf/d cap materially limits northbound throughput with no direct bypass of the constrained segment.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Location Confirmations Changed for 04/18/2025 Timely Cycle and until further notice.
SEV 2/5
Informational0.050 Bcf/d
This is Revision 3 of a Transco Over/Under Performance notice originally posted April 17, 2025, restricting the Poole Road delivery location (Meter M4585, Loc 9002300) to a confirmation quantity of 50,000 MMBtu/day (0.050 Bcf/d) effective the timely cycle for April 18, 2025 and until further notice. No escalation triggers are present in this revision -- no force majeure, no firm curtailments, no new locations added, and no worsened restoration language relative to prior revisions. The restriction applies to a single small delivery meter and has no system-level significance. The live capacity data is from August 18, 2026 -- two days behind today -- and predates this notice's original April 2025 effective date by over 16 months, so it provides no corroboration.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: High: Poole Road is a single small delivery meter at 0.050 Bcf/d; shippers have ample Transco mainline capacity and alternative delivery points available to redirect volumes.
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Transco
Location Confirmations Changed for 04/18/2025 ID1 Cycle and until further notice.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Location Confirmations changed for 04/27/2025 ID1 Cycle and until further notice
SEV 2/5
Informational0.080 Bcf/d
This is Revision 3 of a Transco Over/Under Performance notice originally posted 04/28/2025, now reposted on 08/20/2026 with no new operational information. The notice increases the confirmation quantity available at Poole Road (Location 9002300, Meter M4585) by 80,000 MMBtu/d (0.080 Bcf/d) effective ID1 cycle 04/28/2025 and until further notice. No escalation triggers are present; this is a stale revision with no change to the underlying operational situation.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Not applicable -- this is a small delivery tap confirmation increase (0.080 Bcf/d) on Transco with no supply disruption; Transco's south-to-north mainline and interconnects with SNG and TGP provide ample alternative routing in any event.
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Transco
Location Confirmations changed for 04/28/2025 ID1 Cycle and until further notice
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Station 65 – Unplanned Maintenance 2025
SEV 2/5
Informational1.430 Bcf/d5 Days
This is Revision 3 of a June 2025 unplanned maintenance notice for Transco Station 65 (mainline milepost 626.55), originally posted June 10, 2025. The notice describes a 5-day outage limiting south-to-north capacity to 1.430 Bcf/d (design capacity 3.242 Bcf/d) with 5-10% cuts to primary firm shippers. No escalation triggers are present in this revision -- no new locations, no force majeure, no worsened timeline, no curtailment escalation beyond the original notice.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Limited: Southern Natural Gas (SNG) provides partial alternative capacity in the Southeast corridor, but SNG is unmonitored and significantly smaller than Transco; full offset of a 1.812 Bcf/d throughput reduction at Station 65 is unlikely.
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Transco
2025 Major Construction and Maintenance Projects
SEV 2/5
Informational
This is Revision 3 of Transco's 2025 Major Construction and Maintenance Projects notice, originally posted June 12, 2025. The notice provides no new curtailment details, no specific capacity volumes, and no named locations -- it directs recipients to an external link for the updated maintenance schedule. No escalation triggers are present in this revision.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Not applicable -- no specific capacity constraint or segment restriction is identified in this notice.
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Transco
UPDATE Station 65 – Unplanned Maintenance 2025
SEV 2/5
Informational1.430 Bcf/d3 Days
This is Revision 3 of a June 2025 unplanned maintenance notice for Transco Station 65 (mainline milepost 626.55, south-to-north flow). The notice text states repairs were completed June 13, 2025 with return to service June 14, 2025 -- the event has been fully resolved for over 14 months as of this posting. No escalation triggers are present; this is a stale revision of a long-closed outage. During the constraint, south-to-north capacity was limited to 1.430 Bcf/d (design capacity 3.242 Bcf/d), with an estimated 5-10% cut to primary firm shippers based on historical utilization.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; the Station 65 outage resolved June 14, 2025 and this revision carries no new operational information.
Reroute: Moot: Station 65 returned to service June 14, 2025 per the notice text. For reference, during the live constraint, partial reroute via Southern Natural Gas (SNG, unmonitored) would have been the primary alternative for Southeast-bound volumes, though SNG capacity is significantly smaller than Transco.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Station 50 (Job 933926) CS Outage 2025 Planned Outage and Maintenance Summary
SEV 2/5
Informational0.544 Bcf/d15 Days
This is Revision 3 of a planned maintenance notice for Compressor Station 50 (MP 517.25, Location 9012563) on Transco, originally posted June 24, 2025 for a July 17-31, 2025 outage window -- an event now roughly 3-4 weeks in the past relative to the notice's own schedule and over a year behind the Last Updated date of August 20, 2026. The notice described a partial CS outage limiting south-to-north primary-firm capacity from 2,119 MDth/d (2.119 Bcf/d design) to 1,575 MDth/d (1.575 Bcf/d available), a reduction of approximately 544 MDth/d (0.544 Bcf/d), with 0-15% estimated cuts to primary firm. No escalation triggers are present in this revision; no new operational information has been added.
No new market impact -- operational situation unchanged from prior revision; the July 2025 CS 50 outage (0.544 Bcf/d south-to-north reduction) has long since concluded and the market priced this constraint at the original effective date.
Reroute: Moderate: during the original July 2025 maintenance period, Southern Natural Gas served overlapping Southeast corridors and some volumes could be rerouted via SNG or Tennessee Gas Pipeline, though SNG is unmonitored and spare capacity was not confirmed. This is now a moot point as the outage window has passed.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Unplanned Maintenance Station 115 MU3 Planned Outage and Maintenance Summary
SEV 2/5
Maintenance1.074 Bcf/d
This is Revision 3 of a notice originally posted July 29, 2025 for unplanned maintenance on Transco Station 115 Main Unit 3 at Mainline MP 1031, reducing south-to-north available capacity from 4,524 Mdt/d design to 3,450 Mdt/d total quantity available (a reduction of approximately 1,074 Mdt/d or 1.074 Bcf/d). No escalation triggers are present in this revision -- no force majeure, no firm curtailments beyond the original 0-5% primary impact estimate, no new locations added, and restoration remains TBD as it was in prior revisions. The notice has been active since July 29, 2025 and the market has had ample time to price this constraint.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; the 1.074 Bcf/d south-to-north reduction at MP 1031 affects only non-primary service with primary firm cuts estimated at 0-5%, and live capacity data for MAINLINE MP 1031 TSB S to N (loc 9013083) as of 2026-08-18 shows 3.34 Bcf/d scheduled against 4.58 Bcf/d operating capacity (72.9% utilized, 27.1% headroom), indicating the system is absorbing the constraint without firm service stress.
Reroute: Limited to Moderate: Southern Natural Gas and Gulf South serve overlapping Southeast corridors and could absorb non-firm volumes displaced by this Station 115 constraint; primary firm shippers face minimal impact (0-5% estimated cuts) and are unlikely to need rerouting.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
System Operating Conditions
SEV 2/5
Informational
Transco issued a Revision 3 system operating conditions notice on 08/22/2025 warning shippers of limited flexibility to manage imbalances during a mild-weather weekend period. The notice strongly encourages shippers to avoid daily 'Due To' (long) imbalances and warns that an OFO may be issued absent voluntary compliance. No capacity restriction, force majeure, or curtailment has been declared; this is a pre-OFO advisory.
No new market impact -- operational situation unchanged from prior revision; this is a pre-OFO imbalance warning during mild demand conditions, with no capacity figure or forced curtailment stated, and the market has already priced this advisory.
Reroute: Not applicable -- no capacity constraint has been declared; notice is a voluntary imbalance management advisory. If an OFO is subsequently issued, Southern Natural Gas provides partial Southeast reroute but SNG capacity is significantly smaller than Transco.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Station 35 (Job 240432) 2025 Planned Outage and Maintenance Summary
SEV 2/5
Maintenance0.459 Bcf/d1 Days
This is Revision 3 of a planned maintenance notice originally posted 09/03/2025. Transco is performing pig runs at Station 35 (milepost 327.27, south-to-north) on five discrete single-day windows: 10/14, 10/16, 10/21, 10/23, and 10/28. Each pig run day reduces available S-to-N capacity at location 9011644 from 708,995 Dt/d design capacity to 250,000 Dt/d (approximately 0.250 Bcf/d available), representing a loss of roughly 0.459 Bcf/d and cutting primary firm throughput to 35% of design capacity with 60-65% shipper impact. No escalation triggers are present in this revision relative to prior revisions.
No new market impact -- operational situation unchanged from prior revision; the five single-day pig run dates and the 0.459 Bcf/d S-to-N capacity reduction at Station 35 were already disclosed at original posting, market has already priced this constraint.
Reroute: Limited: Transco is the dominant pipeline in this corridor; Southern Natural Gas (unmonitored) provides some partial Southeast alternative capacity, but SNG is significantly smaller than Transco and its current condition cannot be verified. Partial reroute is possible but unlikely to fully offset the 0.459 Bcf/d single-day reductions.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Unplanned McMullen Lateral Outage 2025 Planned Outage and Maintenance Summary
SEV 2/5
Informational0.095 Bcf/d
This is Revision 3 of a notice originally posted September 8, 2025 regarding an unplanned integrity-driven pressure restriction on a portion of the McMullen lateral between MP 32.65 and MP 52.71 on Transco. The event originally ran September 9-25, 2025 and is now nearly a year old relative to the Last Updated date of August 20, 2026. No escalation triggers are present in this revision; the operational situation appears unchanged from the original posting. The McMullen lateral carries a design capacity of 0.095 Bcf/d bidirectionally, with total available quantity reduced to zero in both directions during the restriction period.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; the underlying event dates to September 2025 and the 0.095 Bcf/d McMullen lateral restriction is immaterial to Transco mainline or Zone 4 basis at current system loading.
Reroute: Moderate: the McMullen lateral is a small Transco lateral; Transco mainline and interconnecting Gulf Coast pipelines (Gulf South, TGC) provide alternative routing for affected volumes. The small scale (0.095 Bcf/d) limits market significance.
Revision 3 of this notice confirms that work on the McMullen Lateral (Job #1071403) has been completed and the pipeline was returned to service by ID1 on September 17, 2025 -- eight days into a planned outage that had an original completion date of September 25, 2025. The constraint had restricted 0.095 Bcf/d (95,000 Dt/d) of capacity in both east-to-west and west-to-east directions between MP 32.65 and MP 52.71. This revision carries no new operational information; it is a restoration confirmation for an event that resolved nearly a year before this repost date of August 20, 2026.
No new market impact -- operational situation resolved on September 17, 2025, and the market has long since priced this constraint; this revision is a stale repost with no current trading signal.
Reroute: Moot: the McMullen Lateral outage affecting 0.095 Bcf/d has been resolved. During the outage, Transco mainline capacity offered partial workaround given the lateral's relatively small design capacity relative to the mainline.
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Transco
Update - Market and Production Constraints
SEV 2/5
Informational
This is Revision 3 of Transco notice 16052846, a daily Market and Production Constraints update originally posted September 17, 2025 -- nearly 11 months prior to the Last Updated timestamp of August 20, 2026. No escalation triggers are present: no force majeure, no firm curtailment escalation, no new locations added, no worsened restoration timeline, and no OFO declarations. The notice is a routine daily constraint table repost with no new operational content relative to prior revisions.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Not applicable -- stale revision with no new constraint identified. Transco Southeast (Zone 4) constraints would have SNG as a partial alternative, though SNG real-time data is unmonitored; Northeast Zone 5/6 constraints would have limited reroute via Tennessee Gas Pipeline.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Update - Station 35 (Job 240432) 2025 Planned Outage and Maintenance Summary
SEV 2/5
Informational0.459 Bcf/d7 Days
This is Revision 3 of a planned maintenance notice originally posted September 30, 2025, covering pig run assessments at Transco Station 35 (mainline milepost 327.27, south-to-north flow) on seven discrete dates between October 14-28, 2025. The notice caps available capacity at 250,000 Dt/d (0.250 Bcf/d) against a design capacity of 708,995 Dt/d (0.709 Bcf/d), representing roughly 35% availability and potential 60-65% primary firm cuts. No escalation triggers are present in this revision -- the affected location, capacity figures, and schedule are unchanged from prior revisions, and the underlying outage dates are now approximately 10 months in the past.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; the underlying October 2025 pig run schedule at Station 35 is long past and this revision carries no new trading signal.
Reroute: Moderate: Southern Natural Gas (SNG) provides partial alternative capacity in the Southeast corridor overlapping Transco Zone 4, though SNG is significantly smaller than Transco; the event dates are historical and reroute is moot.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Unplanned Maintenance SELA Lateral Offshore
SEV 2/5
Informational
This is Revision 3 of a Transco unplanned maintenance notice originally posted October 21, 2025, affecting two offshore Southeast Louisiana Lateral (SELA) receipt locations -- Ship Shoal 28D (Loc 1000033) and Ship Shoal 72J (Loc 1000035) -- with no restoration date provided. No escalation triggers are present in this revision: no new locations added, no force majeure declared, no capacity volume stated, no curtailment escalation, and no worsened timeline language beyond the original TBD. Live capacity data for SELA MP 85.94 and MP 85.93 show zero scheduled and zero operating capacity as of 2026-08-18 (2 days prior to this notice), consistent with ongoing shut-in and suggesting the market has long since absorbed this constraint.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Limited: the two affected locations are offshore Gulf of Mexico receipt points on the SELA lateral; no alternative offshore gathering path exists for these specific platform volumes, though their combined contribution to Transco mainline throughput appears negligible given zero scheduled flow on the SELA segments in the most recent capacity data.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Unplanned Maintenance at Station 195 Outage and Maintenance Summary
SEV 2/5
Informational0.872 Bcf/d2 Days
This is Revision 3 of an unplanned maintenance notice for Transco Station 195 (MP 1674, N-to-S flow) originally posted October 31, 2025, with the outage occurring November 5-6, 2025 -- nearly 10 months before this revision's Last Updated date of August 20, 2026. No escalation triggers are present: the event is a completed 2-day planned outage with a known start and end date, no force majeure, no firm curtailment escalation, and no worsened restoration timeline. The notice states design capacity of 2,772 Mdt/d with 1,900 Mdt/d primary firm available (68%), implying a cut of approximately 872 MDth/d (0.872 Bcf/d) for two days, affecting N-to-S transportation priorities with a 7-12% cut to shippers based on historical utilization.
No new market impact -- this is a stale Revision 3 of a November 2025 outage that has long since concluded; market has already priced this constraint and no new trading signal exists.
Reroute: Limited: Transco is the dominant Southeast-to-Gulf-Coast backhaul pipe; SNG provides partial overlapping capacity in the Southeast, but as this outage is already completed, reroute is moot.
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Transco
Unplanned Maintenance at Station 195 Outage and Maintenance Summary
SEV 2/5
Informational0.872 Bcf/d2 Days
This is Revision 3 of a Transco unplanned maintenance notice originally posted October 31, 2025, concerning Station 195 MP 1674 (N-to-S flow direction), with a revised work window of November 5-6, 2025. The notice restricted all transportation priorities moving north to south through this location, with design capacity of 2.772 Bcf/d (2,772 Mdt/d) and total primary firm available quantity of 1.900 Bcf/d (1,900 Mdt/d), representing a restriction of approximately 0.872 Bcf/d or 32% of design capacity. No escalation triggers are present in this revision -- the event is now more than 30 days old and is a legacy repost with no new operational information.
No new market impact -- this is a stale Revision 3 of a November 2025 outage at Transco Station 195 MP 1674; the 0.872 Bcf/d N-to-S restriction was priced at the original effective date and the market has already fully absorbed this constraint.
Reroute: Moderate: Southern Natural Gas serves overlapping Southeast markets and Tennessee Gas Pipeline (TGP) provides partial alternative capacity for north-to-south flows in the region, though SNG real-time conditions are unmonitored. The event is historical and reroute assessment is moot.
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Transco
Update - Station 35 (Job 240432) 2025 Planned Outage and Maintenance Summary
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
December 2025 Maintenance Jobs Reminder
SEV 2/5
Informational
This is Revision 3 of a November 2025 reminder notice for planned December 2025 maintenance jobs at Transco Station 50, covering four specific dates (December 9, 11, 16, and 18, 2025). The notice was last updated August 20, 2026 -- more than eight months after the maintenance dates referenced -- making this a stale revision of an event that has already occurred. No new operational information is present and no escalation triggers are met.
No new market impact -- this is a stale revision of a December 2025 maintenance reminder posted in November 2025; the underlying Station 50 jobs occurred over eight months ago and any market impact was priced at the original effective date.
Reroute: Not applicable -- this is a historical maintenance reminder with no current operational impact; Transco's Southeast segment has limited reroute via Southern Natural Gas in any case.
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Transco
Unplanned Maintenance Station 60 Outage 2025
SEV 2/5
Maintenance0.833 Bcf/d
This is Revision 3 of the December 3, 2025 unplanned maintenance notice for Transco Mainline B between the 60B10 and 65B0 valves (MP 602.90 to MP 626.51). The original event reduced southbound-to-northbound capacity at the Station 60 TSB from a design capacity of 2.133 Bcf/d to 1.300 Bcf/d available (a reduction of approximately 0.833 Bcf/d), with 15-33% potential cuts to primary firm service. No escalation triggers are present in this revision -- no new locations added, no force majeure declared, no worsening timeline language -- making this a stale revision with no new operational information.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Limited: Transco is the dominant pipeline in this Southeast-to-Mid-Atlantic corridor; Southern Natural Gas (SNG, unmonitored) provides partial real-world alternative capacity but is significantly smaller and its current availability cannot be confirmed from live data.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Update - Unplanned Maintenance Station 60 Outage 2025
SEV 2/5
Informational0.833 Bcf/d6 Days
This is Revision 3 of the Station 60 unplanned maintenance notice, originally posted December 5, 2025 -- approximately 8.5 months before this Last Updated timestamp of August 20, 2026. The notice states that repair work between valves 60B10 and 65B0 on Mainline B (MP 602.90 to MP 626.51) was expected to be completed by December 9, 2025, restoring available capacity back to pre-outage levels effective that date. The constraint ran from December 3 to approximately December 8, 2025 (6 days), reducing available throughput from a design capacity of 2,133 MDth/d to 1,300 MDth/d (a reduction of approximately 833 MDth/d, or 0.833 Bcf/d), with primary firm cuts estimated at 15-33%. No new operational information is introduced in this revision beyond the December 9 restoration date.
No new market impact -- operational situation is resolved per this revision with restoration confirmed by December 9, 2025; market has already priced this constraint months ago and the 0.833 Bcf/d southbound-to-northbound restriction at Station 60 is no longer active.
Reroute: Limited: Transco is the dominant Southeast-to-Northeast pipeline; Southern Natural Gas (SNG, unmonitored) provides partial alternative capacity in overlapping Southeast corridors, but SNG capacity is significantly smaller than Transco and its real-time condition cannot be verified. Tennessee Gas Pipeline (TGP, monitored) serves overlapping Northeast markets and would have been the primary reroute option during the outage period.
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Transco
Update - Unplanned Maintenance Station 60 Outage 2025
SEV 2/5
Informational0.833 Bcf/d4 Days
This is Revision 3 of the Station 60 unplanned mainline B maintenance notice, and it announces full restoration: Transco has completed all integrity assessment work between valves 60B10 and 65B0 and lifted the capacity constraint effective immediately ID1 December 7, 2025. The outage ran December 3-7 (approximately 4 days), during which design capacity of 2.133 Bcf/d was restricted to 1.300 Bcf/d -- a loss of roughly 0.833 Bcf/d -- with 15-33% potential cuts to primary firm shippers. No new operational constraint remains; this revision is a closure notice.
No new market impact -- constraint at Compressor Station 60 (MP 588.62) was fully lifted December 7, 2025; the 0.833 Bcf/d south-to-north restriction is resolved and the market priced this event at the original December 3 effective date.
Reroute: Moot: the constraint has been fully lifted as of this revision. During the outage, reroute was limited -- Southern Natural Gas serves overlapping Southeast markets but carries significantly less capacity than Transco, and Tennessee Gas Pipeline provides partial northeast alternative routing.
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Transco
2025 / 2026 Major Construction and Maintenance Projects
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Update - Station 517 MU5 Outage - Force Majeure Event
SEV 2/5
Force Majeure2.375 Bcf/d
This is Revision 3 of a force majeure notice originally posted December 13, 2025, covering the Main Unit 5 outage at Transco Station 517 on the Leidy Line (MP 127.96). The notice carries a TSB limiting primary firm capacity to 2,375 MDth/d (2.375 Bcf/d) west-to-east with estimated 18-26% cuts to primary firm shippers. No new escalation triggers are present in this revision -- the restoration target of December 27, 2025 was already established, the affected location is unchanged, and no new curtailment escalation language appears. This revision conveys no new operational information beyond confirming the prior status.
No new market impact -- operational situation unchanged from prior revision; this Transco Station 517 MU5 force majeure with a 2.375 Bcf/d TSB limitation was originally effective December 13, 2025, and the market has already priced this constraint.
Reroute: Limited: Transco is the dominant Southeast-to-Northeast pipeline; Tennessee Gas Pipeline (TGP) provides partial alternative capacity for some Northeast-bound volumes, but Leidy Line is a key Appalachian receipt and northbound path with limited bypass for affected shippers.
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Transco
Update - Station 517 MU5 Outage - Force Majeure Event
SEV 2/5
Restoration
Transco has terminated the force majeure event at Compressor Station 517 Main Unit 5, effective ID1 December 24, 2025. All unplanned maintenance work is complete and the constraint through the TSB has been lifted, with available capacities returning to pre-outage levels. This is Revision 3 of the notice and constitutes a restoration/termination filing -- no capacity loss remains active.
No new market impact -- this revision terminates the Station 517 MU5 force majeure and restores previously constrained TSB capacity; the constraint was priced at its original effective date of December 24, 2025 and this notice carries no new trading signal.
Reroute: Not applicable -- the force majeure has been terminated and capacity restored. No reroute assessment required.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
System Operating Conditions
SEV 2/5
Informational
This is Revision 3 of a January 15, 2026 Transco System Operating Conditions critical notice issued ahead of a cold weather event beginning January 18, 2026. The notice invoked Transco's Weather Resiliency Plan, suspended retroactive nominations system-wide, and requested shippers flow gas within contractual entitlements on a uniform hourly basis. No escalation triggers are present in this revision -- no new force majeure, no firm curtailments, no worsened restoration timeline, and no new locations added -- making this a stale revision with no new operational information for a winter weather event now more than six months in the past.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; the underlying January 2026 cold-weather tightness event is now a legacy filing with no current trading signal.
Reroute: Not applicable -- this is a stale revision of a system-wide operational alert from January 2026 with no active capacity constraint identified; Southern Natural Gas (unmonitored) and Tennessee Gas Pipeline serve overlapping Southeast corridors but no reroute assessment is warranted for a resolved historical event.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Station 50 (Job 631201) Outage 2026 Planned Outage and Maintenance Summary
SEV 2/5
Informational0.270 Bcf/d4 Days
This is Revision 3 of a Transco planned maintenance notice for Compressor Station 50 (Job 631201), covering a partial outage of main unit 9 that was scheduled March 3-6, 2026. The outage was a 4-day planned event limiting south-to-north capacity at the TSB at mainline MP 517.23 (Station 50 West) to 1,265 MDt/d against a design capacity of 1,535 MDt/d -- a reduction of approximately 270 MDt/d (0.270 Bcf/d), or 18% of design. As of the Last Updated date of 2026-08-20, the scheduled outage window ended over five months ago and no escalation triggers are present in this revision.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; the March 3-6 outage window expired months before this revision posted and the 0.270 Bcf/d south-to-north restriction at Station 50 is no longer active.
Reroute: Limited: Transco is the dominant pipeline in this corridor, with Southern Natural Gas (unmonitored) providing partial Southeast alternative capacity, though SNG is significantly smaller. This assessment is moot given the outage has long since concluded.
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Transco
System Operating Conditions – Location Specific
SEV 2/5
Informational
This is Revision 3 of a February 6, 2026 Transco operational alert warning of limited flexibility at the Carolina Gas Transmission delivery location (Zone 5, Loc 9003140) during periods of high system utilization. No escalation triggers are present in this revision -- no force majeure, no firm curtailments, no new locations added, and no worsened restoration timeline. The notice remains a pre-OFO voluntary compliance request with no confirmed new operational change from prior revisions.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Limited: Carolina Gas Transmission is one of two major pipes into the Carolinas alongside Transco; a confirmed OFO at this delivery point would tighten Southeast Carolinas supply with partial alternatives only via SNG corridors.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Notice of Force Majeure Event - Unplanned Equipment Outage Station 115
SEV 2/5
Informational0.796 Bcf/d
This is Revision 3 of a Transco force majeure notice originally posted February 11, 2026, covering an unplanned equipment outage at Compressor Station 115 (mainline milepost 1007.66, South-to-North flows). The update reports improved system conditions and a capacity increase effective February 12, 2026, raising primary firm available capacity from 3,850 MDth/d to 3,950 MDth/d (versus 4,746 MDth/d design capacity), reducing potential cuts from 6-13% to 0-5%. No restoration timeline has been provided; return to service remains TBD. None of the Step 1 escalation triggers are present in this revision: no force majeure escalation, no new locations, no firm curtailment language, no worsening timeline, and capacity impact has actually improved.
No new market impact -- the operational situation at Station 115 has improved from the prior revision with primary firm available capacity increasing to 3.950 Bcf/d (0.796 Bcf/d below design), and the market has already priced this constraint from the original February 11 posting; no fresh trading signal.
Reroute: Limited: Tennessee Gas Pipeline (TGP) is the primary competing pipeline for Southeast-to-Northeast flows along this corridor, but Transco's total available primary firm capacity at 3.950 Bcf/d represents only a marginal tightening versus design, limiting the urgency of reroute considerations.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Unplanned Galveston 209 SWLA Lateral Outage 2026
SEV 2/5
Informational
This is Revision 3 of an unplanned outage at the Galveston 209 facility on Transco's Southwest Louisiana lateral, originally declared February 16, 2026 -- over six months before this revision. No escalation triggers are present: no force majeure, no firm curtailments, no capacity volume stated, no worsened restoration timeline, and no new locations added. Live capacity data (2026-08-18, two days behind) shows GA 209 M1694 (loc 9000225) at 0.011 Bcf/d scheduled against 0.139 Bcf/d operating capacity with 92.3% headroom, indicating minimal current throughput at this point; the broader SWLA lateral itself shows 98.2% headroom. Operational situation appears unchanged from prior revisions.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Moderate: the Southwest Louisiana lateral is one of several Transco receipt laterals in the Gulf Coast region; volumes from this point can be partially sourced via other Gulf Coast receipt interconnects on the Transco mainline, though specific shipper nominations on this lateral must be rebid.
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Transco
UPDATE - Notice of Force Majeure Event - Unplanned Equipment Outage Station 115
SEV 2/5
Restoration
Transco has issued Revision 3 of Notice 16572364, terminating the force majeure event at Compressor Station 115 (MP 1007.66) effective ID2 February 17, 2026. All work has been completed and the TSB constraint has been lifted, with available capacities returning to pre-outage levels. This is a restoration notice -- the operational event is fully resolved and no capacity constraint remains active.
No new market impact -- this revision confirms termination of the Station 115 force majeure and full restoration of capacity; the constraint and any associated basis widening were priced at the original February 17, 2026 effective date and the market has already absorbed this event.
Reroute: Not applicable -- the force majeure has been terminated and capacity fully restored at Compressor Station 115.
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Transco
2026 Major Construction and Maintenance Projects
SEV 2/5
Informational
Transco has posted Revision 3 of its 2026 Major Construction and Maintenance Schedule, updating the previously filed schedule with no specific new capacity restriction stated in the notice text. The notice advises that some work may affect interruptible and secondary firm transportation availability, with additional detail to be posted prior to each activity. No escalation triggers are present -- this is a stale schedule update with no new operational information.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Not applicable -- no specific constraint or capacity restriction is identified in this notice; reroute assessment deferred to individual project notices as they are posted.
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Transco
Subject: Location(s) Off Rate Notice - Underperformance
SEV 2/5
Informational
This is Revision 3 of a Transco Over/Under Performance notice originally posted 02/21/2026 -- nearly six months before the 08/20/2026 last-updated date -- flagging underperformance at the CAROLINA GAS delivery point (Location ID 9003140, Zone 5). No escalation triggers are present: no force majeure, no firm curtailments, no capacity volume stated, no worsened restoration timeline, and no new locations added. The situation is operationally unchanged from prior revisions.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Limited: Zone 5 is in the Mid-Atlantic corridor; Transco is the dominant pipeline at this delivery point, with SNG providing partial real-world alternative capacity, though SNG is unmonitored. The underlying underperformance notice carries no stated volume, limiting reroute assessment.
Transco has declared the force majeure at Compressor Station 70 (MP 662, Location 9011500) resolved. Repairs to Main Unit 9 were completed and the unit returned to service; the associated TSB limitation was lifted effective the Evening Cycle for Gas Day August 16, 2026. This is Revision 3 of the original notice and represents a full restoration, not an ongoing constraint.
No new market impact -- force majeure at Station 70 is resolved as of Gas Day August 16 Evening Cycle; live capacity data (2026-08-18 post) shows Station 70 (loc 9011500) at 77.9% utilization with 0.739 Bcf/d of headroom, consistent with the restoration, and no new trading signal exists.
Reroute: Not applicable -- the constraint has been lifted and Station 70 is back in service.
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Transco
Update on Unplanned Maintenance - Bobcat Meter Station # 4609/3609
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Unplanned Maintenance – Station 17/Sinton Meter Station 2026
SEV 2/5
Maintenance0.100 Bcf/d1 Days
Transco posted Revision 3 of this unplanned maintenance notice for Compressor Station 17 in south Texas, with the capacity restriction at Sinton Meter Station (loc 9010299) scheduled for one day only -- August 25, 2026. Available capacity at Sinton M4669 will be limited to 100,000 Mdt/d (0.100 Bcf/d) on that date. No escalation triggers are present in this revision; the event scope and duration are unchanged from prior revisions.
No new market impact -- operational situation unchanged from prior revision, with a single-day 0.100 Bcf/d delivery restriction at Sinton M4669 on August 25 that is too small and localized to move Transco Zone 4 or Henry Hub basis materially; market has already priced this constraint.
Reroute: Moderate: Sinton M4669 is a delivery point in south Texas with access to intrastate alternatives; shippers with flexibility can likely source volumes via intrastate Texas pipelines for the single-day restriction.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Location(s) Off Rate Notice - Underperformance
SEV 2/5
Operational Alert
Transco issued a critical underperformance notice effective 08/19/2026 for a single delivery location, Poole Rd (Location ID 9002300), in Zone 1. No specific volume loss is stated. Transco warned that if performance does not improve, scheduled volumes may be curtailed and a Location Specific OFO could follow with limited advance notice.
Single Zone 1 delivery point underperformance with no stated capacity volume; watch for escalation to a Location Specific OFO, but current impact on Henry Hub or Transco Zone 4 basis is negligible absent further action.
Reroute: Unclear: reroute depends on the specific end-use customer and whether alternative Transco lateral taps or interconnects serve the Poole Rd delivery area; no system-level reroute concern at this stage.
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El Paso Natural Gas (EPNG)
[MAINTENANCE] Preliminary September 2026 Maintenance
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Gulf South Pipeline
Failure to Take Confirmed Quantities at Location 21805
SEV 2/5
Informational1 Days
Gulf South Pipeline issued a Revision 2 Over-Under Performance notice for Gas Day 8/19/2026, citing a customer's failure to take confirmed quantities at Location 21805 (Discovery Gas Transmission), an offshore Gulf of Mexico gathering interconnect. Scheduling reductions are anticipated for remaining nomination cycles on 8/19 and until further notice based on projected daily quantities. No escalation triggers are present in this revision versus the original posting -- no new locations added, no force majeure, no firm curtailment language, and no capacity volume stated.
No new operational information -- situation unchanged from prior revision, market has already priced this constraint.
Reroute: Limited: Discovery Gas Transmission is an offshore Gulf of Mexico gathering interconnect; underperformance at this point reflects upstream production curtailment with no viable reroute for volumes that fail to flow.
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ANR Pipeline (TC Energy)
LIFTED: NOTICE OF FORCE MAJEURE ANR Pipeline Company – Southeast Area – Patterson Compressor Station
SEV 2/5
lifted ✓Restoration1 Days
ANR Pipeline has lifted the force majeure declaration at Patterson Compressor Station in the Southeast Area, effective 08/19/26. All constrained capacities are being reinstated to full pre-outage levels across eight interconnect locations including Shadyside/Sonat (481 MMcf/d), Shadyside/TGP (473 MMcf/d), Riverway/Bridgeline (165 MMcf/d), and others. The original FM was declared 08/18/26 due to unexpected equipment failure at Unit 2, with restrictions originally scheduled through 08/27/26.
FM lifted at Patterson CS restores aggregate Southeast Area capacity across key interconnects including Shadyside/Sonat at 0.481 Bcf/d and Shadyside/TGP at 0.473 Bcf/d; expect ANR Louisiana basis to ease and any short-term tightness premium in Gulf Coast-to-Midwest corridors to dissipate quickly.
Reroute: High: restoration notice -- reroute no longer relevant; full capacity is being reinstated across all affected Patterson interconnects as of 08/19/26.
Complete-Station 50 (Job 933926) 2025 Planned Outage and Maintenance Summary
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Informational
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Transco
January 2025 Maintenance Jobs Reminder
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Informational
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Transco
Station 195 (Job 1075459) 2025 Planned Outage and Maintenance Summary
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Transco
Update - Station 35 (Job 933923/933924) 2025 Planned Outage and Maintenance Summary
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Transco
January 2025 Maintenance Jobs Reminder (Updated)
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Informational
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Transco
Update: Station 195 (Job 1075459) 2025 Planned Outage and Maintenance Summary
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Transco
January 2025 Maintenance Jobs Reminder (Updated)
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Transco
Station 50 (Job 933929) 2025 Planned Outage and Maintenance Summary
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Transco
January 2025 Maintenance Jobs Reminder (Updated)
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Transco
Update - Unplanned Transco’s West End Lateral near MP 1819.17 Outage
SEV 1/5
Informational0.068 Bcf/d10 Days
Revision 3 of this Transco critical notice confirms that repairs to the West End Lateral near MP 1819.17 (Kearny - Parkway M6236, loc 9012223) were completed and the lateral was returned to service as of the ID1 cycle on January 30, 2025. The outage originally began January 20, 2025 and affected a small delivery-only lateral with an operating capacity of approximately 0.068 Bcf/d. No escalation triggers are present in this revision -- the event is fully resolved and no new operational constraint exists.
No new market impact -- operational situation is fully resolved per this revision, with the lateral returned to service; the 0.068 Bcf/d delivery point (Kearny - Parkway M6236) is confirmed available again and the market has already priced this constraint.
Reroute: Moderate: the Kearny - Parkway M6236 lateral is a small delivery point (0.068 Bcf/d operating capacity) in the Transco Zone 5/6 corridor near MP 1819.17; moot given the lateral is back in service.
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Transco
35B40 - Station 40 (Job 933925) 2025 Planned Outage and Maintenance Summary
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Informational
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Transco
February 2025 Maintenance Jobs Reminder
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Informational
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Transco
Update: Station 195 (Job 1075459) 2025 Planned Outage and Maintenance Summary
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Transco
Update: Station 195 (Job 1075459) 2025 Planned Outage and Maintenance Summary
UNSCORED
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Transco
Update - Unplanned Leidy Line near Station 517 Maintenance January 2025
SEV 1/5
Informational1 Days
This is Revision 3 of a January/February 2025 maintenance notice for an unplanned anomaly repair on the Transco Leidy Line segment 517B10 to 517B20, west of Station 517. The notice confirms that repairs were completed and the pipeline was returned to service on 2/5/2025. This is a legacy restoration notice -- the event originated in early February 2025, over six months before the Last Updated date of 2026-08-20.
No new market impact -- this is a stale restoration notice from February 2025 confirming repairs were completed; the event has been fully resolved and priced for over 18 months.
Reroute: Not applicable -- pipeline was returned to service on 2/5/2025; no ongoing constraint exists.
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Transco
Station 45 (Job 933926) 2025 Planned Outage and Maintenance Summary
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Informational
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Transco
Mainline B 50B10 - LC723 (Job 933928) 2025 Planned Outage and Maintenance Summary
UNSCORED
Informational
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February 2025 Maintenance Jobs Reminder (Updated)
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Informational
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Transco
Mainline E 100E10 – 105E10 (Job 109195) 2025 Planned Outage and Maintenance Summary
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Transco
Update - Job 1088505 MLA near Station 100 Unplanned Maintenance Summary
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Transco
Washington Storage Semi-Annual (Job 33862) 2025 Planned Outage and Maintenance Summary
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Transco
Station 195 (Job #133808) 2025 Planned Outage and Maintenance Summary
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Transco
March 2025 Maintenance Jobs Reminder
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Transco
Update - 35B40 - Station 40 (Job 933925) 2025 Planned Outage and Maintenance Summary
SEV 1/5
Informational
This is Revision 3 of a Transco planned maintenance notice (Job 933925) for a line outage on Mainline B between MP 372.85 and MP 389.20 (Station 40 area), associated with Transco's Hard Spot Remediation Program. The notice explicitly states the maintenance is now completed. No capacity impact remains.
No new market impact -- maintenance at Transco Mainline B MP 372.85-389.20 is confirmed complete per this revision, operational situation is resolved and the market has already priced this constraint.
Reroute: Moot -- maintenance is complete and no active constraint exists. During the outage period, Transco Southeast segment alternatives via SNG would have provided limited partial reroute given SNG's smaller capacity relative to Transco.
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Transco
Job #1075439 Station 120 Planned Outage and Maintenance Summary
UNSCORED
Informational
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Transco
Job 153635 Station 100 Compressor Maintenance Summary
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Informational
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Transco
Job 933938 Station 110 2025 Planned Outage and Maintenance Summary
UNSCORED
Informational
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Transco
Job #737885/737886 Station 115 Compressors Planned Outage and Maintenance Summary
UNSCORED
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Transco
Job #1075439 Station 120 Planned Outage and Maintenance Summary
UNSCORED
Informational
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Transco
Job 153635 Station 100 Compressor Maintenance Summary
UNSCORED
Informational
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Transco
Job 113157 Station 77 Eminence Storage Planned Outage and Maintenance Summary
UNSCORED
Informational
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Transco
Job #89639 Station 505 MLA Planned Outage and Maintenance Summary
UNSCORED
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Job #737885/737886 Station 115 Compressors Planned Outage and Maintenance Summary
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Transco
March 2025 Maintenance Jobs Reminder (Update)
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Station 190 (Job 1077373) 2025 Planned Outage and Maintenance Summary
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Job 113157 Station 77 Eminence Storage Planned Outage and Maintenance Summary
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UPDATE - Mainline E 100E10 – 105E10 (Job 109195) 2025 Planned Outage and Maintenance Summary
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Informational
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Transco
April 2025 Maintenance Jobs Reminder
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Transco
Job #880760/1076732 Station 115 and MLD DOT Planned Outage and Maintenance Summary
UNSCORED
Informational
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Transco
Station 155 Planned Outage and Maintenance Summary
UNSCORED
Informational
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Transco
Station 35 MLA (Job 165845) 2025 Planned Outage and Maintenance Summary
UNSCORED
Informational
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Transco
Job #737885/737886 Station 115 Compressors Planned Outage and Maintenance Summary
UNSCORED
Informational
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Transco
April 2025 Maintenance Jobs Reminder (Updated)
UNSCORED
Informational
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Job #737885/737886 Station 115 Compressors Planned Outage and Maintenance Summary
UNSCORED
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Transco
UPDATE - Job 933938 Station 110 2025 Planned Outage and Maintenance Summary
UNSCORED
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Subject: Job #153894 Station 90 Planned Outage and Maintenance Summary
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Update - Washington Storage Semi-Annual (Job 33862) 2025 Planned Outage and Maintenance Summary
UNSCORED
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Job 1075438 Station 110 HS 2025 Planned Outage and Maintenance Summary
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Job #750789 Station 120 Planned Outage and Maintenance Summary
UNSCORED
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Update - Station 155 Planned Outage and Maintenance Summary
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Job #1077537 Station 115 MLA DOT Planned Outage and Maintenance Summary
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May 2025 Maintenance Jobs Reminder
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Transco
Update - Job 113157 Station 77 Eminence Storage Planned Outage and Maintenance Summary
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Job 918302 Station 70 Planned Outage and Maintenance Summary
UNSCORED
Informational
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Update - Job 1075438 Station 110 HS 2025 Planned Outage and Maintenance Summary
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Update - Station 155 Planned Outage and Maintenance Summary
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Station 33 (Job 366224) 2025 Planned Outage and Maintenance Summary
UNSCORED
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Station 115 (Job 737885 & 737888) Planned Outage and Maintenance Summary
UNSCORED
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Update - Station 115 (Job 737885 & 737888) Planned Outage and Maintenance Summary
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June 2025 Maintenance Jobs Reminder
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Update - Station 33 (Job 366224) 2025 Planned Outage and Maintenance Summary
UNSCORED
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Update - Job #880760/1076732 Station 115 and MLD DOT Planned Outage and Maintenance Summary
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Transco
Update - Subject: Job #153894 Station 90 Planned Outage and Maintenance Summary
UNSCORED
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Update - Subject: Job #153894 Station 90 Planned Outage and Maintenance Summary
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Update - Job #750789 Station 120 Planned Outage and Maintenance Summary
UNSCORED
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Transco
Job #1071377 Station 80 to Station 90 MLA ILI Runs Planned Outage and Maintenance Summary
UNSCORED
Informational
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Transco
June 2025 Maintenance Jobs Reminder (Updated)
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Job #153798 Station 175 to 170 MLC ILI Runs Planned Outage and Maintenance Summary
UNSCORED
Informational
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Transco
Update - Job #1077537 & #737888 Station 115 MLA DOT Planned Outage and Maintenance Summary
UNSCORED
Informational
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Transco
Update - Station 155 Planned Outage and Maintenance Summary
UNSCORED
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Station 17 MLA (Job 565065) 2025 Planned Outage and Maintenance Summary
UNSCORED
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Transco
UPDATE - Station 35 MLA (Job 165836 & 165845) 2025 Planned Outage and Maintenance Summary
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Transco
MLV 40B20 to Station 45 (Job #1071375) 2025 Planned Outage and Maintenance Summary
UNSCORED
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Transco
UPDATE - Station 35 MLA (Job 165836, 165845 & 165843) 2025 Planned Outage and Maintenance Summary
UNSCORED
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Transco
Update - Job 918302 Station 70 Planned Outage and Maintenance Summary
UNSCORED
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Transco
July 2025 Maintenance Jobs Reminder
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Update - Job #1077537, #737885 & #737888 Station 115 MLA DOT Planned Outage and Maintenance Summary
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Transco
Station 190 MU13 (Job 565115) 2025 Planned Outage and Maintenance Summary
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Station 17 MLA DOT (Job 1081188) 2025 Planned Outage and Maintenance Summary
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Transco
Update - Station 155 Planned Outage and Maintenance Summary
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Transco
MLV 40B20 to Station 45 (Job #1081200) 2025 Planned Outage and Maintenance Summary
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Columbia Gas Transmission (TCO)
COMPLETED: 1711 Pipeline Maintenance, Eff. EVE Cycle August 18, 2026
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Texas Eastern Transmission (TETCO)
08/17/2026- Lebanon Compressor Station Force Majeure -- LIFTED
SEV 1/5
lifted ✓Restoration6 Days
TETCO has lifted the force majeure at its Lebanon Compressor Station, effective August 17, 2026. The station was returned to service following the outage originally declared on August 11, 2026, lasting approximately 6 days. All restrictions associated with the original force majeure (Notice 181620) have been removed.
Force majeure at Lebanon Compressor Station is fully lifted as of August 17 -- no residual capacity constraint remains; TETCO M-3 basis, which had been trading near -0.93 vs Henry Hub as of August 14, should see any outage-related basis widening reverse as system capacity is restored.
Reroute: No reroute needed -- the force majeure has been lifted and the station is back in service.
