Columbia Gulf Transmission declares a capacity constraint notice for August 15-17, 2026, with an active force majeure at Corinth Compressor Station Unit 505 that has been in effect since June 19, 2026. The CorinSEG is restricted to 2,350,000 Dth/d (2.350 Bcf/d) in the net backhaul direction, while all other segments are listed at total capacity. No OFO has been declared, but Due Shipper service is unavailable. Several point constraints show zero availability (CROSSTEX-GIBSON, TRANSCO/TERREBONNE, SEA ROBIN-ERATH, BURLINGTON-TERREBONNE, SOUTHEASTERN SUPPLY HEADER, Texas Gas Isola), indicating meaningful localized tightness alongside the mainline FM.
Active CGT force majeure at Corinth CS Unit 505 restricts CorinSEG backhaul to 2.350 Bcf/d with no restoration date; CGT mainline basis has recently traded at -0.300 vs Henry Hub (2026-08-12), and continued FM with no timeline raises risk of widening at Columbia Gulf mainline and supportive pressure at Henry Hub as northbound backhaul throughput remains constrained -- watch Transco Zone 4 for downstream tightening.
Reroute: Moderate: Texas Eastern (TETCO) and Trunkline (TGC) serve overlapping Gulf Coast northbound corridors and provide partial reroute options, but the CGT FM has been active since June 19 with no restoration timeline, limiting the market's ability to fully offset the constraint through alternatives.
CGT declares a Critical capacity constraint notice for August 14, 2026 reflecting an active force majeure at Corinth Compressor Station Unit 505 originally declared June 19, 2026, with no restoration date provided. CorinSEG is capped at 2.350 Bcf/d on the backhaul (net backhaul), and InvrnSEG is capped at 2.325 Bcf/d. A single point change from the prior posting restricts MidWestern Pipeline deliveries (Loc 4197) to 50,000 Dth/d effective ID1 for 8/13/2026. Due Shipper service is not available, indicating system tightness; no OFO has been declared.
Active CGT force majeure limits CorinSEG backhaul to 2.350 Bcf/d and InvrnSEG to 2.325 Bcf/d on an unresolved 'until further notice' basis since June 19; Columbia Gulf mainline basis was -0.300 as of 2026-08-12 (5-day average -0.278 vs Henry Hub), and continued force majeure with no restoration timeline supports widening of Southeast delivery basis at Transco Zone 4 and TETCO M3 versus CGT mainline as northbound backhaul capacity remains constrained.
Reroute: Moderate: Texas Eastern (TETCO) and Trunkline (TGC) serve overlapping Gulf Coast northbound corridors and can absorb some volumes, but both are fully subscribed segments of a tight Gulf Coast system; the multi-month duration of this force majeure means alternative paths are likely already being utilized, limiting incremental reroute relief.
EPNG declared force majeure on El Paso D Compressor Station Unit 4 in El Paso County, Texas, effective August 12, 2026 evening cycle, due to damaged fuel nozzles requiring immediate repairs. The outage reduces operational capacity through the ELPASO E and associated constraints by 59,292 Dth/d (0.059 Bcf/d). The stated end date is August 13, 2026 at 9:00 AM, making this a very short-duration event of approximately one day; EPNG has flagged that an updated maintenance notice will follow to reflect total impact.
EPNG force majeure removes 0.059 Bcf/d of westbound Permian takeaway capacity through ELPASO E constraints; expect mild bearish pressure at Waha -- which has already been averaging -0.629 vs Henry Hub over the five trading days ended 2026-08-11 (most recently -0.610 on 2026-08-11) -- and modest bullish pressure at SoCal Border and Arizona delivery points, though the volume is small relative to system scale and the duration is sub-24 hours.
Reroute: Moderate: Transwestern Pipeline (TW) serves overlapping SoCal Border and Arizona markets from the Permian and San Juan basins and can absorb a portion of the 0.059 Bcf/d displacement; the small volume relative to TW and EPNG combined capacity makes full reroute likely achievable at comparable cost.
Golden Pass Pipeline has posted its Annual Planned Maintenance notice for 2025-2026 (Rev 31), covering up to 2.6 Bcf/d of LNG export feed gas capacity on the Sabine Pass TX to Starks LA corridor. This is a planned outage notice filed under the GasNom EBB; specific maintenance windows and curtailment depths within the 2.6 Bcf/d ceiling are not detailed in this posting. Golden Pass Pipeline is an LNG export terminal feed gas system, triggering the LNG feedgas severity floor regardless of the planned nature of the event.
Planned maintenance on Golden Pass Pipeline threatens up to 2.6 Bcf/d of LNG export feed gas capacity; gas displaced from export remains in the domestic market, applying bearish pressure at Gulf Coast points -- the Houston Ship Channel regional proxy basis averaged -0.347 vs Henry Hub over the five trading days ended 2026-08-11, most recently -0.420 on 2026-08-11, and further widening is possible on days when feed gas nominations are curtailed.
Reroute: None: LNG export feed gas displaced by maintenance cannot be rerouted to an alternative export terminal -- curtailed volumes remain in the domestic pipeline system and pressure Gulf Coast supply balances.
Great Lakes Gas Transmission is extending maintenance at Thief River Falls Unit 201, which was previously scheduled to end 8/21/2026 but is now extended through 9/8/2026. The constraint at Emerson Eastbound (LOC #3833975) limits available capacity to 1.326 Bcf/d and has been in effect since 7/17/2026. GLGT explicitly warns that this may result in Firm Primary (estimated 21% impact), Firm Secondary, and Interruptible curtailments -- a significant escalation of service class impact.
GLGT maintenance extending to 9/8 caps Emerson Eastbound at 1.326 Bcf/d with Firm Primary curtailments estimated at 21%, tightening Western Canadian supply into Minnesota/Wisconsin/Michigan; Chicago city-gates basis has already weakened to -0.190 vs Henry Hub as of 2026-08-11 but the extension through September adds duration risk and pressure on Upper Midwest and Dawn interconnect pricing into the remainder of injection season.
Reroute: Limited: GLGT is the primary Western Canadian import corridor into the Upper Midwest via Emerson; ANR serves overlapping Midwest markets from Gulf Coast and Midcontinent origins but cannot replicate Canadian supply volumes or fully substitute for the geographic basis differential. Dawn Hub deliveries via the TransCanada Mainline interconnect have no direct pipeline bypass.
TETCO experienced an unplanned outage at its Lebanon, Ohio compressor station on August 11, 2026, reducing east-to-west nomination capacity to approximately 0.424 Bcf/d at Sarahsville, Summerfield, and Somerset, and 0.523 Bcf/d at Five Points and Lebanon, effective Gas Day August 12, 2026. Downstream operators west of Lebanon may see reduced pressures. No restoration timeline has been provided -- TE will post updates as they become available.
Unplanned TETCO Lebanon CS outage restricts east-to-west capacity to 0.424 Bcf/d on key M-2 segment starting August 12; expect bullish pressure on TETCO M-3, which most recently traded at -0.480 vs HH (hub 2.230 vs HH 2.710 as of 2026-08-10), with potential further widening as reduced westbound flow tightens Mid-Atlantic supply; no restoration date adds a premium.
Reroute: Limited to moderate: Columbia Gas Transmission (TCO) and Equitrans serve overlapping Appalachian corridors and could absorb some displaced volumes, and Transco provides partial Mid-Atlantic alternative, but TETCO is a dominant Mid-Atlantic artery and a compressor constraint of this magnitude on the Ohio segment is difficult to fully offset at comparable cost.
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Texas Eastern Transmission (TETCO)
08/11/2026- TE Force Majeure -- Lebanon Compressor Station
SEV 4/5
Force Majeure
TETCO declared force majeure on August 11, 2026 due to an outage at its Lebanon Compressor Station in Lebanon, Ohio. Restoration timeline is unknown at this time. The station is a critical mid-system compression point on the TETCO mainline connecting Appalachian M-2 receipts to Mid-Atlantic M-3 delivery markets; no specific capacity volume has been stated in this notice.
TETCO force majeure at Lebanon CS with no restoration timeline is a firm directional signal: expect bullish pressure on TETCO M-3 Mid-Atlantic basis (most recently -0.480 vs HH as of 2026-08-10, five-day average -0.511) as downstream Mid-Atlantic deliveries are constrained, and bearish pressure on M-2 Appalachian receipt basis as gas backs up upstream of the failed station.
Reroute: Limited: Transco (monitored) is the primary competing pipeline for Mid-Atlantic deliveries, and Columbia Gas Transmission (TCO, monitored) serves overlapping Appalachian markets, but a TETCO Lebanon CS outage of unknown scope and duration with no timeline constrains a high-capacity mainline segment that alternatives cannot fully replace at short notice.
Trunkline Gas Company posted a Critical maintenance notice on 2026-08-11 for a high-pressure outage at its Henry Hub interconnect. The notice carries no end date (placeholder end date of 2200-01-01), making duration indeterminate -- effectively 'until further notice.' No specific capacity volume is stated in the notice text.
TGC Henry Hub high-pressure outage with no restoration timeline removes an indeterminate volume of throughput at one of the most liquid Gulf Coast pricing hubs; Trunkline ELA basis was already trading at -0.460 vs Henry Hub as of 2026-08-10 (5-day average -0.371), and a sustained outage at this location risks further basis widening and upward pressure on Henry Hub spot as TGC flow through the hub is impaired.
Reroute: Moderate: Texas Eastern (TETCO), Southern Natural (EGT), and ANR serve overlapping Gulf Coast northbound corridors and provide partial reroute alternatives for volumes not able to move through the TGC Henry Hub interconnect, though TGC is a major artery and full offset is unlikely during a sustained high-pressure outage.
CGT has notified customers that Venice Meter Station (DMS-VENICE PLANT, loc 595) will be reduced to zero total receipt capacity beginning August 18, 2026 through September 24, 2026 -- a 38-day window. Design capacity at this point is 163,500 Dth/d (0.164 Bcf/d). CGT explicitly warns that curtailments to Interruptible, Secondary Firm, AND Primary Firm services are anticipated, which is a significant escalation beyond typical maintenance language.
CGT maintenance zeros out 0.164 Bcf/d at DMS-VENICE PLANT for 38 days starting Aug 18, with explicit primary firm curtailment risk declared -- capacity data confirms the point was running at 0.127 Bcf/d scheduled (77.9% utilized) on Aug 11, consistent with near-full utilization prior to the outage; expect modest bullish pressure at Henry Hub and Transco Zone 4, with Columbia Gulf mainline basis (most recently -0.300 vs HH on 2026-08-10, five-day average -0.296) at risk of widening as Gulf Coast receipt supply tightens.
Reroute: Moderate: CGT interconnects with TETCO, ANR, and Trunkline (TGC) in the Gulf Coast/Louisiana corridor, and some volumes may reroute onto those systems; however, the explicit primary firm curtailment warning and the system's already-tight mainline segments (ClemSEG at 99.6%, East Lateral at 98.8%, East Lateral 300 SEG at 99.9% utilization) suggest limited spare capacity exists on CGT itself to absorb displaced volumes.
EPNG has declared force majeure on Line No. 1100 between the Florida A Compressor Station (Luna County, NM) and Red Mountain due to anomalies affecting line integrity. A pressure restriction and isolation are required for immediate repairs, reducing operational capacity through the FLORIDA constraint by 0.277 Bcf/d effective August 11, 2026 Timely Cycle. This is Revision 4 of the notice; the end date remains August 11, 2026 at 9:00 AM, indicating a short-duration event with an active force majeure declaration still in place.
EPNG force majeure on the Florida A segment removes 0.277 Bcf/d of Permian outbound takeaway; expect incremental bearish pressure at Waha -- which has already been trading at a steep discount averaging -0.656 vs HH over the five trading days ended 2026-08-07, most recently -0.725 on 2026-08-07 -- and bullish pressure at SoCal Border and Arizona delivery points as westbound supply tightens.
Reroute: Moderate: Transwestern Pipeline (TW) is the primary competing alternative for SoCal border and Arizona deliveries. However, if TW is simultaneously constrained or fully subscribed, California reroute options narrow significantly; shippers should confirm TW availability before assuming full offset.
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Transco
Update - Market and Production Constraints
SEV 4/5
Capacity ConstraintUntil Further Notice1 Days
Transco has posted a system-wide market and production constraint notice effective August 11, 2026, covering multiple throughput section boundaries (TSBs) across Zones 2 through 6. Numerous delivery TSBs are at zero available capacity including SELA (both directions), Central Penn South, NY Bay Lateral, Mainline Milltown, and Rivervale Lateral, with HBLV swing availability also at zero across Zones 2 through 6. An unplanned maintenance constraint is active at Compressor Station 70 MP 662 (Zone 4 receipt, southbound) alongside planned maintenance at CS 160 and ML S35, indicating simultaneous pressure from both unplanned and scheduled events across the system.
Widespread Transco TSB constraints at zero available capacity across Zones 4-6 -- including SELA, Central Penn South, NY Bay Lateral, and Mainline Milltown -- signal a tightly packed system with no swing buffer (HBLV zero Zones 2-6); expect bullish pressure at Transco Zone 4 Southeast and Zone 6 NY basis versus Henry Hub, with highest risk of curtailment at secondary and interruptible service classes on August 11.
Reroute: Limited: Southern Natural Gas (SNG/EGT) provides partial alternative for Southeast Zone 4 volumes, but cannot replace Transco's scale; Tennessee Gas Pipeline offers partial Northeast/Mid-Atlantic reroute but is also frequently constrained in summer peak; no reroute exists for Florida deliveries via FGT if Transco Zone 2 SWLA lateral constraint (40 Mdt/d available) tightens further.
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Iroquois Gas Transmission
Capacity Constraint
SEV 4/5
Capacity Constraint2 Days
Iroquois Gas Transmission has sealed nominations from all increases at MLV-14 and the Brookfield Interconnect with Algonquin Gas Transmission effective the Timely Cycle for Gas Day August 10, 2026. Interruptible and Extended Receipt/Delivery nominations forward-haul through MLV-14 are reduced 100%, Secondary Out of Path nominations reduced 85%, and Park/Interruptible receipts at Brookfield are reduced 100% with Secondary receipts reduced 98%. Constraint is in effect through 09:00 AM CCT August 11, 2026, a duration of approximately two days.
Iroquois constraint at MLV-14 and the Algonquin Brookfield Interconnect eliminates interruptible and near-eliminates secondary forward-haul capacity, bullish for Algonquin Citygate and Iroquois Zone 2 basis vs Henry Hub through August 11; watch for simultaneous Algonquin constraint given the Brookfield interconnect is directly affected.
Reroute: Limited to none: Algonquin Gas Transmission is the primary competing pipeline for New England and NYC metro deliveries, but this constraint directly involves the Algonquin-Iroquois Brookfield Interconnect, meaning Algonquin supply flowing into Iroquois at this point is also restricted; no meaningful bypass exists for downstream Connecticut and New York deliveries.
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Mountain Valley Pipeline
Stallworth Compressor Station Maintenance 09-14-26
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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ANR Pipeline (TC Energy)
CAPACITY REDUCTION in the Southeast Area – Weeks ISLA/LIG PL
SEV 3/5
Capacity Constraint0.110 Bcf/dUntil Further Notice78 Days
Effective 8/15/26 timely cycle, ANR Pipeline is restricting capacity at Weeks ISLA/LIG PL (LOC#233620) in St. Mary Parish, Louisiana due to incompatible pressures in the Southeast Area. The restriction limits the location to 200 MMcf/d (0.200 Bcf/d), removing 110 MMcf/d (0.110 Bcf/d) of capacity through 10/31/26 -- a 78-day constraint. ANR has flagged potential Firm Secondary and Interruptible curtailments as a result.
ANR removes 0.110 Bcf/d of southbound Gulf Coast receipt capacity at Weeks ISLA/LIG PL through October 31; Firm Secondary and Interruptible curtailments are anticipated, supporting mild bullish pressure at ANR Louisiana and Transco Zone 4 Southeast basis as northbound throughput capacity from this point tightens.
Reroute: Moderate: TETCO (monitored), Trunkline/TGC (monitored), and Gulf South (monitored) provide overlapping Gulf Coast northbound corridors that could absorb some displaced volumes, though these alternatives may not fully offset the restriction if the system area is already running near capacity.
This is Revision 2 of CTPL's 2026 Q3 planned outage and maintenance summary for Creole Trail Pipeline serving Sabine Pass LNG. The most impactful single job is Job 2026111: Gillis Compressor Station compressor maintenance running 8/25/2026 3:00 a.m. through 8/28/2026 6:00 p.m. (4 days, Gas Days 24-28), with a stated transport impact of 130,000 Dths/day (0.130 Bcf/d) against an available capacity of 1,400,000 Dths/day. The two updated Job 2026113 entries (LEAP Meter Station filter changeouts on 9/8 and 9/9, 9 hours each) show zero transport impact and a meter capacity limit of 475,000 Dths/day at CT109461. Job 2026112 (LEAP Meter Station upgrades 9/29-10/2, 4 days) also shows zero transport impact.
The dominant job in this posting removes 0.130 Bcf/d of CTPL feedgas transport capacity to Sabine Pass LNG for 4 days beginning 8/25/2026; expect mild bearish pressure at Henry Hub as that volume stays in the domestic market, with the CT200111-CREOLE TRAIL-SPLIQ-D delivery point currently running at 88.4% utilization (1.50 Bcf/d scheduled against 1.70 Bcf/d operating capacity), leaving roughly 0.197 Bcf/d of headroom that partially absorbs the constraint.
Reroute: None: CTPL is the dedicated pipeline serving Sabine Pass LNG, and the constraint reduces feedgas transport capacity directly to the terminal with no bypass route available for the curtailed volumes.
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NEXUS Gas Transmission (U.S.)
08/13/2026- NEXUS Pipeline Conditions for 08/14/2026
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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ANR Pipeline (TC Energy)
UPDATED: CAPACITY REDUCTION Michigan Leg South – East Joliet MS
SEV 3/5
Maintenance0.328 Bcf/dUntil Further Notice11 Days
ANR Pipeline has extended planned maintenance on the Michigan Leg South at East Joliet MS (LOC ID #4196, Will County, IL), reducing capacity to zero at that location -- 0.328 Bcf/d offline -- through 8/21 (extended from the prior 8/14 end date). The notice supersedes prior notice 26125010 and warns that Firm Secondary and Interruptible curtailments are anticipated. Live capacity data confirms EAST JOLIET (loc 4196) is posting zero operating capacity and zero scheduled flow as of the 2026-08-13 timely cycle, fully corroborating the outage.
ANR maintenance at East Joliet MS removes 0.328 Bcf/d of Michigan Leg South northbound capacity through 8/21, with Firm Secondary and Interruptible curtailments anticipated; watch for tightening at ANR ML 7 and Chicago Citygate basis as Midwest delivery capacity is reduced, with DEFIANCE WESTBOUND already flagged OVER (120.7% utilization) and LAGRANGE WESTBOUND also OVER (122.2%), signaling system stress on ANR's northern delivery segments.
Reroute: Moderate: TETCO (monitored), NGPL (monitored), and PEPL (monitored) serve overlapping Gulf Coast-to-Midwest and Chicago-area corridors; however, DEFIANCE WESTBOUND and LAGRANGE WESTBOUND are already oversubscribed on ANR itself, suggesting limited spare absorption capacity on adjacent infrastructure as well.
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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 declared a Same Day Underage Alert for the Phoenix Area on August 13, 2026, effective 7:28 AM, due to high line pack in that delivery zone. Operators taking less than their scheduled quantities at Phoenix Area delivery points will face Alert Day charges under Section 22.2 of the tariff. Transwestern expects the condition to persist through the full gas day and has not specified a volume restriction.
High line pack at Phoenix signals excess supply on the TW westbound corridor for August 13; Transwestern Permian basis was already averaging -0.663 vs Henry Hub over the five trading days ended 2026-08-12 (most recently -0.620 on 2026-08-12), and the underage condition adds modest bearish pressure on TW/Permian basis -- no reroute-driven SoCal tightness is implied unless deliveries are formally curtailed.
Reroute: Moderate: EPNG serves the same Phoenix and SoCal border markets and could absorb rescheduled volumes, though no curtailment has been declared -- this is an alert day penalty notice, not a capacity restriction.
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Florida Gas Transmission
[Florida Gas Transmission] [Operational Alert] Overage Alert Day 20% Tolerance
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Panhandle Eastern Pipe Line
[Panhandle Eastern Pipe Line] [Maintenance] PEPL West Line Maintenance
SEV 3/5
MaintenanceUntil Further Notice
Panhandle Eastern has posted a Critical maintenance notice on the PEPL West Line, effective 2026-08-11, with no stated end date (posted end date of 2200-01-01 indicates an open-ended event). Affected locations are Kalamazoo and CMS Comstock, both Michigan delivery points serving Midwest/Michigan LDC markets. No specific capacity volume is stated in the notice.
Open-ended PEPL West Line maintenance affecting Michigan delivery points (Kalamazoo, CMS Comstock) with no restoration timeline warrants monitoring for tightening at Panhandle Tx.-Okla. basis, which most recently printed -0.380 vs Henry Hub on 2026-08-10 (5-day average -0.350); if deliveries to Michigan are curtailed, expect mild upward pressure on Midwest basis and potential softening at Panhandle origin points if gas backs up.
Reroute: Moderate: ANR Pipeline, TGT (Texas Gas Transmission), and Southern Star serve overlapping Midwest and Michigan markets and could absorb some diverted volumes, though spare capacity at any single alternative is not confirmed and a simultaneous ANR constraint would significantly limit relief.
Panhandle Eastern posted a Critical maintenance notice for an outage at Sunray Gas Plant (Location 40524) effective 2026-08-11. No end date is specified -- the placeholder end date of 2200-01-01 indicates an open-ended 'until further notice' duration. No specific capacity volume is stated in the notice.
Open-ended Sunray Gas Plant outage removes an unquantified Hugoton/Midcontinent receipt point from PEPL with no restoration timeline; Panhandle Tx.-Okla. basis was already trading at -0.380 vs Henry Hub as of 2026-08-10 (5-day average -0.350), and prolonged loss of this supply node adds mild upward pressure to Panhandle basis and downstream Midwest markets.
Reroute: Moderate: ANR, TIGT, and Southern Star serve overlapping Hugoton/Midcontinent supply corridors and could absorb some volumes, though the specific Sunray Gas Plant receipt point has no direct bypass on PEPL itself.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Update - Market and Production Constraints
SEV 3/5
Capacity ConstraintUntil Further Notice
Transco has posted a Critical constraint update effective August 12, 2026, reflecting capacity restrictions across multiple Throughput Section Boundary locations spanning Zones 2 through 6. Key binding constraints include SELA (Zone 3, 0 available both directions), Compressor Station 160 Zone 5 (1,726 Mdt/d available, 0.0% headroom per live data), TSB MP 1412.98-1369.45 Zone 5 (0 NSRP available, confirmed at 100% utilization), Central Penn Line South Zone 6 (0 Secondary available, confirmed at 100% utilization), and an unplanned outage at Compressor Station 70 MP 662 Zone 4 (2,479 Mdt/d available). HBLV swing capacity is exhausted at Zones 2 through 6 with 0 available, indicating the system has no no-notice swing buffer across most of the mainline. Note that the live capacity data is 2 days old (reflecting 2026-08-09) and may not yet capture the full extent of the August 12 restrictions.
Multiple simultaneous binding TSB constraints on Transco from Zone 3 through Zone 6, with Compressor Station 160, Central Penn South, and Zone 4/6 HBLV segments all at zero headroom per the most recent available data; Transco Zone 4 basis has been running +0.715 vs Henry Hub as of 2026-08-07 and northbound delivery constraints into Zones 5-6 risk further Zone 5/6 basis widening while Southeast receipt-side restrictions at SELA (Zone 3, 0 available) and CS 70 (Zone 4, unplanned, only 7.1% headroom in prior data) add upward pressure across Mid-Atlantic and Northeast delivery markets.
Reroute: Limited: Southern Natural Gas (SNG) provides partial real-world alternative capacity for Southeast segments but is unmonitored and its current condition cannot be verified; Tennessee Gas Pipeline (TGP) serves overlapping Northeast markets but simultaneous system stress on Transco of this multi-zone breadth is unlikely to be fully offset by TGP alone, particularly for Mid-Atlantic Zone 5/6 deliveries.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Station 33 (Job 780583) 2026 Planned Outage and Maintenance Summary
SEV 3/5
Maintenance0.135 Bcf/dUntil Further Notice1 Days
Transco has posted a planned one-day compressor station outage at Station 33 (mainline milepost 284.5) on October 27, 2026, associated with facility modifications under Job #780583. Northbound throughput will be constrained, with available capacity reduced from 709 MDt/d to 574 MDt/d (81% of design capacity), representing a 135 MDt/d (~0.135 Bcf/d) reduction. Primary firm shippers face an estimated 12-15% cut based on historical utilization.
Planned single-day Transco Station 33 constraint on October 27 removes approximately 0.135 Bcf/d of northbound capacity, expect modest bullish pressure on Southeast Transco Zone 4 basis and mild bearish signal at downstream Mid-Atlantic delivery points for that day.
Reroute: Limited: Southern Natural Gas (SNG/EGT) provides partial alternative routing for Southeast markets, but Transco is the dominant Southeast-to-Northeast pipeline and SNG capacity is significantly smaller, so full offset of the constrained volumes is unlikely.
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Transwestern Pipeline
[Transwestern Pipeline] [Operational Alert] CRITICAL NOTICE - SAME DAY - OVERAGE ALERT - PHOENIX AREA
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Gulf South Pipeline
Failure to Take Confirmed Quantities at Location 21805
SEV 2/5
Operational Alert1 Days
Gulf South Pipeline issued a Critical Over-Under Performance notice effective 08/14/2026 at 2:00 PM through 08/15/2026 9:00 AM, citing a customer's failure to take confirmed quantities at Location 21805, Discovery Gas Transmission. Gulf South will apply scheduling reductions for remaining nomination cycles on Gas Day 8/14 and until further notice based on projected daily quantities. Live capacity data for this location on the prior gas day (2026-08-13, td11 cycle) showed 0.139 Bcf/d scheduled against 0.250 Bcf/d operating capacity, suggesting a modest-volume interconnect with meaningful headroom before the event began.
This failure-to-take event at the Discovery Gas Transmission interconnect (~0.139 Bcf/d scheduled as of the prior gas day) is a localized, short-duration scheduling reduction with no stated capacity volume and no material Henry Hub or Gulf Coast basis implication; no trading action warranted.
Reroute: Moderate: Gulf South serves this corridor with multiple receipt alternatives including offshore gatherers and Haynesville-origin receipts; Discovery Gas Transmission volumes are modest and other receipt points can absorb scheduling adjustments.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Natural Gas Pipeline (NGPL)
[FORCE MAJEURE] FORCE MAJEURE-M&M LAT MLV2-3 LIFT
SEV 2/5
Restoration
NGPL is lifting the force majeure on the M&M Lateral Segment 3 in Custer County, Oklahoma, effective August 11, 2026, following completion of repair work originally declared July 30, 2026 (Notice 47124). Three receipt locations -- LOC 5388 (ONEOKFS/NGPL Custer), LOC 44627 (MarkWest/NGPL Custer), and LOC 903474 (EMP-EOIT/NGPL Beaver Creek Custer) -- are being restored for primary firm transports only. Continued scheduling restrictions remain in place for these locations due to ongoing remediation, covered under a separate maintenance notice posted August 11, 2026.
FM lift on NGPL M&M Lateral Segment 3 restores primary firm receipt capacity at three Custer County, OK locations, mildly bullish for NGPL Midcontinent basis (most recently -0.310 vs Henry Hub as of 2026-08-10), but residual scheduling restrictions under the companion maintenance notice limit the full supply recovery signal.
Reroute: High: NGPL is a very high-capacity system with multiple Midcontinent receipt alternatives; the partial restoration of Segment 3 under primary firm only does not create material system-wide tightness.
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Millennium Pipeline (MPC)
REMINDER: Line A5 at Bennetts Creek Maintenance August 18th
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Update- Job #367383 Cascade Creek Planned Outage and Maintenance Summary
SEV 2/5
Maintenance3 Days
Transco has posted a planned maintenance notice for the Cascade Creek meter station (Location ID 9001040) associated with Job #367383. The outage is scheduled from October 6 to October 8, 2026, lasting approximately 3 days. The location will remain available for gas scheduling during the maintenance window, suggesting limited operational disruption.
Planned single-meter maintenance at Cascade Creek with no stated capacity restriction and scheduling availability maintained throughout -- no material basis or Henry Hub price signal expected.
Reroute: High: Cascade Creek is a single bi-directional meter station on Transco; no specific capacity loss is stated and gas scheduling remains available, making reroute considerations largely moot.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Gulf South Pipeline
Failure to Take Confirmed Quantities at Location 23091
SEV 2/5
Operational Alert1 Days
Gulf South Pipeline issued an Over-Under Performance notice for Gas Day 8/7/2026 indicating that Nucor Steel Mill (Location 23091) failed to take confirmed quantities. Gulf South anticipates scheduling reductions for remaining nomination cycles on 8/7/2026 and until further notice based on projected daily quantities. No specific volume figure is stated and the affected customer is a single industrial end-user with no LNG or major market implications.
Single industrial customer failure-to-take at a steel mill delivery point on Gulf South has no material Henry Hub or regional basis implication; no actionable trading signal.
Reroute: Not applicable -- this is a downstream delivery failure at a single industrial customer meter, not a pipeline capacity constraint requiring reroute assessment.
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Kern River Gas Transmission
Kern River - Line Pack Has Returned to Normal
UNSCORED
Informational
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Kern River Gas Transmission
Kern River - Fillmore Compressor Station Unit 2 Force Majeure Update
UNSCORED
Informational
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Kern River Gas Transmission
Kern River - Fillmore Compressor Station Unit 2 Force Majeure Lifted
UNSCORED
lifted ✓Informational
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MountainWest (multi-pipeline)
[MountainWest Pipeline (MWP)] [SKULL CREEK METER REPLACEMENT] SKULL CREEK METER REPLACEMENT
UNSCORED
Informational
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MountainWest (multi-pipeline)
[MountainWest Pipeline (MWP)] [UPDATED RESCHEDULED ML 1 - REDUCTIONS FOR SMART PIGGING] UPDATED RESCHEDULED ML 1 - REDUCTIONS FOR SMART PIGGING
UNSCORED
Informational
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Texas Gas Transmission
Customer Service Update--Inbound Email Communication
