Iroquois Gas Transmission has declared an Operational Flow Order (OFO) effective January 15 gas day, in effect until further notice, for all points south of MLV-12, citing expected high volumes and adverse weather. All point operators must adhere strictly to scheduled volumes to maintain pipeline pressure; no unscheduled OBA gas is available, and Flow Control will be activated if necessary. The OFO has no stated end date and directly restricts flexibility for power plants and distribution customers in the New York and southern New England service area.
Iroquois OFO south of MLV-12 with no restoration timeline restricts delivery flexibility into the NYC metro and southern New England market; Iroquois Zone 2 basis has been running at -0.140 vs Henry Hub as of 2026-08-27 but expect significant bullish pressure on Zone 2 and Algonquin Citygate as the OFO tightens operational flexibility during a high-demand weather event with zero unscheduled gas available.
Reroute: Limited to none: Algonquin Gas Transmission serves overlapping southern New England and Connecticut markets, but if Algonquin is simultaneously stressed during the same weather event, there is effectively no reroute for affected Iroquois delivery points south of MLV-12, including Long Island and NYC metro customers.
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Iroquois Gas Transmission
Operational Flow Order
SEV 4/5
Operational AlertUntil Further Notice
Iroquois Gas Transmission has declared an Operational Flow Order (OFO) effective February 23rd gas day, valid until further notice, for all points south of MLV-12. The OFO is driven by expected high volumes and forecasted weather conditions, requiring all point operators to adhere strictly to scheduled volumes to maintain pipeline pressures; OBA gas is suspended and Flow Control may be activated. No end date has been specified, introducing sustained supply risk for New York and New England markets downstream of the affected segment.
Iroquois OFO south of MLV-12 with no restoration timeline tightens deliveries into New York and New England; Iroquois Zone 2 basis was -0.140 vs Henry Hub on 2026-08-27 (five-day average -0.190), and this open-ended OFO with weather-driven demand pressure is bullish for Zone 2 and Algonquin Citygate -- expect basis to widen further as unscheduled flexibility is eliminated and power plant burn nominations are constrained.
Reroute: Limited to none: Algonquin Gas Transmission provides partial alternative supply into New England and New York markets, but Algonquin and Iroquois are the two dominant pipes serving these markets and Algonquin is frequently simultaneously constrained during high-demand weather events, leaving minimal reroute headroom for volumes south of MLV-12.
TETCO has experienced an unplanned outage at its Lebanon, Ohio compressor station, reducing east-to-west capacity through Berne, Sarahsville, and Somerset to approximately 0.579 Bcf/d and Five Points/Lebanon to 0.676-0.678 Bcf/d. Non-primary nominations at Sarahsville, Five Points, and Lebanon will be restricted beginning Gas Day August 28, 2026, with no firm end date provided. Restoration timeline is unknown; TETCO states updates will follow as repairs progress.
Unplanned Lebanon CS outage cuts TETCO eastbound capacity to 0.579 Bcf/d at the tightest point (Berne/Sarahsville/Somerset) effective August 28; with TETCO M-3 basis already at -1.160 vs Henry Hub as of 2026-08-26, further Mid-Atlantic tightening is likely while Appalachian M-2 supply backs up west of the outage.
Reroute: Limited: Transco (monitored) is the primary competing Mid-Atlantic pipeline and provides partial alternative capacity, but cannot fully replace TETCO M-3 deliveries at comparable volumes; TCO and EGTS serve overlapping Appalachian markets but do not replicate TETCO's Mid-Atlantic reach.
EPNG has declared a system-wide Strained Operating Condition (SOC) effective August 27, 2026, due to linepack falling to 7,530 MMcf following a 105 MMcf draw on Gas Day August 26, driven by deliveries exceeding scheduled volumes. The SOC is in effect until further notice, with EPNG suspending IHSW service, denying imbalance paybacks, and placing Washington Ranch storage on withdrawal. Customers are required to balance deliveries to scheduled supplies immediately.
System-wide EPNG SOC with no stated restoration timeline tightens Permian/San Juan takeaway capacity; Waha basis, already at -1.050 on 2026-08-26 (trailing 5-day average -0.880 vs Henry Hub), faces additional bearish pressure from potential scheduling curtailments, while SoCal Border and Arizona delivery points face bullish pressure from reduced westbound throughput reliability -- monitor for escalation to OFO or firm curtailments.
Reroute: Moderate: Transwestern Pipeline (TW) serves overlapping SoCal border and Arizona markets and provides a partial alternative for westbound Permian flows; however, a simultaneous TW constraint would eliminate California reroute options entirely.
EPNG has declared a system-wide Strained Operating Condition (SOC) effective August 25, 2026, with duration listed as 'until further notice.' Linepack fell to 7,444 MMcf as of the Gas Day August 25 start -- down 291 MMcf from the prior day -- driven by deliveries in excess of scheduled volumes and supply underperformance in the Permian Basin. In response, EPNG has activated Washington Ranch storage withdrawal, suspended IHSW service, and is denying imbalance payback from the system; customers are required to balance deliveries with scheduled supplies.
System-wide SOC with no restoration timeline on EPNG tightens Permian takeaway and pressures linepack; Waha basis, already at -0.870 vs Henry Hub as of 2026-08-24 (5-day average -0.822), faces further bearish pressure as Permian supply backs up, while SoCal Border and Arizona delivery points face reduced supply and bullish basis pressure until the SOC is lifted.
Reroute: Moderate: Transwestern Pipeline (TW) serves overlapping SoCal border and Arizona markets and provides a partial alternative for westbound Permian volumes, though available spare TW capacity is unknown and may not fully offset EPNG throughput constraints during an active SOC.
EPNG has declared force majeure following a dry seal failure at the Seligman 'C' Compressor Station in Yavapai County, Arizona. The outage reduces operational capacity through the NORTH ML constraint by an additional 144,220 Dth/d (0.144 Bcf/d) effective August 25, 2026 Intraday 1 Cycle, with a stated end date of August 26, 2026 9:00 AM. Repair timeline is uncertain; EPNG has noted it is evaluating options and will post an updated maintenance notice reflecting the total NORTH ML impact.
EPNG force majeure at Seligman 'C' removes an additional 0.144 Bcf/d of westbound NORTH ML capacity; expect bearish pressure at Waha -- already at -0.870 vs Henry Hub as of 2026-08-24 and averaging -0.822 over the prior five trading days -- as Permian basin gas backs up further, with incremental bullish pressure at SoCal Border and Arizona delivery points as westbound supply is further tightened.
Reroute: Moderate: Transwestern Pipeline (TW) serves overlapping SoCal Border and Arizona markets and provides a partial alternative for westbound volumes; however, TW capacity availability is unconfirmed and may not fully absorb the constrained volumes, particularly given ongoing NORTH ML aggregate restrictions.
Tennessee Gas Pipeline has declared a Force Majeure at Station 542 near DeKalb, Mississippi, effective August 25, 2026 and until further notice, after discovering a failure requiring immediate repairs on Unit 1. Units 2 and 3 at the same station have been out of service since March and April 2026 respectively, meaning all three compressor units are now offline simultaneously. Tennessee estimates the capacity impact at up to 0.280 Bcf/d, with Primary In the Path nominations on Segment 539 BH at risk of curtailment as early as the Timely Cycle for August 26, 2026.
TGP force majeure at STA 542 removes up to 0.280 Bcf/d of northbound capacity on Segment 539 BH; with all three compressor units now offline and no restoration timeline, expect bullish pressure on Tennessee Zone 4/500 Leg basis vs Henry Hub -- Tennessee Zone 4-300 leg was already trading at a -1.360 basis vs HH as of 2026-08-24 and the loss of primary firm capacity eligibility beginning August 26 Timely Cycle could drive further widening in Southeast and downstream Northeast zones.
Reroute: Moderate: Southern Natural Gas (not live-monitored) and Gulf South serve overlapping Gulf Coast-to-Southeast corridors and may absorb some displaced volumes, though SNG real-time capacity is unverified and neither pipe fully replicates TGP's northbound reach into the Northeast.
Trunkline Gas Company has posted a Critical maintenance notice effective 2026-08-24 for a high-pressure outage at the Henry Hub (loc 80721). The notice carries no end date (end date is effectively open-ended at 2200-01-01), meaning the constraint is 'until further notice.' Live capacity data for the prior gas day shows HENRY HUB HIGH PRESSURE - TGC - SA running at only 7% utilization on the delivery side (0.035 Bcf/d scheduled against 0.500 Bcf/d operating capacity), consistent with a facility that is largely offline or severely restricted. Because this is the physical Henry Hub high-pressure header, even a partial outage carries outsized price signal importance beyond the raw volume removed.
TGC high-pressure outage at the physical Henry Hub with no restoration timeline is bullish for Henry Hub and Trunkline ELA spot prices; the prior gas day's delivery scheduling at this location collapsed to 0.035 Bcf/d against 0.500 Bcf/d operating capacity (93% headroom, consistent with near-full curtailment), and with no end date this constraint must be traded as open-ended until a restoration notice is posted.
Reroute: Moderate: TETCO (monitored), CGT (monitored), and Gulf South (monitored) all have interconnects in the Henry Hub area and can absorb some diverted volumes, but the Henry Hub itself is a pooling and pricing node -- physical access constraints at the hub itself affect settlement and basis pricing beyond simple volume rerouting.
ANR Pipeline has posted a planned maintenance outage at the Wheeler Hidetown meter station (Loc #523099) in Wheeler County, Texas, scheduled September 13-18, 2026 (6 days). Capacity at this location will be reduced from 480 MMcf/d to zero, with ANR explicitly warning of 100% curtailments to Firm Primary service based on both current nominations and contracted MDQ. This is a full capacity elimination at a Southwest Area receipt/delivery point affecting all service classes.
ANR Wheeler Hidetown maintenance removes 0.480 Bcf/d of Southwest Area capacity on September 13-18, with 100% Firm Primary curtailments anticipated; expect tightening at ANR ML 7 (Michigan/Wisconsin) delivery basis and modest bearish pressure at Gulf Coast receipt points as northbound takeaway is reduced, with any unaffected competing pipes (TETCO, TGC) as partial mitigation.
Reroute: Moderate: TETCO (monitored), Trunkline/TGC (monitored), and Southern Star (monitored) serve overlapping Gulf Coast-to-Midwest corridors and may absorb displaced volumes, but the 0.480 Bcf/d full curtailment with advance notice gives shippers time to arrange alternatives before the September 13 effective date.
Gas Transmission Northwest (GTN) has declared an unplanned maintenance outage at Unit 5D affecting Flow Past Kingsgate (LOC #3500), effective 8/26 through 9/4/2026. Available capacity is reduced to 2,550 MMcf/d (2.550 Bcf/d) for the duration. GTN explicitly warns that Firm Primary, Firm Secondary, and Interruptible curtailments are anticipated, and the Reservation Charge Crediting Mechanism has been activated.
GTN unplanned outage at Kingsgate restricts 2.550 Bcf/d of Western Canada/PNW corridor capacity through 9/4; with Firm Primary curtailments possible and GTN Kingsgate basis already deeply negative (most recently -1.710 vs HH as of 2026-08-21), expect the constraint to tighten PG&E Malin and downstream California basis materially over the 8/26-9/4 window.
Reroute: Limited: GTN is the primary Western Canada-to-Pacific Northwest corridor feeding California via Malin; Ruby Pipeline (monitored) and Northwest Pipeline (monitored) provide partial Rockies-origin alternatives but cannot replace WCSB volumes at equivalent scale, and simultaneous system stress on any of these pipes would further limit relief.
EPNG declared force majeure at Gresham Compressor Station in Culberson County, Texas, due to a failed compressor seal requiring immediate repairs. The station is currently unavailable, reducing operational capacity through the WA2CORN constraint and associated points by 67,738 Dth/d (0.068 Bcf/d) effective August 24, 2026 Evening Cycle (Cycle 2). EPNG has indicated a separate updated maintenance notice will follow to reflect total impact, and the stated end date is August 24, 2026 at 9:00 AM, suggesting a short-duration event.
EPNG force majeure at Gresham Station removes 0.068 Bcf/d of Permian outbound capacity via WA2CORN; expect mild additional bearish pressure at Waha, which was already trading at a -0.815 basis vs Henry Hub as of 2026-08-21 (5-day average -0.825), with a corresponding small bullish signal at SoCal Border and Arizona delivery points -- magnitude is modest relative to system scale but force majeure status and promise of a follow-on notice warrant monitoring for escalation.
Reroute: Moderate: Transwestern Pipeline (TW) serves overlapping SoCal Border and Arizona markets and may absorb some displaced volumes; however, the Culberson County location and WA2CORN constraint are specific to EPNG's Permian mainline corridor, and if TW is simultaneously tight, reroute options diminish.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Algonquin Gas Transmission
08/25/2026- AGT Pipeline Conditions for 8/26/2026
SEV 3/5
Capacity Constraint1 Days
For gas day August 26, 2026, AGT has declared a system-wide OFO with 500 Dth/6% tolerance, with numerous key locations restricted to 100% of operational capacity including Stony Point, Cromwell, Burrillville, Weymouth, Iroquois Deliveries and Receipts, Mendon, Lincoln, and Deliveries to Texas Eastern. Multiple locations reflect planned outages affecting TETCO deliveries. The constraint covers one gas day (8/26) and is accompanied by warnings that further OFO escalation is possible if hourly takes are not managed.
AGT system-wide OFO for 8/26 tightens New England supply across all key delivery and interconnect points; Algonquin Citygate basis was already -1.095 vs Henry Hub on 8/24 (5-day average -0.898), and the OFO with near-100% scheduling at Stony Point, Cromwell, Weymouth, and Iroquois creates upward basis pressure at Algonquin Citygate and downstream New England delivery points for tomorrow's gas day.
Reroute: Limited: Iroquois Gas Transmission is the only meaningful alternative for core New England deliveries, and Iroquois Deliveries and Receipts are themselves listed as restricted at 100% in this same notice, leaving virtually no independent reroute capacity for the affected market.
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Columbia Gas Transmission (TCO)
Line SM-80 Pipeline Maintenance (CEREWEST), Effective September 9-26, 2026
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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ANR Pipeline (TC Energy)
CAPACITY REDUCTION Southwest Area
SEV 3/5
Maintenance0.125 Bcf/dUntil Further Notice6 Days
ANR Pipeline has posted a planned maintenance outage at the Red River Interconnect meter station in Loving County, Texas (LOC #185837) in its Southwest Area, effective September 13–18, 2026 (6 days). The full 125 MMcf/d (0.125 Bcf/d) of capacity at this location will be reduced to zero, with ANR explicitly anticipating 100% curtailments of Firm Primary nominations based on both current net shipper nominations and contracted MDQ. Reservation charge credits will be issued per tariff Section 6.36 if primary firm scheduled quantities cannot be delivered.
ANR planned outage removes 0.125 Bcf/d at Red River Interconnect (Loving County, TX) for 6 days beginning 9/13; 100% firm primary curtailment is anticipated, watch ANR Southwest Area receipt point pressure and mild tightening at ANR ML 7 / Midwest delivery basis if no reroute is arranged by shippers ahead of the gas days.
Reroute: Moderate: TETCO, Trunkline (TGC), and Southern Star serve overlapping Gulf Coast-to-Midwest corridors and could absorb a portion of the 0.125 Bcf/d affected volume; the relatively small size of this restriction improves reroute feasibility, though firm shippers at this specific interconnect meter have no direct bypass on ANR itself.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Sea Robin Pipeline
[Sea Robin Pipeline] [Maintenance] Sea Robin East Planned Maintenance
SEV 3/5
Maintenance5 Days
Sea Robin Pipeline has posted a planned maintenance outage for Sea Robin East, requiring all shippers to shut in and cutting nominations to zero from Gas Day September 21 through September 25, 2026 (5 days). The notice is marked Critical with no response required from shippers. No specific capacity volume is stated, but the full system shutdown means all offshore Gulf of Mexico production flowing through Sea Robin East will be curtailed during this window.
Sea Robin East full shut-in from Sep 21-25 removes all offshore Gulf of Mexico volumes from this gathering system for 5 days; no stated capacity figure, but the complete nomination cut is mildly bullish for Gulf Coast onshore supply balance -- Henry Hub has most recently been quoted at 2.810 (2026-08-21), and the outage window falls outside the current 5-day basis pricing window, so near-term market pricing does not yet reflect this event.
Reroute: None: Sea Robin is an offshore gathering system with no alternative pipeline route; production tied to Sea Robin East must be physically shut in at the platform level for the duration of the outage.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
Updated - Market and Production Constraints
SEV 3/5
Capacity ConstraintUntil Further Notice1 Days
Transco posted an updated daily market and production constraints notice effective August 25, 2026, superseding prior notice 17197658. Multiple segments across Zones 2 through 6 show zero or near-zero available capacity, including Compressor Station 160 (Zone 5 delivery, 1,726 Mdt/d available primary), Central Penn Line South N-to-S (Zone 6, 2,093 Mdt/d primary), SELA N-to-S and S-to-N (Zone 3, zero available primary), and several Zone 5/6 segment TSBs at zero NSRP and secondary capacity. HBLV swing availability is zero across Zones 2 through 6, signaling no no-notice swing buffer on the entire mainline north of Zone 1. Live capacity data from 2026-08-22 (two days prior, may not yet reflect August 25 conditions) corroborates tightness at CS 160 and TSB MP 1412.98 to MP 1369.45, both at 100% utilization with zero headroom.
Transco mainline is running at or near capacity on multiple northbound Zone 3-6 segments with zero HBLV swing buffer Zones 2-6 and several delivery laterals at zero available capacity, pointing to bullish pressure at Transco Zone 4 Southeast basis and elevated Zone 5/6 Mid-Atlantic and Northeast basis vs Henry Hub for the August 25 gas day; CS 60 (Zone 3 receipt, 0.0% headroom at 1.92 Bcf/d) and CS 160 (Zone 5 delivery, 0.0% headroom at 1.73 Bcf/d) are the most acute binding points per the two-day-lagged live data.
Reroute: Limited: for Southeast Zone 3/4 tightness, Southern Natural Gas serves overlapping Gulf Coast and Southeast markets but is unmonitored with unknown spare capacity; for Zone 5/6 Mid-Atlantic and Northeast, Tennessee Gas Pipeline (TGP) is the primary alternative but is frequently loaded during summer peak demand.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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El Paso Natural Gas (EPNG)
[FORCE MAJEURE] Force Majeure Lifted – El Paso D Station
SEV 2/5
lifted ✓Restoration1 Days
EPNG has lifted the force majeure declared on August 12, 2026 at El Paso D Compressor Station Unit 4 in El Paso County, Texas (Critical Notice No. 629304). Capacity through the ELPASO E and associated constraints is being restored effective August 25, 2026, Intraday 1 Cycle (Cycle 3). No specific capacity volume is stated in the notice; EPNG indicates a separate updated maintenance notice will follow.
Restoration of El Paso D Unit 4 capacity removes the prior outbound constraint; expect marginal bearish pressure at Waha (basis has averaged -0.822 vs HH over the five trading days ended 2026-08-24, most recently -0.870 on 2026-08-24) as takeaway headroom increases, with a mild offsetting easing of bullish pressure at SoCal Border and Arizona delivery points -- no new market-moving signal given the market has had since August 12 to price this constraint.
Reroute: Moderate: Transwestern Pipeline (TW) provides an alternative westbound route from the Permian to SoCal border and Arizona; with El Paso D now restored, reroute pressure on TW should ease.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Tennessee Gas Pipeline (TGP)
FORCE MAJEURE AT STA 542 RESOLVED 8-27
SEV 1/5
lifted ✓Restoration2 Days
Tennessee Gas Pipeline has resolved the force majeure declared at Station 542 near DeKalb, Mississippi on August 25, 2026 (Notice #403735). Unit 1 repairs are complete and the station is returning to normal operations. Full nominations pathed through STA 542 (Segment 539 BH) will be scheduled up to capacity effective Timely Cycle for the gas day of August 27, 2026. This is the final update on the event.
STA 542 force majeure resolved; full capacity restoration on TGP Segment 539 BH effective August 27 timely cycle removes the prior supply constraint, with Tennessee Zone 4-300 leg basis most recently at -1.290 vs Henry Hub -- no new directional signal as the disruption is over.
Reroute: N/A -- event is resolved; reroute assessment no longer applicable.
