Cove Point LNG (CPL) has issued an Operational Flow Order (OFO) classified as Critical, effective July 1, 2026 at 14:00. This is Revision 2 of the notice originally posted June 30, 2026. No specific capacity volume is stated in the notice text, and the notice predates the live capacity data window (which reflects August 18, 2026); the COVE POINT PLANT delivery point shows 0.747 Bcf/d scheduled against 0.920 Bcf/d operating capacity (81.2% utilized, 18.8% headroom) as of August 18 -- but this reading postdates the OFO effective date by nearly 7 weeks and cannot be treated as representative of conditions at the time of the OFO. As an LNG export terminal, any OFO at Cove Point carries minimum severity 4.
Cove Point LNG OFO removes or curtails feedgas demand at the terminal, keeping Appalachian supply onshore and pressuring Appalachian/Mid-Atlantic basis bearish; Eastern Gas South regional proxy most recently at -1.005 vs Henry Hub (hub ~1.820, HH ~2.825 as of 2026-08-18), though those prices postdate the July 1 OFO effective date and may not reflect conditions at issuance.
Reroute: Not applicable -- Cove Point LNG is a demand sink (LNG export terminal), not a supply pipeline; an OFO restricts feedgas nominations into the terminal, with no reroute concept applicable to a curtailed LNG export facility.
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CPL
Cove Point Restrictions Revision
SEV 4/5
Capacity ConstraintUntil Further Notice
Cove Point LNG (CPL) has posted a Revision 2 to its Cove Point Restrictions notice, originally filed 2026-07-20, designating it as a Critical capacity constraint. No specific restriction volumes or restoration timeline are stated in the notice text. As an LNG export terminal, any feedgas curtailment at Cove Point removes export demand from the domestic Appalachian supply balance, keeping gas onshore and pressuring regional basis bearishly. Live capacity data (gas day 2026-08-18, one day behind) shows the Cove Point Plant delivery point running at 81.2% utilization (0.747 Bcf/d scheduled against 0.920 Bcf/d operating capacity), with 0.173 Bcf/d of headroom; the storage injection point shows an INCONSISTENT flag, so its utilization figures are unreliable.
Cove Point LNG feedgas restriction applies the minimum severity-4 LNG floor; no specific curtailment volume is stated in the notice, but live data (2026-08-18, one day lag) shows the plant delivery point at 81.2% utilization with 0.173 Bcf/d of remaining headroom -- any tightening of that headroom would suppress Appalachian export demand and pressure Eastern Gas South (regional proxy) basis, which most recently printed at -1.005 vs Henry Hub as of 2026-08-18, bearish for Transco Zone 5 delivery points.
Reroute: None: Cove Point is a fixed LNG export terminal; feedgas that cannot be delivered to the liquefaction facility cannot be rerouted to an equivalent export outlet and instead remains in the domestic Appalachian/Mid-Atlantic supply balance.
Cove Point LNG (CPL) has posted a Revision 2 to its Pipeline Conditions / Capacity Constraint critical notice originally filed 2026-07-23, with no additional operational detail or capacity figures provided in the notice text. The notice is a revision with no new quantified impact, but the LNG feedgas severity floor applies because the affected facility is Cove Point LNG export terminal. Live capacity data (gas day 2026-08-18, approximately 1 day lag) shows COVE POINT PLANT operating at 81.2% utilization on the delivery side (0.747 Bcf/d scheduled against 0.920 Bcf/d operating capacity), with 0.173 Bcf/d of remaining headroom; the SI direction is flagged INCONSISTENT and cannot be used for ratio analysis.
Cove Point LNG feedgas constraint minimum severity 4 applies regardless of the absence of a stated volume; the live reading for 2026-08-18 shows the plant delivery point at 81.2% utilization (0.747 Bcf/d scheduled, 0.173 Bcf/d headroom remaining), with the Eastern Gas South regional proxy basis averaging -0.993 vs Henry Hub over the five trading days ended 2026-08-18 (most recently -1.005 on 2026-08-18) -- any escalation of this constraint that further curtails feedgas deliveries would be bearish for Appalachian/Mid-Atlantic basis and bearish for the LNG export arb.
Reroute: None: Cove Point LNG is a fixed-location export terminal; feedgas restrictions cannot be physically rerouted to an alternative facility. Gas displaced from LNG export returns to the domestic Appalachian/Mid-Atlantic supply pool.
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Transco
Notice of Force Majeure Event - Unplanned Outage Station 70 Main Unit 9
SEV 4/5
Force Majeure0.865 Bcf/dUntil Further Notice
Transco declared force majeure on August 7, 2026 due to an unplanned equipment failure at Compressor Station 70 (MP 662), restricting south-to-north throughput effective ID2 8/7/2026 with no stated return-to-service date. Design capacity at the TSB is 3,344 MDth/d but available primary firm transportation is reduced to 2,479 MDth/d, implying a loss of approximately 865 MDth/d (0.865 Bcf/d) of northbound capacity. Potential shipper cuts of 0-15% on primary firm service are indicated, with major repairs anticipated before full restoration.
Transco FM at Station 70 removes approximately 0.865 Bcf/d of northbound capacity with no restoration timeline; expect bullish pressure on Transco Zone 4 and Zone 5 basis as Southeast and Mid-Atlantic shippers compete for reduced northbound scheduling space, with mild upward bias at Henry Hub given Transco's dominant role in Gulf Coast-to-Northeast flows.
Reroute: Limited: Southern Natural Gas (SNG/EGT) provides partial alternative for Southeast volumes, but SNG capacity is significantly smaller than Transco and cannot absorb a full 0.865 Bcf/d displacement; Tennessee Gas Pipeline serves overlapping Northeast markets but may also face summer throughput constraints, leaving meaningful volumes without viable reroute.
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Algonquin Gas Transmission
08/07/2026- AGT Operational Flow Order -- EFF 8/8
SEV 4/5
Operational AlertUntil Further Notice
Algonquin Gas Transmission has declared a system-wide Operational Flow Order effective August 8, 2026, and lasting until further notice (notice end date listed as 11/05/2026). The OFO prohibits daily pathing exceeding 4% over scheduled quantities (500 MMBtu minimum) for all system customers, with a tighter 2% / 500 MMBtu restriction applied to customer-specific nominations. No restoration timeline is given beyond 'until further notice,' indicating an open-ended supply management event on one of New England's two dominant interstate pipelines.
Algonquin system-wide OFO effective 8/8 with no fixed end date signals tightening New England supply balance; expect bullish pressure at Algonquin Citygate and elevated New England basis vs Henry Hub, with risk of extreme spike if Iroquois faces simultaneous constraint.
Reroute: Limited to none: Algonquin and Iroquois are the two primary pipelines serving New England; if Iroquois is simultaneously constrained, there is zero reroute available and extreme basis spikes are likely at Algonquin Citygate.
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Columbia Gulf Transmission (CGT)
CAPACITY POSTING - TIM for August 8, 2026, through August 10, 2026
SEV 4/5
Force Majeure2.350 Bcf/d3 Days
CGT declares a force majeure active since June 19, 2026 at Corinth Compressor Station Unit 505, with this TIM capacity posting covering August 8-10, 2026. The CorinSEG backhaul segment is restricted to 2,350,000 MMBtu/day (2.350 Bcf/d) while all other segments show Total Capacity availability. Multiple point constraints are zeroed out including key interconnects at CROSSTEX-GIBSON, TRANSCO/TERREBONNE, SEA ROBIN-ERATH, BURLINGTON-TERREBONNE, and SOUTHEASTERN SUPPLY HEADER. Due Shipper service is not available.
Active CGT force majeure at Corinth CS restricts backhaul capacity to 2.350 Bcf/d on CorinSEG, tightening Gulf Coast-to-Appalachian northbound flows and supporting bullish pressure at Transco Zone 4 and TETCO M3 versus Henry Hub; multiple zeroed-out interconnect points including Transco/Terrebonne and SESH further constrain routing flexibility.
Reroute: Moderate: Texas Eastern (TETCO) and Trunkline (TGC) serve overlapping Gulf Coast northbound corridors and can absorb some displaced volumes, but the scale of the CorinSEG restriction at 2.350 Bcf/d means partial offset at best, and zeroed SESH and Transco/Terrebonne interconnects further limit reroute optionality.
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Texas Eastern Transmission (TETCO)
08/06/2026- TE Operational Advisory -- UPDATE
SEV 4/5
Operational AlertUntil Further Notice
TETCO has declared an operational advisory effective August 6, 2026, requiring all shippers and point operators in Market Area Zones M2 and M3 to perform to scheduled quantities due to large pipeline imbalances that Texas Eastern cannot manage with existing flexibility. The notice threatens OFOs and underperformance reductions if compliance is not achieved, and remains in effect until further notice with no restoration timeline. This is a first-revision superseding notice (prior notice 181374), indicating an escalation from an earlier advisory.
TETCO M2 and M3 imbalance advisory with OFO threat and no end date tightens Mid-Atlantic and Appalachian supply, expect bullish pressure on TETCO M2, TETCO M3, and Transco Zone 5 basis vs Henry Hub as shipper curtailments and underperformance reductions bite.
Reroute: Limited to moderate: Transco serves overlapping Mid-Atlantic markets and is the primary competing pipeline for M3 deliveries; however, simultaneous demand pressure on both TETCO and Transco in the Mid-Atlantic corridor limits the degree to which volumes can be shifted without further basis widening.
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Columbia Gulf Transmission (CGT)
Clementsville Compressor Station Maintenance (ClemSEG), August 11-12, 2026
SEV 4/5
Maintenance0.245 Bcf/d2 Days
CGT has notified customers of planned maintenance at Clementsville Compressor Station on August 11-12, 2026, reducing backhaul capacity through ClemSEG to 2,050,000-2,150,000 Dth/day against a design capacity of 2,344,656 Dth/day -- a reduction of approximately 195,000-295,000 Dth/day (roughly 0.245 Bcf/d at midpoint). The restriction is explicitly noted as potentially curtailing Interruptible, Secondary Firm, and Primary Firm services, making this a significant planned event. Duration is two gas days.
CGT maintenance reduces ClemSEG backhaul capacity by approximately 0.245 Bcf/d on August 11-12; the explicit mention of Primary Firm curtailment risk warrants bullish positioning in Southeast basis (Transco Zone 4) versus Henry Hub during the affected gas days.
Reroute: Moderate: Texas Eastern (TETCO) and Trunkline (TGC) serve overlapping Gulf Coast northbound corridors and may absorb some displaced volumes, but the explicit Primary Firm curtailment language suggests CGT itself has limited operational flexibility to offset the restriction.
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ANR Pipeline (TC Energy)
UPDATED: CAPACITY REDUCTION Michigan Leg North – Rabbit River MS
SEV 4/5
Maintenance0.083 Bcf/dUntil Further Notice39 Days
ANR Pipeline has updated the maintenance window for the Rabbit River Meter Station (LOC #523093) in Allegan County, Michigan on the Michigan Leg North. The outage now runs August 11 through September 18, 2026 (shifted from the original August 6 to September 14 window), reducing capacity to zero MMcf/d and eliminating all 83 MMcf/d of throughput. ANR explicitly warns of 100% curtailment impact on Firm Primary service based on both current nominations and contracted MDQ.
ANR Michigan Leg North maintenance eliminates all 0.083 Bcf/d at Rabbit River MS through September 18, with 100% firm primary curtailment confirmed; watch for tightening Michigan/Midwest basis and potential reservation charge credit activity indicating shipper distress.
Reroute: Limited: the Rabbit River MS is a local Michigan delivery point on the Michigan Leg North, a specific lateral with limited bypass options; TETCO, PEPL, and Southern Star do not serve this same downstream Michigan local distribution market, so full reroute is unlikely for customers directly served by this meter station.
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ANR Pipeline (TC Energy)
UPDATED: CAPACITY REDUCTION Michigan Leg North – Rabbit River MS
SEV 4/5
Maintenance0.083 Bcf/dUntil Further Notice38 Days
ANR Pipeline has updated maintenance dates for the Michigan Leg North at Rabbit River Meter Station (Allegan County, MI), shifting the window from 8/6-9/14 to 8/11-9/18/2026. Capacity at LOC #523093 is reduced to 0 MMcf/d from 83 MMcf/d for the full duration -- a complete shutoff. ANR explicitly warns of 100% curtailment of Firm Primary nominations and contracted MDQ, making this a full firm curtailment event despite being planned maintenance.
Complete 0.083 Bcf/d firm primary curtailment at Rabbit River MS through 9/18 will tighten Michigan/Midwest local delivery basis; shippers should seek alternative ANR receipt paths or competing pipelines (PEPL, TGT) immediately as 100% of contracted MDQ is at risk.
Reroute: Moderate: ANR serves overlapping Michigan/Midwest markets with PEPL and TGT providing partial alternatives, but Rabbit River MS delivers into a specific Allegan County, MI local distribution area where bypass options may be geographically limited.
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Tennessee Gas Pipeline (TGP)
FORCEMAJEURE AT STA 542 EFFECTIVE 8-4-26
SEV 4/5
Force Majeure0.280 Bcf/dUntil Further Notice
Tennessee Gas Pipeline has declared a Force Majeure at Station 542 near DeKalb, Mississippi effective August 4, 2026, after discovering an issue with Unit 1 requiring immediate repairs. Units 2 and 3 at the same station have been out of service since late March and early April 2026 respectively, meaning all three units at STA 542 are now offline. The estimated capacity impact is up to 280,000 Dth/day (0.280 Bcf/d), with Primary In the Path nominations through Segment 539 BH at risk beginning Timely Cycle for August 5, and the event is open-ended with no restoration timeline.
TGP force majeure at STA 542 with all three compressor units offline removes up to 0.280 Bcf/d of capacity through the Mississippi corridor; with no restoration timeline and primary firm service at risk starting August 5, expect bullish pressure on Southeast basis points (Tennessee Zone 4, Transco Zone 4) versus Henry Hub.
Reroute: Moderate: Southern Natural Gas (EGT) and Transco serve overlapping Gulf Coast-to-Southeast corridors, but both are significantly smaller than TGP in this segment and may lack spare capacity to fully absorb 0.280 Bcf/d of displaced volumes.
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Gulf South Pipeline
Failure to take confirmed quantities - Loc 24329 Stratton Ridge to Freeport LNG
SEV 4/5
Operational AlertUntil Further Notice
Gulf South Pipeline is notifying customers of a failure to take confirmed quantities at Location SLN 24329 Stratton Ridge (to Freeport LNG) in Area 25, effective Gas Day 8/4/2026. Confirmation reductions are anticipated for all remaining nomination cycles for 8/4/2026 and until further notice. No specific volume is stated, but the delivery point explicitly names Freeport LNG, triggering the LNG feedgas floor.
Freeport LNG is failing to take confirmed feed gas volumes at Stratton Ridge via Gulf South, reducing LNG export pull and leaving gas onshore -- bearish for Henry Hub and Gulf Coast basis until Freeport resumes taking confirmed quantities.
Reroute: Moderate: Gulf South interconnects with Southern Natural (EGT), Transco, and Tennessee Gas Pipeline for Gulf Coast and Southeast markets, but displaced Freeport LNG feed gas volumes have no alternative LNG export outlet in this corridor -- volumes will simply remain in the domestic supply pool.
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Gulf South Pipeline
Failure to take confirmed quantities - Loc 24329 Stratton Ridge to Freeport LNG
SEV 4/5
Operational AlertUntil Further Notice
Gulf South Pipeline has issued a critical Over-Under Performance notice (Notice 5038516) for Location SLN 24329 - Stratton Ridge (to Freeport LNG) in Area 25, effective 08/03/2026 at 3:20 PM CDT. Freeport LNG is failing to take confirmed quantities at this delivery point, and Gulf South is reducing confirmations for remaining nomination cycles for Gas Day 8/3/2026 and until further notice. No specific volume curtailment is stated, but the open-ended 'until further notice' language signals this is an ongoing, unresolved operational issue at the Freeport LNG feed gas lateral.
Freeport LNG feed gas curtailment via Gulf South Stratton Ridge lateral is active until further notice -- gas stays in the domestic market, applying bearish pressure to Henry Hub and Gulf Coast cash basis with no stated restoration timeline.
Reroute: None: this lateral explicitly serves Freeport LNG; if Freeport LNG is not taking gas, no alternative delivery destination replaces LNG export demand, and the curtailed volumes remain in the domestic supply pool.
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Transco
Update - Market and Production Constraints
SEV 4/5
Capacity ConstraintUntil Further Notice1 Days
Transco has posted a critical market and production constraints notice effective August 4, 2026, showing widespread capacity restrictions across multiple zones from the Gulf Coast to the Northeast. Key constraints include SELA laterals (Zone 3) at 0 MDt/d for both directions, SWLA Lat at 40 MDt/d NSRP only, Mainline Milltown (Zone 6) at 0 NSRP, NY Bay Lateral at 0 Secondary, Central Penn South at 0 Secondary, and multiple Zone 5 segment TSBs at 0-200 MDt/d NSRP, indicating severe northbound flow restrictions from the Southeast through the Mid-Atlantic. No end date is specified, suggesting conditions are operationally driven on a daily basis with no defined restoration timeline.
Widespread Transco constraint notice with zero available capacity at multiple key Zone 3, 5, and 6 TSBs signals significant northbound flow restrictions; expect bullish pressure at Transco Zone 4, Zone 5, and Zone 6 basis points versus Henry Hub, with particular tightness in Mid-Atlantic and Northeast delivery markets on August 4.
Reroute: Limited: Southern Natural Gas (SNG/EGT) provides partial alternative for Southeast segment volumes, and Tennessee Gas Pipeline serves overlapping Northeast markets, but Transco's dominant capacity share in the Southeast-to-Northeast corridor means partial reroute at best; Zone 6 Mid-Atlantic and Northeast volumes have minimal viable alternatives.
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Mountain Valley Pipeline
Harris Compressor Station Maintenance 11-12-25 Complete
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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ANR Pipeline (TC Energy)
UPDATED.CAPACITY REDUCTION Michigan Leg North – Bridgman Northbound
SEV 3/5
Maintenance0.679 Bcf/dUntil Further Notice35 Days
ANR Pipeline has updated the dates for planned maintenance at Hamilton Compressor Station in Allegan County, Michigan, shifting the window from 8/11-9/18 to 8/18-9/21. Northbound capacity at Bridgman (LOC #FPBRGMNB) will be reduced by 0.679 Bcf/d, leaving 0.943 Bcf/d available. ANR anticipates potential Firm Primary, Firm Secondary, and Interruptible curtailments, with firm primary impact estimated at 0% based on current nominations but up to 35% based on contracted MDQ.
ANR planned maintenance removes 0.679 Bcf/d of northbound Michigan capacity for 35 days; watch for tightening Michigan/Midwest basis and potential Firm Primary curtailments if nominations rise toward contracted MDQ.
Reroute: Moderate: TETCO, TGT, and PEPL serve overlapping Gulf Coast-to-Midwest corridors, though Michigan-specific northbound deliveries on this ANR leg have limited direct bypass options.
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ANR Pipeline (TC Energy)
UPDATED: CAPACITY REDUCTION Michigan Leg North – Rabbit River MS
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Maritimes & Northeast Canada
08/07/2026- MNCA Operational Flow Order -- EFF 8/8
SEV 3/5
Operational AlertUntil Further Notice90 Days
Maritimes & Northeast Pipeline Canada (MNCA) has issued an Operational Flow Order effective August 8, 2026 and running until further notice (posted end date November 5, 2026). The OFO is system-wide and imposes a 12%/500 tolerance on imbalances due to the pipe, restricting shipper flexibility to leave gas in the system. No specific capacity volume is stated, but the OFO signals tightening system balance on the Canadian Maritimes corridor feeding New England.
MNCA OFO effective 8/8 tightens Canadian Maritimes supply discipline into New England; expect modest bullish pressure at Algonquin Citygate and Tennessee Zone 6 as shipper imbalance tolerance is cut and any supply shortfall has no available reroute.
Reroute: Limited: Algonquin Gas Transmission provides partial alternative for some New England deliveries but cannot replace Canadian Maritimes supply volumes; no direct bypass of MNCA exists for its core receipt points.
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Maritimes & Northeast U.S.
08/07/2026- MNUS Customer Specific Operational Flow Order -- EFF 8/7
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 Notice1 Days
Transco posted a daily market and production constraints update effective August 7, 2026, showing multiple zero-capacity TSB locations across Zones 2 through 6. Most notable are zero available capacity readings at SELA N-to-S and S-to-N MP 85.93/85.94 (Zone 3), NY Bay Lateral MP 35.00 (Zone 6), Central Penn South N-to-S (Zone 6), Mainline Milltown MP 1790.85 (Zone 6), and Rivervale Lat North NJ Extension (Zone 6), alongside heavily restricted Zone 5 segment TSBs capped at 0-200 Mdt/d. HBLV secondary swing availability is zero across Zones 2 through 6, indicating system-wide swing service exhaustion from Louisiana through the Northeast.
Multiple zero-capacity TSBs on Transco spanning Zones 3 through 6 with zero HBLV swing in Zones 2-6 signal meaningful northbound and southbound flow restrictions; watch for widening basis at Transco Zone 5 and Zone 6 versus Henry Hub, with potential bearish pressure in Southeast Zone 3-4 if southbound receipts are backed up.
Reroute: Limited: Tennessee Gas Pipeline (TGP) provides the primary competing route for Gulf Coast-to-Northeast flows and may absorb some diverted volumes, but simultaneous system stress on Transco of this breadth across multiple zones limits the degree to which TGP or SNG can fully offset; Zone 6 Mid-Atlantic and Northeast deliveries have particularly constrained alternatives.
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 has declared a Same Day Underage Alert for the Phoenix Area on August 5, 2026, due to high line pack conditions. Shippers with actual deliveries below scheduled quantities at Phoenix Area delivery points are subject to Alert Day imbalance charges under Section 22.4 of Transwestern's FERC Gas Tariff. The condition is expected to persist through the full gas day with updates to follow.
High line pack on Transwestern's Phoenix Area segment signals excess westbound supply relative to demand, putting bearish pressure on Arizona and SoCal Border basis; shippers holding long Phoenix area positions face financial exposure via Alert Day charges if they cannot bring takes up to scheduled quantities.
Reroute: Moderate: EPNG serves overlapping Arizona and SoCal Border delivery markets and can absorb some volumes, though the high line pack condition suggests demand-side weakness rather than a supply constraint requiring reroute.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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East Tennessee Natural Gas
08/04/2026- Wartburg to Topside 3100-1 Unplanned Outage
SEV 3/5
Capacity Constraint91 Days
East Tennessee Natural Gas has declared an unplanned outage on its 3100-1 Line Valve Section 1 between Wartburg Compressor Station and Topside, caused by third-party activity. Effective immediately, ETNG is lowering line pressure on the affected segment until remediation is complete, with one meter (MR 59337 - Ariana Energy Morgan Co. 9) taken out of service. ETNG states it does not anticipate nomination reductions through Wartburg at this time, but the notice end date extends through November 2, 2026, suggesting an extended remediation window.
Unplanned third-party damage on ETNG 3100-1 reduces operating pressure on the Wartburg-Topside segment through early November 2026; no stated volume loss but pressure reduction affecting downstream meters warrants monitoring for escalation to nomination curtailments, with bullish implications for local Southeast Appalachian basis if nominations are later impacted.
Reroute: Moderate: Transco and Columbia Gas Transmission (TCO) serve overlapping Southeast and Appalachian markets, though East Tennessee serves specific local distribution points in Tennessee with limited bypass for directly affected meters on this segment.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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ANR Pipeline (TC Energy)
UPDATED.CAPACITY REDUCTION Michigan Leg North – Bridgman Northbound
SEV 3/5
Maintenance0.679 Bcf/dUntil Further Notice38 Days
ANR has updated the scheduled maintenance window at Hamilton Compressor Station in Allegan County, Michigan, shifting the dates from August 6 - September 14 to August 11 - September 18, 2026. The Bridgman Northbound location (LOC #FPBRGMNB) will be restricted to 943 MMcf/d, a reduction of 0.679 Bcf/d. ANR explicitly anticipates potential Firm Primary, Firm Secondary, and Interruptible curtailments, with up to 35% of contracted MDQ at risk for firm primary shippers based on contracted volumes.
ANR planned maintenance removes 0.679 Bcf/d of northbound capacity at Bridgman through September 18; with firm primary curtailments possible at 35% of MDQ, expect mild bullish pressure on Michigan/Midwest delivered basis and watch PEPL and TGT as alternative Midwest supply routes.
Reroute: Moderate: TETCO, PEPL, and TGT serve overlapping Gulf Coast-to-Midwest corridors and can absorb some displaced volumes, though a 0.679 Bcf/d northbound restriction on a major Midwest artery may strain available alternatives during late-summer shoulder demand.
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Texas Eastern Transmission (TETCO)
08/04/2026- TE Pipeline Conditions for 8/4/2026 -- INTRADAY (Updated Systemwide Note)
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 Notice1 Days
Transco has posted its daily market and production constraint update effective August 4, 2026, superseding prior notice 17089214. Multiple system TSB locations show zero or near-zero available capacity, including SELA N-to-S and S-to-N at MP 85.93/94 (Zone 3, both directions at 0), Central Penn South N-to-S (Zone 6, 0 secondary), NY Bay Lateral MP 35.00 (Zone 6, 0 secondary), Mainline Milltown MP 1790.85 (Zone 6, 0 NSRP), and the SWLA Lat N-to-S (Zone 2, 40 MDt/d NSRP remaining). Several Zone 5 segment TSBs (MP 1412.98 to 1674.56) are at 0 NSRP northbound, and HBLV swing service is exhausted in Zones 2 through 6 with only 1 MDt/d remaining in Zone 1. The Vinton FGT Meter 4381 (Zone 2 delivery) is at 0, indicating no available capacity at that key FGT interconnect.
Transco daily constraint posting shows zero HBLV swing in Zones 2-6 and multiple zero-capacity TSBs on northbound Zone 5-6 segments and Southeast laterals, signaling tightness along the full mainline corridor from Gulf Coast through Mid-Atlantic with particular basis widening risk at Transco Zone 5/Zone 6 and the Algonquin Citygate interconnect (135 MDt/d non-traditional remaining).
Reroute: Limited: Southern Natural Gas (EGT) provides partial Southeast alternative for Gulf Coast-origin volumes, and Tennessee Gas Pipeline competes for Mid-Atlantic and Northeast deliveries, but neither can fully replace Transco mainline capacity at the volumes indicated; Zone 5-6 northbound NSRP at zero with no swing backup leaves Mid-Atlantic and Northeast shippers with minimal flexibility.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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CPL
Cove Point Restrictions
SEV 2/5
Informational
This is Revision 2 of CPL-1010310, a Critical/Capacity Constraint notice for Cove Point LNG restrictions originally posted 2026-06-29 and effective 2026-07-01. No escalation triggers are present in this revision: no force majeure declaration, no escalated curtailment language, no new locations, no worsened timeline, and no OFO or emergency protocols. The notice text contains no updated operational detail beyond the original filing. This is a stale revision with no new market information.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Limited: Cove Point LNG feed gas arrives via Transco Pleasant Valley and Columbia/EGTS Loudoun interconnects; alternative Appalachian supply paths exist but are irrelevant given no new curtailment is described in this revision.
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CPL
Cove Point System Alert
SEV 2/5
Informational
This is Revision 2 of CPL-1010320, a Cove Point LNG system alert originally posted on 2026-06-30 with an effective date of 2026-06-30T14:00. No escalation triggers are present in this revision: no force majeure declaration, no curtailment escalation to firm service, no new affected locations, no worsened restoration timeline, and no OFO or emergency protocol language. The notice is a stale re-filing of a nearly 50-day-old event with no new operational content. Live capacity data (gas day 2026-08-18, approximately one day behind today) shows COVE POINT PLANT delivering at 0.747 Bcf/d against 0.920 Bcf/d operating capacity (81.2% utilized, 18.8% headroom), consistent with normal LNG export operations and providing no corroboration of an active disruption.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Not applicable -- this revision contains no new operational constraint. In the event of an actual Cove Point LNG feedgas curtailment, the Appalachian receipt system (EGTS, Transco Pleasant Valley) has moderate alternative demand outlets, but there is no reroute for LNG export volumes themselves.
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CPL
Cove Point Restrictions Revision
SEV 2/5
Informational
This is Revision 2 of a Cove Point LNG capacity constraint notice originally posted July 19, 2026 -- one month before this revision date of August 19, 2026. The notice body contains no updated operational details, no new curtailment volumes, no revised restoration timeline, and no escalation triggers relative to the prior revision. The LNG feedgas floor (minimum severity 4) applies to original Cove Point notices, but the stale revision downgrade caps this at severity 2 because none of the Step 1 escalation triggers are present.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; live capacity data from 2026-08-18 (one day lag) shows Cove Point Plant delivery at 0.747 Bcf/d against 0.920 Bcf/d operating capacity (81.2% utilized, 0.173 Bcf/d headroom), consistent with a constrained but partially operating terminal, though this reading predates today's revision and may not reflect current conditions.
Reroute: Not applicable to a stale revision with no new operational content; underlying event affects Cove Point LNG feedgas with no pipeline reroute possible -- gas not taken by Cove Point remains in the domestic Appalachian/Mid-Atlantic market.
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CPL
Pleasant Valley Station Unit #1 Returned to Service
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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CPL
Cove Point Restrictions Termination
SEV 2/5
Informational
This is Revision 2 of a Cove Point LNG capacity constraint termination notice, effective 2026-08-06. The notice announces the end of a prior restriction at Cove Point LNG, restoring normal operations. No escalation triggers are present in this revision -- no new curtailments, no worsened timeline, and no new affected locations.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; the prior Cove Point restriction ended 2026-08-06 and live capacity data (2026-08-18, id2 cycle) shows COVE POINT PLANT operating at 81.2% utilization with 0.173 Bcf/d of headroom remaining, consistent with restored normal operations.
Reroute: Not applicable -- this is a termination/restoration notice; the prior constraint has ended and feed gas to Cove Point LNG is restored via Transco Pleasant Valley (0.600 Bcf/d scheduled, 71.8% utilized) and Columbia/EGTS Loudoun interconnects.
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CPL
Cove Point System Alert Termination
SEV 2/5
Informational
This is a Revision 2 notice terminating a prior Cove Point LNG system alert that was effective 2026-08-06. The notice signals that the operational alert condition has been resolved and normal operations have resumed at Cove Point LNG. No escalation triggers are present in this revision -- no force majeure, no firm curtailments, no worsened restoration timeline, and no new affected locations.
No new market impact -- situation resolved from prior revision, system alert terminated, market has already priced this constraint.
Reroute: Not applicable -- this is a termination/resolution notice. Cove Point LNG feed gas supply via EGTS, Transco Pleasant Valley, and Columbia Loudoun interconnects appears to have returned to normal operations per the alert termination.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Gulf South Pipeline
Failure to Take Confirmed Quantities at Location 9154
SEV 2/5
Operational Alert1 Days
Gulf South Pipeline has issued a Critical Over-Under Performance notice for Gas Day 8/7/2026 due to a customer's failure to take confirmed quantities at Location 9154, Sabine Fee #1 Well. Gulf South is implementing scheduling reductions for remaining nomination cycles on 8/7/2026 and until further notice based on projected daily quantities. No specific volume restriction is stated and the event appears limited to a single well receipt point.
Single-well receipt point under-performance on Gulf South with no stated volume impact -- localized nomination management issue with no discernible Henry Hub or regional basis signal.
Reroute: Not applicable -- this is a receipt-point under-performance at a single well; no reroute is relevant as the constraint is on production uptake, not pipeline transmission capacity.
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Northwest Pipeline
Pegram ESD & Pocatello M&ERP Tie-in ML - Maintenance Reminder
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Tennessee Gas Pipeline (TGP)
FORCEMAJEURE AT STA 542 EFF 8-4 RESOLVED
SEV 2/5
lifted ✓Restoration3 Days
Tennessee Gas Pipeline has resolved the Force Majeure declared on August 4, 2026 at Station 542 near DeKalb, Mississippi, where Unit 1 required emergency repairs. Full nominations will be scheduled up to capacity through STA 542 (Segment 539 BH) effective Intraday Cycle 1 on August 7, 2026. This is the final update on the event, which lasted approximately 3 days.
TGP STA 542 force majeure resolved -- full capacity restored through Segment 539 BH effective August 7 IC1, removing any Southeast supply tightness that had been associated with this 3-day outage; no new trading signal.
Reroute: N/A -- constraint resolved. During the outage, Transco (monitored) and SNG/EGT (monitored) would have provided partial Southeast alternatives, though TGP is one of two dominant Gulf Coast-to-Northeast pipelines.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Transco
UPDATE - Unplanned Maintenance St, James LIG Meter station (LOC 9002760)
SEV 2/5
Restoration
Transco has completed repairs at the St. James LIG Meter Station (LOC 9002760) in Louisiana. Effective intraday cycle 2 for gas day 08/06/2026, scheduling and physical flow at the bi-directional meter are restored to open status. This supersedes prior notice 17135953, which initiated the unplanned maintenance event.
Restoration of St. James LIG meter on Transco removes a localized Louisiana receipt-point constraint; no lasting basis impact expected given the intraday resolution and absence of a stated capacity volume.
Reroute: High: restoration notice -- reroute question is moot as the constraint has been resolved. During the outage, alternative Transco receipt points and interconnecting Gulf Coast pipelines (SNG/EGT, Gulf South, CGT) would have provided partial coverage.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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El Paso Natural Gas (EPNG)
[OPERATIONAL FLOW ORDER] SOC Lifted - Loc Specific Draft
UNSCORED
lifted ✓Informational
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El Paso Natural Gas (EPNG)
[FORCE MAJEURE] Force Majeure - Line No. 1204
SEV 1/5
Informational
Not scored -- last_updated is more than 24h old, treated as historical backlog rather than a live trading signal. No Claude API call was made for this notice.
Transco has posted an updated 2026 major construction and maintenance schedule, superseding prior notice 17115660. The update adds a new tab for Pipeline Inspection (ILI) activities. No specific capacity restrictions or curtailments are announced in this notice; individual maintenance events will be posted separately prior to commencement.
No immediate market impact -- this is a schedule update only; individual events affecting transportation availability will be posted as separate notices prior to each activity.
Reroute: Not applicable -- no capacity constraint is identified in this notice.
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Algonquin Gas Transmission
08/03/2026- AGT Pipeline Conditions for 8/4/2026
UNSCORED
Informational
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Columbia Gulf Transmission (CGT)
CAPACITY POSTING - TIM for August 7, 2026
UNSCORED
Informational
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El Paso Natural Gas (EPNG)
[OPERATIONAL FLOW ORDER] SOC Delcaration - Loc Specific Draft
UNSCORED
Informational
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El Paso Natural Gas (EPNG)
[MAINTENANCE] Updated August 2026 Maintenance
UNSCORED
Informational
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TransColorado Gas Transmission
[MAINTENANCE] Operations Planning Report V2 Aug 2026
UNSCORED
Informational
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Columbia Gas Transmission (TCO)
CAPACITY POSTING - TIM for August 6, 2026
UNSCORED
Informational
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El Paso Natural Gas (EPNG)
[MAINTENANCE] Updated August 2026 Maintenance
UNSCORED
Informational
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El Paso Natural Gas (EPNG)
[MAINTENANCE] Updated August 2026 Maintenance
UNSCORED
Informational
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Natural Gas Pipeline (NGPL)
[OPERATIONAL ALERT] SEG 14 - DEPUE LATERAL - PIPE INTEG
UNSCORED
Informational
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Algonquin Gas Transmission
08/02/2026- AGT Pipeline Conditions for 8/3/2026
UNSCORED
Informational
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Columbia Gulf Transmission (CGT)
CAPACITY POSTING - TIM for August 5, 2026
UNSCORED
Informational
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El Paso Natural Gas (EPNG)
[FORCE MAJEURE] Force Majeure - Seligman Station
UNSCORED
Informational
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El Paso Natural Gas (EPNG)
[MAINTENANCE] Updated August 2026 Maintenance
UNSCORED
Informational
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Algonquin Gas Transmission
08/01/2026- AGT Pipeline Conditions for 8/2/2026
UNSCORED
Informational
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El Paso Natural Gas (EPNG)
[CAPACITY CONSTRAINT] FGT VERM (LOC 7936) - PRIM ONLY LIFTED
SEV 1/5
lifted ✓Informational
Not scored -- last_updated is more than 24h old, treated as historical backlog rather than a live trading signal. No Claude API call was made for this notice.
Not scored -- notice too old to be actionable.
Reroute: Not assessed.
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El Paso Natural Gas (EPNG)
[MAINTENANCE] SEG 26-GC #3 ML-LIL TOOL RUNS-UPD2
SEV 1/5
Informational
Not scored -- last_updated is more than 24h old, treated as historical backlog rather than a live trading signal. No Claude API call was made for this notice.
Not scored -- notice too old to be actionable.
Reroute: Not assessed.
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El Paso Natural Gas (EPNG)
[MAINTENANCE] SEG 25 - UNIT MAINTENANCE - CS 302
SEV 1/5
Informational
Not scored -- last_updated is more than 24h old, treated as historical backlog rather than a live trading signal. No Claude API call was made for this notice.
Not scored -- notice too old to be actionable.
Reroute: Not assessed.
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El Paso Natural Gas (EPNG)
[OPERATIONAL ALERT] SEG 3/4 - M&M LINE - PIPE INTEG
SEV 1/5
Informational
Not scored -- last_updated is more than 24h old, treated as historical backlog rather than a live trading signal. No Claude API call was made for this notice.
Not scored -- notice too old to be actionable.
Reroute: Not assessed.
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El Paso Natural Gas (EPNG)
[MAINTENANCE] SEG 26-GC#3 ML-ILI TOOL RUNS-POSTPONE
UNSCORED
Informational
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El Paso Natural Gas (EPNG)
[OPERATIONAL ALERT] SEG 18 - THOMPSONVILLE LAT - PIPE INTEG
UNSCORED
Informational
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El Paso Natural Gas (EPNG)
[FORCE MAJEURE] FORCE MAJEURE-M&M LAT MLV2 TO MLV3-PT
UNSCORED
Informational
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El Paso Natural Gas (EPNG)
[MAINTENANCE] OUTAGE IMPACT REPORT 7-30-26
UNSCORED
Informational
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Columbia Gulf Transmission (CGT)
CAPACITY POSTING - TIM for August 4, 2026
UNSCORED
Informational
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Southern Star
River Rock – Ft Scott (Location # 16908) - Capacity Reduction
SEV 1/5
Informational
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Southern Star
Planned Service Outage - May 13th, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - May 13th, 2026
SEV 1/5
Informational
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Southern Star
TERMINATED: River Rock – Ft Scott (Location # 16908) - Capacity Reduction
SEV 1/5
Informational
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Southern Star
River Rock – Ft Scott (Location # 16908) - Capacity Reduction
SEV 1/5
Informational
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Southern Star
Planned Service Outage - May 15th, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - May 19th, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - May 19th, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - May 20th, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - May 22nd, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - May 26th, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - May 26th, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - May 26th, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - May 29th, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - June 4th, 2026
SEV 1/5
Informational
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Southern Star
CSI Connectivity Issues
SEV 1/5
Informational
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Southern Star
CSI Connectivity Issues
SEV 1/5
Informational
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Southern Star
Planned Service Outage - June 15th, 2026
SEV 1/5
Informational
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Southern Star
Operational Capacity Reduction - Line Segment 385
SEV 1/5
Informational
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Southern Star
Planned Service Outage - June 16th, 2026
SEV 1/5
Informational
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Southern Star
Operational Capacity Reduction - Line Segment 490
SEV 1/5
Informational
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Southern Star
Planned Service Outage - June 17th, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - June 18th, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - June 23rd, 2026
SEV 1/5
Informational
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Southern Star
Dilworth (Location # 16750) - Capacity Reduction
SEV 1/5
Informational
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Southern Star
Nomination Cycle Closing Evening 6/30/2026
SEV 1/5
Informational
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Southern Star
CSI Connectivity Issues
SEV 1/5
Informational
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Southern Star
Scheduling Cycle Closing
SEV 1/5
Informational
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Southern Star
CSI Connectivity Issues Resolved
SEV 1/5
lifted ✓Informational
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Southern Star
Scheduling Cycle Closing - Resolved
SEV 1/5
lifted ✓Informational
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Southern Star
Operational Capacity Reduction - Line Segment 490
SEV 1/5
Informational
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Southern Star
Planned Service Outage - July 9th, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - July 9th, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - July 13th, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - July 16th, 2026
SEV 1/5
Informational
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Southern Star
Planned Service Outage - July 23rd, 2026
SEV 1/5
Informational
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Southern Star
Operational Capacity Reduction - Line Segment 385
SEV 1/5
Informational
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Southern Star
Planned Service Outage - August 3rd, 2026
SEV 1/5
Informational
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Southern Star
Operational Capacity Reduction - Line Segment 490
SEV 1/5
Informational
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Southern Star
Operational Capacity Reduction - Line Segment 490
SEV 1/5
Informational
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Southern Star
Dilworth (Location # 16750) - Capacity Reduction
SEV 1/5
Informational
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Southern Star
Cheyenne Hub (17105) - Capacity Reduction
SEV 1/5
Informational
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Southern Star
Dilworth (Location # 16750) - Capacity Reduction
SEV 1/5
Informational
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Kern River Gas Transmission
Kern River - Line Pack Has Returned to Normal
SEV 1/5
Informational
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Kern River Gas Transmission
Kern River - Warning - Line Pack is Trending High
SEV 1/5
Informational
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Kern River Gas Transmission
Kern River - Warning - Line Pack is High
SEV 1/5
Informational
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Kern River Gas Transmission
Kern River - High Line Pack Condition Update
SEV 1/5
Informational
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Kern River Gas Transmission
Kern River - High Line Pack Condition Update
SEV 1/5
Informational
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Kern River Gas Transmission
Kern River - Line Pack Has Returned to Normal
SEV 1/5
Informational
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Kern River Gas Transmission
Kern River - Warning - Line Pack is Trending Low
SEV 1/5
Informational
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Kern River Gas Transmission
Kern River - Line Pack Has Returned to Normal
SEV 1/5
Informational
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Kern River Gas Transmission
Kern River - Warning - Line Pack is Trending High
SEV 1/5
Informational
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Kern River Gas Transmission
Kern River - Line Pack Has Returned to Normal
SEV 1/5
Informational
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Kern River Gas Transmission
Kern River - Warning - Line Pack is Trending High
SEV 1/5
Informational
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Kern River Gas Transmission
Kern River - Warning - Line Pack is High
SEV 1/5
Informational
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Kern River Gas Transmission
Kern River - Line Pack Has Returned to Normal
SEV 1/5
Informational
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Kern River Gas Transmission
Kern River - Warning - Line Pack is Trending Low
SEV 1/5
Informational
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Kern River Gas Transmission
Kern River - Warning - Line Pack is Low
SEV 1/5
Informational
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Northwest Pipeline
Kemmerer ESD & Baker ESD - Maintenance Reminder
SEV 1/5
Informational
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Northwest Pipeline
Caldwell Compressor Station Deficiency Period
SEV 1/5
Informational
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Northwest Pipeline
Highway 20/26 Expansion LL - Maintenance Complete
SEV 1/5
Informational
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Northwest Pipeline
Willard Compressor Station Deficiency Period
SEV 1/5
Informational
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Northwest Pipeline
Caldwell Unit 4 Repairs - Maintenance Reminder
SEV 1/5
Informational
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Northwest Pipeline
Muddy Creek ESD, Mosquito Lake, Soda Springs ESD, Mt. Vernon ESD, Pocatello M&ER
SEV 1/5
Informational
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Northwest Pipeline
Green River ESD & Solar Inspections - Maintenance Complete
SEV 1/5
Informational
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Iroquois Gas Transmission
Operational Flow Order
SEV 1/5
Informational
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EGTS
Hastings Extraction Plant Return to Service
SEV 1/5
Informational
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Sabine Pass / Creole Trail
[CAPACITY CONSTRAINT] FGT VERM (LOC 7936) - PRIM ONLY LIFTED
SEV 1/5
lifted ✓Informational
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Sabine Pass / Creole Trail
[MAINTENANCE] SEG 26-GC #3 ML-LIL TOOL RUNS-UPD2
SEV 1/5
Informational
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Sabine Pass / Creole Trail
[MAINTENANCE] SEG 25 - UNIT MAINTENANCE - CS 302
SEV 1/5
Informational
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Sabine Pass / Creole Trail
[OPERATIONAL ALERT] SEG 3/4 - M&M LINE - PIPE INTEG
SEV 1/5
Informational
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Sabine Pass / Creole Trail
[MAINTENANCE] SEG 26-GC#3 ML-ILI TOOL RUNS-POSTPONE
SEV 1/5
Informational
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Sabine Pass / Creole Trail
[OPERATIONAL ALERT] SEG 18 - THOMPSONVILLE LAT - PIPE INTEG
SEV 1/5
Informational
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Sabine Pass / Creole Trail
[FORCE MAJEURE] FORCE MAJEURE-M&M LAT MLV2 TO MLV3-PT
