[OPERATIONAL ALERT] BERTRAND COMPRESSOR STATION OPERATIONAL ISSUE - UPDATE #11
SEV 5/5
Compressor Issue1.103 Bcf/dUntil Further Notice
Rockies Express Pipeline has restricted capacity on Segment 250 (West-to-East direction) to 1,103 MDth/d (1.103 Bcf/d) effective March 31, 2026, until further notice due to an ongoing operational issue at Bertrand Compressor Station. This is Update #11, indicating a prolonged unresolved outage. Primary firm, secondary firm, and interruptible service (ITS/AOR) are all at risk of not being scheduled, meaning even firm shippers face potential curtailments with no restoration timeline provided.
REX Segment 250 restriction to 1.103 Bcf/d with all service classes including primary firm at risk tightens Rockies-to-Midcontinent eastbound takeaway; expect bearish pressure at CIG and Opal as Rockies basin gas backs up, with bullish signals at Midcontinent and REX Zone 3 downstream delivery points -- Trailblazer is NOT an independent reroute as it shares Bertrand CS.
Reroute: None: Trailblazer Pipeline leases capacity at Bertrand Compressor Station on REX and is simultaneously constrained by the same facility failure -- these are not independent reroute options. No viable alternative exists for affected West-to-East REX volumes.
Tallgrass Energy
[Trailblazer Pipeline (TPC)] [OPERATIONAL ALERT] THIRD PARTY OPERATIONAL ISSUE - BERTRAND COMPRESSOR STATION - UPDATE #10
SEV 5/5
Compressor Issue0.813 Bcf/dUntil Further Notice
Trailblazer Pipeline Segment 20 is restricted to 0.813 Bcf/d effective March 30, 2026 gas day due to a third-party operational issue at Bertrand Compressor Station, and the restriction continues until further notice. Primary firm, secondary firm, and interruptible service are all at risk of curtailment. This is Update #10, indicating an ongoing, unresolved multi-day constraint with no restoration timeline.
Trailblazer Segment 20 restricted to 0.813 Bcf/d with primary and secondary firm at risk; because Trailblazer shares Bertrand CS with REX, both pipes are simultaneously constrained -- expect bearish pressure on Rockies/CIG basis as gas backs up in the basin, with bullish pressure at Midcontinent and Chicago Citygate as eastbound takeaway remains curtailed until further notice.
Reroute: None: REX and Trailblazer share Bertrand Compressor Station -- both are simultaneously constrained by the same third-party facility, eliminating any independent reroute option for eastbound Rockies volumes.
Rockies Express
[OPERATIONAL ALERT] BERTRAND COMPRESSOR STATION OPERATIONAL ISSUE - UPDATE #10
SEV 5/5
Compressor Issue1.174 Bcf/dUntil Further Notice
Bertrand Compressor Station on REX Segment 250 remains operationally impaired, restricting eastbound capacity to 1.174 Bcf/d until further notice. Primary firm, secondary firm, and interruptible service are all at risk of not being scheduled -- a rare and serious escalation beyond interruptible-only curtailments. No restoration timeline has been provided.
REX Segment 250 eastbound restriction to 1.174 Bcf/d with primary firm service at risk signals severe Rockies takeaway constraint; expect bearish pressure at CIG/Cheyenne Hub as Rockies gas backs up, with bullish pressure at Midcontinent and Chicago Citygate as eastbound supply is reduced.
Reroute: None: Trailblazer Pipeline leases capacity at Bertrand Compressor Station on REX -- both pipes are simultaneously constrained by the same facility failure. No independent reroute exists for eastbound Rockies volumes.
Tallgrass Energy
[Trailblazer Pipeline (TPC)] [FORCE MAJEURE] THIRD PARTY FORCE MAJEURE - JULESBURG COMPRESSOR STATION
SEV 5/5
Force Majeure0.722 Bcf/dUntil Further Notice
A third-party force majeure at REX's Julesburg Compressor Station, effective Gas Day March 2, 2026, has reduced Trailblazer Segment 20 operating capacity to 722 MDth/d (0.722 Bcf/d) until further notice. Primary firm, secondary firm, and AOR/ITS service are all at risk of curtailment. This is Revision 3 and the force majeure remains active with no restoration timeline.
Active force majeure at the shared Julesburg/Bertrand CS facility constrains both REX and Trailblazer simultaneously to 0.722 Bcf/d on Segment 20 with no restoration timeline; expect bearish pressure on Rockies CIG/Cheyenne Hub basis as eastbound Rockies takeaway is severely curtailed with zero reroute alternative.
Reroute: None: REX and Trailblazer share the Julesburg/Bertrand Compressor Station -- this force majeure is at the shared facility, meaning both pipelines are constrained simultaneously. No independent reroute exists for Rockies eastbound volumes.
Rockies Express
[FORCE MAJEURE] JULESBURG COMPRESSOR STATION FORCE MAJEURE
SEV 5/5
Force Majeure1.045 Bcf/dUntil Further Notice
REX declared force majeure at Julesburg Compressor Station effective Gas Day March 2, 2026, reducing operating capacity through Segment 240 (west-to-east direction) to 1.045 Bcf/d until further notice. This is Revision 3 and the force majeure remains active with no restoration timeline; primary firm, secondary firm, and interruptible service are all at risk of curtailment. The end date of 12/31/9000 confirms an open-ended outage with no known resolution.
Active REX FM at Julesburg CS caps westbound-to-eastbound throughput on Segment 240 at 1.045 Bcf/d until further notice, with firm service curtailments confirmed at risk; expect bullish pressure on Midcontinent and Chicago Citygate basis as Rockies/DJ Basin gas loses eastbound takeaway, and bearish pressure at CIG/Cheyenne Hub as supply backs up in the basin.
Reroute: Limited: Trailblazer Pipeline (TPC) is the primary alternative for Rockies eastbound gas, but Trailblazer leases capacity at Bertrand CS on REX -- if the Julesburg FM affects shared infrastructure, Trailblazer reroute reliability is uncertain. CIG provides some alternative egress but does not serve the same downstream Midcontinent/Chicago markets.
Tallgrass Energy
[Trailblazer Pipeline (TPC)] [OPERATIONAL ALERT] THIRD PARTY OPERATIONAL ISSUE - BERTRAND COMPRESSOR STATION - UPDATE #11
SEV 4/5
Compressor Issue0.764 Bcf/dUntil Further Notice
Trailblazer Pipeline Segment 20 is restricted to 0.764 Bcf/d effective March 31, 2026 ID2 cycle and continuing until further notice due to a third-party operational issue at Bertrand Compressor Station. This is Update #11, indicating a prolonged unresolved outage with no restoration timeline. Primary firm, secondary firm, and interruptible service are all at risk of curtailment.
Bertrand CS restriction caps Trailblazer Segment 20 at 0.764 Bcf/d with firm service at risk; because REX also shares Bertrand CS, reroute is effectively unavailable, placing bearish pressure on Rockies basin basis (CIG/Cheyenne) with no meaningful eastbound relief valve until Bertrand is restored.
Reroute: None: Trailblazer and REX share Bertrand Compressor Station -- both are simultaneously constrained by the same third-party facility, making REX a non-viable reroute option for affected Trailblazer volumes.
Algonquin Gas Transmission
03/18/2026- AGT Hourly Customer Specific Operational Flow Order
SEV 4/5
Operational AlertUntil Further Notice
Algonquin Gas Transmission has issued a system-wide Hourly Customer Specific Operational Flow Order (OFO) effective March 18, 2026, and continuing until further notice (notice end date listed as June 16, 2026). The OFO imposes a No Deficiency Point constraint of 25%/250 on an hourly basis for all customers system-wide, indicating active system stress requiring shippers to maintain balanced or surplus positions on an intra-day basis. No specific capacity volume is stated, but the 'until further notice' language and system-wide scope signal an unresolved operational constraint.
Algonquin system-wide Hourly OFO active from March 18 with no firm restoration date -- expect significant bullish pressure at Algonquin Citygate and broader New England basis as shippers scramble to comply with hourly balancing requirements, with heightened spike risk given no reroute alternative exists for core New England deliveries.
Reroute: Limited to none: Algonquin and Iroquois are the two primary pipelines serving New England; Iroquois is not reported constrained at this time but cannot absorb full Algonquin system shortfall. No meaningful reroute exists for the core New England LDC market.
Northern Border Pipeline (NBPL)
Northern Border Low Inventory OFO
SEV 4/5
Operational AlertUntil Further Notice
Northern Border Pipeline has issued an active OFO effective immediately and until further notice due to low system inventory and linepack concerns driven by sustained cold weather. Shippers are required to stay within 5% or 25,000 Dth/day of posted nominations, with NBPL reserving the right to impose prorated meter capacity restrictions. The OFO was originally posted January 20, 2026 and this revision (Rev 3) confirms the OFO remains in effect through at least January 30, 2026.
Active NBPL OFO with no-notice curtailment authority and an 'until further notice' posture tightens Canadian gas flows into the Chicago/Midwest corridor, supporting bullish basis pressure at Chicago Citygate and NGPL Midcontinent vs Henry Hub.
Reroute: Limited: Alliance Pipeline provides an alternative Canadian border crossing into Chicago, but Alliance volumes are typically fully subscribed, especially during cold weather events, limiting meaningful displacement of constrained NBPL capacity.
Northern Border Pipeline (NBPL)
UPDATE: OFO - Under Performance, Effective ID1 Gas Day January 21
SEV 4/5
Operational Alert0.740 Bcf/dUntil Further Notice
NBPL has issued a Revision 3 OFO for under-performance, active since January 21, 2026 and continuing until further notice. Receipt capacity at Stateline is capped at 100,000 MMBtu/d and Spring Creek at 640,000 MMBtu/d, combining for approximately 0.740 Bcf/d of constrained Canadian border receipt capacity. This revision escalates prior capacity limits (Stateline was 50,000 and Spring Creek was 600,000 in the Timely cycle) and the OFO remains active with no restoration timeline, indicating ongoing supply under-delivery from the Canadian side.
Active NBPL OFO with 0.740 Bcf/d of combined border receipt capacity constrained until further notice tightens Canadian gas imports into the Midwest; expect bullish pressure at Chicago Citygate and NGPL Midcontinent basis versus Henry Hub with no defined restoration date amplifying the signal.
Reroute: Limited: Alliance Pipeline provides an alternative Canadian import corridor into Chicago but is typically fully subscribed; partial mitigation is possible but NBPL volumes cannot be fully replaced, leaving Midwest markets structurally short on Canadian supply.
El Paso (EPNG)
[FORCE MAJEURE] Force Majeure – Casa Grande C Station
SEV 4/5
Force MajeureUntil Further Notice1 Days
EPNG has declared force majeure at Casa Grande C Compressor Station, effective 03/17/2026 at 11:41 AM with an expected restoration by 03/18/2026 at 9:00 AM. Casa Grande is located in Arizona on EPNG's westbound mainline, meaning this constraint affects gas movement from the Permian/Waha origin area toward SoCal Border and Arizona delivery points. No specific capacity volume was stated in the notice. Duration is approximately one day.
EPNG force majeure at Casa Grande C Station restricts westbound flow on the Permian-to-SoCal/Arizona corridor; expect bearish pressure at Waha as basin gas backs up and bullish pressure at SoCal Border and Arizona delivery points for the next ~22 hours.
Reroute: Moderate: Transwestern Pipeline (TW) is the primary competing westbound pipeline serving SoCal Border and Arizona markets and may absorb some displaced volumes, though available spare capacity on TW will determine how fully the constraint can be offset.
Energy Transfer
[Gulf Run Transmission] [Force Maj] CGT GR FMJ
SEV 4/5
Force MajeureUntil Further Notice
Gulf Run Transmission has declared a Force Majeure at the CGT GR Meter Station (#13548) in Richland Parish, Louisiana (Zone 1), effective January 28, 2026. Nominations at this interconnect have been reduced to EPSQ (Equivalent Prior Scheduling Quantity) with no restoration timeline provided. The event is open-ended ('until further notice') and affects a key interconnect between Gulf Run and Columbia Gulf Transmission, a primary Haynesville-to-Gulf Coast backhaul route.
Gulf Run force majeure on the CGT GR interconnect removes an indeterminate volume of Haynesville supply from the Columbia Gulf Transmission corridor with no restoration timeline; expect modest bullish pressure at Henry Hub and Transco Zone 4 until flow restoration is confirmed.
Reroute: Moderate: Gulf South Pipeline and Kinder Morgan assets serve overlapping Haynesville Basin corridors and may absorb some displaced volumes, but the specific CGT interconnect serves a unique routing path and full reroute is uncertain without knowing the affected volume.
Energy Transfer
[Gulf Run Transmission] [Force Maj] CGT GR FMJ Update
SEV 4/5
Force Majeure0.200 Bcf/dUntil Further Notice62 Days
Gulf Run Transmission declared force majeure at the CGT GR meter station (#13548) in Richland Parish, Louisiana (Zone 1), effective January 29, 2026. Nominations at this interconnect are restricted to 200,000 MMBtu/day (0.200 Bcf/d), superseding the prior total shutdown under Notice #60993. The restriction runs through April 1, 2026, approximately 62 days, though the pipeline retains 'until further notice' language for updates.
Gulf Run FM at CGT GR limits Zone 1 throughput to 0.200 Bcf/d, curtailing Haynesville-origin gas moving toward Columbia Gulf Transmission and downstream Southeast/LNG markets; expect bearish Henry Hub and Haynesville basis pressure as supply backs up, with modest bullish signal at Transco Zone 4 and CGT downstream delivery points.
Reroute: Moderate: Gulf South and Kinder Morgan assets serve overlapping Haynesville corridors and could absorb some diverted volumes, but CGT GR is a key interconnect for moving Gulf Run Zone 1 gas into the Columbia Gulf northbound system; full offset is unlikely given the scale of the restriction.
Energy Transfer
[Gulf Run Transmission] [Force Maj] CGT GR FMJ Update #2
SEV 4/5
Force Majeure0.520 Bcf/dUntil Further Notice
Gulf Run Transmission declared force majeure at its CGT GR meter station (#13548) in Richland Parish, Louisiana (Zone 1), initially cutting nominations to zero, then to 200,000 MMBtu/d, and as of January 29 partially restoring to a cap of 520,000 MMBtu/d effective January 30. The end date is listed as April 1, 2026, but the notice states it remains in effect until further notice. This interconnect is a key Haynesville production outlet into Columbia Gulf Transmission, and the restriction limits approximately 0.52 Bcf/d of northbound Gulf Coast flow capacity.
Gulf Run FM caps CGT GR nominations at 0.52 Bcf/d with no firm restoration timeline, tightening Haynesville takeaway and supporting Henry Hub and Transco Zone 4 basis as supply that would otherwise flow north via CGT is constrained.
Reroute: Moderate: Gulf South and other Kinder Morgan Haynesville-area assets serve overlapping corridors, but Gulf Run is a dedicated high-capacity Haynesville egress pipe and partial reroute may not fully absorb the constrained volumes at CGT GR.
Energy Transfer
[Enable Mississippi River Transmission] [Force Maj] East Line FMJ
SEV 4/5
Force MajeureUntil Further Notice
Enable Mississippi River Transmission has declared force majeure on its East Line due to unplanned maintenance at STL Chain of Rocks (MP 100007) in St. Louis County, Missouri, effective January 21, 2026, with no restoration timeline given. Nominations at the STL Chain of Rocks delivery/receipt point will not be scheduled for the duration. MRT acknowledges firm service impacts are anticipated based on current nominations.
MRT force majeure on East Line removes a key Arkansas/Missouri delivery point with no restoration timeline and confirmed firm service impacts; expect tightening of MRT-served local distribution markets in AR/MO with limited reroute alternatives.
Reroute: Limited: MRT serves specific local markets in Arkansas and Missouri with few pipeline alternatives; ANR and Gulf South provide some overlapping supply paths but cannot fully replace MRT East Line deliveries into St. Louis County-area points.
Tallgrass Energy
[Trailblazer Pipeline (TPC)] [OPERATIONAL ALERT] THIRD PARTY OPERATIONAL ISSUE - BERTRAND COMPRESSOR STATION - UPDATE #7
SEV 4/5
Operational Alert0.810 Bcf/dUntil Further Notice
Trailblazer Pipeline Segment 20 capacity is restricted to 0.810 Bcf/d effective January 1, 2026 and until further notice due to a third-party operational issue at Bertrand Compressor Station. This is Update #7 (Revision 3), indicating the constraint has been ongoing since at least late December 2025 with no restoration timeline. Primary firm, secondary firm, and interruptible service quantities are all explicitly at risk of not being scheduled.
Escalation trigger present: firm service curtailment risk explicitly stated and 'until further notice' timeline active -- Trailblazer restricted to 0.810 Bcf/d at Bertrand CS tightens Rockies eastbound takeaway; expect bearish pressure at CIG/Cheyenne Hub as basin gas backs up, with REX simultaneously constrained at the shared Bertrand CS facility eliminating any independent reroute.
Reroute: None: REX and Trailblazer share Bertrand Compressor Station -- both pipelines are simultaneously constrained by the same third-party facility, meaning REX cannot serve as an independent reroute for Trailblazer volumes affected at this location.
Tallgrass Energy
[Trailblazer Pipeline (TPC)] [OPERATIONAL ALERT] THIRD PARTY OPERATIONAL ISSUE - CHEYENNE COMPRESSOR STATION
SEV 4/5
Compressor Issue0.674 Bcf/dUntil Further Notice
On January 20, 2026, REX experienced an operational issue at its Cheyenne Compressor Station, which directly impacts Trailblazer Pipeline's leased capacity on Segment 10. Effective January 20-21, 2026 and until further notice, Segment 10 operating capacity is reduced to 0.674 Bcf/d ratable. Primary firm, secondary firm, and interruptible service are all at risk of not being scheduled.
Trailblazer Segment 10 constrained to 0.674 Bcf/d until further notice with primary and secondary firm service at risk; expect bearish pressure on Rockies basis (CIG/Cheyenne Hub) as eastbound takeaway is curtailed, with limited Midcontinent supply relief downstream.
Reroute: None: Trailblazer leases capacity at Cheyenne Compressor Station on REX -- the same facility causing this constraint. REX is simultaneously affected per notice ID 13346 on REX's EBB, meaning REX cannot serve as an independent reroute for affected Trailblazer volumes.
Tallgrass Energy
[Trailblazer Pipeline (TPC)] [OPERATIONAL ALERT] THIRD PARTY OPERATIONAL ISSUE - BERTRAND COMPRESSOR STATION - UPDATE #8
SEV 4/5
Capacity Constraint0.813 Bcf/dUntil Further Notice
Trailblazer Pipeline Segment 20 capacity remains restricted to 0.813 Bcf/d due to a third-party operational issue at Bertrand Compressor Station, effective February 3, 2026 and continuing until further notice. This is Update #8 (Revision 3), indicating an ongoing unresolved constraint with no restoration timeline. Primary firm, secondary firm, and interruptible service are all at risk of curtailment.
Trailblazer Segment 20 restricted to 0.813 Bcf/d with primary and secondary firm service at risk; because Trailblazer leases capacity at Bertrand CS on REX, this constraint simultaneously affects both pipelines -- expect bearish Rockies basin basis pressure at CIG/Cheyenne Hub with limited reroute relief.
Reroute: None: Trailblazer and REX share Bertrand Compressor Station -- a third-party issue at Bertrand simultaneously constrains both pipelines, eliminating independent reroute options for Rockies eastbound volumes.
Tallgrass Energy
[Trailblazer Pipeline (TPC)] [OPERATIONAL ALERT] THIRD PARTY OPERATIONAL ISSUE - BERTRAND COMPRESSOR STATION - UPDATE #9
SEV 4/5
Capacity Constraint0.820 Bcf/dUntil Further Notice
Trailblazer Pipeline Segment 20 remains restricted to 0.820 Bcf/d due to a third-party operational issue at Bertrand Compressor Station, effective gas day March 3, 2026, until further notice. This is Update #9 (Revision 3 of this notice), indicating the constraint has been ongoing for multiple days with no restoration timeline. Primary firm, secondary firm, and interruptible service are all at risk of not being scheduled.
Trailblazer Segment 20 restricted to 0.820 Bcf/d with primary and secondary firm at risk; Bertrand CS is a shared facility with REX Zone 1 -- both eastbound Rockies takeaway pipes are simultaneously constrained, with no reroute available and no restoration timeline, supporting bearish Rockies basis pressure.
Reroute: None: REX and Trailblazer share Bertrand Compressor Station -- both are simultaneously constrained by the same third-party facility, making independent reroute impossible for affected Rockies eastbound volumes.
Rockies Express
[OPERATIONAL ALERT] BERTRAND COMPRESSOR STATION OPERATIONAL ISSUE - UPDATE #7
SEV 4/5
Compressor Issue1.185 Bcf/dUntil Further Notice
Rockies Express Bertrand Compressor Station operational issue restricts Segment 250 West-to-East capacity to 1.185 Bcf/d until further notice, effective January 1, 2026. Primary firm, secondary firm, and interruptible service are all at risk of curtailment. This is Revision 3 of the notice but escalation triggers are present: capacity loss exceeds 500,000 MMBtu/day, firm service is explicitly at risk, and no restoration timeline exists.
REX Segment 250 restricted to 1.185 Bcf/d eastbound with primary and secondary firm at risk; expect bearish pressure at Rockies/CIG basis as gas backs up, with bullish pressure at Midcontinent and Chicago Citygate as eastbound Appalachian and Midcontinent supply tightens.
Reroute: None: Trailblazer Pipeline leases capacity at Bertrand Compressor Station on REX -- when REX Zone 1 is constrained at Bertrand, Trailblazer is simultaneously affected and cannot serve as an independent reroute option.
Rockies Express
[OPERATIONAL ALERT] CHEYENNE COMPRESSOR STATION OPERATIONAL ISSUE
SEV 4/5
Compressor Issue0.985 Bcf/dUntil Further Notice
REX experienced an operational issue at Cheyenne Compressor Station on January 20, 2026, reducing eastbound capacity on Segment 200 to 0.985 Bcf/d until further notice. This is Revision 3 of the notice, but the end date remains open-ended with primary firm, secondary firm, and ITS/AOR quantities all at risk of curtailment. No restoration timeline has been provided.
REX Segment 200 eastbound capacity capped at 0.985 Bcf/d with firm service at risk and no restoration timeline; expect bullish pressure on Midcontinent and Chicago Citygate basis as Rockies gas is unable to move east, with mild bearish pressure on Rockies/CIG hub as supply backs up in the basin.
Reroute: Limited: Trailblazer Pipeline serves the same Rockies-to-Midcontinent eastbound corridor, but Trailblazer leases capacity at Bertrand CS on REX -- simultaneous constraints at Cheyenne CS and Bertrand CS are correlated and cannot be treated as independent reroutes. CIG provides some partial alternative for DJ Basin volumes but cannot replace REX Segment 200 eastbound throughput at scale.
Rockies Express
[OPERATIONAL ALERT] BERTRAND COMPRESSOR STATION OPERATIONAL ISSUE - UPDATE #8
SEV 4/5
Compressor Issue1.181 Bcf/dUntil Further Notice
Bertrand Compressor Station on REX Segment 250 remains restricted to 1.181 Bcf/d westbound-to-eastbound (West to East direction), effective February 3, 2026 and continuing until further notice -- this is Update #8 with no restoration timeline. Primary firm, secondary firm, and interruptible service are all at risk of curtailment. The event originated February 2, 2026 and remains unresolved as of this revision.
REX Segment 250 restricted to 1.181 Bcf/d eastbound with firm curtailment risk; expect bullish pressure at Midcontinent and Chicago Citygate basis as Rockies/Appalachian eastbound volumes remain constrained, with no restoration timeline keeping the market signal elevated.
Reroute: None: Trailblazer Pipeline leases capacity at Bertrand Compressor Station on REX -- when REX Bertrand is constrained, Trailblazer is simultaneously affected, making these two pipelines correlated rather than independent reroute alternatives. No viable bypass exists for this corridor.
Rockies Express
[OPERATIONAL ALERT] BERTRAND COMPRESSOR STATION OPERATIONAL ISSUE - UPDATE #9
SEV 4/5
Compressor Issue1.187 Bcf/dUntil Further Notice
REX Bertrand Compressor Station remains operationally constrained as of Update #9, restricting Segment 250 westbound-to-eastbound capacity to 1.187 Bcf/d until further notice. Primary firm, secondary firm, and ITS/AOR service are all at risk of curtailment. No restoration timeline has been provided.
REX Segment 250 restricted to 1.187 Bcf/d with primary firm service at risk and no restoration date; expect bullish pressure at Midcontinent and Dawn Hub as Appalachian/Rockies eastbound takeaway remains constrained, with bearish pressure at Rockies origin points where gas cannot move east.
Reroute: None: Trailblazer Pipeline leases capacity at Bertrand CS on REX -- both pipes share this facility and are simultaneously constrained, eliminating any meaningful reroute for eastbound Rockies volumes.
Energy Transfer
[Enable Mississippi River Transmission] [Oper Alert] Warm Weather SPW
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
Energy Transfer
[Trunkline Gas Company] [Maint] Trunkline South Texas Maintenance Update #2
SEV 3/5
Maintenance77 Days
Trunkline Gas Company (TGC) is performing integrity work on its South Texas Modified Transmission System (STX System) between the Jalapeno interconnection (Jim Wells County) and Mainline Valve 16 (Bee County) from March 23 through June 8, 2026 -- a 77-day window. The segment is operating under reduced pressure and is effectively shut in for deliveries unless a delivery point in the segment can accept gas. Reservation Charge Crediting has been invoked, confirming firm service impact.
TGC South Texas segment effectively shut in through June 8, 2026; no specific capacity volume stated but firm service is curtailed on the STX segment, tightening Gulf Coast supply and modestly supporting Henry Hub and TETCO STX basis over the maintenance window.
Reroute: Moderate: Texas Eastern (TETCO), Southern Natural (EGT), and ANR serve overlapping Gulf Coast and northbound Midwest corridors, but specific South Texas delivery points on the STX segment have limited bypass options without interconnect access in the affected reach.
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
Columbia Gas Transmission (TCO)
Force Majeure: Emporia Compressor Station
SEV 3/5
Force MajeureUntil Further Notice
TCO has declared force majeure effective January 23, 2026 due to an unexpected mechanical failure at Emporia Compressor Station Unit 3 in Greensville County, Virginia. As of this third revision (last updated March 20, 2026), TCO states there is no anticipated commercial impact under current operating conditions, but the Emporia VA-34 interconnect (E13) may be restricted if pressures or nominations fluctuate. No restoration timeline has been provided and the force majeure remains active with no confirmed curtailments.
Force majeure remains active at TCO Emporia CS with no confirmed volume curtailments and no restoration date; monitor Transco Zone 4 and Dominion South basis for any tightening if E13 interconnect restrictions are triggered.
Reroute: Moderate: Texas Eastern (TETCO, monitored) and Equitrans serve overlapping Appalachian/Mid-Atlantic markets, providing partial reroute options if commercial restrictions materialize at the Emporia E13 interconnect.
El Paso (EPNG)
[CAPACITY CONSTRAINT] EPNG OPEN FOR CONFIRMATIONS ID2
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
Northern Border Pipeline (NBPL)
UPDATE: OFO - Under Performance, Effective ID2 Gas Day January 21
SEV 2/5
Informational0.855 Bcf/d
This is Revision 3 of an OFO under-performance notice originally issued January 21, 2026, now reposted on March 20, 2026. The current revision updates North Roosevelt receipt capacity to 115,000 Dth/d (from 100,000 Dth/d) while Stateline (100,000 Dth/d) and Spring Creek (640,000 Dth/d) remain unchanged, for a combined capped receipt capacity of approximately 855,000 Dth/d across the three locations. No new escalation triggers are present relative to the prior revision; the OFO and capacity caps remain in place with no restoration timeline.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint.
Reroute: Limited: Alliance Pipeline provides partial alternative Canadian gas import capacity into Chicago, but is typically fully subscribed; NBPL remains the dominant Western Canadian supply conduit into the U.S. Midwest and no fully offsetting reroute exists.
