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Pipeline Critical Notices

Every critical notice posted by the 192 monitored U.S. interstate pipelines, scored 1–5 by AI within minutes of posting. Today’s feed, the status of every system, and the full notice archive.

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Showing 15 of 30 notices · Sun Oct 25, 2026
Transwestern Pipeline

[Transwestern Pipeline] [Force Majeure] Force Majeure - Station 3 (Leupp, AZ.) - Compressor Station mechanical Failure - Gas Day 10/24/26 (Until Further Notice)

SEV 4/5
Force Majeure capped at 1.100 Bcf/d, cut unknown

Transwestern Pipeline declared force majeure at Station 3 (Leupp, AZ) due to a compressor station mechanical failure, effective Gas Day October 24, 2026 until further notice. The Mainline Thoreau West System capacity is restricted to approximately 1.1 Bcf/d with no stated restoration timeline. No pre-event baseline is available in the notice itself to quantify the net reduction, but the 1.1 Bcf/d ceiling on a major westbound segment represents a material capacity constraint on Permian/San Juan outbound flows toward SoCal and Arizona.

TW force majeure at Station 3 caps Mainline Thoreau West at 1.1 Bcf/d UFN; expect bearish pressure at Waha/Permian as westbound takeaway tightens, with bullish pressure at SoCal Border and Arizona delivery points -- EPNG is the only remaining major California-bound alternative.
Reroute: Moderate: EPNG serves the same SoCal border and Arizona markets and is the primary competing pipeline, but a simultaneous EPNG constraint would leave California with no reroute option. At current TW capacity restriction levels, some westbound reroute via EPNG is possible but may not fully offset the constrained volumes.
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Posted: 2026-10-23 16:36 UTC  |  Rev. 1  |  ID: TW-121481 Capacity: capped at 1.100 Bcf/d, cut unknown  |  Direction: Bullish
SEV 4/5
Force Majeure capped at 1.100 Bcf/d, cut unknown 9 Days

Transwestern Pipeline has declared a Force Majeure effective Gas Day October 24, 2026 due to a compressor station mechanical failure at Station 3 in Leupp, AZ. The Mainline Thoreau West System capacity is reduced to approximately 1.1 Bcf/d until further notice, with a currently stated end date of November 2, 2026. This is an unplanned event on a major westbound supply artery serving Arizona and California SoCal border markets.

Transwestern FM at Station 3 (Leupp, AZ) caps Thoreau West System at 1.1 Bcf/d; expect bullish pressure at SoCal Border and Arizona delivery points as westbound capacity is constrained, while Permian/Waha and San Juan basin points face bearish pressure from backed-up supply -- no pre-event baseline available to quantify the net reduction from the stated 1.1 Bcf/d ceiling, and EPNG is the only partial reroute for California markets.
Reroute: Moderate: EPNG serves overlapping SoCal border and Arizona markets and is the primary competing pipeline; however, if EPNG is simultaneously constrained, California supply reroute drops to none. TW and EPNG together represent the two dominant westbound arteries from the Permian and San Juan basins.
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Posted: 2026-10-23 15:46 UTC  |  Rev. 1  |  ID: TW-121479  |  Permalink Capacity: capped at 1.100 Bcf/d, cut unknown  |  Direction: Bullish
SEV 4/5
Operational Alert Until Further Notice 1 Days

Gulf South Pipeline has issued a second consecutive Over-Under Performance notice (new ID 5038899) for Loc 24329 Stratton Ridge to Freeport LNG, covering Gas Day 10/21/2026 and until further notice -- an exact reissuance of yesterday's notice (GSPL-5038892) shifted forward one gas day. The customer continues to fail to take confirmed quantities at the Stratton Ridge delivery point, and Gulf South will reduce scheduling for remaining nomination cycles based on Projected Daily Quantities. Pre-event scheduled flow at Loc 24329 was 1.43 Bcf/d median (range 1.02-1.46 Bcf/d over the prior seven days), against 1.78 Bcf/d operating capacity; no explicit new cap or volume cut is stated in this notice.

Freeport LNG feed gas curtailment at Stratton Ridge (Loc 24329) now extends a second consecutive gas day (10/21/2026 UFN); pre-event scheduled flow was ~1.43 Bcf/d median (1.02-1.46 range) vs 1.78 Bcf/d operating capacity, with displaced volumes remaining in the domestic Gulf Coast pool -- bearish Henry Hub regional proxy as long as the under-take persists.
Reroute: None: Stratton Ridge is the dedicated Gulf South delivery point feeding Freeport LNG; displaced feed gas volumes have no alternate export outlet and remain in the domestic market.
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Posted: 2026-10-21 16:05 UTC  |  Rev. 1  |  ID: GSPL-5038899  |  Permalink Direction: Bearish
What changed: same curtailment at Stratton Ridge (Loc 24329) extends to Gas Day 10/21/2026 under new notice ID; event continues UFN
SEV 4/5
Maintenance 0.100 Bcf/d cut (capped at 0.700 Bcf/d) 2 Days

CGT is conducting planned maintenance at Lake Arthur Compressor Station on October 27-28, 2026, which will reduce delivery capacity at Cameron LNG (loc 4246) from its design capacity of 0.800 Bcf/d to 0.700 Bcf/d (Primary Only), a reduction of 0.100 Bcf/d. CGT explicitly warns that this restriction may result in curtailments to Interruptible, Secondary Firm, and Primary Firm services. Live capacity data for Cameron LNG (loc 4246) shows the point currently running at 0.696 Bcf/d scheduled against 0.800 Bcf/d operating capacity, confirming the new 0.700 Bcf/d cap is effectively at or just above current flows but Primary Firm curtailment risk makes this actionable.

CGT maintenance cuts Cameron LNG feed gas delivery cap by 0.100 Bcf/d (0.800 to 0.700 Bcf/d) on Oct 27-28 with explicit Primary Firm curtailment risk; gas that cannot be exported stays domestic, bearish for Henry Hub and Gulf Coast basis over the two-day window.
Reroute: Limited: Cameron LNG feed gas can only arrive via pipelines serving that terminal; no alternative LNG export outlet exists for these specific curtailed volumes, so the gas remains in the domestic market.
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Posted: 2026-10-20 15:45 UTC  |  Rev. 1  |  ID: CGT-26320017  |  Permalink Capacity: 0.100 Bcf/d cut (capped at 0.700 Bcf/d)  |  Direction: Bearish
SEV 4/5
Operational Alert Until Further Notice 1 Days

Gulf South Pipeline issued a Critical Over-Under Performance notice on Gas Day 10/20/2026 for Loc 24329 (Stratton Ridge to Freeport LNG), citing a customer's failure to take confirmed quantities and triggering scheduling reductions for remaining nomination cycles through at least Gas Day 10/21/2026. This is a recurrence of the same event posted on 10/17/2026 (GSPL-5038889). The live evening-cycle reading at Loc 24329 shows 1.45 Bcf/d scheduled against 1.78 Bcf/d operating capacity (81.5% utilized, 18.5% headroom), compared to a pre-event 7-day median of 1.43 Bcf/d (range 1.11-1.46 Bcf/d); no explicit volume cut is stated, but scheduling reductions are anticipated and the UFN language keeps the event open-ended.

Gulf South curtailment at Stratton Ridge (Loc 24329) again reduces Freeport LNG feed gas on Gas Day 10/20/2026 -- pre-event baseline was 1.43 Bcf/d median (range 1.11-1.46), live evening cycle shows 1.45 Bcf/d scheduled vs 1.78 Bcf/d operating capacity with no explicit cut volume stated; displaced gas stays in the domestic Gulf Coast pool, bearish Gulf Coast/Henry Hub basis; this is a repeat occurrence from 10/17 and remains UFN.
Reroute: None: Freeport LNG feed gas delivered via this specific lateral cannot be rerouted to the terminal through an alternative path; any curtailed volume remains in the domestic pipeline system.
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Posted: 2026-10-20 15:30 UTC  |  Rev. 1  |  ID: GSPL-5038892  |  Permalink Direction: Bearish
What changed: fresh recurrence on Gas Day 10/20/2026 -- same Freeport LNG feed gas curtailment as 10/17 event, new gas day, still UFN
SEV 4/5
Force Majeure 0.205 Bcf/d cut (capped at 0.180 Bcf/d) Until Further Notice 25 Days

Southern Star has declared a force majeure at the Saginaw Compressor Station (Jasper County, MO) due to a mechanical failure of the Saginaw Turbine, reducing capacity by 180,000 Dth/d (0.180 Bcf/d) at Saginaw CS and 25,000 Dth/d (0.025 Bcf/d) at Empire Energy Center, totaling 0.205 Bcf/d. This update (superseding #11240) pushes the in-service date back to November 2, 2026, extending the outage that began ID2 cycle October 9. Live capacity data for Saginaw CS Area Deliveries (loc_id 444550) shows operating capacity at 0.180 Bcf/d with 0.143 Bcf/d scheduled, corroborating the reduced operating cap stated in the notice.

Southern Star force majeure at Saginaw CS removes 0.205 Bcf/d of Midcontinent/Missouri delivery capacity through Nov 2; timeline extension is bearish for update direction but the sustained capacity loss is bullish for Southern Star basis -- watch for tightening in Kansas/Missouri LDC markets with limited reroute via ANR, PEPL, or Southern Star alternatives.
Reroute: Moderate: ANR and Panhandle Eastern (PEPL) serve overlapping Midcontinent and Midwest corridors and may absorb some volumes, but Southern Star serves specific Kansas/Missouri local markets that have limited direct bypass options.
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Posted: 2026-10-19 16:10 UTC  |  Rev. 1  |  ID: ss-11248  |  Permalink Capacity: 0.205 Bcf/d cut (capped at 0.180 Bcf/d)  |  Direction: Bullish
What changed: in-service date pushed back to Nov 2 (was implied sooner); timeline extension worsens constraint duration
SEV 4/5
Operational Alert Until Further Notice 1 Days

Gulf South Pipeline issued a Critical Over-Under Performance notice for Gas Day 10/17/2026, citing the customer's failure to take confirmed quantities at Loc 24329 Stratton Ridge to Freeport LNG. Gulf South is implementing scheduling reductions for remaining nomination cycles on 10/17 and until further notice. Live capacity data shows Stratton Ridge (Loc 24329) running at 1.46 Bcf/d scheduled against 1.78 Bcf/d operating capacity (82.2% utilization, 0.317 Bcf/d headroom) as of the evening cycle; the pre-event baseline median was 1.43 Bcf/d over the prior seven gas days, so the posted evening reading is consistent with a partial reduction already in progress with no stated volume for the cut.

Gulf South curtailment at Stratton Ridge (Loc 24329) reduces Freeport LNG feed gas on Gas Day 10/17/2026 -- pre-event baseline was 1.43 Bcf/d (flat over the prior week), live evening cycle shows 1.46 Bcf/d scheduled against 1.78 Bcf/d operating capacity with no explicit cut volume stated; gas displaced from LNG export remains in the domestic Gulf Coast market, bearish for Henry Hub-area pricing.
Reroute: None: this notice directly curtails feed gas deliveries to Freeport LNG at the terminal delivery meter; there is no alternative pipeline pathway that replaces LNG offtake once the customer fails to take at the terminal.
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Posted: 2026-10-17 18:46 UTC  |  Rev. 1  |  ID: GSPL-5038889  |  Permalink Direction: Bearish
What changed: initial posting for Gas Day 10/17/2026 -- separate recurrence of same curtailment pattern at Stratton Ridge (Loc 24329) to Freeport LNG
SEV 4/5
Force Majeure 0.395 Bcf/d cut (capped at 0.930 Bcf/d) Until Further Notice 29 Days

ANR Pipeline has extended its Force Majeure at St. John Eastbound (LOC #FPSTJNEB) on the Michigan Leg South through October 31, 2026, pushed back from the prior end date of October 19. The FM was originally declared on October 3 due to an anomaly between MLV 56 and MLV 57, reducing eastbound capacity by 395 MMcf/d (0.395 Bcf/d), leaving 930 MMcf/d available. Firm Primary curtailments of approximately 34% of contracted MDQ remain in effect, with RCC eligibility active under ANR Tariff Section 6.36.

ANR FM at St. John Eastbound removes 0.395 Bcf/d of Michigan Leg South eastbound capacity through Oct 31 (extended from Oct 19); live data shows 0.977 Bcf/d operating capacity with 0.642 Bcf/d scheduled on TD1 against the 0.930 Bcf/d post-FM ceiling, consistent with the stated constraint, and pre-event flow averaged ~0.67 Bcf/d (0.60-0.77 range) on TD1 -- the 0.930 Bcf/d cap sits above recent scheduled flow but well below normal operating capacity, with firm primary shippers taking a ~34% MDQ curtailment signaling real tightness at ANR ML 7 Michigan delivery points.
Reroute: Limited: TETCO, TGT, and PEPL serve overlapping Midwest/Michigan markets but ANR Michigan Leg South is a specific geographic corridor; partial reroute may be possible via TETCO or PEPL for some Michigan deliveries but full offset is unlikely given the firm primary curtailment level.
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Posted: 2026-10-16 15:20 UTC  |  Rev. 1  |  ID: ANR-26320011  |  Permalink Capacity: 0.395 Bcf/d cut (capped at 0.930 Bcf/d)  |  Direction: Bullish
Columbia Gas Transmission (TCO)

UPDATE: Force Majeure – MXP Line

SEV 4/5
Force Majeure 1.900 Bcf/d Until Further Notice

TCO has issued a revision to its October 14, 2026 force majeure on MXP Line-100 in West Virginia, originally triggered by a detected leak near the Saunders Creek Regulator Station (a separate event from the September 24 force majeure on the same line). As of this update, MXPSEG remains at zero total capacity, with firm service impact estimated at 1.9 MMDth/day; TCO is estimating a return to service for Gas Day Saturday October 17, 2026, though the timeline is subject to change and Timely/Evening Cycle nominations for October 17 are likely to be impacted. The force majeure and capacity elimination remain fully in effect, and RCC eligibility requires 10 or more consecutive days of firm curtailment.

TCO force majeure on MXPSEG remains at zero total capacity with 1.9 Bcf/d of estimated firm service impact; targeted return is October 17 but is not guaranteed, keeping bearish pressure on Columbia Appalachia basis and mildly bearish pressure on Dominion South and TETCO M2 through at least the weekend gas days.
Reroute: Limited to moderate: TETCO (monitored) and Equitrans serve overlapping Appalachian markets, but TCO MXPSEG is very high capacity and 1.9 Bcf/d of stranded firm volumes cannot be fully absorbed by competing pipes without significant basis pressure at Columbia Appalachia pool.
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Posted: 2026-10-16 12:45 UTC  |  Rev. 2  |  ID: TCO-26316011  |  Permalink Capacity: 1.900 Bcf/d  |  Direction: Bullish
SEV 4/5
Maintenance 0.400 Bcf/d cut (capped at 1.530 Bcf/d) Until Further Notice 6 Days

CTPL 2026 Q4 maintenance summary (updated 10/15/26) bundles two jobs at Gillis Compressor Station. The highest-impact job is Job 2026115, a 6-day Station Upgrade (11/12-11/18/2026) that reduces available capacity to zero transport impact (0 Dths transport impact) with available capacity of 1,530,000 Dths and a TETCO (CT109413) meter capacity limit set to 0, effectively cutting one feed interconnect entirely. The lesser job, 2026114, is a 15-hour compressor maintenance event (11/17/2026) with a 400,000 Dth/day transport impact and 1,130,000 Dths available capacity.

Job 2026115 Station Upgrade at Gillis Compressor Station (11/12-11/18, 6 days) sets TETCO CT109413 meter limit to zero and posts zero transport impact Dths with 1.530 Bcf/d available capacity, reducing feedgas flexibility at Sabine Pass LNG and applying bearish pressure on Henry Hub as export throughput is constrained during the upgrade window.
Reroute: None: Sabine Pass LNG is the delivery endpoint; no alternative pipeline can substitute for LNG feedgas curtailed at the Gillis terminal interconnect during the station upgrade.
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Posted: 2026-10-15 13:45 UTC  |  Rev. 1  |  ID: 00002006  |  Permalink Capacity: 0.400 Bcf/d cut (capped at 1.530 Bcf/d)  |  Direction: Bearish
SEV 5/5
Force Majeure 1.900 Bcf/d Until Further Notice

TCO has declared a new Force Majeure effective Gas Day October 14, 2026, due to a detected leak near the Saunders Creek Regulator Station in West Virginia on MXP Line-100 -- explicitly separate from the September 24 FM (Notice 26276009). Effective the Evening Cycle of October 15 and until further notice, scheduled volumes through the MXPSEG MA42 internal constraint are reduced to zero total capacity, with estimated firm service impact of 1.9 MMDth/d (1.9 Bcf/d). Live capacity data at MXPSEG (loc_id MXPSEG, dir TD1:SGQ:FTS) already shows NON-FIRM-RESTRICTED with zero operating capacity posted against 1.85 Bcf/d scheduled as of the timely cycle on Oct 14, corroborating the constraint. TCO will provide an update by Friday morning October 16.

New TCO force majeure on MXP Line-100 eliminates 1.9 Bcf/d of Appalachian firm transport capacity to zero effective Oct 15 evening cycle (MXPSEG already NON-FIRM-RESTRICTED at 1.85 Bcf/d scheduled vs zero operating capacity in the Oct 14 timely cycle); expect significant bullish pressure on Dominion South, TETCO M2, and downstream Mid-Atlantic basis, with bearish pressure at Appalachian receipt points where gas backs up in-basin -- this is a second, independent TCO FM active simultaneously with the Sep 24 event.
Reroute: Limited to moderate: TETCO (monitored) and Equitrans serve overlapping Appalachian markets and provide partial reroute, but with 1.9 Bcf/d of firm capacity offline and a simultaneous active TCO force majeure from September 24 still in effect, the combined system stress severely limits practical bypass options for affected shippers.
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Posted: 2026-10-14 19:50 UTC  |  Rev. 1  |  ID: TCO-26308024  |  Permalink Capacity: 1.900 Bcf/d  |  Direction: Bullish
SEV 4/5
Force Majeure 0.205 Bcf/d Until Further Notice 14 Days

Southern Star declared force majeure on Line Segment 455 due to a mechanical turbine failure at Saginaw Compressor Station in Jasper County, Missouri, effective October 9, 2026 (ID2 cycle). Capacity reductions total 205,000 Dth/d (0.205 Bcf/d): 180,000 Dth/d at Saginaw CS (Location ID 444550) and 25,000 Dth/d at Empire Energy Center (Location ID 378502). This notice (11240) supersedes 11238 and adds a repair timeline -- contractors are scheduled to complete turbine repairs by October 26, 2026, approximately two weeks from the notice date.

Southern Star force majeure removes 0.205 Bcf/d of Midcontinent/Kansas-Missouri capacity through approximately October 26; expect mild bullish pressure on Southern Star basis and Kansas-Missouri delivery markets, with tightening most acute at points downstream of Saginaw CS -- live data shows Saginaw CS Area Deliveries (loc 444550) running at 83.9% utilization with only 16.1% headroom, consistent with the stated constraint.
Reroute: Moderate: ANR, PEPL, and Southern Natural (EGT) serve overlapping Midcontinent and Kansas-Missouri markets, though Southern Star serves specific local delivery points in Missouri that may have limited bypass. PEPL Princeton Receipt (loc 17131) is posting 74.5% utilization with 25.5% headroom, suggesting some alternative capacity exists.
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Posted: 2026-10-12 13:35 UTC  |  Rev. 1  |  ID: ss-11240  |  Permalink Capacity: 0.205 Bcf/d  |  Direction: Bullish
SEV 4/5
Force Majeure 0.205 Bcf/d Until Further Notice

Southern Star declared force majeure effective October 9, 2026 due to a mechanical failure at Saginaw Compressor Station in Jasper County, Missouri. The event reduces capacity by 180,000 Dth/d (0.180 Bcf/d) at Saginaw CS (Location ID 444550) and 25,000 Dth/d (0.025 Bcf/d) at Empire Energy Center (Location ID 378502), for a combined 0.205 Bcf/d reduction on Line Segment 455. No restoration timeline has been given; Southern Star will post updates as available.

Southern Star force majeure removes 0.205 Bcf/d of Midcontinent throughput capacity on Line Segment 455 with no restoration timeline; expect bullish pressure on Southern Star / Midcontinent Kansas-Missouri basis with tightening likely to spill into Oneok Oklahoma pricing and modest supportive signal at Henry Hub if Midwest pull-back reduces southbound displacement.
Reroute: Moderate: ANR, PEPL, and TIGT serve overlapping Midcontinent and Kansas/Missouri markets and could absorb a portion of the displaced volumes, but Southern Star Line Segment 455 serves specific local and downstream Missouri delivery points that may have limited bypass options.
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Posted: 2026-10-09 18:45 UTC  |  Rev. 1  |  ID: ss-11238  |  Permalink Capacity: 0.205 Bcf/d  |  Direction: Bullish
SEV 4/5
Force Majeure 0.395 Bcf/d cut (capped at 0.930 Bcf/d) Until Further Notice 17 Days

ANR Pipeline has declared a force majeure on the Michigan Leg South at St. John Eastbound (LOC #FPSTJNEB) due to an anomaly discovered between MLV 56 and MLV 57, restricting capacity by 395 MMcf/d (0.395 Bcf/d) and leaving only 930 MMcf/d available. The constraint, originally set to run from 10/3 through 10/12, has now been extended through 10/19, a total of 17 days. ANR anticipates firm primary curtailments of approximately 34% of contracted MDQ, with firm secondary and interruptible services also affected.

ANR force majeure removes 0.395 Bcf/d of Michigan Leg South eastbound capacity through 10/19; pre-event flow at St. John Eastbound (FPSTJNEB TD1) was running at a median 0.67 Bcf/d (range 0.59-0.75) against the now-constrained 0.977 Bcf/d operating capacity, with the new 0.930 Bcf/d cap implying a modest physical cut relative to recent scheduled flows of ~0.593 Bcf/d currently posted, but firm primary curtailments at 34% of MDQ signal tightening at ANR ML 7 Michigan/Wisconsin delivery markets.
Reroute: Limited: ANR is one of the primary pipelines serving Michigan and Wisconsin markets; NGPL, PEPL, and ANR's own alternative segments provide partial relief but cannot fully replace constrained Michigan Leg South eastbound capacity, particularly for firm primary shippers already facing 34% MDQ curtailments.
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Posted: 2026-10-08 17:52 UTC  |  Rev. 1  |  ID: ANR-26305016  |  Permalink Capacity: 0.395 Bcf/d cut (capped at 0.930 Bcf/d)  |  Direction: Bullish
Columbia Gas Transmission (TCO)

UPDATE: Force Majeure – MXP Line

SEV 5/5
Force Majeure 1.800 Bcf/d Until Further Notice

TCO declared force majeure on MXP Line-100 in West Virginia following detection of a gas leak at the Saunders Creek Regulator Station on September 24, 2026. As of September 25, 2026, MXPSEG MA42 is reduced to zero total capacity, eliminating an estimated 1.8 Bcf/d of firm service through this internal constraint; the outage is expected to persist at minimum through the weekend gas days September 26-28, with restoration timing still 'until further notice.' Live capacity data confirms TM MXP MA42 (loc_id TMMXP) is posting 0 Bcf/d scheduled against 0.500 Bcf/d operating capacity, consistent with the constraint being upstream of that delivery metering point, though the notice-stated firm impact of 1.8 Bcf/d is the controlling figure.

TCO force majeure on MXP Line-100 eliminates 1.8 Bcf/d of firm throughput through MXPSEG with no firm restoration date; expect significant bullish pressure on Dominion South and TETCO M2 basis as Appalachian supply is stranded, with downstream Mid-Atlantic and Midwest markets tightening -- Columbia Gas Appalachian basis was already at -0.795 vs HH on 2026-09-24 and is likely to narrow sharply or flip positive given the scale of firm curtailment.
Reroute: Limited: TETCO (monitored) and TCO itself are the primary Appalachian corridor pipes; at 1.8 Bcf/d of firm curtailment, competing capacity on TETCO M2 and Rover is unlikely to absorb the full volume, and any available headroom will clear at a premium basis.
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Posted: 2026-09-25 13:02 UTC  |  Rev. 1  |  ID: TCO-26276017 Capacity: 1.800 Bcf/d  |  Direction: Bullish

Every notice Enercast has captured, by month — 7,828 in all. Each month page lists the notices with their scores and links to the permanent notice pages.

Oct 2026
504 notices · 30 sev 4–5
Sep 2026
782 notices · 58 sev 4–5
Aug 2026
2,480 notices · 58 sev 4–5
Jul 2026
703 notices · 36 sev 4–5
Jun 2026
586 notices · 24 sev 4–5
May 2026
506 notices · 11 sev 4–5
Apr 2026
722 notices · 10 sev 4–5
Mar 2026
467 notices · 22 sev 4–5