EPNG has declared force majeure at its Roswell Compressor Station in Chaves County, New Mexico following a fuel system failure. The outage reduces operational capacity through the CAPROCK N constraint by an additional 106,848 Dth/d (0.107 Bcf/d) effective September 19, 2026 Intraday 1 cycle, with restoration targeted by 9:00 AM September 20. EPNG noted this FM stacks on top of an existing maintenance constraint at CAPROCK N and will post an updated maintenance notice reflecting the total combined impact.
EPNG FM at Roswell CS removes an incremental 0.107 Bcf/d through the CAPROCK N constraint, compounding an existing maintenance restriction on the same bottleneck; expect bearish pressure at Waha as Permian/San Juan takeaway tightens further, with bullish pressure at SoCal Border and Arizona delivery points -- the short 24-hour window limits multi-day basis impact but intraday tightness at downstream points is real.
Reroute: Moderate: Transwestern Pipeline (TW) provides competing westbound capacity from the Permian and San Juan basins to SoCal border and Arizona, but cannot fully replace EPNG CAPROCK N segment capacity if the existing maintenance restriction plus this FM materially reduce total throughput; simultaneous TW constraints would eliminate reroute entirely.
Transwestern Pipeline declared force majeure at the P-3 Compressor Station effective September 19, 2026 at 9:00 AM through September 20, 2026 at 8:59 AM -- a roughly 24-hour window. No capacity volume is stated in the notice, but TW is a primary westbound pipeline from the Permian and San Juan basins to SoCal border and Arizona markets. The force majeure designation triggers a minimum severity of 4 regardless of stated volume.
TW force majeure at P-3 Comp Sta tightens westbound takeaway from Permian and San Juan; expect bearish pressure at Waha and San Juan basis as basin gas backs up, with bullish pressure at SoCal Border and Arizona delivery points for the roughly 24-hour event window -- no capacity figure posted, so magnitude is unquantified but reroute to EPNG is the only alternative.
Reroute: Moderate: El Paso Natural Gas (EPNG) is the primary competing pipeline serving SoCal border and Arizona from the Permian Basin and can absorb some displaced volumes, but EPNG spare capacity as of the evening cycle on 2026-09-19 shows SOCAL NEEDLES at 72.3% utilized with 27.7% headroom (0.235 Bcf/d OAC), suggesting partial but not full reroute is feasible; any simultaneous EPNG constraint would eliminate California reroute entirely.
Cove Point LNG is entering its annual planned maintenance outage effective 2026-09-19 at 14:00. The notice is classified as a Capacity Constraint / Critical notice by the operator but provides no specific duration or volume impact. As an LNG export terminal, any feedgas curtailment at Cove Point removes export demand from the domestic market, which is directionally bullish for Appalachian supply basis.
Cove Point annual maintenance removes LNG export demand from the Appalachian supply basin; gas that would have fed the terminal stays domestic, bearish the LNG export arb and bullish Appalachian regional basis -- the Eastern Gas South regional proxy has been trading at approximately -1.270 vs HH as of 2026-09-17 (5-day trailing average -1.317), and reduced feedgas pull from Cove Point is expected to widen that discount further; COVE POINT PLANT delivery meter (loc 10001, D:DPQ) was running at 94.4% utilization (0.868 Bcf/d scheduled against 0.920 Bcf/d operating capacity) in the 2026-09-18 evening cycle, indicating pre-maintenance throughput was near-full and the maintenance impact on nominations could be material.
Reroute: None: Cove Point is the sole LNG export terminal served by this system; there is no alternate delivery point for LNG export volumes, though gas volumes displaced from feedgas can be absorbed by the broader Appalachian/Mid-Atlantic grid via EGTS, Transco, and TCO interconnects.
Transwestern Pipeline declared force majeure on the Panhandle Lateral due to compressor station mechanical failure, effective September 17, 2026. This Revision 1 extends the event through September 20, 2026 (4 days total), reducing Panhandle Lateral Receipt and Delivery capacity from 0.263 Bcf/d to 0.175 Bcf/d -- a loss of 0.088 Bcf/d. Capacity is expected to return to normal on September 21, 2026 at 9:00 AM.
TW Panhandle Lateral FM removes 0.088 Bcf/d of receipt/delivery capacity through 9/20/26; expect mild bullish pressure at SoCal Border and Arizona delivery points as westbound supply tightens, with offsetting bearish pressure at Permian/San Juan basin as lateral gas cannot move westbound at full volume.
Reroute: Moderate: EPNG serves overlapping SoCal Border and Arizona markets and may absorb some displaced volumes, but if EPNG is simultaneously constrained, no California reroute remains. The Panhandle Lateral itself is a discrete lateral with no direct bypass.
On September 18, 2026, Texas Gas Transmission reported a pipeline release and fire on its 16-inch line southwest of Jennings, LA. The pipeline was shut in and the fire has been extinguished with no injuries. No restoration timeline has been provided and TGT has indicated it will update as more information becomes available.
TGT 16-inch line shut-in southwest of Jennings with no restoration timeline removes northbound Louisiana receipt capacity of unknown volume; expect bullish pressure on Texas Gas Zone 1 basis (most recently -0.245 vs HH on 2026-09-17) and Midwest delivery markets as Gulf Coast supply into the system is curtailed until further notice.
Reroute: Moderate: ANR, TETCO, and Gulf South serve overlapping Gulf Coast-to-Midwest corridors and may absorb some displaced volumes, but TGT's specific Louisiana receipt infrastructure at this location has limited immediate bypass; full offset is unlikely until the shut-in segment is restored.
EPNG has declared force majeure at Caprock Compressor Station Unit #2 in Lea County, New Mexico, due to a second-stage nozzle system cooling blockage. The CAPROCK N constraint remains reduced by 68,380 Dth/d (0.068 Bcf/d), and effective September 18 Timely Cycle, the LUSK constraint will be additionally reduced by 9,542 Dth/d (0.010 Bcf/d), bringing total combined reductions to approximately 100,272 Dth/d (0.100 Bcf/d). The force majeure end date is currently posted as September 18, 2026 at 9:00 AM, though an updated maintenance notice is pending.
EPNG force majeure at Caprock Unit #2 removes a combined 0.100 Bcf/d across CAPROCK N and LUSK constraints; expect modest bearish pressure at Waha/Permian as New Mexico takeaway is reduced, with correspondingly mild bullish pressure at SoCal Border and Arizona delivery points -- impact is small relative to system scale but force majeure status and pending LUSK expansion warrant close monitoring into the September 18 Timely Cycle.
Reroute: Moderate: Transwestern Pipeline (TW) serves overlapping SoCal border and Arizona markets and provides partial alternative routing for westbound Permian volumes; however, the combined constraint volume of 0.100 Bcf/d is modest and reroute via TW is likely feasible at comparable cost.
Gulf South Pipeline issued a Critical Over-Under Performance notice on 2026-09-17 for Loc 24329 Stratton Ridge to Freeport LNG, citing the customer's failure to take confirmed delivery quantities. Gulf South is reducing scheduling for remaining nomination cycles for Gas Day 9/17/2026 and until further notice. The LNG feedgas severity floor applies -- this is a direct curtailment of feed gas deliveries to Freeport LNG.
Gulf South curtailment at Stratton Ridge (Loc 24329) reduces Freeport LNG feed gas; live capacity data shows 1.47 Bcf/d scheduled against 1.78 Bcf/d operating capacity at 82.6% utilization as of the evening cycle on 2026-09-17, with no stated volume of the reduction -- gas displaced from LNG export stays in the domestic market, bearish near-term for Henry Hub (regional proxy at 3.010 on 2026-09-16) and Gulf Coast basis.
Reroute: None: Freeport LNG feed gas delivered via the Stratton Ridge lateral has no alternative pipeline path -- curtailed volumes cannot be rerouted to the terminal; instead, displaced supply increases domestic onshore availability.
Cove Point LNG (CPL) has posted a Critical capacity constraint notice effective 2026-09-19 at 14:00, classified as a PPO (Planned Partial Outage). No specific capacity reduction volume is stated in the notice text. Live EBB data as of the 2026-09-16 evening cycle shows COVE POINT PLANT (loc 10001, D:DPQ) running at 94.5% utilization with only 0.051 Bcf/d of headroom against 0.920 Bcf/d operating capacity, indicating the terminal is already near full throughput before the restriction takes effect. The restriction is set to begin September 19, approximately 3 days after posting.
CPL PPO effective 2026-09-19 removes LNG export demand at Cove Point, bearish for Appalachian/Mid-Atlantic supply balance; Eastern Gas South regional basis most recently printed at -1.420 vs HH (2026-09-15) against a 5-day average of -1.273, and any further feedgas displacement into a region already trading deep negative to Henry Hub will pressure that spread wider to the bearish side.
Reroute: None applicable from an LNG export perspective -- Cove Point is the only LNG export terminal on the East Coast, and displaced feedgas volumes have no alternative LNG outlet; gas backing into the Appalachian/Mid-Atlantic system may find limited domestic absorption given shoulder-season demand.
Golden Pass Pipeline has posted its Annual Planned Maintenance 2025-2026 Rev 32, covering the Sabine Pass TX to Starks LA corridor with up to 2.6 Bcf/d of LNG export feed gas capacity at risk. This is listed as Revision Number 1 (not a revision of a prior posting), indicating a fresh or newly re-labeled filing as of September 15-16, 2026. No specific per-job schedule, individual outage dates, or discrete capacity impact figures are provided in the notice text; the 2.6 Bcf/d figure represents the system's full feed gas capacity ceiling, not a stated curtailment volume.
Golden Pass Pipeline planned maintenance threatens feed gas deliveries to the Golden Pass LNG export terminal (up to 2.6 Bcf/d system capacity); any realized curtailment is bearish Gulf Coast basis as unexported gas stays domestic -- Houston Ship Channel regional basis has already softened to -0.455 vs Henry Hub as of 2026-09-15 (5-day average -0.287), and further feed gas disruptions would pressure that spread wider on the downside.
Reroute: None: Golden Pass Pipeline is a dedicated LNG export feed gas pipeline serving only the Golden Pass LNG terminal; curtailed feed gas volumes have no alternative export outlet and instead back into the Gulf Coast domestic market.
Golden Pass Pipeline has posted a critical ACA (Authorized Contract Authority) change effective October 1, 2026, affecting up to 2.6 Bcf/d of LNG export feed gas capacity on the Sabine Pass TX to Starks LA corridor. The nature of the change (reduction, reallocation, or scheduling adjustment) is not specified in the notice text. Because this directly involves LNG export feed gas nominations at Golden Pass LNG, the LNG feedgas severity floor of 4 applies regardless of the notice's informational framing.
ACA change at Golden Pass Pipeline effective October 1, 2026 places up to 2.6 Bcf/d of LNG export feed gas nominations at risk; if feed gas deliveries are curtailed or reduced, gas remains onshore and is bearish for Henry Hub and Gulf Coast basis -- regional Houston Ship Channel basis was most recently -0.455 vs Henry Hub on 2026-09-15 (trailing 5-day average -0.287), with the October 1 effective date falling outside this pricing window; watch for follow-on nominations notices confirming actual curtailment volumes.
Reroute: None: Golden Pass Pipeline is the dedicated feed gas supply line to Golden Pass LNG at Sabine Pass, TX; no alternative pipeline replaces this function for this terminal. Any reduction in ACA capacity directly curtails LNG export throughput with no bypass.
Transwestern Pipeline declared force majeure on the Panhandle Lateral due to a compressor station mechanical failure. Receipt and delivery capacity on the Panhandle Lateral is reduced from 0.263 Bcf/d to 0.175 Bcf/d (a loss of 0.088 Bcf/d) effective September 17, 2026 through September 19, 2026 at 8:59 AM -- a two-day event. Full capacity of 0.263 Bcf/d is expected to be restored on September 19.
TW Panhandle Lateral FM removes 0.088 Bcf/d of receipt and delivery capacity for two days; expect mild bearish pressure at Permian/San Juan basin points (Waha, TW Permian) and modest bullish support at SoCal Border and Arizona delivery points, though the relatively small volume limits the broader market impact.
Reroute: Moderate: EPNG serves overlapping SoCal border and Arizona markets and likely has spare capacity to absorb some displaced volumes; however, a simultaneous EPNG constraint would eliminate this option entirely.
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Mountain Valley Pipeline
Stallworth Compressor Station Maintenance 09-14-26 Complete
Below alert threshold -- no detailed analysis performed.
Reroute: Not assessed.
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Texas Gas Transmission
Pipeline Incident Southwest of Jennings, LA
SEV 2/5
Informational
This is Revision 2 of TGT-5038741, a pipeline incident notice for a location southwest of Jennings, LA posted originally on 2026-09-18. The notice carries a 'Supersede' status but contains no updated operational content -- no capacity figures, no restoration timeline, and no new curtailment language relative to prior revisions. The situation is operationally unchanged from the prior posting.
No new market impact -- operational situation unchanged from prior revision, market has already priced this constraint; Texas Gas Zone 1 basis was most recently -0.445 vs Henry Hub on 2026-09-25, reflecting current system conditions rather than any incremental signal from this repost.
Reroute: Moderate: ANR, TETCO, and PEPL serve overlapping Gulf Coast-to-Midwest corridors; however, reroute assessment is moot given no new capacity constraint is stated in this revision.
