News wire — U.S. natural gas futures edged up about 1% on Friday on record flows to liquefied natural gas (LNG) export plants.
Front-month gas futures for April delivery on the New York Mercantile Exchange rose 5.3 cents, or 1.3%, to $4.028 per million British thermal units (mmBtu) at 9:16 a.m. EDT (1316 GMT). On Thursday, the contract closed at its lowest since February 28.
That increase came despite record output and forecasts of milder weather and lower heating demand than previously expected through early April, which should allow utilities to keep adding fuel to storage in the coming weeks.
Some analysts say gas stockpiles are on track to increase in March for the first time since 2012 and only the second time in history.
So far, however, gas stockpiles remain around 8% below normal levels for this time of year after extremely cold weather in January and February forced energy firms to pull large amounts of gas out of storage, including record amounts in January.
SUPPLY AND DEMAND
Financial firm LSEG said average gas output in the Lower 48 U.S. states rose to 105.9 billion cubic feet per day (bcfd) so far in March, up from a record 105.1 bcfd in February.
Meteorologists projected temperatures in the Lower 48 states would remain mostly warmer than normal through April 5.
LSEG forecast average gas demand in the Lower 48, including exports, will rise from 106.8 bcfd this week to 108.0 bcfd next week before sliding to 106.1 bcfd in two weeks. The forecasts for this week and next week were similar to LSEG’s outlook on Thursday.
The amount of gas flowing to the eight big operating U.S. LNG export plants rose to an average of 15.7 bcfd so far in March, up from a record 15.6 bcfd in February, as new units at Venture Global’s 3.2-bcfd Plaquemines LNG export plant, currently under construction in Louisiana, enter service.
On a daily basis, LNG feedgas was on track to hit a preliminary record high of 16.6 bcfd on Friday, up from 16.0 bcfd on Thursday and an average of 15.9 bcfd over the prior seven days. If correct, that would top the current all-time daily high of 16.4 bcfd set on February 23.
The U.S. became the world’s biggest LNG supplier in 2023, surpassing Australia and Qatar, as surging global prices fed demand for more exports due in part to supply disruptions and sanctions linked to Russia’s 2022 invasion of Ukraine.
Gas was trading around $14 per mmBtu at both the Dutch Title Transfer Facility (TTF) benchmark in Europe and the Japan Korea Marker (JKM) benchmark in Asia.
Week ended Mar 21 Forecast | Week ended Mar 14 Actual | Year ago Mar 21 | Five-year average Mar 21 | ||
U.S. weekly natgas storage change (bcf): | +11 | +9 | -30 | -31 | |
U.S. total natgas in storage (bcf): | 1,718 | 1,707 | 2,301 | 1,866 | |
U.S. total storage versus 5-year average | -7.9% | -10.0% | |||
Global Gas Benchmark Futures ($ per mmBtu) | Current Day | Prior Day | This Month Last Year | Prior Year Average 2024 | Five-Year Average (2019-2023) |
Henry Hub | 3.92 | 3.98 | 1.75 | 2.41 | 3.52 |
Title Transfer Facility (TTF) | 13.92 | 13.67 | 8.54 | 10.95 | 15.47 |
Japan Korea Marker (JKM) | 13.53 | 13.78 | 8.95 | 11.89 | 15.23 |
LSEG Heating (HDD), Cooling (CDD) and Total (TDD) Degree Days | |||||
Two-Week Total Forecast | Current Day | Prior Day | Prior Year | 10-Year Norm | 30-Year Norm |
U.S. GFS HDDs | 211 | 231 | 255 | 246 | 236 |
U.S. GFS CDDs | 30 | 25 | 10 | 20 | 18 |
U.S. GFS TDDs | 241 | 256 | 265 | 266 | 254 |
LSEG U.S. Weekly GFS Supply and Demand Forecasts | |||||
Prior Week | Current Week | Next Week | This Week Last Year | Five-Year (2020-2024)Average For Month | |
U.S. Supply (bcfd) | |||||
U.S. Lower 48 Dry Production | 105.7 | 106.1 | 105.6 | 101.6 | 97.5 |
U.S. Imports from Canada | 9.1 | 8.8 | 9.0 | N/A | 7.8 |
U.S. LNG Imports | 0.0 | 0.0 | 0.0 | 0.0 | 0.1 |
Total U.S. Supply | 114.7 | 114.8 | 114.5 | N/A | 105.4 |
U.S. Demand (bcfd) | |||||
U.S. Exports to Canada | 3.8 | 4.0 | 3.9 | N/A | 3.3 |
U.S. Exports to Mexico | 6.2 | 5.9 | 6.2 | N/A | 5.4 |
U.S. LNG Exports | 15.5 | 16.0 | 16.4 | 13.1 | 11.8 |
U.S. Commercial | 11.2 | 10.3 | 10.7 | 11.9 | 11.8 |
U.S. Residential | 17.2 | 15.6 | 15.6 | 17.7 | 18.3 |
U.S. Power Plant | 25.9 | 24.0 | 24.0 | 30.8 | 27.5 |
U.S. Industrial | 23.7 | 23.5 | 23.7 | 24.5 | 23.8 |
U.S. Plant Fuel | 5.2 | 5.2 | 5.2 | 5.2 | 5.2 |
U.S. Pipe Distribution | 2.3 | 2.2 | 2.2 | 2.5 | 3.3 |
U.S. Vehicle Fuel | 0.1 | 0.1 | 0.1 | 0.1 | 0.2 |
Total U.S. Consumption | 85.6 | 80.9 | 81.5 | 92.7 | 90.1 |
Total U.S. Demand | 111.1 | 106.8 | 108.0 | N/A | 110.6 |
N/A is Not Available | |||||
U.S. Northwest River Forecast Center (NWRFC) at The Dalles Dam (Fiscal year ending Sep 30) | 2025 Current Day % of Normal Forecast | 2025 Prior Day % of Normal Forecast | 2024 % of Normal Actual | 2023 % of Normal Actual | 2022 % of Normal Actual |
Apr-Sep | 91 | 92 | 74 | 83 | 107 |
Jan-Jul | 88 | 89 | 76 | 77 | 102 |
Oct-Sep | 89 | 90 | 77 | 76 | 103 |
U.S. weekly power generation percent by fuel – EIA | |||||
Week ended Mar 21 | Week ended Mar 14 | 2024 | 2023 | 2022 | |
Wind | 18 | 15 | 11 | 10 | 11 |
Solar | 6 | 7 | 5 | 4 | 3 |
Hydro | 7 | 7 | 6 | 6 | 6 |
Other | 1 | 1 | 1 | 2 | 2 |
Petroleum | 0 | 0 | 0 | 0 | 0 |
Natural Gas | 32 | 34 | 42 | 41 | 38 |
Coal | 14 | 16 | 16 | 17 | 21 |
Nuclear | 20 | 20 | 19 | 19 | 19 |
SNL U.S. Natural Gas Next-Day Prices ($ per mmBtu) | |||||
Hub | Current Day | Prior Day | |||
Henry Hub | 4.23 | 4.21 | |||
Transco Z6 New York | 3.31 | 3.34 | |||
PG&E Citygate | 3.75 | 3.86 | |||
Eastern Gas (old Dominion South) | 3.27 | 3.33 | |||
Chicago Citygate | 3.35 | 3.69 | |||
Algonquin Citygate | 3.55 | 3.54 | |||
SoCal Citygate | 3.71 | 3.88 | |||
Waha Hub | 1.12 | 0.77 | |||
AECO | 1.51 | 1.46 | |||
ICE U.S. Power Next-Day Prices ($ per megawatt-hour) | |||||
Hub | Current Day | Prior Day | |||
New England | 40.00 | 45.92 | |||
PJM West | 49.96 | 50.42 | |||
Mid C | 24.08 | 33.77 | |||
Palo Verde | 8.38 | 11.16 | |||
SP-15 | 2.60 | 1.42 |
Reporting by Scott DiSavino; Editing by Joe Bavier – Reuters
