By Scott DiSavino
(Reuters) -U.S. edged up about 1% to a 15-week high as reduced output so far this year has cut the amount of the fuel going into storage for the winter heating season.
Storage injections in July, August and so far in September were at record lows, according to federal energy data going back to 1997.
That is because many producers reduced their drilling activities earlier this year after average spot monthly prices at the U.S. Henry Hub benchmark in Louisiana fell to a 32-year low.
Even though storage injections have been lower than usual in 19 of the past 20 weeks, the amount of gas in inventory was still about 6% above normal for this time of year due to relatively low heating demand during mild winter of 2023-2024. [EIA/GAS] [NGAS/POLL]
Front-month gas futures for November delivery on the New York Mercantile Exchange rose 2.1 cents, or 0.7%, to settle at $2.923 per million British thermal units (mmBtu), their highest close since June 13.
That kept the front-month in technically overbought territory for a second day in a row for the first time since May.
For the month, the contract was up about 37%, the most in a month since July 2022.
For the quarter, the front-month was up about 12% after jumping 48% last quarter.
Futures rose despite a small increase in output over the weekend and forecasts for less demand over the next two weeks than previously expected.
That small output increase came as some drillers restarted their Gulf of Mexico production now that Hurricane Helene passed through the area.
The decline in demand, meanwhile, was due in part to a reduction in the amount of gas power generators will likely need to burn with over 1.9 million homes and businesses still without power in the U.S. Southeast and Midwest after Helene battered the region late last week.
The U.S. National Hurricane Center projected a tropical disturbance in the Caribbean Sea had a 40% chance of strengthening into a cyclone as it moves into the Gulf of Mexico over the next week.
SUPPLY AND DEMAND
LSEG said gas output in the Lower 48 U.S. states fell to an average of 102.1 bcfd so far in September, down from 103.2 bcfd in August. That compares with a record 105.5 bcfd in December 2023.
The average output for September, however, was higher than seen last week as some Gulf of Mexico production returned to service.
LSEG forecast average gas demand in the Lower 48 states, including exports, will rise from 95.9 bcfd this week to 96.6 bcfd next week. Those forecasts were lower than LSEG’s outlook on Friday.
Gas flows to the seven big U.S. liquefied natural gas (LNG) export plants eased to an average of 12.7 bcfd so far in September, down from 12.9 bcfd in August. That compares with a monthly record high of 14.7 bcfd in December 2023.
That reduction was due mostly to the planned Sept. 20 shutdown of Berkshire Hathaway (NYSE:) Energy’s 0.8-bcfd Cove Point LNG export plant in Maryland for around three weeks of annual maintenance.
Week ended Week ended Year ago Five-year
Sep 27 Sep 20 Sep 27 average
Actual Actual Sep 27
U.S. weekly natgas storage change (bcf): +60 +47 +87 +98
U.S. total natgas in storage (bcf): 3,552 3,492 3,420 3,357
U.S. total storage versus 5-year average 5.8% 7.1%
Global Gas Benchmark Futures ($ per mmBtu) Current Day Prior Day This Month Prior Year Five-Year
Last Year Average Average
2023 (2018-2022)
Henry Hub 2.93 2.90 2.70 2.66 3.60
Title Transfer Facility (TTF) 12.68 12.47 11.44 13.04 14.39
Japan Korea Marker (JKM) 13.21 13.19 13.92 14.39 14.31
LSEG Heating (HDD), Cooling (CDD) and Total (TDD) Degree Days
Two-Week Total Forecast Current Day Prior Day Prior Year 10-Year 30-Year Norm
Norm
U.S. GFS HDDs 50 51 65 77 94
U.S. GFS CDDs 94 97 75 75 61
U.S. GFS TDDs 144 148 130 152 155
LSEG U.S. Weekly GFS Supply and Demand Forecasts
Prior Week Current Next Week This Week Five-Year
Week Last Year (2019-2023)
Average For
Month
U.S. Supply (bcfd)
U.S. Lower 48 Dry Production 101.8 102.2 102.2 102.3 96.5
U.S. Imports from Canada 7.9 7.6 7.4 N/A 7.1
U.S. LNG Imports 0.0 0.0 0.0 0.0 0.0
Total U.S. Supply 109.7 109.9 109.6 N/A 103.6
U.S. Demand (bcfd)
U.S. Exports to Canada 1.9 2.0 1.9 N/A 2.3
U.S. Exports to Mexico 6.2 6.1 6.8 N/A 6.0
U.S. LNG Exports 12.3 12.4 13.0 12.7 8.2
U.S. Commercial 4.8 4.9 5.3 5.0 4.9
U.S. Residential 4.0 4.0 4.7 4.2 3.9
U.S. Power Plant 40.2 37.2 35.6 35.4 36.0
U.S. Industrial 21.9 21.9 22.1 21.7 21.7
U.S. Plant Fuel 5.0 5.0 5.0 5.0 5.1
U.S. Pipe Distribution 2.1 2.0 2.0 2.0 2.2
U.S. Vehicle Fuel 0.1 0.1 0.1 0.1 0.1
Total U.S. Consumption 78.1 75.3 74.9 73.4 80.0
Total U.S. Demand 98.5 95.9 96.6 N/A 90.4
N/A is Not Available
U.S. Northwest River Forecast Center (NWRFC) at The Dalles Dam Current Day Prior Day 2023 2022 2021 %
% of Normal % of Normal % of Normal % of Normal of Normal
Forecast Forecast Actual Actual Actual
Apr-Sep 74 74 83 107 81
Jan-Jul 76 76 77 102 79
Oct-Sep 77 78 76 103 81
U.S. weekly power generation percent by fuel – EIA
Week ended Week ended 2023 2022 2021
Oct 4 Sep 27
Wind 7 7 10 11 10
Solar 4 5 4 3 3
Hydro 5 5 6 6 7
Other 1 1 2 2 2
Petroleum 0 0 0 0 0
Natural Gas 44 46 41 38 37
Coal 18 18 17 21 23
Nuclear 20 18 19 19 20
SNL U.S. Natural Gas Next-Day Prices ($ per mmBtu)
Hub Current Day Prior Day
Henry Hub 2.53 2.64
Transco Z6 New York 1.28 1.23
PG&E (NYSE:) Citygate 3.05 3.00
Eastern Gas (old Dominion South) 1.32 1.21
Chicago Citygate 2.35 2.52
Algonquin Citygate 1.55 1.65
SoCal Citygate 2.55 2.47
Waha Hub 0.96 1.39
AECO 0.04 0.07
SNL U.S. Power Next-Day Prices ($ per megawatt-hour)
Hub Current Day Prior Day
New England 32.25 36.50
PJM West 43.25 37.00
Ercot North 21.50 25.25
Mid C 49.25 50.50
Palo Verde 29.50 36.00
SP-15 28.25 34.75