U.S. Energy Information Administration logo
Skip to sub-navigation

Natural Gas

‹ See all Natural Gas

Natural Gas Weekly Update

for week ending August 20, 2025   |  Release date:  August 21, 2025   |  Next release:  August 28, 2025   |   Previous weeks

JUMP TO: Prices | Supply and Demand | Liquefied Natural Gas (LNG) | Rig Count | Other Market Drivers | Storage

Today in Energy

Recent Today in Energy analysis of natural gas markets is available on the EIA website.

Market Highlights:

(For the week ending Wednesday, August 20, 2025)

Prices

  • Henry Hub spot price: The Henry Hub spot price fell 11 cents from $2.92 per million British thermal units (MMBtu) last Wednesday to $2.81/MMBtu yesterday.
  • Henry Hub futures price: The price of the September 2025 NYMEX contract decreased 8 cents, from $2.828/MMBtu last Wednesday to $2.752/MMBtu yesterday. The price of the 12-month strip averaging September 2025 through August 2026 futures contracts declined 7 cents to $3.501/MMBtu.
  • Select regional spot prices: Natural gas spot prices fell at most locations this report week (Wednesday, August 13, to Wednesday, August 20). Price changes ranged from a decrease of 76 cents at Algonquin Citygate to an increase of $1.67 at Northwest Sumas.
    • Prices across the West Coast rose this report week. The price at Northwest Sumas on the Canada-Washington border, the main pricing point for natural gas in the Pacific Northwest, rose $1.67 from $0.53/MMBtu last Wednesday to $2.20/MMBtu yesterday. The price at SoCal Citygate in Southern California increased 45 cents from $3.33/MMBtu last Wednesday to $3.78/MMBtu yesterday. Average temperatures in the Riverside Area, inland from Los Angeles, fell to an intraweek low of 74°F on Saturday before rising to an intraweek high of 83°F on Wednesday, 3°F higher than normal. The price at PG&E Citygate in Northern California rose 29 cents, up from $3.11/MMBtu last Wednesday to $3.40/MMBtu yesterday. Temperatures in the Sacramento Area followed a similar upward trend, reaching an intraweek low of 72°F on Sunday before rising to an intraweek high of 78°F yesterday, 3°F higher than normal. The California electric power sector consumed 2.4 billion cubic feet per day (Bcf/d) of natural gas on August 20, the highest volume since October 8, 2024, according to data from S&P Global Commodity Insights.

    Daily spot prices by region are available on the EIA website.

  • International futures prices: International natural gas futures prices decreased this report week. According to Bloomberg Finance, L.P., weekly average front-month futures prices for liquefied natural gas (LNG) cargoes in East Asia decreased 58 cents to a weekly average of $11.35/MMBtu. Natural gas futures for delivery at the Title Transfer Facility (TTF) in the Netherlands decreased 40 cents to a weekly average of $10.78/MMBtu. In the same week last year (week ending August 21, 2024), the prices were $13.90/MMBtu in East Asia and $12.60/MMBtu at TTF.
  • Top

    Supply and Demand

  • Supply: According to data from S&P Global Commodity Insights, the average total supply of natural gas rose by 0.4% (0.5 Bcf/d) compared with the previous report week. Dry natural gas production grew by 0.6% (0.7 Bcf/d) to average 107.4 Bcf/d, and average net imports from Canada decreased by 3.5% (0.2 Bcf/d) from last week.
  • Demand: Total U.S. consumption of natural gas rose by 0.2% (0.2 Bcf/d) compared with the previous report week, according to data from S&P Global Commodity Insights. Natural gas consumed for power generation rose by 1.0% (0.5 Bcf/d) week over week, with warmer temperatures observed across the country. Consumption in the industrial sector decreased by 0.3% (0.1 Bcf/d) week over week, and consumption in the residential and commercial sector declined by 2.7% (0.2 Bcf/d). Natural gas exports to Mexico decreased 2.6% (0.2 Bcf/d). Natural gas deliveries to U.S. LNG export facilities (LNG pipeline receipts) averaged 15.5 Bcf/d, or 1.3 Bcf/d lower than last week.
Top

Liquefied Natural Gas (LNG)

  • Pipeline receipts: Average natural gas deliveries to U.S. LNG export terminals fell 1.3 Bcf/d from last week to 15.5 Bcf/d, according to data from S&P Global Commodity Insights. Natural gas deliveries to terminals in South Louisiana fell 7.0% (0.8 Bcf/d); natural gas deliveries to terminals in South Texas fell by 12.2% (0.5 Bcf/d). Natural gas deliveries to terminals outside the Gulf Coast remained essentially unchanged at 1.1 Bcf/d this week.
  • Vessels departing U.S. ports: Thirty-one LNG vessels with a combined LNG-carrying capacity of 116 Bcf departed the United States between August 14 and August 20, according to shipping data provided by Bloomberg Finance, L.P.:
    • Eight tankers from Sabine Pass
    • Six from Plaquemines
    • Five from Corpus Christi
    • Four from Freeport
    • Three from Cameron
    • Two each from Cove Point and Calcasieu Pass
    • One from Elba Island
    Top

    Rig Count

    • According to Baker Hughes, for the week ending Tuesday, August 12, the natural gas rig count decreased by 1 rig from a week ago to 122 rigs. The Eagle Ford added one rig, and one rig was added among unidentified producing regions. The Haynesville, the Permian, and the Utica each dropped one rig. The number of oil-directed rigs increased by 1 rig to 412 rigs. The Utica added one rig, and one rig was added among unidentified producing regions. The Mississippian dropped one rig. The total rig count, which includes 5 miscellaneous rigs, now stands at 539 rigs, 50 fewer rigs than at this time last year.
    Top

    Storage

    • Net injections into storage totaled 13 Bcf for the week ending August 15, compared with the five-year (2020–24) average net injections of 35 Bcf and last year's net injections of 29 Bcf during the same week. Working natural gas stocks totaled 3,199 Bcf, which is 174 Bcf (6%) more than the five-year average and 95 Bcf (3%) lower than last year at this time.
    • According to The Desk survey of natural gas analysts, estimates of the weekly net change to working natural gas stocks ranged from net injections of 13 Bcf to 32 Bcf, with a median estimate of 19 Bcf.
    • The average rate of injections into storage is 20% higher than the five-year average so far in the refill season (April through October). If the rate of injections into storage matched the five-year average of 9.5 Bcf/d for the remainder of the refill season, the total inventory would be 3,927 Bcf on October 31, which is 174 Bcf higher than the five-year average of 3,753 Bcf for that time of year.
    More storage data and analysis can be found on the Natural Gas Storage Dashboard and the Weekly Natural Gas Storage Report.

    Top

    See also:

    Top


Natural gas spot prices
Spot Prices ($/MMBtu)
Thu,
14-Aug
Fri,
15-Aug
Mon,
18-Aug
Tue,
19-Aug
Wed,
20-Aug
Henry Hub
2.77
2.97
2.96
2.86
2.81
New York
2.61
2.60
2.32
2.23
2.03
Chicago
2.64
2.74
2.71
2.63
2.55
Cal. Comp. Avg.*
2.75
2.77
2.85
2.98
3.20
*Avg. of NGI's reported prices for: Malin, PG&E Citygate, and Southern California Border Avg.
Data source: NGI's Daily Gas Price Index
Natural gas futures prices


U.S. natural gas supply - Gas Week: (8/14/25 - 8/20/25)
Average daily values (billion cubic feet)
this week
last week
last year
Marketed production
121.4
120.6
115.1
Dry production
107.4
106.7
101.8
Net Canada imports
5.2
5.4
6.1
LNG pipeline deliveries
0.0
0.0
0.1
Total supply
112.6
112.1
108.0

Data source: S&P Global Commodity Insights
Note: This table reflects any data revisions that may have occurred since the previous week's posting. Liquefied natural gas (LNG) pipeline deliveries represent natural gas sendout from LNG import terminals.

U.S. natural gas consumption - Gas Week: (8/14/25 - 8/20/25)
Average daily values (billion cubic feet)
this week
last week
last year
U.S. consumption
76.3
76.1
78.5
    Power
45.7
45.2
48.1
    Industrial
21.7
21.8
22.3
    Residential/commercial
8.9
9.1
8.1
Mexico exports
7.3
7.5
7.1
Pipeline fuel use/losses
7.0
7.0
6.9
LNG pipeline receipts
15.5
16.8
12.9
Total demand
106.1
107.4
105.3

Data source: S&P Global Commodity Insights
Note: This table reflects any data revisions that may have occurred since the previous week's posting. Liquefied natural gas (LNG) pipeline receipts represent pipeline deliveries to LNG export terminals.

Natural gas supply


Weekly natural gas rig count and average Henry Hub
Rigs
Tue, August 12, 2025
Change from
 
last week
last year
Oil rigs
412
0.2%
-14.7%
Natural gas rigs
122
-0.8%
24.5%
Note: Excludes any miscellaneous rigs
Rig numbers by type
Tue, August 12, 2025
Change from
 
last week
last year
Vertical
13
-7.1%
-23.5%
Horizontal
471
0.0%
-9.6%
Directional
55
1.9%
14.6%
Data source: Baker Hughes Company


Working gas in underground storage
Stocks
billion cubic feet (Bcf)
Region
2025-08-15
2025-08-08
change
East
690
677
13
Midwest
812
796
16
Mountain
255
253
2
Pacific
301
305
-4
South Central
1,141 
1,154
-13
Total
3,199 
3,186
13

Data source: U.S. Energy Information Administration Form EIA-912, Weekly Underground Natural Gas Storage Report
Note: Totals may not equal sum of components because of independent rounding.
Working gas in underground storage
Historical comparisons
Year ago
8/15/24
5-year average
2020-2024
Region
Stocks (Bcf)
% change
Stocks (Bcf)
% change
East
733
-5.9
689
0.1
Midwest
885
-8.2
812
0.0
Mountain
263
-3.0
203
25.6
Pacific
288
4.5
265
13.6
South Central
1,125
1.4
1,055
8.2
Total
3,294
-2.9
3,025
5.8
Data source: U.S. Energy Information Administration Form EIA-912, Weekly Underground Natural Gas Storage Report
Note: Totals may not equal sum of components because of independent rounding.


Temperature – heating & cooling degree days (week ending Aug 14)
 
HDDs
CDDs
Region
Current total
Deviation from normal
Deviation from last year
Current total
Deviation from normal
Deviation from last year
New England
1
-2
-3
61
22
36
Middle Atlantic
1
-2
-1
66
13
28
E N Central
0
-5
-9
81
31
57
W N Central
0
-3
-15
72
9
46
South Atlantic
0
0
0
91
-2
-11
E S Central
0
0
0
98
8
14
W S Central
0
0
0
131
8
-2
Mountain
1
-3
-3
89
18
11
Pacific
0
-2
0
67
22
0
United States
0
-2
-4
84
14
18
Data source: National Oceanic and Atmospheric Administration
Note: HDDs=heating degree days; CDDs=cooling degree days

   Average temperature (°F)


   7-day mean ending Aug 14, 2025

Mean Temperature (F) 7-Day Mean ending Aug 14, 2025

        Data source: National Oceanic and Atmospheric Administration

  Deviation between average and normal temperature (°F)


   7-day mean ending Aug 14, 2025

Mean Temperature Anomaly (F) 7-Day Mean ending Aug 14, 2025

        Data source: National Oceanic and Atmospheric Administration

 

Monthly U.S. dry shale natural gas production by formation is available in the
Short-Term Energy Outlook.