In the News:
Current Storage Injection Rate Is Lower than Last Year and the Five-Year Average. Since April 27, injections of working natural gas into underground storage have fallen short of both year-ago levels and the 5-year (2007-2011) average.
A warmer than normal winter, particularly in March, positioned natural gas inventories 927 billion cubic feet (Bcf) above the 5-year average near the end of the natural gas storage withdrawal season (which traditionally ends on March 31). Since then, the slower pace of injections has narrowed the overhang. While still significantly high, the surplus level dropped to 666 Bcf above the 5-year average on June 1.
The U.S. Energy Information Administration (EIA) expects this trend will continue through the end of the injection season. EIA's current Short-Term Energy Outlook projects that inventories will end the injection season at the end of October at 4,015 Bcf, which is 329 Bcf above the five-year average end-of-October levels.
(For the Week Ending Wednesday, June 13, 2012)•Natural gas prices, led by the futures market, declined moderately in nearly all markets over the week.
At the New York Mercantile Exchange (NYMEX), the July 2012 natural gas contract ended the week down 23.6 cents per million British thermal units (MMBtu) to close at $2.185 per MMBtu on June 13.
- The Henry Hub price followed the NYMEX lead, closing at $2.18 per MMBtu on June 13, down 23 cents per MMBtu for the week.
- Working natural gas in storage rose last week to 2,944 Bcf as of Friday, June 8, according to EIA's Weekly Natural Gas Storage Report (WNGSR).
An implied storage build of 67 Bcf for the week positioned storage volumes 708 Bcf above year-ago levels.
- The natural gas rotary rig count, as reported by Baker Hughes Incorporated on June 8, slid by 23 to 565 active units. Meanwhile, oil-directed rigs increased by 28 to 1,414 units.
At the NYMEX, the July 2012 contract fell from $2.421 per MMBtu last Wednesday to $2.185 per MMBtu yesterday, a decrease of 23.6 cents per MMBtu (9.7 percent) over the period.
The July 2012 contract led the futures market decline with a 9.7 percent loss on expectations that hotter weather (and greater consumption) was still elusive.
The 3-Month Strip (average of July-August-September contracts) followed suit with a 23.8 cent per MMBtu (9.6 percent) loss for the week.
Movement in the Henry Hub day-ahead price reflected a widespread decrease in market prices in this week's cash market by falling 9.5 percent, from $2.41 per MMBtu the previous Wednesday to $2.18 per MMBtu yesterday.
As the Spot Prices tab on the left shows, the Henry Hub cash price fell beginning last Thursday. During the same period, numerous other spot market pricing points exhibited similar losses.
Nearly all downstream trading locations registered lower prices as consumption dropped modestly this week. Spot prices at Transcontinental Pipeline's Zone 6 trading point for delivery into New York City, which started the week at $2.54 per MMBtu, lost $0.21 per MMBtu over the week (Wednesday to Wednesday) to close at $2.33 per MMBtu (down 8.3 percent).
Over the same period, the Chicago citygate spot price registered a 25-cent per MMBtu price loss (from $2.45 per MMBtu last Wednesday), ending the week at $2.20 per MMBtu (down 10.2 percent).
Despite increased natural gas use for power generation, total domestic consumption decreased slightly. According to estimates from BENTEK Energy LLC (Bentek), domestic natural gas consumption fell by 0.6 percent from last week.
The residential/commercial sector led the decrease, posting a 14.0 percent decline, while the industrial sector registered a 0.9 percent decrease.
The power sector, however, showed a partially offsetting 6.0 percent week-over-week gain attributed to increased power burn in key regions including the Northeast, Midwest, Southeast, and Midcontinent.
Total supply was up slightly for the week despite flat dry gas production. According to Bentek estimates, the week's average total natural gas supply posted a 0.6 percent increase from last week's level, led by a 7.5 percent increase in imports from Canada, which averaged 6.1 Bcf per day over the period. Imports from Canada stand 12.0 percent above year-ago volumes for the same week.
There was a 1.3 percent decrease in supply of liquefied natural gas (LNG) during the week, with sendout averaging 246 million cubic feet (MMcf) per day. Sendout volumes remain 70.4 percent below year-ago levels.
Anchoring these net supply gains was another week of essentially flat domestic dry gas production which averaged 63.3 Bcf per day, unchanged from the previous week and 3.4 percent above this time last year.
Working natural gas in storage increased to 2,944 Bcf as of Friday, June 8, 2012, according to EIA's WNGSR.
This represents an implied net injection of 67 Bcf from the previous week. This week's injection was 21 Bcf below the 5-year (2007-2011) average of 88 Bcf for the same week, and 5 Bcf below the injection of 72 Bcf during the same week last year.
Working inventories are currently 666 Bcf greater (29.2%) than the 5-year average level and 708 Bcf higher (31.7%) than last year at this time.
Injections in each of the three storage regions were below the 5-year average injection. The East region injected 43 Bcf (compared with a 5-year average of 56); the West injected 11 Bcf (compared with a 5-year average of 18 Bcf); and the Producing region injected 13 Bcf (compared with an average of 14). In the Producing region, stocks increased 1 Bcf in salt caverns and 10 Bcf in non-salt facilities.
Temperatures during the storage report week were cooler than both the 30-year normal and last year's temperatures. The average temperature in the lower 48 States was 66.7 degrees, 1.1 degrees below the 30-year normal and 5 degrees below last year's temperature.
The coolest areas relative to normal were New England, where temperatures averaged 57.6 degrees; and the East North Central, where temperatures averaged 60.7 degrees.