for week ending September 9, 2001 | Release date: September 10, 2001 | Previous weeks
Spot market prices at the
Henry Hub trended upward most days last week reaching a high of $2.40 per MMBtu
on Thursday before ending the week at $2.35-20 cents higher than the previous Friday.
This increase occurred as market fundamentals were generally unchanged last
week with continued weakness in weather-related demand along with persistent
strong natural gas supplies and above average stock levels. On the weather
front moderate temperatures prevailed in most parts of the country again last
week. (See Temperature Map) (See Deviation from Normal
Temperatures Map) At the NYMEX futures market, the near-month October contract also moved
up last week to the end the week at $2.50 per MMBtu. The price of West Texas
Intermediate (WTI) crude gained $0.80 per barrel last week and finished at
$28.05 or $4.84 per MMBtu.
Prices:
At most major upstream
market hub locations last week, the spot price increased within a rough range
of between 10 and 20 cents per MMBtu, with the main exceptions being markets in
the Rockies and the San Juan Basin. Prices at most of these markets began the
holiday--shortened week trading in a range between $2.06 and $2.20 per MMBtu but moved up steadily over the next few
days. Prices reached their highs for the week on Thursday despite the lack of
any warm weather to stimulate cooling demand; indications of reduced industrial
consumption due to the overall slowing in the US economy, and recent growth in
domestic production. Prices varied by region but the trend was similar. At Katy
in East Texas, spot prices reached $2.32 before ending the week at $2.22; at
Waha in West Texas, the high was $2.22 before dropping to $2.13; and at
Midcontinent in Oklahoma a high of $2.25 dropped to $2.17. The lowest prices
were reported in the Rockies at the Opal Hub in Wyoming where prices reached a
high of $1.93 before ending the week at $1.81. At Blanco, located in the San
Juan Basin in New Mexico, prices reached $2.09 then ended the week at $1.93 per
MMBtu. Prices at major citygate markets were reported to have followed a
similar pattern at Chicago and New York City as prices gained 16 to 18 cents
per MMBtu early in the week before moving down on Friday.
Prices on the NYMEX, which have been generally trending down for several months, moved up each day last week as the settlement price for the October contract ended the week at $2.50 per MMBtu. The key winter heating months of December, January, and February settled on Friday at $3.095 per MMBtu $3.240, $3.207, respectively. Although high relative to current prices, this is a decline of more than 30 percent compared with the end of the first week in September last year, when these winter month future contracts traded for $5.187, $5.140, and $4.865, respectively.
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Storage:
The storage injection rate held steady
for a second consecutive week at an average of 11 Bcf per day, as the American
Gas Association (AGA) estimated that a net 77 Bcf of natural gas was injected
for the week ended August 31, following estimated inventory additions of 76 Bcf
during the preceding week.(See Storage Figure) According to EIA estimates based on AGA
data, total net injections for the month of August were 323 Bcf, an average of
10.4 Bcf per day. This is 24 percent
greater than the EIA 6-year (1995-2000) average of 261 Bcf for the month (8.4
Bcf per day). Net injections for the week in the East region matched the
average over the previous 6 years. Net injections in both the Producing and
West regions and for the nation as a whole exceeded their respective 6-year
averages, with the West region more than doubling its 6-year average of 3
Bcf. At an estimated 2,608 Bcf, total
working gas in storage is just 90 Bcf less than the highest EIA end-of-August
level since 1992, which was recorded in 1998. If net injections in September and October equal the EIA 6-year averages
for these months, total working gas in storage will be 3,109 Bcf as of November
1—6 percent higher than the 6-year average of 2,935 Bcf.
All Volumes
in BCF |
Current
Stocks (Fri,8/31) |
Estimated
6-Year (1995-2000) Average |
Percent
Difference from 6 Year Average |
Net Change
from Last Week |
One-Week
Prior Stocks (Fri,8/24) |
|
East Region |
1,512 |
1,497 |
1.0% |
49 |
1,463 |
|
West Region |
361 |
324 |
11.5% |
7 |
354 |
|
Producing Region |
735 |
612 |
20.1% |
21 |
714 |
|
Total Lower 48 |
2,608 |
2,433 |
7.2% |
77 |
2,531 |
|
Note: net change data are estimates published by
AGA on Wednesday of each week. All
stock-level Figures are EIA estimates based on EIA monthly survey data and
weekly AGA net-change estimates. Column sums may differ from Totals because of independent rounding.
*Revised to incorporate EIA survey data for June 2001. |
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Other Market Trends:
In the September issue of the Short Term Energy
Outlook (STEO), EIA again lowered its forecast for natural gas prices covering
the upcoming winter. The latest STEO
projects wellhead prices of $2.83 per MMBtu in the fourth quarter of 2001 and
$2.79 in the first quarter of 2002. The lower prices are forecasted to continue
throughout 2002 as the annual average wellhead price for next year is projected
to be $2.57 per MMBtu. This compares with an annual average of $3.50 in 2000
and a projected level of $4.11 per MMBtu for 2001Continued declines in
industrial consumption in 2001 coupled with elevated stock levels and increases
in domestic production have been key factors in the steady decline in projected
prices. (The complete STEO report is available on the EIA Web Site at the
"Forecasts" section.)
ection.)
Summary:
Spot prices moved up early last
week then retreated, as the relatively abundant supplies could not support this
upward trend. EIA's latest STEO forecast calls for a decline in natural gas
prices during the last quarter of this year and continuing into 2002.