Energy Market Report
Tuesday, January 8, 2002

*See attached pdf file.
__________________________________________________________
Western Pre-Scheduled Firm Electricity Prices($/MWh)
January 8, 2002 for January 9, 2002

Peak(Heavy)
                   Low     Change     High    Change
NW/N. Rockies     18.00     1.00     19.00     1.00
Mid-Columbia      18.00     1.00     19.00     1.00
COB               20.00     1.00     21.25     1.50
N. California     22.25     1.75     23.75     1.75
Midway/Sylmar       NA       NA        NA       NA
S. California     21.25     0.75     23.00     0.50
Mead              21.00     1.50     22.50     1.00
Palo Verde        20.00     1.25     22.00     0.00
Inland SW         20.00     1.25     22.50     0.50
4-Corners         20.00     2.50     21.50     0.75
Central Rockies   17.75     0.00     18.75     0.25
__________________________________________________________
Off-Peak(Light)
                   Low     Change     High    Change
NW/N. Rockies     15.00     0.50     16.00     0.75
Mid-Columbia      15.00     0.50     16.00     0.75
COB               16.50     2.25     17.00     1.00
N. California     16.50     1.00     18.00     0.75
Midway/Sylmar       NA       NA        NA       NA
S. California     15.00     0.00     17.25     0.25
Mead              14.00    -0.50     14.75    -1.00
Palo Verde        13.20    -0.80     15.00    -1.25
Inland SW         13.20    -0.80     15.00    -1.25
4-Corners         13.00    -0.50     14.00    -1.00
Central Rockies   14.25    -0.25     15.50    -0.50
__________________________________________________________
And the Winner Is???

Day-ahead peak power prices in the Western U.S. rose slightly Tuesday on
revised weather forecasts calling for colder temperatures over the next few
days.  The most significant cooling was expected in the Northwest, where
heating demand was forecast to climb to above-normal levels by week's end.
"They've got plenty of hydro in the Northwest and that's what limited the
upside, but that also means there's less power available from the north, so
our prices went up a little as well," said one Southern California utility
trader.  Many players anticipated more strength on Wednesday as the colder
weather draws closer, but most expected the upside to be limited due to the
abundant hydropower and relatively soft spot gas prices.  In other industry
news, Weil Gotshal & Manges, the lead law firm for bankrupt Enron, reported
Tuesday that multiple bids had been filed for a controlling stake in Enron
Corp.'s energy trading business.  Weil plans to announce the winning bidder
at its New York offices Thursday, and then present the offer to the U.S.
bankruptcy court in New York for approval on Friday.  Meanwhile, the court
is hearing arguments from creditors on why the case should be transferred to
Texas.  While the bids and the bidders were to remain confidential, it was
reported that Citicorp Inc. and UBS Warburg were among the suitors, though a
third financial institution that had previously expressed interest, J.P.
Morgan Chase & Co., declined to submit a bid by Monday's night's deadline.
British company BP Plc. also said it may be interested in the operations,
and had submitted a bid of $25 million for a small portion of Enron's
assets, including some back office functions and some IT assets.  Enron's
lawyers have stated that the company is not looking for cash bids, but
rather an ownership stake of up to 51 percent.

Heavy load energy costs in the Northwest rose by an average of 1$/MWh for
Wednesday delivery.  Cooler weather forecasts were near-universally blamed
for the rising dailies, though most players conceded that healthy river
flows would limit the upside.  "The colder weather is a small blessing for
sellers, but also for the region as a whole.  The recent warm weather has
caused some snowmelt, something few people want to see until the spring, and
the lower temperatures should put a stop to that," said one Northwest
trader.  According to Weather Derivatives, heating demand in the region was
expected to average 64 percent of normal Wednesday, and then rise to a peak
of 120 percent of normal by Sunday.  Flow forecasts for Chief Joseph were
little changed from a day ago, coming in at 85 kcfs through Friday, 70 kcfs
Saturday, 55 kcfs Sunday, and back up to 85 kcfs next Monday and Tuesday.

Despite lackluster trading and continued mild weather, day-ahead electricity
prices enjoyed a tempered upturn in California on Tuesday.  Gains were
modest, on the order of a dollar everywhere.  Traders cited colder
temperatures on the horizon and an incremental upswing in Western spot gas
prices as the main factors leading prices higher.  "Balance of the month is
trading at a premium to the dailies, which is usually a sign of coming
strength," said one trader.  Peak goods at NP15 were bought and sold between
22.25 and 23.75$/MWh, while the off-peak products changed hands from 16.5 to
18$/MWh.  In political news, the FERC judge for the California refund case
said he will hold evidentiary hearings through July 12, and submit his
proposal to FERC by early August.  The state accuses energy companies of
overcharging during last year's energy crisis, an allegation the companies
deny.  On a less litigious note, last month FERC asked the CAISO to come up
with a detailed plan for reforming the state's energy market.  The proposal
could be unveiled as early as late Tuesday, and would include elements of
the much-admired PJM RTO.  It would also emphasize a way to reduce
intra-zonal congestion and include a plan for a day-ahead market, although
on a smaller scale then the former one run by the CalPX.  There were no
dramatic changes in the generation landscape on Tuesday.  Moss Landing #6
(739 MW) and Etiwanda #4 (320 MW) returned to the grid, while hydro unit Big
Creek Project (1,020 MW) was operating at 970 MW.  On the weather front,
Wednesday forecasts predicted high temperatures in the mid-50s and low-60s
at mid-state load centers, and in the high-60s in the south.  Little change
was expected in temperatures through Saturday.  The most current six-to-ten
called for below-normal temperatures from January 14 to 18.

Heavy load energy costs in the Southwest rose by an average of less than a
dollar on Tuesday, with the modicum of strength chalked up to rising spot
gas prices and cooler temperatures on the horizon.  Peak power at Palo Verde
ranged from 20 to 22$/MWh, with the bulk of transactions seen right in the
middle at 21$/MWh.  Balance-of-January contracts were heard trading at about
a $2/MWh premium to the dailies on Tuesday, likely in reaction to the cooler
forecasts.  In unit news, Coronado #1 (365 MW) was in the process of
restarting Tuesday afternoon, as expected.  Four Corners #5 (750 MW) was
operating at 550 MW Tuesday due to air-preheater problems, with no available
ETR to full.  Weather Derivatives forecast heating demand in the desert
region to climb from its current level of 50 percent of normal, to just
above normal over the coming weekend, but the latest six-to-ten was still
calling for a mix of normal and above-normal temperatures from January 14
through 18.



Patrick O'Neill and Jessie Norris
_________________________________________________________

Western Generating Unit Outages

Current                            Begins          Ends          Reason
CAISO units <250/6594 total          NA             NA
planned/unplanned*
Alamitos #3/320/gas               04-Dec-01         ?            planned
Alamitos #4/320/gas               04-Jan-02         ?            planned
Coronado #1/365/coal              22-Dec-01     08-Jan-02    main
transformer
Etiwanda #3/320/gas               22-Dec-01         ?            planned
Grand Coulee #19/600/hydro        10-Dec-01       March          repairs
Haynes #6/341/gas                 07-Jan-02         ?            planned
Helms PGP #2/407/hydro            01-Oct-01         ?            planned
Hyatt/Thermalito/933/hydro        02-Oct-01         ?      @607 MW,
unplanned
Morro Bay #3/337/gas              04-Jan-02         ?            planned
Moss Landing #7/739               29-Dec-01         ?            planned
Ormond Beach #1/725/gas           28-Dec-01         ?            planned
Ormond Beach #2/750/gas           05-Oct-01         ?      @350 MW,
unplanned
Pittsburg #6/317/gas              22-Nov-01         ?            planned
Pittsburg #7/682/gas              03-Jan-02         ?            unplanned
Redondo #8/480/gas                09-Dec-01         ?            planned


For unit owners refer to pdf version.
*Indicates a change from previous EMR.
______________________________________________________________________

Eastern Markets Pre-Scheduled Firm Power Prices ($/MWh)

January 8, 2002 for January 9, 2002

Peak (Heavy) in $/MWh
                 Low     Change   High      Change
Into Cinergy    19.55    -0.95    21.25     -0.75
Western PJM     24.25    -1.25    24.85     -1.40
Into Entergy    19.00     0.00    20.00     -5.00
Into TVA        20.25    -0.75    21.50      0.00
___________________________________________________________
Amid forecasts for warmer weather on Wednesday and little else changed in
market fundamentals, heavy load energy costs drifted lower across the
Eastern Interconnect on Tuesday.  "The EIA revised the Q1 electricity demand
estimate downwards today.  That shouldn't really affect the dailies, but
sometimes its what people think will happen that matters more than what
actually does happen," suggested one market analyst, who added that he
thought weather was a greater factor in the dip in day-ahead prices.  NYMEX
Henry Hub natural gas futures settled higher on Tuesday.  February gained
0.9 cents to close at 2.281$/mmBtu, while the March contract picked up 2.4
cents to end at 2.285$/mmBtu.

Day-ahead electricity prices softened in the Mid-Atlantic on Tuesday amid
warm weather forecasts for the rest of this week and next, and on light
demand in the region.  Western PJM goods changed hands in a narrow range
between 24.2 and 24.85$/MWh.  According to traders, prices were low out of
the gate, climbed to the peak within an hour, and ended the day back down at
the low end.  No new outage information was available on Tuesday.  High
temperatures were expected in the 45 to 51 degree range in PJM on Wednesday,
and forecast to stay within five degrees of there through Saturday.  The
latest six-to-ten called for normal temperatures from January 14 to 18.

Temperatures in the Midwest were expected to climb to their highest level of
the week on Wednesday, bringing peak power prices down by about a dollar on
Tuesday.  Into Cinergy pieces for Wednesday delivery traded between 19.55
and 21.25$/MWh, dropping 0.75 and 0.95$/MWh off the high and low ends,
respectively.  The February contract gained some support Tuesday morning,
opening strong and climbing to 23.15$/MWh before dropping back down to
22.25$/MWh.  "Prior to the open, gas looked strong, and people were buying
February to cover their shorts, but gas came off fast and that was the end
of that," said one trader of the ill-fated early rally and fizzle.
Temperatures at most ECAR load centers were expected to hit the upper-40s on
Wednesday, with corresponding lows in the mid-30s.  Thursday forecasts
called for temperatures to stay near that level, while Friday was expected
to cool five to seven degrees.  The most current six-to-ten from the NWS
predicted normal temperatures from January 14 to 18.

As natural gas weakness continued to concern Southeastern traders, and
forecasts called for significantly warmer temperatures for the rest of the
week, heavy load electricity prices softened in the Southeast on Tuesday.
Into Entergy deals were done from 19 to 20$/MWh, while Into TVA deals for
Wednesday delivery were heard between 20.25 and 21.5$/MWh.  TVA prices
reached their low late in the day.  In unit news, sources said one of the
Scherer coal units (832, 833, 844, and 844 MW) was off-line but expected
back on Thursday.  The latest six-to-ten called for above-normal
temperatures from January 14 to 18.
___________________________________________________________
California ISO Congestion Index in $/MWh

                         Path                 Peak   Off-peak
for 08-Jan-02         NW1 to NP15             0.00     0.00
                      NW3 to SP15             0.00     0.00
                      AZ3 to SP15             0.00     0.00
                      LC1 to SP15             0.00     0.00
                      SP15 to NP15            0.00     0.00

for 09-Jan-02         NW1 to NP15             0.00     0.00
                      NW3 to SP15             0.00     0.00
                      AZ3 to SP15             0.00     0.00
                      LC1 to SP15             0.00     0.00
                      SP15 to NP15            0.00     0.00


OTC Forward Peak Electricity Contracts in $/MWh

                    Mid-C              PV              SP-15
                Bid      Ask      Bid      Ask      Bid      Ask
BOM            21.25    22.25    23.00    24.00    24.25    25.25
February       20.00    21.50    23.00    24.00    24.50    25.50
March          18.50    20.00    23.00    24.00    24.25    25.25
April          18.50    20.00    24.50    25.50    23.50    24.50
Q2 '02         17.50    19.00    27.00    28.00    26.50    27.50
Q3 '02         30.50    32.00    40.50    41.50    39.50    40.50
Q4 '02         26.00    27.50    27.00    28.00    28.25    29.25
Q1 '03         25.50    27.00    26.50    27.50    28.50    29.50
Cal '03        26.00    27.50    31.00    32.00    32.75    33.75

Represents the most recent bid/ask spread obtainable
by the Energy Market Report.



Alberta Power Pool Index (C$/MWh)

                    Peak(14)   Peak(16)   Off-Peak    Flat     Change
for  07-Jan-02       30.83      30.57      13.63      25.51     8.84



BPA's Offer for 01/10/02.

Hours        Amount          NW delivered        COB/NOB delivered

7-22         100MW           Market Price*          Market Price*

*Market price will be determined at time of request.



NYMEX Henry Hub Gas Futures in $/mmBtu

                 Close        Change
        Feb      2.281         0.009
        Mar      2.285         0.024



Natural Gas Spot Prices in $/mmBtu

                  Low          High
Sumas             2.02         2.07
So. Cal Border    2.18         2.23
San Juan          2.03         2.08
__________________________________________________________

Economic Insight, Inc. - 3004 SW First, Portland, Oregon 97201,
Telephone (503) 222-2425, Internet e-mail emr@econ.com -
Copyright, Economic Insight, Inc. 2002.