THANKS!!!!!!!!

Marie

 -----Original Message-----
From: 	"Dixon, Billy D" <billy.dixon@bp.com>@ENRON
Sent:	Tuesday, November 06, 2001 1:00 PM
To:	Heard, Marie
Subject:	RE: Enron Canada Corp

Principal Operating Offices:

BP Corporation North America Inc.
200 East Randolph Drive
Chicago, Illinois 60601

BP Energy Company
501 West Lake Park Boulevard
Houston, Texas 77079

Vastar Resources, Inc.
200 East Randolph Drive
Chicago, Illinois 60601

BP Canada Energy Company
240 - 4th Avenue S.W.
Calgary, Alberta T2P 4H4

BP Canada Energy Marketing Corp.
200 East Randolph Drive
Chicago, Illinois 60601

Cibola Energy Services Corporation
350 N. St. Paul Street
Dallas, TX 75201

IGI Resources, Inc.
200 East Randolph Drive
Chicago, Illinois 60601

BP Oil Supply Company
200 East Randolph Drive
Chicago, Illinois 60601

BP Products North America Inc.
200 East Randolph Drive
Chicago, Illinois 60601

BP Amoco Chemical Company
200 East Randolph Drive
Chicago, Illinois 60601

Atlantic Richfield Company
333 S. Hope Street
Los Angeles, CA 90071

Amoco Production Company
501 WestLake Park Boulevard
Houston, Texas 77079

BP Chemicals Inc.
200 East Randolph Drive
Chicago, Illinois 60601

-----Original Message-----
From: Heard, Marie [mailto:Marie.Heard@enron.com]
Sent: Tuesday, November 06, 2001 8:54 AM
To: billy.dixon@bp.com
Subject: RE: Enron Canada Corp

I sure will if you will tell me the principal place of business of all
your entities party to the Master Netting Agreement.

Enron Canada Corp.
3500, 400 - 3rd Avenue S.W.
Calgary, Alberta  T2P 4H2

>  -----Original Message-----
> From: 	"Dixon, Billy D" <billy.dixon@bp.com>@ENRON
> Sent:	Tuesday, November 06, 2001 7:47 AM
> To:	Heard, Marie
> Subject:	Enron Canada Corp
>
> Would you please tell me where Enron Canada Corp.'s principal place of
> business in Canada is located?
>
> Very truly yours,
>
> BILLY
> Billy D. Dixon
> Attorney
> BP America Inc.
> 501 Westlake Park Blvd., Rm 16.166
> Houston, Texas 77079
> Direct 281/366-4745
> Fax 281/366-5901
> billy.dixon@bp.com
>
> ***IMPORTANT -- THIS EMAIL AND ANY ATTACHMENTS HERETO ARE
> ATTORNEY-CLIENT
> AND/OR ATTORNEY WORK-PRODUCT PRIVILEGED AND CONFIDENTIAL.  If you have
> received this email in error, do not under any circumstances read,
> forward,
> copy, disseminate or save this email or any of its attachments.  If
> you have
> received this email in error, take the following actions: (1) reply to
> this
> email indicating that you received this email in error, and (2) delete
> and
> completely erase this email and its attachments from your computer and
> any
> backup systems or "Deleted Items" folders.
>

**********************************************************************
This e-mail is the property of Enron Corp. and/or its relevant affiliate and
may contain confidential and privileged material for the sole use of the
intended recipient (s). Any review, use, distribution or disclosure by
others is strictly prohibited. If you are not the intended recipient (or
authorized to receive for the recipient), please contact the sender or reply
to Enron Corp. at enron.messaging.administration@enron.com and delete all
copies of the message. This e-mail (and any attachments hereto) are not
intended to be an offer (or an acceptance) and do not create or evidence a
binding and enforceable contract between Enron Corp. (or any of its
affiliates) and the intended recipient or any other party, and may not be
relied on by anyone as the basis of a contract by estoppel or otherwise.
Thank you.
**********************************************************************


Im on vacation till Jan. 2.  If you want to discuss this, give me a call at the house (505) 624-0353.

 -----Original Message-----
From: 	Big-Lake, Team
Sent:	Friday, December 07, 2001 11:45 AM
To:	Campbell, Larry
Cc:	Big-Lake-Eldorado, Team
Subject:	Matrix

Larry, We will be digging up the lead lines going to the old pumps at the Ozona Station in order to install skillets. We plan to start next week. Sorry for the short notice. Would you please give one of us a call when you approve this?
Thanks, Big Lake
Ricky  cell - 915.638.5160
pager - 1.800.511.5386
 << File: EnvMatOzona.doc >>


Ugh.  We'll keep working this angle if their new attorney shows up on deck,
but I think Susan and I have done as much as can be done with Howard H.  Do
any of you know what the Red Cedar facilities look like?  I.e. how many miles
of line, any big diameter line, any compression, etc?  Howard must have read
some old cases and gotten himself spooked that their facilites aren't
gathering under the modified primary function test.  I'm not sure why he
thinks signing a transport contract with us will make their situation any
worse, but that seems to be his conclusion.  If Steve and Bill can't nudge
Red Cedar's management into doing the deal, I'd suggest that you both or one
of you ask Tsuri (sp?) to have his new lawyer call me and Susan after Howard
leaves, maybe with one of the Kinder Morgan lawyers on the phone also, and
we'll try to straighten this out.
---------------------- Forwarded by Drew Fossum/ET&S/Enron on 01/12/2000
08:37 AM ---------------------------

	From:  Susan Scott                           01/11/2000 05:29 PM

To: Drew Fossum@ENRON
cc:

Subject: Red Cedar

I regret to report that I just ended a very unproductive phone conversation
with Mr. Hertzberg.  He thanked us for all our cooperation but politely
declined to give me any information on what authority he was relying on to
conclude that there is a jurisdictional problem.  However, it sounded to me
like whatever authority he does have is shaky at best.  He also sounded
interested in the possibility of our making some sort of anonymous inquiry at
FERC (if such a thing is possible) on the issue.  Obviously they are very
leery of making that phone call themselves and risking revealing their
identity.  He said he would discuss it with Ed Meaders.  Also, he mentioned
that after tomorrow he will be on vacation for a month, and another attorney
will be taking over in his absence.  That could be good, or it could be bad.
Maybe Lorraine can sweet talk Meaders into at least citing us some cases from
Hertzberg's memo.  At the very least, I hope he will show it to the Kinder
Morgan lawyers.


FYI

DJ Calif ISO, PUC Inspect Off-line Duke South Bay Pwr Plant
Copyright , 2000 Dow Jones & Company, Inc.

LOS ANGELES (Dow Jones)--Representatives of the California Independent System
Operator and Public Utilities Commission inspected Duke Energy Corp.'s (DUK)
off-line 700-MW South Bay Power Plant in Chula Vista, Calif., Wednesday
morning, a Duke spokesman said.

The ISO and PUC have been inspecting all off-line power plants in the state
since Tuesday evening to verify that those plants are shut down for the
reasons generators say they are, ISO spokesman Pat Dorinson said.

About 11,000 MW of power has been off the state's power grid since Monday,
7,000 MW of which is off-line for unplanned maintenance, according to the ISO.

The ISO manages grid reliability.

As previously reported, the ISO told utilities and the Federal Energy
Regulatory Commission Wednesday that it would call a stage three power alert
at 5 PM PST (0100 GMT Thursday), meaning power reserves in the state would
dip below 1.5% and rolling blackouts could be implemented to avoid grid
collapse. However, the ISO said the action wouldn't result in rolling
blackouts.

The ISO and PUC also inspected Tuesday plants owned by Dynegy Inc (DYN),
Reliant Energy Inc. (REI) and Southern Energy Inc (SOE).

Duke's 1,500-MW Moss Landing plant was also inspected by PUC representatives
in June, when some units were off-line for repairs, the Duke spokesman said.

-By Jessica Berthold, Dow Jones Newswires; 323-658-3872;
mailto:jessica.berthold@dowjones.com

(END) Dow Jones Newswires 06-12-00


ESTIMATED ACTUALS

Teco Tap       24.917

When we receive actuals from Duke, I will forward them to you.


I also need to sign up for the executive impact and influence course

Thanks

---------------------- Forwarded by Hunter S Shively/HOU/ECT on 07/22/2000
08:13 PM ---------------------------

Becky Tlucek
07/20/2000 04:00 PM
To: Alonzo Williams/HOU/ECT@ECT, Andrea Ring/HOU/ECT@ECT, Andrew H
Lewis/HOU/ECT@ECT, Andrew R Conner/HOU/ECT@ECT, Ashton
Soniat/Corp/Enron@ENRON, Bhavna Pandya/HOU/ECT@ECT, Bill
Berkeland/Corp/Enron@Enron, Bill Rust/HOU/ECT@ECT, Bob Crane/HOU/ECT@ECT,
Brad McKay/HOU/ECT@ECT, Brian O'Rourke/HOU/ECT@ECT, Bruce
Hebert/GCO/Enron@ENRON, Caroline Abramo/Corp/Enron@Enron, Chad
Starnes/Corp/Enron@Enron, Charles H Otto/HOU/ECT@ECT, Charlie
Jewell/HOU/ECT@ECT, Chris Gaskill/Corp/Enron@Enron, Chris
Germany/HOU/ECT@ECT, Chris Lenartowicz/Corp/Enron@ENRON, Clint
Dean/Corp/Enron@Enron, Colleen Sullivan/HOU/ECT@ECT, Corry
Bentley/HOU/ECT@ECT, Craig Breslau/HOU/ECT@ECT, Cyril Price/HOU/ECT@ECT, Dan
Junek/HOU/ECT@ECT, Daniel Diamond/HOU/ECT@ECT, Daniel Reck/HOU/ECT@ECT,
Darren Delage/HOU/ECT@ECT, David J Vitrella/HOU/ECT@ECT, David
Ryan/Corp/Enron@ENRON, David Zaccour/HOU/ECT@ECT, Dean Laurent/HOU/ECT@ECT,
Diana Allen/Corp/Enron@ENRON, Dick Jenkins/HOU/ECT@ECT, Don
Baughman/HOU/ECT@ECT, Douglas Miller/ECF/Enron@ENRON, Douglas
SMITH/ENRON@Gateway, Ed Smith/HOU/ECT@ECT, Edward D Baughman/HOU/ECT@ECT,
Elsa Piekielniak/Corp/Enron@Enron, Eric Saibi/Corp/Enron@ENRON, Erik
Serio/Corp/Enron@Enron, Fletcher J Sturm/HOU/ECT@ECT, Frank
Ermis/HOU/ECT@ECT, Fred Lagrasta/HOU/ECT@ECT, Gary Hickerson/HOU/ECT@ECT,
Geoff Storey/HOU/ECT@ECT, George Hopley/HOU/ECT@ect, George
McClellan/HOU/ECT@ECT, George N Gilbert/HOU/ECT@ECT, George
Wood/Corp/Enron@Enron, Gerald Gilbert/HOU/ECT@ECT, Greg
Trefz/Corp/Enron@ENRON, Greg Whalley/HOU/ECT@ECT, Greg Woulfe/HOU/ECT@ECT,
Gretchen Lotz/HOU/ECT@ECT, Hunter S Shively/HOU/ECT@ECT, James E
Terrell/HOU/ECT@ECT, Jane M Tholt/HOU/ECT@ECT, Janel
Guerrero/Corp/Enron@Enron, Janelle Scheuer/HOU/ECT@ECT, Jared
Kaiser/HOU/ECT@ECT, Jason Choate/Corp/Enron@ENRON, Jason
Crawford/Corp/Enron@Enron, Jay Reitmeyer/HOU/ECT@ECT, Jay
Wills/Corp/Enron@ENRON, Jeff King/Corp/Enron@Enron, Jeff
Kinneman/HOU/ECT@ECT, Jeffrey A Shankman/HOU/ECT@ECT, Jennifer
Fraser/HOU/ECT@ECT, Jennifer Shipos/HOU/ECT@ECT, Jim Homco/HOU/ECT@ECT, Joe
Errigo/Corp/Enron@Enron, Joe Parks/Corp/Enron@ENRON, Joe
Stepenovitch/Corp/Enron@Enron, John Arnold/HOU/ECT@ECT, John
Berger/HOU/ECT@ECT, John Craig Taylor/HOU/ECT@ECT, John D Suarez/HOU/ECT@ECT,
John Grass/Corp/Enron@ENRON, John Greene/HOU/ECT@ECT, John
Kinser/HOU/ECT@ECT, John Llodra/Corp/Enron@ENRON, John M
Singer/Corp/Enron@ENRON, John Zufferli/HOU/ECT@ECT, John Zurita/HOU/EES@EES,
Juan Hernandez/Corp/Enron@ENRON, Judy Townsend/HOU/ECT@ECT, Kate
Fraser/HOU/ECT@ECT, Kayne Coulter/HOU/ECT@ECT, Keith
Comeaux/Corp/Enron@Enron, Keith Holst/HOU/ECT@ect, Keller
Mayeaux/Corp/Enron@Enron, Kelli Stevens/HOU/ECT@ECT, Kevin
Cline/Corp/Enron@Enron, Kevin M Presto/HOU/ECT@ECT, Kevin
McGowan/Corp/Enron@ENRON, Kyle Schultz/HOU/ECT@ECT, Larry
Jester/Corp/Enron@ENRON, Larry May/Corp/Enron@Enron, Larry
Valderrama/HOU/ECT@ECT, Laura Podurgiel/HOU/ECT@ECT, Lawrence
Clayton/Corp/Enron@Enron, Lisa Burnett/Corp/Enron@Enron, Lisa
Lees/HOU/ECT@ECT, Lloyd Will/HOU/ECT@ECT, Lucy Ortiz/HOU/ECT@ECT, Madhup
Kumar/Corp/Enron@ENRON, Madhur Dayal/HOU/ECT@ECT, Marc Bir/Corp/Enron@ENRON,
Maria Valdes/Corp/Enron@Enron, Mark Anthony Rodriguez/HOU/ECT@ECT, Mark Dana
Davis/HOU/ECT@ECT, Mark Smith/Corp/Enron@Enron, Mark Symms/Corp/Enron@ENRON,
Martin Cuilla/HOU/ECT@ECT, Matt Lorenz/HOU/ECT@ECT, Matthew
Arnold/HOU/ECT@ECT, Matthew Goering/HOU/ECT@ECT, Maureen Smith/HOU/ECT@ECT,
Michael W Bradley/HOU/ECT@ECT, Michelle D Cisneros/HOU/ECT@ECT, Mike
Carson/Corp/Enron@Enron, Mike Curry/HOU/ECT@ECT, Mike
Fowler/Corp/Enron@ENRON, Mike Grigsby/HOU/ECT@ECT, Mike
Maggi/Corp/Enron@Enron, Mitch Robinson/Corp/Enron@Enron, Nelson
Ferries/Corp/Enron@ENRON, Patrice L Mims/HOU/ECT@ECT, Patrick
Hanse/HOU/ECT@ECT, Paul Pizzolato/HOU/ECT@ECT, Per Sekse/NY/ECT@ECT, Peter F
Keavey/HOU/ECT@ECT, Phillip K Allen/HOU/ECT@ECT, Pushkar Shahi/HOU/ECT@ECT,
Randall L Gay/HOU/ECT@ECT, Richard Hrabal/HOU/ECT@ect, Robert
Benson/Corp/Enron@ENRON, Robin Barbe/HOU/ECT@ECT, Rogers Herndon/HOU/ECT@ect,
Ronald Acevedo/LON/ECT@ECT, Sandra F Brawner/HOU/ECT@ECT, Scott
Goodell/Corp/Enron@ENRON, Scott Hendrickson/HOU/ECT@ECT, Scott
Neal/HOU/ECT@ECT, Steve Olinde/Corp/Enron@Enron, Steven Kleege/HOU/ECT@ECT,
Steven P South/HOU/ECT@ECT, Susan W Pereira/HOU/ECT@ECT, Susan
Wood/HOU/ECT@ECT, Sylvia S Pollan/HOU/ECT@ECT, Sylvia S Pollan/HOU/ECT@ECT,
Tammi DePaolis/Corp/Enron@ENRON, Terri Clynes/HOU/ECT@ECT, Theresa
Branney/HOU/ECT@ECT, Todd DeCook/Corp/Enron@Enron, Tom Donohoe/HOU/ECT@ECT,
Tom Dutta/HOU/ECT@ECT, Tom May/Corp/Enron@Enron, Tom Mcquade/HOU/ECT@ECT,
Tori Kuykendall/HOU/ECT@ECT, Troy Black/Corp/Enron@ENRON, Wayne
Herndon/Corp/Enron@ENRON, William Patrick Lewis/HOU/ECT@ECT, William
Stuart/HOU/ECT@ECT
cc: Jeffrey T Hodge/HOU/ECT@ECT, Mark E Haedicke/HOU/ECT@ECT, Mark
Frevert/NA/Enron@Enron, David W Delainey/HOU/ECT@ECT, John J
Lavorato/Corp/Enron@Enron
Subject: Antitrust Training

Please see the attached memo regarding the Antitrust Training.


Per Duke Energy Field Services, we can ramp up after the outtage and keep
the meter whole at 20M, if we choose.

Mary


Dennis:  Here are the new numbers for the admin contract,  basically  subtract 4118 from poi 78093 & add it to 58646, for the contract term 6/1/2002 to 12/31/2999.  Have fun!  PT 3-0667

	Adm cr# 27698
3/1/2002				POI's	58646	58647	58649	78093
						WTX	PH	Agave	EPFS/Eddy
	6/1/2002	6/30/2002		46552	53300	15000	5148	120000
	7/1/2002	10/31/2002		86552	13300	15000	5148	120000
	11/1/2002	2/28/2003		86552	13300	15000	5148	120000
	3/1/2003	5/31/2003		86552	13300	15000	5148	120000
	6/1/2003	3/31/2004		87847	15300	15000	1853	120000
	4/1/2004	5/31/2017		82847	20300	15000	1853	120000
	6/1/2017	6/30/2017		80147	23000	15000	1853	120000
	7/1/2017	12/31/2999		40147	63000	15000	1853	120000

-----Original Message-----
From: Lokay, Michelle
Sent: Friday, March 01, 2002 10:48 AM
To: Lee, Dennis; Frazier, Perry; Buehler, Craig
Subject: Amendment to TW#27608

Approved.  Please generate amendment for Western's Redrock expansion contract #27608, effective 06/01/2002.  This amendment will now change their 10,000 MMBtu/day contract to have all receipts in the West Texas Pool #58646.  Effective ending date will be the term of the contract, through 05/31/2017.  Thanks.

-----Original Message-----
From: Terri Dickerson [mailto:TDICKERS@westerngas.com]
Sent: Friday, March 01, 2002 10:21 AM
To: Lokay, Michelle
Subject: Redrock

Michelle:  This e-mail is to inform you that I would like to adjust my Redrock Receipt point for the total volume of 10,000 MMBtu/d to the Permian West Texas Pooling point consistent with our oral discussion.

Thank you. Terri Dickerson


Note:  The following was sent out by CERA and has a short term forecast of
prices and alternate fuel pricing.  Note the price differential forecasts by
basin.

**********************************************************************
CERA Alert: Sent Wed, November 15, 2000
**********************************************************************

Title: Midmonth Report: Early Warning
Author: N. American Gas Team
E-Mail Category: Alert
Product Line: North American Gas ,
URL: http://www.cera.com/cfm/track/eprofile.cfm?u=5526&m=1420 ,

Alternative URL:
http://www.cera.com/client/nag/alt/111500_18/nag_alt_111500_18_ab.html
*********************************************************

After a warm October, the first cold weather this year
has provided an early warning of what winter could bring
for the gas market. Cold weather across much of the
great plains and a cold forecast for larger heating
markets in the Midwest and Northeast have driven a surge
in gas prices of more than $1.00 per million British
thermal units (MMBtu) over the past week. This rebound
in price highlighted the continued tightness of supply
and moved the price of gas back above that of residual
fuel oil, assuring that dual-fuel loads remain off of
gas. Supplies for the winter are not adequate to allow
most dual-fuel end users to burn gas. If this cold snap
extends through the remainder of November, a heavy
early-winter draw on storage could set the stage for
unprecedented high prices through the winter.

Though storage inventories have reached near the 2,750
billion cubic feet (Bcf) level, they remain at a record
low heading into the heating season, and even a normal
winter would reduce inventories to a near record or
record absolute low by spring. This supply tightness
places the gas price playing field in the broad
territory above the resid price (near $5.00 in the Gulf
Coast) and into a range potentially testing the next,
difficult level of demand resistance. This resistance
could come from switching to distillate oil, but low
distillate inventories and high distillate prices mean
that switching would require a gas price above $7.50 per
MMBtu, and any move to switch to distillate would likely
drive prices of both commodities higher. Rather, a
combination of some switching to resid in industrial
boilers and a shutdown of a few more price-sensitive end
users may be required. None of these measures comes
easily or cheaply, however, and they can be overwhelmed
by weather-driven swings in demand. As a result, as cold
weather settles in, CERA expects heightened price
volatility at levels above the price of resid and
extreme sensitivity in the market to weather and weather
forecasts. Under normal weather conditions, CERA expects
Henry Hub prices to average $5.70 during December (see
Table 1), which by itself would represent an all time
high for December. But even this estimate could prove
low. If the current cold snap extends through early
December, prices could easily climb into the $6.50-$7.00
per MMBtu range.

Gas Storage-The Record Low Maximum
CERA estimates that storage inventories reached a
maximum of 2,746 Bcf as of the end of October, a record
low for that month by 64 Bcf (see Table 2). Even this
level was reached only through a fortunate combination
of a lack of storms in the Gulf of Mexico and consistent
warmth through most of October. The withdrawal season is
likely to have begun this week, however, and in a strong
way. The cold weather now settling in is likely to
offset warmth early this month, increasing the
withdrawal rate this November to 3.5 Bcf per day on
average, well above the 1.0 Bcf per day average rate of
the past two years. By the end of this month, the US
inventory deficit is likely to have widened again, to
350 Bcf.

CERA estimates that normal December weather would
require storage withdrawals of approximately 17.0 Bcf
per day, which is above last year's rate of 16.6 Bcf per
day. This year, however, this withdrawal rate would
apply consistent pressure in the market through December
and beyond, as it would keep inventories on a path to
reach 756 Bcf by the end of March, just below the 1996
all-time end-of-March low of 758 Bcf. So long as
inventories remain on this path the pressure does not
end even with the end of winter, as a significant
increase in injections next year would be required for
inventories to reach even 2.6 trillion cubic feet (Tcf)
by next fall. Although the supply build will begin to
help by late winter, it is unlikely to be of the
magnitude required both to offset power generation
demand growth and to allow this increase in storage
injections to occur-unless demand continues to be priced
out of the market.

Demand-Keeping Warm
After last year's warm winter, CERA expects a strong
rebound in heating demand, and this week's weather and
forecast reinforce that expectation. Weather last winter
(November through March) was the warmest of the decade,
and there will be a significant rebound in heating
demand in the residential and commercial sectors as
weather returns toward normal this heating season.

Under normal weather conditions,
* Average heating demand through the winter would be 3.5
Bcf per day higher than last year's.

* Monthly average heating demand through the winter
would be 36.7 Bcf per day, peaking at 45.6 Bcf per day
in January.

* December heating demand would increase by 4.8 Bcf per
day relative to last December.

Weather 5 percent colder than normal could further
increase December demand by 1.8 Bcf per day relative to
normal weather; likewise, a 5 percent warmer-than-normal
scenario could decrease demand by 1.7 Bcf per day
relative to normal weather.

Fuel Switching
With natural gas markets this tight, there is
significant pressure for demand to be backed out of the
market. Residential and commercial demand is inelastic
to price in the short run, which leaves industrial
demand and power demand as the only relief valve for the
market. This winter we expect

* all plants capable of burning residual fuel oil as an
alternative to gas to do so

* a loss of 700 million cubic feet (MMcf) per day of
demand for power generation relative to last winter

* industrial consumers to switch the equivalent of 500
MMcf per day off of gas

* gas prices to act as a ceiling for residual fuel oil
prices, as much as resid will act as a floor for gas

For December CERA expects an overall demand increase of
4.5 Bcf per day relative to last December and a 14.4 Bcf
per day increase in demand relative to November, with
increasing heating load offset somewhat by fuel
switching.

Supply-The Rebound
The pressure from increasing demand and lower storage
inventories is intense, but US supply is beginning to
rebound. The recent steep decline in US lower-48
capacity is expected to reverse in late 2000, given the
soaring gas-related rig count.

* The success in reversing the decline in the Gulf of
Mexico is related to the combination of

- the ramp-up of the Hickory and Tanzanite subsalt
discoveries on the shelf, adding to the recent startup
of the Muni field; these fields could add over 0.5 Bcf
per day later in 2001

- the response of the shallow water to the strong
late 1999 turnaround in drilling activity

* Other important capacity additions are occurring in
the deepwater Gulf of Mexico, with 0.5 Bcf per day in
2000 and 2001, and onshore, led by the Bossier sand play
in Freestone County, Texas, the Barnett Shale play in
Wise County, Texas, and the Powder River Basin coal seam
play.

* Further increases in drilling are likely to slow. New
deep land rigs are under construction and shallow rigs
are being refurbished with cannibalized parts from older
rigs. Producers are experiencing delays in obtaining
rigs as the supply of quality rigs depletes and drilling
companies struggle to round out drilling crews.

Regional Markets-Wild Winter in the West
Extremely cold weather in the West has brought Rockies
prices close to parity with Henry Hub prices and
triggered early season spikes at Sumas in the north and
Topock in the south. Pipeline maintenance on El Paso is
exacerbating the regional demand pressure and has
contributed to Topock differentials of over $2.00 per
MMBtu. Tight pricing relationships to the Henry Hub in
the San Juan and Rocky Mountains should hold through
February, with significant widening in differentials as
heating loads decline.

Winter has arrived in earnest across North America, but
the start-up of firm transportation service on Alliance
is delayed once again, this time until December 1.
Nonetheless, flows on the pipeline are under way; CERA
estimates that flows during October averaged 450 MMcf
per day. During November that total should climb to 750
MMcf per day, despite the later published start date.
With or without Alliance flows, a weather-driven rebound
in midwestern demand relative to November and December
last year should keep prices in Chicago at a significant
premium to Henry Hub prices. In the Northeast,
differentials remain extremely strong and exposed to
spikes throughout the winter, despite greater flows into
the region from Atlantic Canada this year (see Table 3).

CERA's outlook by region follows:
* Rockies. Very cold weather within the region has
brought Rocky Mountain prices near parity with Henry Hub
prices. A break in the cold or a cold snap in the East
will likely widen the differentials, but strong heating
demand in the region will keep differentials within
about $0.25 per MMBtu below the Henry Hub price. CERA
expects a December average differential of $0.25 per
MMBtu; however, this differential is expected to show
significant volatility based on regional weather. A warm
week in the Rockies could still push differentials
toward $0.50 per MMBtu.

* San Juan. San Juan prices will continue to hold close
to Rockies prices through the winter, with significant
pipeline capacity between the two regions. Heating loads
in the Rockies will determine the San Juan to Henry Hub
differential, with extended cold weather in the Rockies
pulling both prices close to the Henry Hub price. CERA
expects the December differential in the San Juan Basin
to average $0.20 per MMBtu.
* Permian and Mid-Continent. Unlike prices within the
rest of the West, differentials between the Henry Hub
and the Mid-Continent and Permian Basins are likely to
trade within a relatively narrow range during the
winter, as supplies from those basins are pulled either
east or west, depending on regional weather. CERA
expects a Permian to Henry Hub differential of $0.11 per
MMBtu and a Mid-Continent differential of $0.08 per
MMBtu for December.
* Chicago. Alliance flows into the Chicago market are
now running close to 750 MMcf per day. However, the
onset of the heating season has offset those increased
flows and pushed Chicago differentials up to near $0.15
per MMBtu relative to the Henry Hub, despite delays in
the completion of the Vector pipeline. CERA expects the
strong pricing at Chicago to continue, and December
differentials should average $0.25 per MMBtu.

* Northeast markets. Assuming normal weather, we expect
to see December basis for New York relative to Henry Hub
at $1.03 per MMBtu. New England will likely see prices
$0.05-$0.15 higher, depending on the pipeline. Much of
this increased basis differential is caused by fuel
costs. For example, with a 9 percent retention rate from
the Gulf Coast into New England, last December would
have seen retention costs of approximately $0.22; at
$5.70, that same retention equates to $0.50. Despite
additional volumes of gas deliverable into the Northeast
from the Atlantic Canadian fields, there have been no
additional regional pipeline facilities to deliver this
gas to the local markets, and an additional 166,000
MMBtu per day of potential demand will compete for the
capacity. Because of this tightness, should this month's
weather be colder than normal, we could see severe
spikes in basis similar to those seen in January 2000.
These spikes could even exceed the highs seen in
January, depending on the severity of any cold snaps and
the extent to which new electric loads are realized.

Canadian Markets-Winter Begins
The colder-than-normal weather has increased demand in
western Canada but is only now being felt in the East.
Storage peaked in the West in early October at
approximately 225 Bcf below last year's level and 6 Bcf
below the five-year average. Even with modest
withdrawals since that time, storage inventories are
still estimated to be adequate to meet winter needs.
Easter Canadian storage has continued to grow, pushing
levels to over 245 Bcf, 11 Bcf above last year and well
above the five-year average. With the eastward movement
of the colder weather, withdrawals are likely to begin.
This higher level of eastern storage will be useful with
the expected reduction of flows on TransCanada.

The good news resulting from the cold is a more normal
"freeze-up," which bodes well for a longer winter
drilling season. Gas well completions are expected to
reach 8,500 for 2000 and will likely be even higher next
year.

Further Delays for Alliance?
The "commercial" in-service date for Alliance has been
delayed until December 1, the result of a combination of
problems with clearing the line, delays in the
completion of the Aux Sable liquids extraction plant,
the delay of Vector, and a lack of supply. The pipeline
has been flowing gas, however, with volumes building up
since September. It is estimated that flows for November
will average 750 MMcf per day. TransCanada has taken the
full brunt of the Alliance flows so far, with Northern
Border and PGT remaining strong. December should see
Alliance flows build to between 900 and 1,000 MMcf per
day, with modest reductions in flows on Northern Border
and PGT. Storage withdrawals will likely keep
TransCanada reductions close to 350 MMcf per day, year-
over-year, until Vector begins service to eastern
Canada.

High Prices: Strong Pull West
The high demand in the Pacific Northwest has also
provided strength for AECO. The AECO-Henry differential
has dropped to the high $0.30s and low $0.40s as a
result of this increased pull. For December, the
differential is expected to average $0.50 per MMBtu, for
a resulting AECO average of C$6.97 per gigajoule
(US$5.10 per MMBtu).

**end**

Follow URL for PDF version of this message with associated Tables.

*********************************************************
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http://www.cera.com/event
*********************************************************

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Rick/George,

Below is this weeks iPayit update report

Overall, the Accounts Payable process continues to improve and appears to be heading toward a steady state. Though on a daily basis we continue to take calls regarding errors which have occurred and/or confusion as to why things happen like they do in this new process, overall these calls and issues are occurring at a much reduced  pace. We are continuing to see improvements in the overall aging of invoices sitting in in the various stages of the accounts payable process including document handling, transaction processing, support group and employee iPayit inboxes. Additionally, the call center is consistently answering calls well within the established service level agreements.

Primary areas of focus:
1) Monitor and manage the various stages of the process and ensure that invoices are flowing through each stage within an acceptable time frame.
2) Continue to network and assist the business units in addressing questions/issues/problems
3) Assess effectiveness of non-routine AP transaction processing tasks which SourceNet is attempting to perform and make necessary mid-course changes (i.e. P-Card expense allocation journal entries, etc.
4) Complete system integration audit verifying proper transfer of information from the various components of the iPayit platform (FileNet, SAP and iPayit).
5) Implement processes and procedures for all return check/void check/refunds handling. Assign roles and responsibilities for GSS/Accounting/Treasury/SourceNet
6) Improvements in the turn-around time with call center ticket which are escalated
7) Evaluate the benefits of migrating the AP pricing model to transaction based verses the current cost/plus model

Attached for your information is the "Drain the Swamp" scorecard for the period ending October 23rd.

Please advise if you have any questions or if you need any additional information.

Thank You
John


David:
Here is the language that I would recommend for the "backup" letter that we
discussed this afternoon that our counterparties would send to us:

We hereby confirm that the confirmations that have been sent by you to us in
connection with the transactions that are described on Exhibit A attached
hereto correctly set forth the terms of the transactions between
_______________________ and Enron North America Corp. confirmed thereby.

In drafting this, I am assuming that the information that would be on Exhibit
A would be something like the deals numbers and perhaps trade dates.

Carol


We are attaching the following:
1. Revised draft of the Letter Agreement (marked against the drafts of 4/11
and 4/12)
2. ENA Promissory Note (marked against the draft of 4/12)
3. First Amended and Restated LLC Agreement (marked against the draft of
4/12)
4. Escrow Agreement (marked against the draft of 4/12)
5. NorSub Promissory Note (marked against the draft of 4/12)

We have no comments with respect to the Guaranty (other than the request
that the "IN WITNESS WHEREOF" appears with the signature block).

We look forward to discussing the attachments with you on Monday.
 <<Letter Agreement.DOC>>  <<blackline against April 11 draft.DOC>>
<<blackline against April 12 draft.DOC>>  <<blackline E Note.DOC>>
<<E-Note.DOC>>  <<blackline LLC Agreement.DOC>>  <<LLC Agreement.DOC>>
<<Escrow Agreement.DOC>>  <<blackline - Escrow Agreement.DOC>>  <<Promissory
Note.DOC>>  <<blackline - Promissory Note.DOC>>

"paulhastings.com" made the following annotations on 04/13/01 23:10:37
------------------------------------------------------------------------------
NEW E-MAIL ADDRESSES AT PAUL, HASTINGS, JANOFSKY & WALKER LLP

We have changed our e-mail address.  Our new domain name is
paulhastings.com.  In most cases, our address is composed of conventional
first name and last name plus @paulhastings.com.  Here are two examples:
janesmith@paulhastings.com and danjones@paulhastings.com.  If you have any
questions, please contact us at noc@paulhastings.com.

==============================================================================
"The information transmitted is intended only for the person or entity to
which it is addressed and may contain confidential and/or privileged
material. Any review, retransmission, dissemination or other use of, or
taking of any action in reliance upon, this information by persons or
entities other than the intended recipient is prohibited. If you received
this in error, please contact the sender and delete the material from all
computers."

==============================================================================

 - Letter Agreement.DOC
 - blackline against April 11 draft.DOC
 - blackline against April 12 draft.DOC
 - blackline E Note.DOC
 - E-Note.DOC
 - blackline LLC Agreement.DOC
 - LLC Agreement.DOC
 - Escrow Agreement.DOC
 - blackline - Escrow Agreement.DOC
 - Promissory Note.DOC
 - blackline - Promissory Note.DOC


Effective today, I am designating Janel Guerrero as the primary point person for Enron's comprehensive RTO efforts.  In this capacity, she will be coordinating all of the advocacy functions outside of the FERC mediation process. This effort is absolutely of the highest priority for the company. Please cooperate with Janel to the fullest and coordinate with her  on all of your strategic efforts and communications that are related to the RTO effort.

Thanks very much.

Additional details regarding our RTO campaign will be emailed to you later today.


please approve this for me or come help me to approve it.

thank you

scott

 -----Original Message-----
From: 	enron_update@concureworkplace.com@ENRON
Sent:	Thursday, November 01, 2001 8:42 AM
To:	Neal, Scott
Subject:	<<Concur Expense Document>> - Travel

The following expense report is ready for approval:

Employee Name: Chris L. Germany
Status last changed by:  Automated Administrator
Expense Report Name: Travel
Report Total: $436.02
Amount Due Employee: $436.02

To approve this expense report, click on the following link for Concur Expense.
http://expensexms.enron.com


Laurel:

Jason is ready to send comments on this agreement requested by John Greene.
Can you please provide Jason with the name, address, fax number of the party
with whom we should be communicating in order to negotiate this agreement.
If you need to speak with Jason, you can call him at (713) 220-4124.

Thanks.  Sara


Susan:

Please send the foregoing list to Richard.  Thanks.

Sara Shackleton
Enron Wholesale Services
1400 Smith Street, EB3801a
Houston, TX  77002
Ph:  (713) 853-5620
Fax: (713) 646-3490


fyi
 -----Original Message-----
From: 	Anderson, Diane
Sent:	Wednesday, November 14, 2001 3:51 PM
To:	Theriot, Kim S.; Wallumrod, Ellen
Subject:	FW: Highlights from ENE Analyst Conference Call 11/14

 -----Original Message-----
From: 	Mills, Bruce
Sent:	Wednesday, November 14, 2001 2:40 PM
To:	Best, Kristine; Hayman, Kendra; Bowen, Bob; Anderson, Diane
Subject:	FW: Highlights from ENE Analyst Conference Call 11/14

 -----Original Message-----
From: 	Williams, Jason (Trading)
Sent:	Wednesday, November 14, 2001 2:34 PM
To:	Mills, Bruce
Subject:	FW: Highlights from ENE Analyst Conference Call 11/14

 -----Original Message-----
From: 	Tucker, Patrick
Sent:	Wednesday, November 14, 2001 11:44 AM
To:	Pollan, Sylvia S.; Culotta, Lindsay; Murrell, Russell E; Plachy, Denver; Cuilla, Martin; Storey, Geoff; Yawapongsiri, Virawan; Mahmassani, Souad; Donohoe, Tom; Ruscitti, Kevin; Shively, Hunter S.; Lewis, Andrew H.; Giron, Darron C.; Frihart, Bryant; Roberts, Linda; Luce, Laura; Hogan, Irena D.; Vickers, Frank; Williams, Jason (Trading); Mims, Patrice L.; Simpson, James; Hodge, John; Keavey, Peter F.; Mckay, Brad; Mckay, Jonathan; Pereira, Susan W.; Pimenov, Vladi; Ring, Andrea; Savvas, Leonidas; Townsend, Judy; Versen, Victoria; Barbe, Robin; Concannon, Ruth; Goodell, Scott; Jones, David; Kaiser, Jared; Loving, Scott; Bates, Kimberly; Muhl, Gil; Smith, Maureen; Smith, Shauywn; Taylor, Craig; Willis, Jim; Tucker, Patrick; McCaffrey, Deirdre; Penman, Gregg; Kinsey, Lisa; Brady, Kevin; Pendergrass, Cora
Subject:	Highlights from ENE Analyst Conference Call 11/14

Here are my notes from today's call.  As with Monday, I've focused on getting them out as quickly as possible rather than taking extra time to re-organize them by subject.

Enron's business has been grouped into three buckets:  Core, Non-core, and Under Review.
Core:  Wholesale energy business in North America and Europe, retail energy, pipelines
Non-core:  Broadband, water, and international assets (i.e. EGAS).  Enron has approx. $8Bn in investments in these assets, and they have produced 'dismal' returns.  Enron will be exiting these businesses and will attempt to wind them up in an orderly fashion.  An aggressive divestiture program has been set in motion for these assets.
Under Review:  EGM, EIM.  These businesses are being closely examined to determine whether they have a reasonable chance of long-term viability.  Required resource levels are being carefully studied.  Following review, Enron will move the different portions of these businesses to core or non-core as the analysis dictates.
Approximately $800MM of asset sales are under contract and expected to close in the fourth quarter.  These include a gas LDC in Brazil, EcoElectrica, and our Indian E&P assets.
Enron is in active pursuit of an additional private equity infusion of $500MM-1Bn.  Given the current environment, raising equity in the public markets would be 'inefficient', McMahon says.
Short-term liquidity is provided by the $3Bn of credit drawn upon a few weeks ago, the $1Bn of new debt, and the $1.5Bn equity infusion from Dynegy.  Longer-term, the proceeds from the sale of PGE will provide liquidity.  Asset sales over the next year will be used to pay down debt.
McMahon described the major off-balance-sheet vehicles:
Marlin was set up to hold Azurix assets.  It was initially capitalized with $950MM of 144a debt and $125MM of equity (raised from Enron and institutional investors).  The debt is supported by the equity and by Azurix' assets.  Enron is obligated to cover any deficit at the time the debt becomes due on 3/17/03 (the 'Enron topup' obligation).  The 3/17/03 date is accelerated in the event that Enron is rated below-investment-grade by any one of the three major agencies.  The primary asset of Marlin is Wessex Water.  As long as Wessex is worth at least $2.6Bn, there will be no Enron topup required.  If we take a 25% haircut to present book value, Enron will have to provide $650MM in consideration upon retirement of the debt.  This $650MM would hit Enron cash, income, and equity balances.
Osprey contains energy-related assets and 'other assets'.  It was initially capitalized with $2.4Bn of 144a debt and $220MM in equity (ENE and institutionals).  As with Marlin, the entity is an asset-backed structure with an Enron topup guarantee. The debt is supported by a) the assets; b) $1Bn of convertible preferred ENE (convertible into 50MM shares of ENE common); and c) additional ENE common as needed for topup.  Assuming the same 25% hypothetical haircut to current book value, Enron would have to deliver approx. $600MM of topup funds--which would hit ENE cash, income, and equity.  The debt must be retired by 9/17/02, with the same cut-to-junk early trigger provision as Marlin.
Yosemite and the Credit-Linked Notes are predominantly commodity transactions entered into with 'large financial institutions'.  The underlying transactions are already on Enron's balance sheet.  McMahon says that there is no Enron share obligation related to these instruments.
Dynegy has reviewed all of these vehicles, McMahon says.
Our 10Q will be filed five days late.  The 10Q will include all of this detail regarding the off-balance-sheet vehicles.
The special committee investigation is still ongoing.  The committee meets 2-3 times/week, sometimes more often.  The outside auditors (D&T) and external counsel hired by the committee are working 'virtually 7 days a week'.  Lay estimates that it will take the committee several more weeks to complete its investigation.
McMahon says it's 'way too early to tell' if any asset writedowns are called for.  That analysis is underway, but it will not be complete for some time.
Osprey contains the European power projects (Trakya and Saarlux), some North American merchant investments, and some Brazilian assets.
Under the merger agreement, Enron cannot dispose of assets representing more than 15% of the balance sheet without Dynegy approval.  However, an appendix to the agreement holds a list of assets that are specifically permitted to be sold without Dynegy approval.
Broadband is expected to be fully wound up 'sometime over the course of the next year'.  (Did not catch this part clearly).
The ENE topup obligation for Marlin (represented by ENE common that would have to be delivered) will be converted into an obligation for an equivalent amount of DYN shares upon closing.
$1.9Bn of debt is carried at the Azurix level.
Current book value of the Osprey assets is $2.1Bn.
No Dynegy outs other than the previously discussed general MAC clause and the $3.5Bn legal liability clause.
Yosemite and the Credit-Linked notes are functionally equivalent to ENE senior unsecured debt (this section somewhat unclear).  The underlying transactions represented volumes of 'crude oil and gas'.  The transactions relate to the 'physical movement' of these commodities.  The swaps related to Yosemite and the CLNs would be financially settled.
Whalley was asked about the return of trading business to normal volumes.  He said that he cannot yet give an update on the progress of customers returning to our longer-term products.  Acknowledges that a few anxious customers put long-term deals on hold last week.  Says that our first focus is on getting our short-term business back up to normal levels.  It will be 'a couple of weeks' before we're able to give an update on the comfort levels of our customers regarding long-term deals with us.
McMahon:  There hasn't been a major relaxation of credit requirements by our customers--credit requirements continue to follow strict contractual provisions as called for in our individual agreements with our various customers.  But 'we have seen a return of some of the transactions, some of the flows.'
Whalley says that we're hoping to see a return to more normal trading levels late this week or early next week.
Lay says that cost cuts will be made across of all of our businesses.  The situation gives us an opportunity to review our entire cost structure, he says.  The cuts will certainly be deeper in our non-core businesses.  Whalley then quickly interjects (some might say interrrupts) with a clarification that there are no plans to reduce the size of our North American energy trading business.  We will be looking at, perhaps, streamlining some of our processes and making prudent adjustments, but there are no plans to reduce the size of the business.
McMahon:  "The company is overlevered; that's a fact."--hence our pursuit of additional equity.
McMahon mentions that business was better at the start of this week than at the end of last week.
ENE had approx. $1Bn in cash as of 9/30, which McMahon points out would be unusual for us.

As before, give me a call at 3-3055 if you'd like more color.

Patrick Tucker


Thank you for the fax of Wheatland O&M Contract.

A fax was also received of water analysis.  What plant is this for?

Please note that my fax number is 724-830-5402.

Thanks.

Tom Irwin
724-838-8488
724-830-5402 fax
tirwin@alleghenyenergy.com


Thanks for your voice mail.  In case you are wondering what my former
secretary and long time friend thinks of me .... This goes with a bigger
story I will tell you about sometime when I can.  Talk to you later.

----- Forwarded by Elizabeth Sager/HOU/ECT on 09/05/2000 10:35 AM -----

	"DAVID, GAIL" <gdavid@mdck.com>
	09/05/2000 09:24 AM

		 To: "'elizabeth.sager@enron.com'" <elizabeth.sager@enron.com>
		 cc:
		 Subject: Managers

this made me think of you...

  All in good humor:
  A man in a hot air balloon realized he was lost.  He reduced
altitude and spotted a woman below.  He descended a bit more and shouted,
"Excuse me, can you help me?  I promised a friend I would meet him an hour
ago, but I don't know where I am."
  The woman below replied, "You are in a hot air balloon
hovering approximately 30 feet above the ground.  You are between 40 and 41
degrees north latitude and between 59 and 60 degrees west longitude."
  "You must be an engineer," said the balloonist.
  "I am," replied the woman.  "How did you know?"
  "Well," answered the balloonist, "everything you told me is
technically correct, but I have no idea what to make of your information,
and the fact is I am still lost.  Frankly, you've not been much help so
far."
  The woman below responded, "You must be a manager."  "I am,"
replied the balloonist, "but how did you know?"
"Well," said the woman, "you don't know where you are or where you are
going.  You have risen to where you are due to a large quantity of hot air.
You made a promise which you have no idea how to keep, and you expect me to
solve your problem.  The fact is you are in exactly the same position you
were in before we met, but now, somehow, it's my fault."

Carolyn Kirk
Managed Care
Phone:  281-423-3421
Fax:  281-423-3621
carolyn.kirk@usoncology.com <mailto:carolyn.kirk@usoncology.com>


KENNETH LAY,

The PEP system will be open through Friday, June 1st so that you may complete or decline your reviews.

Our records indicate that you have one or more requests for feedback that have not yet been submitted.  Please complete or decline these requests as soon as possible by logging into PEP at http://pep.enron.com and selecting Complete Feedback from the Main Menu.

If you have any questions, please contact the PEP Help Desk at:
Houston:  713.853.4777, Option 4 or email: perfmgmt@enron.com
London:  44.207.783.4040, Option 4 or email: pep.enquiries@enron.com

Thank you for your participation in this important process.


Yes,  I will just initial by the signature line that Jean signs.

	John Kiani/ENRON@enronXgate
	04/17/2001 10:13 AM

		 To: Gerald Nemec/HOU/ECT@ECT
		 cc:
		 Subject: RE: LOI Stagecoach

Gerald,

Can I bring a copy of the Stagecoach LOI on Enron letterhead to you for your
signature?  Chris Hilgert said that we need your initials or signature,
including Jean Mrha,s.  Where on the document would you sign or initial?  I
would like to get this out to El Paso today.

Thanks,

John


The speaker presentations are now available at the Enron Law Conference
website at http://lawconference.corp.enron.com/. These materials can be found
under Presentation Handouts or the Conference Schedule. Click the icon to the
left of the presentation which will launch the application. Once the file is
visible, you can navigate to the various slides using the Page Up and Page
Down keys or print the file. To return to the Handouts Menu use the back
arrow. If you are not able to access the website from your location, please
contact me and the files can be sent via e-mail. These materials will be
available on the website until next year's conference. The CLE Committee
hopes you enjoyed your first "Binder Free" conference!

Paulette Obrecht
Legal Project Coordinator
713-646-6305


Everyone,
 Please note the following static scheduling charges from each of the
following control areas.

  HLP  $49
  COA $40
  Brazos $25
  TNMP $55

 These charges are just like the ones we incur when doing business with HLP.
Each time you have a schedule with these CA's we will get the charged the
above rates.

Greg


I was very much looking forward to reviewing the protocol but to my
disappointment it was not attached!


Dinner in LaGrange will be a great affair.  Randy Gross of the Enron Aviation Department will again provide us with his fabulous barbecued brisket and sausage.  The Marriott will be there with some great side dishes and some chicken thing that I know will be wonderful as well.

J. Paul Oxer is once again Camp Director and has some great improvements to the 2001 tent.  Heather Choate is the Volunteer Coordinator for the 65 operations volunteers in Bellville, LaGrange and Austin.  Thanks to all!

IT IS VERY IMPORTANT FOR YOU TO KNOW THAT THIS DINNER IS PROVIDED FOR ENRON RIDERS AND QUALIFIED VOLUNTEERS ONLY.  Many of you have family and friends gathering in LaGrange with you, and they are welcome to visit us in the tent, but we can't feed them.  We will need to strictly guard against the possibility of running out of food before the last rider comes in.  As a means to control this, if you are not wearing an Enron cycling jersey or an Enron Cycling Club volunteer t-shirt, your name will be checked on a master list before you are invited to participate in the dinner.  Since all our volunteers do not know you, please don't be offended when they check the list for your name if you are not wearing an Enron jersey.

PLEASE DO EVERYTHING YOU CAN TO SPREAD THE WORD ABOUT THIS.  IT'S NOT THAT WE ARE INHOSPITABLE, IT'S THAT WE ARE IN A REMOTE LOCATION WHERE REPLENISHMENT OF OUR FOOD SUPPLY IS NOT POSSIBLE, AND WE DO NOT WANT TO TURN A TIRED, HUNGRY RIDER OR VOLUNTEER AWAY FROM THE TABLE.

THERE IS FOOD AVAILABLE FOR YOUR FAMILY AND FRIENDS THROUGH THE MAIN DINING PROVIDED BY THE MS SOCIETY, AND YOU CAN GET THE LOCATION FROM OUR INFORMATION BOOTH IN THE TENT.  THE CHARGE IS $5 FOR DINNER, AND $3 FOR BREAKFAST FOR NON-RIDERS.

THANK YOU FOR YOUR COOPERATION !!


Energy Market Report
Monday, January 14, 2002

*See attached pdf file.
__________________________________________________________
Western Pre-Scheduled Firm Electricity Prices($/MWh)
January 14, 2002 for January 15, 2002

Peak(Heavy)
                   Low      Change    High      Change
NW/N. Rockies     18.75      0.25     21.25      2.00
Mid-Columbia      18.75      0.25     21.25      2.00
COB               21.50      2.00     23.00      1.50
N. California     22.50      1.50     25.50      3.00
Midway/Sylmar       NA        NA        NA        NA
S. California     23.00      1.50     26.25      3.25
Mead              22.75      1.75     25.75      4.00
Palo Verde        22.00      1.75     26.00      3.75
Inland SW         22.00      1.75     26.00      3.75
4-Corners         22.50      2.00     23.50      2.50
Central Rockies   17.75     -1.00     22.00      1.00
__________________________________________________________
Off-Peak(Light)
                   Low      Change     High     Change
NW/N. Rockies     16.50      0.50     17.25      0.00
Mid-Columbia      16.50      0.50     17.25      0.00
COB               16.50      1.50     19.00      1.25
N. California     17.00      2.00     19.00      1.00
Midway/Sylmar       NA        NA        NA        NA
S. California     16.75      2.25     18.75     -0.75
Mead              17.00      0.50     18.25      0.25
Palo Verde        16.00      1.00     18.00     -0.25
Inland SW         16.00      1.00     18.25      0.00
4-Corners         16.00      1.00     17.00      0.50
Central Rockies   13.00      0.25     15.00      0.50
__________________________________________________________
Hungry for Heat

Heavy load energy costs in the West received a boost on Monday, compliments
of forecasts calling for below-normal temperatures, increased generation
curtailments, and slightly higher natural gas prices.  The long-awaited
colder weather was likely to strengthen spot electricity prices over the
coming days, but opinions varied as to the extent and duration of the
forecasted cooling.  "The cold is finally coming here, and temperatures
should remain below normal for at least a week," said one Northwest trader,
who added, "I'm sure the dailies will react to this bullish weather pattern,
but there's so much gas in storage and water in the rivers that prices may
not rise as much as some people are anticipating."  NYMEX Henry Hub futures
contracts rose Monday amid reported short covering, but the gains were said
to be limited by moderate weather forecasts for the eastern U.S., and
continued concerns surrounding high gas storage levels.  February Hub gas
rose 4.6 cents to close at 2.25$/mmBtu, while March gained 3.7 cents to
settle at 2.24$/mmBtu.  In other industry news, attorneys for bankrupt Enron
Corp. said Monday they were delaying the release of details about Enron's
trading unit sale to the Swiss financial institution UBS Warburg until 23:00
EST Monday.  Enron and its attorneys would not comment on the reason for the
delay.  Patience is a virtue?isn't it?

Peak power prices in the Northwest were on the rise for Tuesday delivery, a
trend many players believed would continue through much of the week.  A
round of colder weather was expected to increase heating demand in the
region over the next several days.  According to Weather Derivatives,
heating demand in the region was expected to average 110 percent of normal
through January 21, while the most recent six-to-ten-day forecast from the
National Weather Service was predicting that below-normal temperatures would
continue blanketing the Northwest through January 24.  Healthy flows at
regional hydro generating units, however, had some parties convinced that
the cold would come and go without incident, and that the upside for daily
prices would therefore be limited.  Flows for Chief Joseph on the Columbia
River came in at 95 kcfs through Thursday, 90 kcfs Friday, 60 kcfs Saturday,
50 kcfs Sunday, and 100 kcfs next Monday.  In unit news, Bridger #3 (520 MW)
was reportedly still off line Monday for tube leak repairs, though sources
were expecting the Wyoming-based unit to return later Monday evening.
Wyoming-based Naughton #3 (330 MW) came down Sunday for tube leak repairs
expected to last from 48 to 72 hours.

With temperatures slated to remain near to slightly above normal through
Friday, day-ahead peak power in the Golden State firmed up for Tuesday
delivery.  Marketers cited an increase in off-line generation as the primary
factor in the price increase.  Peak goods at SP-15 were the premium fare on
Monday, with pieces changing hands between 23 and 26.25$/MWh.  The latest
six-to-ten called for temperatures to hover around normal from January 20 to
24. In the news, the California Chamber of Commerce and the California
Business Roundtable proposed eliminating the Consumer Power and Conservation
Financing Authority and the Electricity Oversight Board, and to consolidate
the duties of the Public Utilities Commission, the Energy Commission, the
Department of Conservation, and the energy division of the California
Department of Water Resources.  Chamber of Commerce President Allan
Zaremberg cited the many overlapping duties of these government entities as
creating competition and conflicts of interest, with the end result of
inflating the state's electricity costs, while two of the entities are of
dubious worth anyhow.  The newly-formed Consumer Power and Conservation
Financing Authority has not done anything besides drain state resources
since its inception in August, and the Electricity Oversight Board has
shrunk to a single board member in the absence of its primary duty - to
oversee the now-defunct California Power Exchange.  Legislators vowed to
untangle the web of conflict, redundancy, and inefficiency carefully, to
avoid causing an even bigger mess than the one they aim to repair.
Generation had a turbulent weekend, with small-unit outages climbing by
almost 1,700 MW since Friday, and Encina #4 (303 MW) joining sister unit
Encina #5 (332 MW) in off-line status.

As temperatures in the Southwest were poised to dip through the week, spot
electricity prices reacted in kind, gaining as much as 4$/MWh for Tuesday
delivery.  Slightly higher natural gas prices were also said to be adding
strength to the dailies.  Peak power at Palo Verde ranged from 22 to
26$/MWh, with the bulk of transactions seen between 23.75 and 24$/MWh.
Weather Derivatives projected that heating demand in the desert region would
average 112 percent of normal through January 21, peaking out at 123 percent
of normal on January 18.  The latest six-to-ten from the NWS was also
calling for below-normal temperatures across the Southwest through January
24.  "Our daytime highs are expected to fall into the mid 60s, and our
overnight lows into the mid 40s.  I know that doesn't sound all that cold,
but thin-blooded Southwesterners will undoubtedly be turning on the heat,"
said one Phoenix-based trader.  In unit news, Coronado #1 (365 MW) ramped up
to two thirds capacity over the weekend, and was scheduled to hit full power
sometime on Tuesday.

Patrick O'Neill and David Ramberg
_________________________________________________________

Western Generating Unit Outages

Current                            Begins          Ends          Reason
CAISO units <250/7801 total          NA             NA
planned/unplanned*
Alamitos #3/320/gas               04-Dec-01         ?            planned
Alamitos #4/320/gas               04-Jan-02         ?            planned
Bridger #3/520/coal               12-Jan-02     14-Jan-02        tube leak
Colstrip #3/700/coal              11-Jan-02         ?            repairs
Encina #4/303/gas                 12-Jan-02         ?            unplanned*
Encina #5/332/gas                 11-Jan-02         ?            planned
Etiwanda #3/320/gas               22-Dec-01         ?            planned
Four Corners #5                   09-Jan-02     14-Mar-02        maintenance
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         ?      @506 MW,
unplanned*
Morro Bay #3/337/gas              04-Jan-02         ?            planned
Moss Landing #6/739/gas           11-Jan-02         ?           unplanned
Moss Landing #7/739/gas           29-Dec-01         ?            planned
Naughton #3/330/gas               13-Jan-02     16-Jan-02        tube leak*
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
Redondo #8/480/gas                09-Dec-01         ?            planned
San Juan #4/534/coal              10-Jan-02     14-Jan-02       tube leak*

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

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

January 14, 2002 for January 15, 2002

Peak (Heavy) in $/MWh
                 Low     Change   High      Change
Into Cinergy    16.00    -0.50    18.50      0.345
Western PJM     22.00    -2.55    23.65     -1.45
Into Entergy    18.00     0.60    22.50      3.50
Into TVA        18.00     0.00    21.50      2.50
___________________________________________________________
Day-ahead peak power turned in mixed results on Monday across the Eastern
Interconnect, with northern hubs showing slight price decreases and southern
hubs strengthening in the face of covert unit outages.  In the north,
temperatures as much as 15 degrees above normal sucked the life out of the
market, while southern hubs, despite above-normal temperatures, surged
upward amid what some marketers assumed were unreported unit outages.  NYMEX
gas futures gained some ground Monday on short covering, but mild weather
and massive inventory levels limited the upside. The February Henry Hub
contract gained 4.6 cents to close at 2.25$/mmBtu, while March rose 3.7
cents to settle at 2.24$/mmBtu.

Peak power prices for Tuesday delivery at Western PJM changed hands from 22
to 23.65$/MWh, losing ground from Friday's 24.55 to 25.1$/MWh trades.
Marketers blamed forecasts calling for temperatures as high as 12 degrees
above normal at least through Friday, with rain showers likely Monday and
Tuesday. The latest six-to-ten likewise forecasted temperatures to remain
firmly entrenched in above-normal territory from January 20 through 24. Many
described Monday's market environment as a "state of confusion, with a lack
of clear direction and thin, illiquid trading" among players.  Just before
06:30 on Monday, LMPs spiked to 46$/MWh, and rose again right before 07:00
to just under 40$/MWh, but during peak hours prices did not reach more than
about 32$/MWh.  The average for LMPs on Monday was 22.51$/MWh through 14:00.
In unit news, nuclear unit Salem (1105 MW) was reportedly off-line Monday
for undisclosed reasons, with an ETR of Tuesday, January 15.

Into Cinergy day-ahead prices were mostly flat to Friday's peak power
prices, with goods for Tuesday delivery changing hands from 16 to 18.5$/MWh.
This represented a loss of 50 cents on the low end and a gain of 35 cents on
the high.  Temperatures remained unseasonably warm on Monday, with the
five-day forecast calling for temperatures to swing from up to 8 degrees
above normal on Tuesday to 3 degrees below normal on Thursday.  "There's
still hope that the week could see some strength," dreamed one player in
reference to the favorable forecast.  The latest six-to-ten called for a
return to normalcy from January 20 through 24.  There were no new unit
outages to report in ECAR on Monday, but it was reported that Palisades #1
(789 MW) could join the grid again as soon as January 18.

The blast of cold air that brushed across the Midwest last week was
breathing its last icy breaths in the Southeast on Monday, with temperatures
predicted to pick up and remain above normal through Friday.  Into Entergy
goods traded at a 0.6 to 3.5$/MWh premium from Friday's trades, with peak
power for Tuesday delivery changing hands from 18 to 22.5$/MWh.  Some
marketers insisted that weather had nothing to do with it.  "Obviously,
there are some units off, or prices wouldn't have come up like they did,"
commented one contented seller, "it's just that nobody's going to know which
ones for a couple of days."  The latest six-to-ten predicted Southeastern
temperatures would remain firmly above normal from January 20 to 24.  Peak
power prices for Tuesday delivery at Into TVA also gained ground from prices
seen on Friday, with pieces changing hands from 18.25 to 21.5$/MWh on
Monday.  "Prices started out at the low end, but I think some buyers got
caught, and didn't mind paying a little more to cover themselves, so prices
came up over the session," ventured one savvy trader.  There were no new
unit outages or curtailments to report in the SERC region on Monday, despite
assertions by various players that some units must be out.
___________________________________________________________

California ISO Congestion Index in $/MWh

                         Path                 Peak   Off-peak
for 13-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            0.01    15.49

for 14-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 15-Jan-02         NW1 to NP15             0.19     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            20.00    21.00    23.25    24.25    25.00    26.00
February       19.50    21.00    22.75    23.75    24.00    25.00
March          17.50    19.00    22.25    23.25    23.50    24.50
April          17.25    18.75    23.50    24.50    23.50    24.50
Q2 '02         17.00    18.50    26.00    27.00    25.50    26.50
Q3 '02         30.50    32.00    39.25    40.25    38.25    39.25
Q4 '02         25.75    27.25    26.25    27.25    27.75    28.75
Q1 '03         25.50    27.00    26.25    27.25    28.50    29.50
Cal '03        27.00    28.50    30.50    31.50    31.75    32.75

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  11-Jan-02       35.25     34.18       15.40      28.52    -2.01
for  12-Jan-02       52.98     49.565      22.53      41.13    12.61
for  13-Jan-02       36.32     35.75       23.99      32.12    -9.01

BPA's Offer for 01/16/02.

Hours        Amount          NW delivered        COB/NOB delivered
7-22         100MW           Market Price*          Market Price*
1-6, 23-24   100MW           Market Price*          Market Price*

*Market price will be determined at time of request.

NYMEX Henry Hub Gas Futures in $/mmBtu

                 Close        Change
        Feb      2.250         0.046
        Mar      2.240         0.037

Natural Gas Spot Prices in $/mmBtu

                  Low          High
Sumas             2.02         2.07
So. Cal Border    2.14         2.19
San Juan          2.00         2.05
__________________________________________________________

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


Kathy,

As you know we are trying to eliminate all the plugs on the Gas Benchmark.
Therefore we would like to begin pulling your positions from the GRMS
system.  I have attached a file that shows the position that I got when I
queried GRMS for the June 14 position.  I have also included the detail and a
copy of what you reported.

As you will see these positions are significantly different.  Please look at
the detail and let me know if you see the reason for the descrepancy (ie
books that we have omitted).  Let me know if you need more information.

Thanks,
Robin
713-345-7478


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FYI Tuesday, October 23 was Jan's 20 year anniversary with Enron.


----- Forwarded by Sara Shackleton/HOU/ECT on 08/29/2000 11:36 AM -----

	Carol St Clair
	08/29/2000 08:13 AM

		 To: Sara Shackleton/HOU/ECT@ECT, Mary Cook/HOU/ECT@ECT
		 cc:
		 Subject: Enron/McGarret C Transaction

Carol St. Clair
EB 3892
713-853-3989 (Phone)
713-646-3393 (Fax)
carol.st.clair@enron.com
----- Forwarded by Carol St Clair/HOU/ECT on 08/29/00 08:10 AM -----

	"CHRIS KRECEK" <KRECC@andrews-kurth.com>
	08/28/00 12:53 PM

		 To: <alan.quaintance@enron.com>, <brenda.l.funk@enron.com>,
<Carol.St.Clair@enron.com>, <charles.delacey@enron.com>,
<Clement.abrams@enron.com>, <David.roland@enron.com>,
<Gina.Karathanos@enron.com>, <Joel.ephross@enron.com>,
<tina.livingston@enron.com>, <Trevor.Randolph@enron.com>,
<trushar.patel@enron.com>, <mniebruegge@mayerbrown.com>,
<tellwood@mayerbrown.com>, <eawilburn@prickett.com>, <Tamullen@prickett.com>,
<kenton@rlf.com>, <mark.wolf@us.cibc.com>, <mercedes.arango@us.cibc.com>,
<schottla@us.cibc.com>, <aroberts@wilmingtontrust.com>
		 cc: "David Barbour" <BARBD@andrews-kurth.com>, "MURIEL McFARLING"
<MCFAM@andrews-kurth.com>, "Michael Thimmig" <THIMM@andrews-kurth.com>
		 Subject: Enron/McGarret C Transaction

Attached in WordPerfect format are each of the following documents marked
against the version previously circulated:

Drawdown Request (254322);
Put Option Agreement (254334);
Warrant Assignment (254351);
Amended and Restated LLC Agreement for McGarret III (254352);
Receipt of Asset LLC (254362);
Independent Auctioneer Letter Agreement (254369);
Direction Letter (254376);
Sale and Auction Agreement (254372); and
General Opinion of A&K (254385).

If you have any questions or comments, please call Muriel McFarling at (214)
659-4461.  Thank you.

Chris Krecek, Secretary/Legal Assistant
Andrews & Kurth L.L.P.
1717 Main Street, Suite 3700
Dallas, Texas 75201
Phone: (214) 659-4481
Fax: (214) 659-4401
Email: ckrecek@andrews-kurth.com

CONFIDENTIALITY NOTICE:  The information in this e-mail (including any
attachments) is confidential, legally privileged and intended only for the
use of each recipient named above.  If you are not an intended recipient, you
must not read, use or disseminate this information.  If you have received
this e-mail in error, please notify the sender immediately by reply e-mail
and delete this e-mail from your computer.
VIRUS WARNING:  Although this e-mail (including any attachments) is not
intended to contain any virus or defect that may affect your computer, you
are responsible for ensuring that no virus or defect exists.  The sender
disclaims any responsibility for any loss or damages arising from any virus
or defect associated with this e-mail.

 - 254385.wpd
 - 254334.wpd
 - 254351.wpd
 - 254352.wpd
 - 254362.wpd
 - 254369.wpd
 - 254372.wpd
 - 254376.wpd
 - 254322.wpd


Attached is a marked up copy of Jan's memo with comments regarding possible
responses on each point.

In addition, I suggest being prepared to describe some affirmative ideas we
think the Governor should support -- just to see what they say.  Below are a
few suggestions that I am working on for my memo to the Board on 2001
legislation.

Fixed Price Contracts
Require the California Public Utilities Commission (CPUC) to establish
criteria for reviewing and approving or rejecting proposed fixed term, fixed
price contracts within 20 days of their submission by an investor-owned
utility.

Demand-Side Management
Require the CPUC to resolve the interruptible tariff issues in a manner that
will make the program workable from customer and reliability perspectives.
(I am not up to speed on the issues associated with this -- only that the
CPUC has industrial customers up in arms.)

Power Plant Siting
Require the California Energy Commission to consider the positive
environmental impacts of proposed projects when analyzing alternatives to
proposed projects, including the &no project8 alternative.  (This has little
affect but makes a point about the CEC process.)

Simplified Interconnection Rules for Preferred Technologies
Require the CPUC to adopt standard, simplified interconnection options for
distributed generation, renewable, and small cogeneration projects.  (A
perverse version of this was in a Peace bill last year.  As proposed, it
applied only to projects that did not sell onto the grid.  When Enron and
cogenerators made clear that they would cause problems if it wasn't changed,
SCE asked to have the whole section deleted.  It was.)

Community Access
Permit cities and/or other political subdivisions of the state to aggregate
their consumers into electricity buying coops by adopting a local ordinance
that gives customers the opportunity to &opt-out8 of the program.  (TURN has
said it intends to sponsor this next year.)

Have fun in the meeting!  Karen

-----Original Message-----
From: Katie Kaplan [mailto:kaplan@iepa.com]
Sent: Wednesday, November 22, 2000 3:46 PM
To: Jeff.Dasovich@enron.com; knorton@mcnallytemple.com; 'John Stout for
Reliant'; 'Curtis Keebler at Reliant'; 'Julie @ Edson'; 'Paula
Hall-Collins'; 'Marty Wilson'; 'Rob Lamkin'; Karen Edson; Bob
Weisenmiller; Sue Mara; Andy Brown; B Brown Andy; Bob Escalante; Greg
Blue; Jack Pigott; Jan Smutny-Jones; Joe Ronan; Karen Denne; Kassandra
Gough; Kristin Vellandi; Lynn Lednicky; McNally Ray; Richard Hyde;
Stephanie-Newell; Tom Ross; Roger Pelote; Richard Hyde; Lynn Lednicky;
cabaker@duke-energy.com
Cc: chudson@iepa.com
Subject: Governors Meeting

Greetings:
Apologies in advance for those of you who have already received this e-mail
but we are having transmission problems and I just wanted to make sure
everyone had this.  Contrary to the message we will not be holding a
conference call.

Have a happy and safe Thanksgiving!

Katie Kaplan
Manager of State Policy Affairs
Independent Energy Producers Association
(916) 448-9499

 - Govs meeting KE Notes.doc


FYI---

Please note that 7,305 of the Kinder Morgan sale was moved from Hardy (meter
68) to Flagstaff (meter 1606) intraday on the 4th, and carried forward
through the end of the month due to pressure problems.  This change was
confirmed with Patsy Shimek @ Kinder Morgan.

Thanks,

Mark
x33396


Got a question about Enron or what our businesses are doing?  Ask Jeff Skilling!  Join him for an Office of the Chairman "open mike" session today (May 30) on eSpeak at 10 a.m. Houston time.
Can't make the live event?  No worries.  Go to eSpeak (http://ethink.enron.com/eSpeak/exec/default.asp) now and submit your question.  Jeff will try to answer it during his event and you can read the transcript later.

Cost cutting ideas are still coming into the Thinkbank (http://nahou-lnapp01.corp.enron.com/eThink/Thinkbank.nsf/HomePage?OpenPage).  We know you've got some great ideas tucked away in that brainy head of yours -- deposit them into the ThinkBank!

There's some fiesty conversations going on in eMeet http://nahou-lnapp01.corp.enron.com/eThink/eMeet.nsf.  Start your own today!


Nicole,

These are the FT Canada positions excluding the Exotic text file that Kathy
sent.  I'm going to pull it in shortly and then I'll resend you your
positions.

Robin


marcus:
any thoughts about next weekend?  i still want to go somewhere.  this is killing me.  how about south america or is it too far?


---------------------- Forwarded by Susan Scott/ET&S/Enron on 12/08/2000
02:30 PM ---------------------------

Estalee Russi
12/06/2000 07:37 PM
To: Susan Scott/ET&S/Enron@ENRON
cc:

Subject: Deferral Election Form

Susan

Here is the manual enrollment form, please send to Kim Bolton.

Thanks
Estalee


Jean --

Why not ask Marianne Carroll to draft a short note on the current status of the docket and likely outcomes/timing?  Thanks.

 -----Original Message-----
From: 	Twiggs, Thane
Sent:	Wednesday, November 14, 2001 9:46 AM
To:	Nicolay, Christi L.; Ryall, Jean; Ogenyi, Gloria; Maurer, Luiz; Yeung, Charles
Cc:	Steffes, James D.
Subject:	RE: QSEs and QFs in Texas

There have been settlement discussions at the PUCT, however, since we have not been a party I have not participated in any of the discussions.  Jean would be in the best location to get details since Marianne Carroll has been representing Dynegy and others.

 -----Original Message-----
From: 	Nicolay, Christi L.
Sent:	Wednesday, November 14, 2001 9:32 AM
To:	Twiggs, Thane; Ryall, Jean; Ogenyi, Gloria; Maurer, Luiz; Yeung, Charles
Cc:	Steffes, James D.
Subject:	QSEs and QFs in Texas

Texas folks:  The East desk originators would like to know the current status of QFs with PURPA put contracts in Texas and how QSEs can provide scheduling services to these entities.  They said that customers have told them that this issue is being discussed in ERCOT now.

I am aware of the FERC decision last year that precluded the TX PUC from basically abrogating the PURPA contracts.  We circulated that decision to the originators and traders at that time.

Thanks.


meeting details below and EWS presentations attached (paper copies on the
way) with original mckinsey report

Elspeth
---------------------- Forwarded by Elspeth Inglis/Corp/Enron on 02/01/2001
02:15 PM ---------------------------

Gerry Gibson
01/31/2001 01:13 PM
To: David Oxley/HOU/ECT@ECT, Robert Jones/Corp/Enron@ENRON, Marla
Barnard/Enron Communications@Enron Communications, Elizabeth
Tilney/HOU/EES@EES, Gary P Smith/OTS/Enron@ENRON, Drew C Lynch/LON/ECT@ECT,
Jon_zagrodzky@mckinsey.com, Cindy Olson/Corp/Enron@ENRON,
suzanne_nimocks@mckinsey.com, dan_marcontell@mckinsey.com, Ray
Bennett/HOU/EES@EES, Kalen Pieper/HOU/EES@EES, Dave Schafer/NA/Enron@ENRON,
Elspeth Inglis/Corp/Enron@Enron, Gina Corteselli/Corp/Enron@Enron
cc: Norma Yeverino/HR/Corp/Enron@ENRON, Sandy Stone/Enron
Communications@Enron Communications, Ruth Ann Brown/HOU/EES@EES, Carolyn
Perry/OTS/Enron@ENRON, Rachael Adams/LON/ECT@ECT, Hilda
Bourgeois-Galloway/Corp/Enron@ENRON, Kathy McMahon/NA/Enron@Enron, Lisa
Costello/NA/Enron@ENRON, Julie Clyatt/Corp/Enron@ENRON

Subject: Feb. 2 Partnership & Peer-group Meeting Agenda

Hello Folks:

Enclosed is a proposed agenda / discussion outline for the Partnership &
Peer-group Meeting that will take place on Feb. 2 from 8:30 - 10:00 in
EB30C2. Please feel free to offer suggestions for improving this agenda.

Regards, Gerry Gibson


The information contained herein is based on sources that we believe to be
reliable, but we do not represent that it is accurate or complete.  Nothing
contained herein should be considered as an offer to sell or a solicitation
of an offer to buy any financial instruments discussed herein.  Any
opinions expressed herein are solely those of the author.  As such, they
may differ in material respects from those of, or expressed or published by
on behalf of Carr Futures or its officers, directors, employees or
affiliates.  ? 2001 Carr Futures

The charts are now available on the web by clicking on the hot link(s)
contained in this email. If for any reason you are unable to receive the
charts via the web, please contact me via email and I will email the charts
to you as attachments.

Daily Energy Letter
http://www.carrfut.com/research/Energy1/Energy-Letter1-28-02.pdf


I hope to have your list to you sometime tomorrow.

Debra Perlingiere
Enron North America Corp.
Legal Department
1400 Smith Street, EB 3885
Houston, Texas 77002
dperlin@enron.com
Phone 713-853-7658
Fax  713-646-3490


I'm fine with it.
m


Payables

iBuyit Payables Invoice Process
*  No longer use coding sheets!  Invoices will be coded and approved on-line
in the iBuyit Payables system.
*  Remind vendors to submit invoices directly to the new PO Box:  PO Box
4734, Houston, TX 77210-4734, ATTN:  Enron Accounts Payable.  Provide vendors
with the paying company name and paying company number, invoice contact name,
and coder,s EID.
*  No longer receive invoices directly from the vendor.  If you do, forward
them to Accounts Payable via an AP drop box or mail to the new PO Box.  Be
sure to indicate the paying company name and paying company number, invoice
contact name, and coder,s EID on the invoice.

New Urgent Pay and Payment Request Forms
No longer use the SAP Payment Request form!  For same day/next day check
requests, you must use the new Urgent Pay Request Form.  Remember, urgent pay
requests should only be made for business critical issues (for example,
issues that would obstruct business operations).  If you need a payment, but
do not have an invoice, use the new Payment Request form.  These forms are
located in the iBuyit Payables system.  To access these forms, click on the
forms icon (looks like a pencil).

iBuyit Payables Training
To access online system demonstrations and quick reference cards, visit the
Integrated Solutions Center Document Library at
<http://sap.enron.com/sap_doclib/user/file_list.asp?cabinet_id=265>.
Note:  You must use the Enron standard Microsoft Internet Explorer to view
these materials.

Attention Houston-based coders and approvers:  All iBuyit Payables Classroom
training is full, but there will be four more iBuyit Payables Overview
sessions.  These sessions will provide you with a demonstration of the system
and provide you with the opportunity to ask questions.  There is no need to
register for the Overview sessions.
*  June 6, 2001, 10:30 - 11:30 and 1:30 to 2:30, The Forum, 2AC 12th Floor
*  June 13, 2001, 10:30 - 11:30 and 1:30 to 2:30, The Forum, 2AC 12th Floor

To Access iBuyit Payables
*  If you receive an e-mail notification from iBuyit.Payables@enron.com,
click on the link to the system.
*  From the Enron Home page, type ibuyitpayables.Enron.com
*  From the Enron Home page, type ibuyit, and click on the link to iBuyit
Payables located on the iBuyit Portal

Who do I call for help?
*  For help using the iBuyit Payables system, contact the ISC Call Center at
(713) 345-4727.
*  For invoice payment status, contact the Accounts Payable Call Center at
(713) 853-7127
 or toll free at (866) AP ENRON, or send an e-mail to
<mailto:iBuyit.payables@enron.com>.

Questions?
For general information about iBuyit, send an e-mail to
<mailto:ibuyit@enron.com>.


Dear Advisory Board Member,

Thank you for your continued support of NACECs Initiative "Environmental
Challenges and Opportunities of the Evolving Continental Electricity Market".

Please find attached the following documents for your review and to be
further discussed during the conference call Thursday May 24 at 3:00 EST.

1) an Interim Note for the Secretariat report
2) a draft recommendations checklist (for initial discussion)
3)  a list of the advisory board members and bios (please note that we have
shortened some of the bios, if you have yet to submit a bio please send a
copy to yolanda@ccemtl.org )

Items to be discussed during conference call:
I) Secretariat update - progress, expert report, symposium
II) Process and approach for developing guidelines/recommendations
III) Initial discussion of guidelines/recommendations
IV) 2nd Advisory Board meeting date and venue

Details of the conference call:

Participants from Canada and the United States should dial:
1-877-633-5353 (toll free)

Participants from Mexico should dial:
0-1-800-123-0200 and ask the operator to charge this telephone call to the
telephone number: (1-514) 868-2558

then enter the following Code: 023405#

If there is any problem with the communication during the call  please dial *0
(Conference call reference: C799250)

On behalf of my colleagues at NACEC,
Sincerely,

Yolanda Clegg

Yolanda Clegg, M.Sc.
Environment, Economy and Trade Program
North American Commission for Environmental Cooperation
393 rue St-Jacques Ouest, bureau 200
Montreal
Quebec
CANADA         H2Y 1N9

tel: 514-350-4368
fax: 514-350-4314
yolanda@ccemtl.org

http://www.cec.org

 - Interim Note.doc
 - Recommendations checklist.doc
 - Members and Bios.doc


Does anyone have this file?  The master was executed on 2/28/92.  Thanks.
Sara


Jim, thought i should send you this just in case you were thinking of dedicating your afternoon to it......

 -----Original Message-----
From: 	Presto, Kevin M.
Sent:	Tuesday, October 16, 2001 12:27 PM
To:	Roan, Michael
Subject:	RE: Updated EPMI/EES draft ICAP paper

Looks fine.

 -----Original Message-----
From: 	Roan, Michael
Sent:	Monday, October 15, 2001 5:42 PM
To:	Belden, Tim; Presto, Kevin M.; Black, Don; Herndon, Rogers; Steffes, James D.; Shapiro, Richard; Gilbert-smith, Doug; Davis, Mark Dana
Cc:	Sharp, Vicki; Sager, Elizabeth; Nicolay, Christi L.
Subject:	Updated EPMI/EES draft ICAP paper

Attached is the final draft of this paper for comment.  It incorporates the comments of those who responded but there is time for further redrafting.  However, given the filing deadline (Wednesday) further changes are likely to be wordsmithing unless someone vehemently objects to the structure.

regards
Mike ext. 57634

PS.  There were no objections to my thoughts on structure so we have concentrated on the rationale supporting RTO's and effective spot markets as mechanisms that achieve the goals of ICAP (i.e A spot market is Enrons solution).  We then state that if others have different views, any resulting separate iCap proposal if implemented should be interim in nature and minimise spot market distortions.  Finally we attach a simple interim solution as an appendix (so it does not detract from our main argument structure) so that if there is an ongoing debate we will be able to take part...

 << File: ICAP paper 15 October.doc >>


Start Date: 12/29/01; HourAhead hour: 19;  No ancillary schedules awarded.  No variances detected.

    LOG MESSAGES:

PARSING FILE -->> O:\Portland\WestDesk\California Scheduling\ISO Final Schedules\2001122919.txt
###Cannot locate a Preferred or Revised_Preferred Schedule that matches the FINAL Individual Interchange Schedule.  Unable to assign deal number.
###Cannot locate a Preferred or Revised_Preferred Schedule that matches the FINAL Individual Interchange Schedule.  Unable to assign deal number.
###Cannot locate a Preferred or Revised_Preferred Schedule that matches the FINAL Individual Interchange Schedule.  Unable to assign deal number.
###Cannot locate a Preferred or Revised_Preferred Schedule that matches the FINAL Individual Interchange Schedule.  Unable to assign deal number.


Here is the file from last night.  Shout with any questions.  Thanks.
PL
3-7376


HL&P was short on the following days:

December

4th (2256)
9th (7214)
11th (2527)
12th (3537)
15th (7058)
16th (4776)
17th (4465)
28th (264)

How do you want to handle this??

---------------------- Forwarded by Kimberly Vaughn/HOU/ECT on 01/12/2000
01:07 PM ---------------------------

	Anita Luong
	01/12/2000 10:46 AM

To: Kimberly Vaughn/HOU/ECT@ECT
cc: Howard B Camp/HOU/ECT@ECT
Subject: HL&P for 12/99

For days 4, 9, 11, 12, 15, 16, 17 and 28,  we are short at the aggregate
meter.   Should the Reliant transport and Sales or do we charge Reliant a
penalty?

Also, I notice that at meter 1554 we have 3rd party transport this month.
This look strange because I've not seen them here before.

Please advice.

Thanks