---------------------- Forwarded by Jennifer Rudolph/HOU/EES on 07/09/2001
03:27 PM ---------------------------
From: Alan Comnes/ENRON@enronXgate on 07/06/2001 06:33 PM
To: Jeff Dasovich/NA/Enron@Enron, Angela Schwarz/HOU/EES@EES, Beverly
Aden/HOU/EES@EES, Bill Votaw/HOU/EES@EES, Brenda Barreda/HOU/EES@EES, Carol
Moffett/HOU/EES@EES, Cathy Corbin/HOU/EES@EES, Chris H
Foster/ENRON@enronXgate, Christina Liscano/HOU/EES@EES, Craig H
Sutter/HOU/EES@EES, Dan Leff/HOU/EES@EES, Debora Whitehead/HOU/EES@EES,
Dennis Benevides/HOU/EES@EES, Don Black/HOU/EES@EES, Dorothy
Youngblood/HOU/ECT@ECT, Douglas Huth/HOU/EES@EES, Edward
Sacks/ENRON@enronXgate, Eric Melvin/HOU/EES@EES, Erika Dupre/HOU/EES@EES,
Evan Hughes/HOU/EES@EES, Fran Deltoro/HOU/EES@EES, Gayle W
Muench/HOU/EES@EES, Ginger Dernehl/NA/Enron@Enron, Gordon Savage/HOU/EES@EES,
Harold G Buchanan/HOU/EES@EES, Harry Kingerski/NA/Enron@Enron, Iris
Waser/HOU/EES@EES, James D Steffes/NA/Enron@Enron, James W Lewis/HOU/EES@EES,
James Wright/Western Region/The Bentley Company@Exchange, Jeff
Messina/HOU/EES@EES, Jeremy Blachman/HOU/EES@EES, Jess Hewitt/HOU/EES@EES,
Joe Hartsoe/Corp/Enron@ENRON, Karen Denne/Corp/Enron@ENRON, Kathy
Bass/HOU/EES@EES, Kathy Dodgen/HOU/EES@EES, Ken Gustafson/HOU/EES@EES, Kevin
Hughes/HOU/EES@EES, Leasa Lopez/HOU/EES@EES, Leticia Botello/HOU/EES@EES,
Mark S Muller/HOU/EES@EES, Marsha Suggs/HOU/EES@EES, Marty Sunde/HOU/EES@EES,
Meredith M Eggleston/HOU/EES@EES, Michael Etringer/ENRON@enronXgate, Michael
Mann/HOU/EES@EES, Michelle D Cisneros/ENRON@enronXgate,
mpalmer@enron.com@SMTP@enronXgate, Neil Bresnan/HOU/EES@EES, Neil
Hong/HOU/EES@EES, Paul Kaufman/ENRON@enronXgate, Paula Warren/HOU/EES@EES,
Richard L Zdunkewicz/HOU/EES@EES, Richard Leibert/HOU/EES@EES, Richard
Shapiro/NA/Enron@Enron, Rita Hennessy/ENRON@enronXgate, Roger
Yang/SFO/EES@EES, Rosalinda Tijerina/HOU/EES@EES, Sandra
McCubbin/NA/Enron@ENRON, Sarah Novosel/Corp/Enron@ENRON, Scott
Gahn/HOU/EES@EES, Scott Stoness/HOU/EES@EES, Sharon Dick/HOU/EES@EES,
skean@enron.com@SMTP@enronXgate, Tanya Leslie/HOU/EES@EES, Tasha
Lair/HOU/EES@EES, Ted Murphy/HOU/ECT@ECT, Terri Greenlee/ENRON@enronXgate,
Tim Belden/ENRON@enronXgate, Tony Spruiell/HOU/EES@EES, Vicki
Sharp/HOU/EES@EES, Vladimir Gorny/ENRON@enronXgate, Wanda
Curry/ENRON@enronXgate, William S Bradford/ENRON@enronXgate, Kathryn
Corbally/Corp/Enron@ENRON, Jubran Whalan/HOU/EES@EES, Tony
Riley/Enron@EUEnronXgate, Richard B Sanders/Enron@enronXgate, Robert C
Williams/ENRON@enronXgate, Greg Wolfe/ENRON@enronXgate, James Wright/Western
Region/The Bentley Company@Exchange, Dirk vanUlden/Western Region/The Bentley
Company@Exchange, Steve Walker/SFO/EES@EES, Jennifer Rudolph/HOU/EES@EES,
Martin Wenzel/SFO/HOU/EES@EES, Douglas Condon/SFO/EES@EES,
wgang@enron.com@SMTP@enronXgate, Scott Govenar
<sgovenar@govadv.com>@SMTP@enronXgate, Hedy Govenar
<hgovenar@govadv.com>@SMTP@enronXgate, jklauber@llgm.com@SMTP@enronXgate,
Mike D Smith/HOU/EES@EES, John Neslage/ENRON_DEVELOPMENT@ENRON_DEVELOPMENT,
Janel Guerrero/Corp/Enron@Enron, Eric Letke/DUB/EES@EES, Richard B
Sanders/Enron@enronXgate, gfergus@brobeck.com@SMTP@enronXgate, Michael
Tribolet/ENRON@enronXgate, Robert Frank/NA/Enron@Enron, Richard B
Sanders/Enron@enronXgate, gfergus@brobeck.com@SMTP@enronXgate, Susan J
Mara/NA/Enron@ENRON, Chris Holmes/HOU/EES@EES, David Leboe/ENRON@enronXgate
cc:
Subject: POWER POINTS:Nevada Suffers FERC Unintended Consequences

Great dialog on everything that's wrong with price controls.

 -----Original Message-----
From:  "Onukogu, Ernest" <Ernest.Onukogu@dowjones.com>@ENRON
[mailto:IMCEANOTES-+22Onukogu+2C+20Ernest+22+20+3CErnest+2EOnukogu+40dowjones+
2Ecom+3E+40ENRON@ENRON.com]
Sent: Friday, July 06, 2001 1:11 PM
To: undisclosed-recipients:;@ENRON
Subject: POWER POINTS:Nevada Suffers FERC Unintended Consequences --

> POWER POINTS:Nevada Suffers FERC Unintended Consequences
>
>    By Mark Golden
>    A Dow Jones Newswires Column
>
>   NEW YORK (Dow Jones)--Those who have opposed wholesale electricity price
> controls have been labeled as extreme free-market ideologues who are
> insensitive
> to the practical impacts on peoples' lives of high electricity prices.
>   But the most common argument against price caps has been logical, not
> ideological: Price controls have never worked. Market participants always
> find a
> way around the rules.
>   This week the Federal Energy Regulatory Commission decided that it will
> have
> to consider at its meeting next week revisions to its June 19 price
> control
> ruling. The initial price cap rule, set by the California Independent
> System
> Operator last spring, was only a few paragraphs long. Each successive
> price cap
> order has gotten longer, though effectiveness still appears out of reach.
> The
> FERC's April order was 28 pages long; the June order was 48 pages. And now
> additional rules are on call to plug the new loopholes.
>   The revisions will also try to repair damage done to the market by the
> June
> order. During a spell of very hot weather Monday, Sierra Pacific Resources
> (SRP)
> subsidiary Nevada Power had to initiate limited rolling blackouts to a
> small
> number of customers for 45 minutes. The company attributed the blackouts,
> in
> part, to the new price controls.
>   Sierra Pacific's chief spokesman, Paul Heagen, provided a bird's eye
> view of
> the practical realities of the FERC's new price cap regime.
>   Power Points: After having a few days to look into it, can you say that
> price
> caps definitely contributed to blackouts in Nevada on Monday?
>   Paul Heagen: Yes, but first let me say that all of it was unintentional.
> FERC
> was trying to do the right thing. Price caps were a noble effort to solve
> a real
> problem in California.
>   But on Monday the market needed speed and clarity to function. It had
> neither,
> and that can be attributed to the price caps. Normally, in one or two
> phone
> calls we could have got what we needed. On Monday, we were five to six
> calls
> into it and still on the phone.
>   Price caps are having the unintended consequence of dragging other
> states into
> the California morass. We have this artificial environment which we are
> all
> trying to sort through.
>   PP: How, specifically, are the caps having this effect?
>   PH: There are a couple of elements. The 10% premium for power sold to
> California is supposed to reflect concerns about credit. That 10% in an
> open
> market is no big deal, but in a constrained situation the seller will grab
> it,
> because now it's his only chance to make money.
>   Also, the way this is set up, they look backwards. They determine the
> price
> after the fact. I can't think of any business in the world where you sell
> a
> product and find out later what price you sold at.
>   This had a very chilling effect on people's willingness to sell.
> Normally, a
> cloud cover comes in and a utility has a little extra power to sell in the
> real-time market. Normally, those little 50-megawatt packets move pretty
> easily,
> and that's really important for maintaining reliability.
>   With the price cap, utilities hunkered down. Selling at $92 wasn't worth
> the
> risk. They figured they might as well hang on in case they needed it.
>   Also, we have a voluntary curtailment program that allows us to share
> savings
> with customers who agree to curtail use. If the market is, say, $500, we
> might
> pay them $250/MWh to curtail demand. But in a $92/mkt, we can offer them
> such a
> small amount of money that they stay on.
>   PP: Have you talked to FERC about these problems with the price
> controls?
>   PH: We've had a senior team in Washington, D.C., at the FERC since last
> week.
> Right away we saw another effect of the FERC order: It penalizes companies
> like
> ours that signed long-term supply contracts before the order because many
> of
> those deals were done at prices above the price cap.
>   The biggest issue for us, is, did FERC really mean to penalize companies
> like
> us that planned ahead? It's long-term contracts that provide price
> stability.
>   It's unfair to our customers to expect them to pay for long-term
> contracts
> that have been undercut by price caps. If we get into a situation where we
> have
> a little extra to sell, now we can't recover our costs.
>   PP: With such high prices the past year, a lot of small, oil-fired
> turbines
> have been dusted off and put into service on time for this summer. Traders
> for
> other southwest utilities have said that all these little turbines have
> been
> very helpful when supplies got tight earlier in the year, but they weren't
> available this week because they cost more to run than the price cap. Did
> you
> see the same thing?
>   PH: We have some small turbines that we put in Reno and the Lake Tahoe
> area in
> the last few months. They were supposed to provide peak power, but they
> get
> uneconomic in a hurry under the price cap scheme.
>   You know, we've tried to isolate ourselves as best we could from the
> California situation and behave very independent of how California
> behaves. So
> Nevada is a great test case to see if price caps have an unintended effect
> outside of California. We were able to minimize the impact on our
> customers
> Monday, but the situation has maximized the attention of the country on
> the
> impact of price caps.
>   -By Mark Golden, Dow Jones Newswires; 201-938-4604;
> mark.golden@dowjones.com
>
>   (END) DOW JONES NEWS  07-06-01
>   03:14 PM- - 03 14 PM EDT 07-06-01
>


Optimization/ Facility Planning Team Weekly Report
Week of September 25 - 29, 2000

ET&S Outages  (Outages: Jerry Graves  713/345-8923)

System Optimization Team  (Team Leader: Ben Asante  713/853-9432)

TW Fuel Performance Measurement Model (FPM)
Working with the SCADA support group to identify the equivalent SCADA points
to existing MIPS Points, for conversion of the model to a real-time basis. An
initial query revealed that only ~50% of MIPS points have a SCADA
equivalent.  Priority will be given to identification/addition of points on
the San Juan Lateral and the Thoreau Junction to Needles.

Developing an estimate of the time required to complete the conversion of the
FPM Model to a real-time basis.

TW Fuel Performance Measurement for Fuel Overage Forecasting
The Revenue/Risk Management group are analyzing the existing FPM model
groupings to evaluate the use of our model in combination with their demand
model.  The combined model would provide fuel burned on forecasted demand.
Initial analysis looks promising and they hope to give us an answer by next
week whether the FPM model can be used as is.

Beaver to Mullinville B-C Sweeping
 Pipeline operating conditions have been analyzed since the sweep was
completed on 09/21/00.  Recent sweeps had improved flow efficiency only about
5%.  Last week's sweep improved the efficiency by 35% to about 85%.  Pressure
drops decreased from 125 PSI down to about 40 PSI.  Mullinville has operated
with one less 2000 HP unit while Beaver units are operating with less load
while producing lower suctions.

Outage Modeling
Ran hydraulic models for Gas Control to determine flows with Bisti down and
with Unit 303 down.

San Juan Efficiency Study
Developed multiple scenarios for San Juan flows and pressures if the line was
to be cleaned.  Basic economic analysis was also performed.

Hydraulic Model for EOTT
The current EOTT hydraulic model has been revised to include the dependence
of the fluid properties on temperature and pressure as well the appropriate
heat transfer considerations.

Houston Facility Planning Team    (Team Leader: Perry Frazier 713/853-0667)

TW Expansion Studies
Looked at different combinations of pipe loop and compression trying to
reduce overall costs.  No luck so far.  A brainstorming session is scheduled
next week to see if there are any different approaches not considered to date.
El Paso Field Services
Compiling information for inclusion into the Interconnect and Operating
Agreement between EPFS and Enron.  Mostly locations, materials and POI
number, expect to have all information gathered by the end of the week.

San Juan Lateral
Enron Operations Services has visited 3 laboratories in the area and compiled
information on their analysis procedures.  They want Facility Planning to
help evaluate and choose one for the sample evaluation.  Results will take
about 2 weeks.  Also, received some expected flow/pressure enhancements for
the last 30 - 40 miles of the SJ Lateral, using the expected efficiencies
calculated for a pressure profile taken after the 1998 chemical cleaning
run.   Results will be reported next week.

Liberal Operations - PRIDE Meeting
Attended operations meeting in Liberal that covered various areas of
operations and ways to improve.  Facility Planning did a presentation on the
proposed Emergency Response Program and provided general information on
Facility Planning services that can assist Operations.

Prospective Market Zone Wichita, Kansas
Commercial requested market study of competitor pipelines serving the
Wichita, Kansas area (Duke, KPL, Williams), research possible load
requirements, and facility requirements to connect the area to NNG's pipeline
system.  Wichita is located about 90 miles from the Macksville compressor
station as a crow flies.
Outage Coordination
 Provided the study to determine flows on the San Juan lateral and mainline
when Bisti outage occurs in October.  Both San Juan and the mainline will
have reduced flows.  Study results were given to Market Services. Also
provided support for System Optimization to determine the flows west when
Station #3 unit 3 is out of service.

Marketing Strategy Meeting
Attended and participated in the Marketing Strategy meeting.  Main assignment
for Planning is to continue looking for revenue generating projects.

E&C
Participated in a review of the responding candidates for the vacant Project
Engineering position.

Omaha Facility Planning Team     (Team Leader: Steve Thomas 402-398-7468)

Earlville Outage
On October 12th starting at 8:00 am the Earlville unit will be taken down for
relocation of the blow down silencer.   Solar will also be on site to do some
bleed air manifold baffle modifications.  After this work is completed, the
District will perform a water wash in preparation for emissions testing on
October 16th & 17th.  The unit should be back on-line sometime near midnight
on October 12th.

With Earlville down for this time frame the flow on the East leg will be
limited to the 660-680 mmcf/d range.  We anticipate that normal nominations
will be below this threshold, and that by packing the system the night before
we will be able to make it through without any impact.   Gas Control is
putting this outage on the EBB.  From a Marketing perspective we should limit
short term sustainables, but Ops did not want to call an allocation day.  If
we did, the allocation would be 86% of firm in Zone D for all deliveries.

The emissions testing on October 16th & 17th will have very little impact on
system flows.

Planning White Paper
Planning met with various Marketing representatives to try and attach a value
to the four ideas put forth in the White Paper.   The ideas were thoroughly
discussed and the input we received will be incorporated into the Paper.
One suggestion was that we use the Pricing Desk to determine the value of the
additional capacity.  We will be meeting with them to do that.  Meanwhile
research continues on the various costs associated with the White Paper,
specifically sites for proposed inlet pressure additions.

Engineering Records Research
EOG - Texas Co. #4 (C.000269.01):
This is an interconnect where the Texas Co. #4 8" Lateral (OKG-19301)
connected to the 24" OKM-12001.  An incorrect line number on the project
authorization located the project six miles upstream of the actual site.
Engineering Records did not have the one page amendment with the project
authorization to explain who owns and operates the facilities.  Texas Co. #4
facilities had been removed.  The remaining pipe downstream of the compressor
site to OKM-12001 (approximately 4.5 miles) has been transferred to EOG
Resources as of June 16, 2000.  (Project Authorization C.000369.02/Removal).

Ogden H2S Monitor (SN0157):
Verification of materials used in the construction of the monitor was
needed.  Operations confirmed that a Farm Tap Assembly was used to create the
monitoring facilities, not to install a farm tap within the Ogden Plant yard.

Cedar Falls #2
Marketing needed to know if there was any money left in the work order to
purchase a new regulator, since the interruptible peaking turbine load is
causing problems with the existing regulator.  Property Accounting reported
the amount remaining, but it will not be enough for a new regulator.

St. Croix Valley
Provided options for the proposed ten year expansion for St. Croix Valley.
Examined cost versus incremental growth on the Black River Falls Branchline.
Provided an analysis for option of integrating the growth with the Wisconsin
Gas proposal.  Following the latest strategic marketing meeting, will examine
compression alternatives for St. Criox Valley as a stand-alone project.

Grimes #1 TBS - Pressure Increase
Working with Marketing and the Field.  Examined several options regarding the
customer,s request for a pressure increase to a delivery of 150 psig.
Marketing will examine all the options in order to determine best strategic
fit for the customer.

Ogden Building #2 Discharge Pressure
Research has been completed in trying to locate documentation that supports
the 1000 psig MAOP for the building #2 discharge header.  The supporting
documentation has been forwarded to Lisa Choquette in Codes for approval.  If
documentation is approved as supporting evidence for the 1000 psig MAOP then
only minor controls work will be required in the field in order to increase
the discharge pressure of the building #2 engines.

Pengilly TBS - Mesabi System
Marketing was presented with two separate estimates for modification required
to increase firm at Pengilly from 12 mcf/day to 210 mcf/day.   The first
estimate for $85,000 consisted mostly of contract labor with field personnel
only installing the EFM.  The team responded with a proposal that they would
be willing to do all of the labor if it could be scheduled during Jan-March.
A second estimate of $66,000 was submitted to Marketing, which included all
district labor.  This estimate is contingent on completing the deal prior to
Dec 31,2000.  If a deal is made after Dec 31, 2000 then the higher cost
estimate applies.

Monroe #1 TBS Mods / Pressure Increase
The Monroe #1 TBS Mods Project was released to Engineering.   The project was
the result of WIGas raising the IT load by approximately 4000 mcf/day.  They
also requested a pressure increase at the station from 80 psig to 275
psig.    A Form 2476 "Pressure Increase Request Form" is being circulated for
signature.  The project has a targeted Nov 30, 2000 in-service date.  The
modifications consist of replacing both meters with spool pieces and
performing a pressure test to upgrade the MAOP.

Milbank Project
Continued gathering data to model the Milbank system as it is today.

Melbourne #1 - Project Release
The Melbourne #1 TBS Mods project was released to Engineering.   The project
consists of TBS mods to support the increase of firm from 330 mcf/day to 500
mcf/day at Melbourne. Presently the Marshalltown B/L is constrained and could
not support the incremental firm.  Alliant will realign gas away from the
Marshalltown #1 TBS which is at the end of this B/L to the Marshalltown #1A
TBS which is on a different B/L.  This will open up capacity on the line for
this new load.   The project has a targeted Nov 30, 2000 in-service date.
Modifications consist of replacing the first and second cut regulators and
replacing the meter.

Adel #1A TBS Mods - project release
The Adel #1A TBS Mods Project was released to engineering.  This project was
a result of the customer wanting to convert an existing IT load at Adel #1A
to a Firm load.  The new Firm load will be 1400 mcf/day.   The project has a
targeted Nov 30, 2000 in-service date.  The station will have a new meter
installed along with piping size modifications.

Ethanol Injection
Reviewed and researched (for Marketing) the possibility of injecting Ethanol
into the pipeline for a possible "Green Energy" rating and as a means of BTU
enhancement.  Since ethanol would remain a liquid at any normal pipeline
conditions, even atomizing the ethanol at the point of injection would not
insure the Ethanol from liquefying, dropping out and collecting into the
pipeline low spots.  Also, there were many issues concerning possible liquids
entering the fuel systems of our equipment and other customers, equipment.
Planning recommended that this project not be pursued.

Researched (for Marketing) was the possibility of burning a Methane/Ethanol
mix in our equipment (i.e.: Turbines) in order to receive a "Green Power"
rating.  Solar was contacted concerning the possibility of "co-burning"
ethanol and methane.  As a manufacturer they said they would be willing to
work with us, however, they only recommended it if it were to be a constant
fuel source.  Solar said there would be considerable fuel injection system
retrofits required.  Also, if this were not a constant fuel then there would
have to be two separate fuel systems (co-burn and methane only) and a
complete fuel control system change.  With all that the project has been
deemed cost prohibitive.

Vapor Injection of Propane (VIP Service)
Research was started for Marketing into the possibility of injecting
vaporized propane into the pipeline as a way of increasing capacity during
peak days.  Upon initial review many questions were generated by the planning
team concerning specific requirements of the new service (i.e.: # of days/yr,
firm, daily firm etc.)  Planning awaits feedback from Marketing before any
more action is taken.

Electric Generation
Proposal was reviewed for Marketing from APA for an engineering study to
review the possibility of utilizing stand-by generators as electric producers
for the Utilities during peak power times in the summer months.  A few
discrepancies were found and are being worked out before APA can be released
to complete the engineering study.

Beaver Dehy
A request was received from John Sturn of the optimization team to review the
Capacity of the Mole sieve Dehy system at Beaver Compressor Station on the SE
24" line.  Beaver is considering a capital project to re-route the dehy
system that is currently piped into the suction of the station to the
discharge, thus increasing the capacity.

Cogentrix Power Plant
Three detailed cost estimates for the Cogentrix Power Plant proposals were
prepared and forwarded to Marketing.  The details of the cost estimate
included a breakdown of costs for:
Material Costs
Labor
Freight and Taxes
Surveys/Permits
Construction Support
District Labor
Engineering/Drafting/As-builts
Contingency
Overhead
AFUDC
The break down of costs was done for the Sheldon, Lehigh, and Raun projects
in Nebraska and Iowa.

Cherokee Ethanol Projects
Seven sites were examined for a proposed ethanol plant in Cherokee County,
Iowa.  The delivery volume was for 8 MMCF/D at a delivery pressure of 70
psig.  It was assumed for this study that the initial load would be for 4
MMCF/D for two years and then increase to the 8 MMCF/D level.  The cost
estimate assumed that the initial design would be for the 8 MMCF/D.  This was
done to reduce the cost for the project.  Each cost estimate was done for a
firm transport level and an interruptible transport level (14 cost estimates
total).  Two of the sites are on the C line approximately 10 miles southwest
of the Paullina Station.  The remaining sites were on the Storm Lake/Lytton
Branchline.


Rod and Tracy,

As a result of a state of Colorado audit TW has been assessed tax (+penalties and interest) for compressor fuel use ($.4mm), and on the purchase of a La Plata facility ($1.3mm). We are protesting. However, it has been recommended, and I concur, that we pay
the compressor fuel use assessment ("under protest") to stop interest accruals on the use tax assessment. We believe the sales tax assessment is at best -weak- and therefore do not recommend any payment.

We're requesting approval to cut a check to the Colorado Dept of Revenue for $356,736.95.
This payment would be a deferred expense until the protest is fully resolved.

 -----Original Message-----
From: 	Rittgers, Dan
Sent:	Wednesday, February 06, 2002 4:40 PM
To:	Saunders, James
Cc:	Chandler, Bob; Zahn, Gary; Russo, Gavin
Subject:	Transwestern Pipeline Payment Under Protest (Confirmed PAYMENT BY MAIL ONLY   -  $356,736.95)

Thank you for your time today.  I have confirmed that the payment under protest amount is $356,736.95 calculated as follows:

Transwestern Pipeline - Colorado Sales & Use Tax
Payment Under Protest - Compressor Fuel
For Period September 1996 to July 2001

	Consumer Use	County Sales	Total
Normal Tax	 $      185,626.00 	 $      109,037.00 	 $      294,663.00
Normal Interest	          54,594.76 	          28,181.67 	 $        82,776.43
	 $      240,220.76 	 $      137,218.67 	 $      377,439.43
Less 1/2 discount	         (13,669.15)	           (7,033.33)	         (20,702.48)
Payment Due	 $ 226,551.61 	 $ 130,185.34 	 $ 356,736.95

Confirmed 2/06/2002 with D. Malonson at (303) 866-3083

Check Reference Description should include:

	Colorado Notice Number 0240300178948
	Colorado Account: L 80-30571-000   (Compressor Fuel)

We would like to include check number in our transmittal, when known.

We do not have to pay the $1.2 Million for the purchase of the Compressor Station.

Dan Rittgers
(713) 853-5734


Kinda of like a Mary in a Bathtub, only different.

ckm

Heather Kroll@ECT
10/31/2000 03:55 PM
To: Kay Mann/Corp/Enron@Enron, Ozzie Pagan/HOU/ECT@ECT
cc:

Subject: Halloween Goody

This is pretty funny.
---------------------- Forwarded by Heather Kroll/HOU/ECT on 10/31/2000 03:55
PM ---------------------------

"O'Brien, Karen [IBD]" <karen.obrien@ssmb.com> on 10/31/2000 03:35:52 PM
To: "'bob masco'" <bobmasco@olsusa.com>, "'christine oliviero'"
<christine.oliviero@chamnessrelocation.com>, "Hobson, Cynthia P [IBD]"
<cynthia.p.hobson@ssmb.com>, "'Clare Reed'" <clare_reed@msdw.com>, "'Clare
Reed'" <clare_reed@msdw.com>, "'Colleen O'Brien'" <shopper5232@aol.com>,
"'Dennis'" <dvelotta@spalding.com>, "'flea'" <felicia.annucci@gs.com>,
"'FOB'" <fpobrien@lucent.com>, "'Glenn'" <renshi108@aol.com>, "'heather'"
<hkroll@enron.com>, "'jimmy spillane'" <spillane_james@jpmorgan.com>, "'Joan
D'" <demanuelj@sullcrom.com>, "'Linda S.'" <sicill@sullcrom.com>, "'marie
alexandru'" <marie.alexandru@moorecap.com>, "Obrien, Michael [CITI]"
<michael.obrien@citicorp.com>, "'Steve Pinado'" <spinado@ownx.com>
cc:
Subject: Halloween Goody

 <<PUMPKINCJ.JPG>>

 - PUMPKINCJ.JPG


Text:  Please plan to attend and reception and dinner for Analysts and
Associates who have made significant contributions to ENA.  The function will
be hosted by the Office of the Chairman at Morton's Steak House located at
5000 Westheimer on August 17, 2000.  The reception will start at 7:00pm with
dinner to follow at 7:45pm.  Please RSVP to Ted Bland at ext. 3-5275 no later
than close of business Monday, August 14.  This will be an informal gathering
to discuss the progress of ENA and an open forum to interact with members of
the senior management team on a one on one basis.

See you on the 17th.

Mark, Dave and John


Thanks for the update.  Congratulations on your progress.

Keith Miceli@ENRON
07/24/2000 04:18 PM
To: Steven J Kean@EES, Mark Palmer/Corp/Enron@ENRON, Karen.Denne@enron.com
cc: Karen.Denne@enron.com
Subject: Re: Chorety Crisis

Steve and Mark:

I arrived in the US on Saturday with a good feeling about what appears to be
a successful resolution of the Chorety crisis.  Under Steve Hopper's
leadership, the Chorety spill became a non-issue by Friday.  During the
crisis, I collaborated with my counterpart from Shell/London, Michael
Megarry, in developing a Key Messages and Internal Q&As document (attached).
At the daily meeting/conference call, there was an Operations Report from the
site, an analysis of the day's newspaper articles (which I handled), and
discussions on how to respond to media that were reporting or airing
inaccurate information that was damaging Transredes' image.

I also developed a Stakeholders Action Plan (attached) for the Incident
Commander to use in organizing and monitoring team member actions taken in
response to stakeholder concerns.  The Plan was updated daily by the
Transredes PR Office and given to team members prior to every
meeting/conference call.   The Stakeholder Report is intended to complement
the Operations Report.

I also want to acknowledge the support of Karen and Dennis during the early
stages of the crisis.  It was extremely helpful.

Regards, Keith


I'm working through the "agent for" issue, and thought I would share the
info.  I've asked our local counsel for  a bit more direct answer (ie, his
opinion).

Kay
---------------------- Forwarded by Kay Mann/Corp/Enron on 06/06/2001 03:42
PM ---------------------------

"Wilson Montjoy" <wmontjoy@brunini.com> on 06/06/2001 12:30:41 PM
To: <Kay.Mann@enron.com>
cc:

Subject: Joint agency as reseller of power

I've recopied below Miss. Code Ann. Sec. 77-5-727. Subsection (u) appears to
answer your question, at least as to purchases of electric power. I'm not
aware of anything under the joint action agancy law that empowers the entity
to buy gas on behalf of its members.

Section 77-5-729 provides authority for the member utility to contract with
the joint agency to purchase power. It's recopied below as well.

o 77-5-725. Powers of joint agencies
Current through End of 2000 3rd Ex. Sess.
References     Annotations
Each joint agency shall have all of the rights and powers necessary or
convenient to carry out and effectuate the purposes and provisions of this
article, including, but without limiting the generality of the foregoing, the
rights and powers:
(a) To adopt bylaws for the regulation of the affairs and the conduct of its
business, and to prescribe rules, regulations and policies in connection with
the performance of its functions and duties;
(b) To adopt an official seal and alter the same at pleasure;
(c) To maintain an office at such place or places as it may determine;
(d) To sue and be sued in its own name, and to plead and be impleaded;
(e) To receive, administer and comply with the conditions and requirements
respecting any gift, grant or donation of any property or money;
(f) To acquire by purchase, lease, gift or otherwise, or to obtain options
for the acquisition of, any property, real or personal, improved or
unimproved, including an interest in land less than the fee thereof;
(g) To sell, lease, exchange, transfer or otherwise dispose of, or to grant
options for any such purposes with respect to, any real or personal property
or interest therein;
(h) To pledge or assign any money, rents, charges or other revenues and any
proceeds derived by the joint agency from the sales of property, insurance or
condemnation awards;
(i) To issue bonds of the joint agency for the purpose of providing funds for
any of its corporate purposes;
(j) To study, plan, finance, construct, reconstruct, acquire, improve,
enlarge, extend, better, own, operate and maintain, one or more projects,
either individually or jointly, with one or more municipalities in this state
or any other state owning electric distribution facilities or with any
political subdivision, agencies or instrumentalities of any state, or with
any one or more joint agencies created pursuant to this article, or any
person, firm, association or corporation, public or private, engaged in the
generation, transmission or distribution of electric power and energy within
this state or any other state, and to pay all or any part of the costs
thereof from the proceeds of bonds of the joint agency or from any other
funds made available to the joint agency;
(k) To authorize the construction, operation or maintenance of any project or
projects by any person, firm or corporation, including political subdivisions
and agencies of any state, or of the United States;
(l) To acquire by lease, purchase or otherwise an existing project or a
project under construction, or any interest therein, or portion thereof;
(m) With the unanimous consent of the member municipalities, to sell or
otherwise dispose of any project or projects, or any interest therein or
portion thereof.  The member municipalities may enter into an agreement with
the joint agency whereby certain types of property may be traded or otherwise
disposed of without unanimous consent of the member municipalities;
(n) To fix, charge and collect rents, rates, fees and charges for electric
power or energy and other services, facilities and commodities sold,
furnished or supplied through any project;
(o) To generate, produce, transmit, deliver, exchange, purchase or sell for
resale only, electric power or energy, and to enter into contracts for any or
all such purposes;
(p) To negotiate and enter into contracts for the purchase, sale, exchange,
interchange, wheeling, pooling, transmission or use of electric power and
energy with any municipality in this state or any other state owning electric
distribution facilities, or with any political subdivisions, agencies or
instrumentalities of any other state or with other joint agencies created
pursuant to this article, any electric power association, any public or
private utility, and any state, federal or municipal agency which owns
electric generation, transmission or distribution facilities in this state or
any other state;
(q) To make and execute contracts and other instruments necessary or
convenient in the exercise of the powers and functions of the joint agency
under this article, including contracts with persons, firms, corporations and
others;
(r) To apply to the appropriate agencies of the state, the United States or
any state thereof, and to any other proper agency for such permits, licenses,
certificates or approvals as may be necessary, and to construct, maintain and
operate projects in accordance with, and to obtain, hold and use, such
licenses, permits, certificates or approvals in the same manner as any other
person or operating unit of any other person;  provided, however, nothing
herein contained shall be construed to require the joint agency to obtain any
permit, license, certificate or approval from the Public Service Commission
of Mississippi;
(s) To employ engineers, architects, attorneys, real estate counselors,
appraisers, financial advisors and such other consultants and employees as
may be required in the judgment of the joint agency and to fix and pay their
compensation from funds available to the joint agency therefor;
(t) To purchase all kinds of insurance including, but not limited to,
insurance against business interruption, and/or risks of damage to property;
(u) To purchase power and energy and related services from any source on
behalf of its members and other customers and to sell the same to its members
and other customers in such amounts, with such characteristics, for such
periods of time and under such terms and conditions as the board of
commissioners shall determine;  and
(v) To do all acts and things necessary, convenient or desirable to carry out
the purposes, and to exercise the powers granted to the joint agency herein.

o 77-5-729. Contracts by members to buy power from joint agencies
Current through End of 2000 3rd Ex. Sess.
References
Any municipality which is a member of the joint agency may contract to buy
from the joint agency power and energy required for its present or future
requirements, including the capacity and output of one or more specified
projects.  As the creation of a joint agency is an alternative method whereby
a municipality may obtain the benefits and assume the responsibilities of
ownership in a project, any such contract may provide that the municipality
so contracting shall be obligated to make the payments required by the
contract whether or not a project is completed, operable, operating, retired
or decommissioned and notwithstanding the suspension, interruption,
interference, reduction, curtailment or termination of the output of a
project or the power and energy contracted for, and that such payments under
the contract shall not be subject to any reduction whether by offset or
otherwise, and shall not be conditioned upon the performance or
nonperformance of the joint agency or any other member of the joint agency
under the contract or any other instrument.  Any contract with respect to the
sale or purchase of capacity or output of a project entered into between a
joint agency and its member municipalities may also provide that if one or
more of such municipalities shall default in the payment of its or their
obligations, with respect to the purchase of said capacity or output, then in
that event the remaining member municipalities which are purchasing capacity
and output under the contract shall be required to accept and pay for and
shall be entitled proportionately to and may use or otherwise dispose of the
capacity or output which was to be purchased by the defaulting municipality.
Notwithstanding the provisions of any other law to the contrary, any such
contracts with respect to the sale or purchase of capacity, output, power or
energy from a project may extend for a period not exceeding fifty (50) years
from the date a project is estimated to be placed in normal continuous
operation;  and the execution and effectiveness thereof shall not be subject
to any authorizations or approvals by the state or any agency, commission or
instrumentality or political subdivision thereof except as in this article
specifically required and provided.
Payments by a municipality under any contract for the purchase of capacity
and output from a joint agency shall be made solely from the revenues derived
from the ownership and operation of the electric system of said municipality
and any obligation under such contract shall not constitute a legal or
equitable pledge, charge, lien or encumbrance upon any property of the
municipality or upon any of its income, receipts or revenues, except the
revenues of its electric system, and neither the faith and credit nor the
taxing power of the municipality are, or may be, pledged for the payment of
any obligation under any such contract.  A municipality shall be obligated to
fix, charge and collect rents, rates, fees and charges for electric power and
energy and other services, facilities and commodities, sold, furnished or
supplied through its electric system sufficient to provide revenues adequate
to meet its obligations under any such contract and to pay any and all other
amounts payable from or constituting a charge and lien upon such revenues,
including amounts sufficient to pay the principal of and interest on bonds
heretofore or hereafter issued by the municipality for purposes related to
its electric system.
Any municipality which is a member of a joint agency may furnish the joint
agency with money derived solely from the ownership and operation of its
electric system or facilities and may make available for the use of the joint
agency any personnel, equipment and property, both real and personal, which
is a part of its electric system or facilities.
Any member of a joint agency may contract for, advance or contribute funds
derived solely from the ownership and operation of its electric system or
facilities to a joint agency as may be agreed upon by the joint agency and
the member, and the joint agency shall repay such advances or contributions
from proceeds of bonds, from operating revenues or from any other funds of
the joint agency, together with interest thereon as may be agreed upon by the
member and the joint agency.


John,

This is the update on what I have done for the LNG transactions.

1. I was not involved in the LNG ship project. I shall  read the DASH
and give you my comments. Without looking at the details, I think that the
decision
to charter a tanker removes one significant risk we have at the Elba Island
project (please, see point 2).

2. Elba Island. I am working with Doug Rotenberbg, Brad Hitch, Scott Earnest
(Sally Beck's organization) and RAC to set up the book for the Elba Island
transaction. The next step
will be to expand the book to capture all the Enron's LNG-related  positions
in one place and
to look for natural risk offsets and possible hedges. A working group is
meeting to close a few
remaining gaps  tomorrow (Tuesday) at 8:30.

A few comments on the book design and my view of the project:

a. The current thinking is that LNG will be sourced for the Elba Island
facility
by buying marginal cargos on the fob basis. Marginal cargos will represent
supply from excess capacity that has not been committed under long-term
contracts or became available due to some short-term frictions.

The fob cargos are typically selling at a significant discount to the
long-term
contract prices. The economics of the deal, as represented by the book we are
setting up, will reflect the assumption that not only we can locate marginal
cargos
but that we shall be able to do it on a regular basis, arranging shipping and
coordinating
the facility schedule and natural gas transactions in the US. In other words,
we have a significant logistical and operational risk in this transaction.

b. The transaction will cover the period of 17 years (with an extension
option of
5 years). Even if we can lock-in the LNG volumes over this time period, we
have no ability to lock-in the other side of the spread (US gas prices) for
such a long tenor. This is
essentially a tolling transaction with exposure to the LNG - nat gas spread
and
I would not recommend locking-in only one leg of the spread.

One solution would be to  cover, let's say, 50% of he LNG volumes for the
first
5 years and lock-in the nat gas side on the US market side.

c. The book we are setting up will be based on many managerial assumptions
regarding sources of LNG, shipping rates, schedules, etc. I would set up a
big prudence reserve
in case we mark it to market.

d. My group will work on valuation of some options we have in the Elba Island
deal
(that are good for Enron) and on the hedging strategy for the LNG positions.
Long-term LNG contracts are typically based on the Japanese Crude Cocktail
that
correlates very well with Brent.

Vince

John Sherriff
05/14/2000 01:40 AM
To: Vince J Kaminski/HOU/ECT@ECT
cc: Lauren Urquhart/LON/ECT@ECT
Subject: LNG May 19 decision

Vince

I haven't spoken to you for awhile but hope the world is treating you well.
Anyway with Greg moving to his
new role I have (I hope only temporarily) staff trading oversight for the
Eastern Hemishere plus LNG.

I understand that your group is taking a first cut at developing curves for
LNG and LNG ship values.   I also understand
that another LNG ship decision is on the dockets for May 19 (not very far
away).  Anway I understand this
is a big decision but I still have gotten very little info yet.  Can you
please let me know where you stand now?

I will ask my assistant Lauren to set up a time that I can speak with you in
the next couple of days and if you
have anything for me to review before then she can get it faxed to me as well.

Look forward to connecting with you Vince.

John


am on vacation. sorry otherwise i would do it.


Why don't you reserve a conference room.  That way Jeff can leave when he
needs to and everyone else can continue meeting.

Thanks,
Joannie

From: Dorothy Dalton@ENRON COMMUNICATIONS on 03/26/2001 03:47 PM
To: Jeff Skilling/Corp/Enron@ENRON
cc:

Subject: Re: 4/3/01 - 1:30-3:30 p.m. - Meeting Confirmation

Yes, Ken will be present for the first hour with Jeff and Partha has asked
for an additional hour with Ken following that meeting.  Would you like me to
secure a conference room for both meetings or have Jeff's portion in his
office and then have them come down to Ken's office for the second hour?

Dorothy Dalton
Office of the Chairman
Enron Broadband Services
1400 Smith Street, EB4505
Houston, TX  77002
713-853-6724 - direct
713-853-9469 - fax

	Jeff Skilling@ENRON
	Sent by: Joannie Williamson@ENRON
	03/26/01 03:42 PM

		 To: Dorothy Dalton/Enron Communications@ENRON COMMUNICATIONS
		 cc:
		 Subject: Re: 4/3/01 - 1:30-3:30 p.m. - Meeting Confirmation

Dorothy, I have this meeting scheduled on Jeff's calendar from 1:30 - 2:30.
Do you anticipate Jeff and Ken being present for the first hour of the
meeting, and Ken handling the second hour?

Thanks,
Joannie

From: Dorothy Dalton@ENRON COMMUNICATIONS on 03/26/2001 01:28 PM
To: Ken Rice/Enron Communications@Enron Communications, Sherri
Sera/Corp/Enron@ENRON, Joannie Williamson/Corp/Enron@ENRON, Jeff
Skilling/Corp/Enron@ENRON
cc:

Subject: Re: 4/3/01 - 1:30-3:30 p.m. - Meeting Confirmation

Fyi - agenda for meeting with Partha Ghosh of Adventis next week.  Are Ken &
Jeff interested in dinner Monday evening?

Dorothy Dalton
Office of the Chairman
Enron Broadband Services
1400 Smith Street, EB4505
Houston, TX  77002
713-853-6724 - direct
713-853-9469 - fax
----- Forwarded by Dorothy Dalton/Enron Communications on 03/26/01 01:16 PM
-----

	Parthasg@aol.com
	03/23/01 10:26 PM

		 To: Dorothy Dalton/Enron Communications@Enron Communications
		 cc: PGHOSH@adventis.com, MBruneau@adventis.com, ABelt@adventis.com,
Bkirby@adventis.com
		 Subject: Re: 4/3/01 - 1:30-3:30 p.m. - Meeting Confirmation

Dear Dorothy:

Thank you very much for your note; below I have laid out the agenda for the
meeting for Ken and Jeff's approval:

1. Introduction to Adventis and our work in the Broad band space; - 20 minutes
2.  Ken's brief on Broad Band Services group's way forward: challenges,
issues, aspirations; - 15 minutes
3. Jeff's expectations and views form the corporate center;-10 minutes
4. Adventis' approach, likely routes to partnership;-10 minutes
5. Next steps: JEFF, KEN and our team.- 10/15 minutes

During the second hour with Ken, we wish to address specific points on the
out come of the first meeting to define areas of focus for path forward:

1 Strategic and operational issues for short term value creation, and
long-term robust development of BBS as global player
2. Acceleration capacity at BBS to capture short range opportunities versus
outside assistance.
3. Likely ways we could engage with Enron for both short term and long-term
wins.
4. Time line for creating the upside.

I am sure Ken and Jeff, will have a lot to add. Please do let me know.

Dorothy, given the significant challenges and opportunities ahead for Enron
BBS, we will have four of our senior most partners with deep insights into
Broad band and ASPs/CSPs join the meeting. I will come the night before, if
possible to have dinner with Jeff and/or Ken. Please do let me know the
possibility.

Regards,

Partha Ghosh
617 421 9990 X475

 - att1.htm


You are invited to attend a Profiles Manager Meeting

Date                                                               11/10/00

Time                                                                3:00- 5:00

Location                                                           Training
Room EB 572


Due to the current business circumstances the hours to the Energizer Cafe, The Express Store, and Plaza Java will be adjusted as of Monday, December 10, 2001.  Please note the operating hours for each location below:

Energizer Cafe		Breakfast: 7:30 to 9:00 AM
			Lunch: 11:30 AM to 1:00 PM

The Express Store	8:30 AM to 3:00 PM

Plaza Java		7:00 AM to 3:00 PM

Thank you.


Looks like NatWest's cross-complaint against Farallon's fund managers may
hold up at the pleading stage.? See below.

-----Original Message-----
From:?? Bhalla, Sabina
Sent:?? Friday, September 22, 2000 12:03 PM
To:???? Howard, Steve
Subject:??????? Farallon Demurrer hearing

This morning I attended the hearing on Cross-Defendants demurrer to Natwest's
Cross-Complaint.? The judge permitted extensive oral argument from Bruce
MacLoed representing Farallon and Oaktree, and Jim Wines representing
Natwest.?

Judge Berle was extremely active in asking questions to each party.? He was
primarily concerned with the relationship between the fund managers and
Oaktree and Farallon, and whether that was a fiduciary relationship, and if
so, what level of fiduciary duty was owed (he seemed inclined to leave this
issue for summary judgment).? The Cross-Defendants argued that if this suit
was to go forward, it would create a disincentive for fund managers to report
fraud, since the? fund managers may ultimately be personally liable.?

Judge Berle asked Natwest if this was more of an affirmative defense instead
of a cross claim, which was being used to diminish Plaintiffs complaint.?
Natwest stated that the fiduciaries were liable for not investigating.?
Farallon/Oaktree admitted that it has imputed any negligence and actual
knowledge from the fund managers to itself, and that Defendants are entitled
to an offset.? Interestingly, Plaintiffs stated that the fund managers were
damaged themselves, since they did not receive a bonus etc.??

The Judge seemed inclined to permit a demurrer to the contribution cause of
action, since Natwest did not really defend that cause of action separate
from the indemnity action.?

Natwest pointed to a case Platt v. Coldwell Banker 217 Cal. App.3d 1439,
which Natwest claimed, allows the fund managers to be sued independently.? A
cross action is permitted if the Plaintiffs could have brought the same
claims against the fund managers, and Natwest argued that the Plaintiffs
could have brought such a claim.? Finally, Natwest said it would be
prejudiced if it could not "point the finger" at the highly paid investement
manager.? According to the Platt case, a nonparty witness is very different
than a potential indemnitor who is sitting at the table at trial.??

???
The judge said his ruling would occur before Oct. 10.? Legg Mason
Cross-Defendants have until that time to file a response to the
cross-complaint (that was what the ex parte application was about).

This e-mail message may contain legally privileged and/or confidential
information. If you are not the intended recipient(s), or the employee
or agent responsible for delivery of this message to the intended
recipient(s), you are hereby notified that any dissemination,
distribution or copying of this e-mail message is strictly prohibited.
If you have received this message in error, please immediately notify
the sender and delete this e-mail message from your computer.


Start Date: 4/21/01; HourAhead hour: 22;  No ancillary schedules awarded.
Variances detected.
Variances detected in Load schedule.

    LOG MESSAGES:

PARSING FILE -->> O:\Portland\WestDesk\California Scheduling\ISO Final
Schedules\2001042122.txt

---- Generation Schedule ----
*** Final schedule not found for preferred schedule.
     Details:

  TRANS_TYPE: FINAL
  SC_ID: HARBOR
  MKT_TYPE: 2
  TRANS_DATE: 4/21/01
  UNIT_ID: HARBGN_7_UNITS

---- Load Schedule ----
$$$ Variance found in table tblLoads.
     Details: (Hour: 22 / Preferred:   5.22 / Final:   4.89)
  TRANS_TYPE: FINAL
  LOAD_ID: PGE2
  MKT_TYPE: 2
  TRANS_DATE: 4/21/01
  SC_ID: EPMI


Start Date: 1/5/02; HourAhead hour: 1;  No ancillary schedules awarded.  Variances detected.
Variances detected in Load schedule.

    LOG MESSAGES:

PARSING FILE -->> O:\Portland\WestDesk\California Scheduling\ISO Final Schedules\2002010501.txt

---- Load Schedule ----
$$$ Variance found in table tblLoads.
     Details: (Hour: 1 / Preferred:  36.57 / Final:  36.54)
  TRANS_TYPE: FINAL
  LOAD_ID: PGE2
  MKT_TYPE: 2
  TRANS_DATE: 1/5/02
  SC_ID: ENRJ


Check for ML


See attached.

Thanks,

Rose


Subject: FW: New Ballot for West Palm Beach County

 - BallotWPBF11.11.00.doc


---------------------- Forwarded by Susan M Scott/HOU/ECT on 04/13/2000 10:58
AM ---------------------------

	Enron Capital & Trade Resources Corp.

	From:  Monique Sanchez                           04/13/2000 10:44 AM

To: Susan M Scott/HOU/ECT@ECT
cc:
Subject: Fw: This is long but definitely worth reading

---------------------- Forwarded by Monique Sanchez/HOU/ECT on 04/13/2000
10:43 AM ---------------------------

	Enron North America Corp.

	From:  Mark Friedman                           12/27/99 09:52 AM

To: David Oliver/HOU/ECT@ECT, Reagan Mathews/HOU/ECT@ECT, Monique
Sanchez/HOU/ECT@ECT
cc:
Subject: Fw: This is long but definitely worth reading

---------------------- Forwarded by Mark Friedman/HOU/ECT on 12/27/99 09:51
AM ---------------------------

"ANDREW J COWEN" <andrew@b2b123.com> on 12/23/99 12:44:30 PM
To: "Staci Markman" <staci.markman@courts.state.tx.us>, Mark
Friedman/HOU/ECT@ECT, "'Jeff Masanow'" <Jeff@exchange.nssco.com>, "Litofsky,
Marcus" <Marcus.Litofsky@sci-us.com>, "Rachel Abbott" <patandband@aol.com>,
"Rachel Gary" <rgary@us.oracle.com>, "Maria Hale" <maria.hale@carlberg.com>,
"David Barton" <dave.barton@carlberg.com>, "Brian Fisher"
<brian.fisher@carlberg.com>, "Heather Kristoff" <heather.kristoff@chron.com>,
"Jacki Schwartz" <jschwartz@glesbymarks.com>, "Arthur Polott"
<apolott@bsmpc.com>, "Dina Ginsberg" <dginsber@bindview.com>, "Shara"
<shara@flash.net>, "Terri Lubrano" <terrilubrano@worldnet.att.net>, "Hugh
Morrison" <pilgrimboss@prodigy.net>, "Carey Bradfield-Harvey"
<gph24@aol.com>, "Jeff Estes" <jestes@hbk.com>, "Jed Freedlander"
<jed_freedlander@heliosconsulting.com>
cc:
Subject: Fw:  This is long but definitely worth reading

OK everyone.  This story is why Yankees tell redneck jokes.

> > This is an e-mail from some guy named J.D. Horne, who, according to the
> > messages that were attached to this, is not a 21 year-old frat boy, but
an
> > attorney of indeterminate age. He sent it to his friend Brian Brice and
it
> > got forwarded around the country. You have to give the guy some props
for
> > being self-deprecating...but I hope I never meet him on game day.
> >
> > ******
> > A chronology of events for Saturday, December 4, 1999, and the early
morning
hours of Sunday, December 5, 1999:
6:00 Arise, play the Eyes of Texas and Texas Fight at full-freaking blast
6:20 Get in car, drive to New Braunfels
7:30 Tee off (me and a buddy were the FIRST tee-time of the morning)
8:50 Turn 9 (crack open first beer)
8:53 Crack open second beer
8:58 Crack open...(you get the idea)
10:30 Finish 18 (holes, as well as beers), sign scorecard for smoooooth 95
10:35 Headed for San Antonio
10:50 Buy three 18-packs for pre- and post-game festivities
11:10 We decide we don't have enough booze, so we double-back to a liquor
store and buy the good ol' 750 ml plastic bottle "Traveler" Jim Beam
11:50 Arrive at the tailgate spot. Awesome day. Not a single cloud in the
sky. About 70 degrees.
11:55 I decide that we're going to kick the shit out of Nebraska.
11:56 I tell my first Nebraska fan to go fuck himself.
12:15 The UT band walks by on the way to the Alamodome. We're on the second
floor of a two-story parking garage on the corner (a couple hundred of us).
We're hooting and hollering like wildmen. The band doubles back to the
street right below us and serenades us with Texas Fight and The Eyes of
Texas. AWESOME MOMENT.
12:25 In the post-serenade serendipity, 50-100 grown men are bumping chests
with one another, each and every one of them now secure and certain of the
fact that we are going to kick the shit out of Nebraska.
1:00 The Nebraska band walks by on the way to the Alamodome. Again, we hoot
and holler like wildmen. Again, the band doubles back and stops right below
us to serenade us, this time, however, with the Nebraska fight songs.
*Although somewhat impressed by their spirit and verve, we remain convinced
that we are going to kick the shit out of Nebraska.
1:30 I begin the walk to the Alamodome, somehow managing to stuff the
"Traveler" and 11 cans of beer into my pants.
1:47 I am in line surrounded by Nebraska fans. They are taunting me. I am
taunting back, still certain that we are going to kick the shit out of
Nebraska. I decide to challenge a particularly vocal Nebraska fan to play
 what I now call and will forever be remembered as "Cell-Phone Flop Out."
Remember flop out for a dollar? The rules are similar. I tell this Nebraska
jackass that if he's so confident in his team, he should "flop out" his cell
 phone RIGHT NOW and make plane reservations to Phoenix for the Fiesta
Bowl.
 And then I spoke these memorable words: "And not those damn refundable
tickets, either! You request those non-refundable, non-transferrable
sons-of-bitches!" He backs down. He is unworthy. I call Southwest Airlines
and buy two tickets to Phoenix, non-refundable and non-transferrable. Price:
 $712. He is humbled. He lowers his head in shame. I raise my cell phone in
 triumph to the cheers of hundreds of Texas fans. I am KING and these are my
 subjects. I distribute the 11 beers in my pants to the cheering masses. I
 RULE the pre-game kingdom.
2:34 Kickoff. Brimming with confidence, I open the Traveler and pour my
first stiffy.
2:45 I notice something troubling: Nebraska is big. Nebraska is fast.
Nebraska is very pissed off at Texas.
3:01 The first quarter mercifully ends. 9 yards total offense for Texas.
Zero first downs for Texas. I'm still talking shit. I pour another stiffy
 from the Traveler.
3:36 Four minutes to go in the first half: the Traveler is a dead soldier.

I buy my first $5 beer from the Alamodome merchants. While I am standing in
line, a center snap nearly decapitates Major Applewhite and rolls out of the
end zone. Safety.
3:56 Halftime score: Nebraska 15, Texas 0. I wish I had another Traveler.
4:11 While urinating next to a Nebraska fan in the bathroom at halftime, I
attempt to revive the classic Brice-ism from the South Bend bathroom:
"Hey, buddy, niiiiiiiiice cock." He is unamused.
4:21 I buy my 2nd and 3rd $5 beer from the Alamodome merchants. I share my
beer with two high school girls sitting behind me. Surprisingly, they are
equipped with a flask full of vodka. I send them off to purchase Sprites, so
that we may consume their vodka. I have not lost faith.  Nebraska is a bunch
of pussies.
4:51 No more vodka. The girls sitting behind me have fled for their lives.

I purchase two more $5 beers from the Alamodome merchants.
5:18 Score is Nebraska 22, Texas 0. I am beginning to lose faith. This
normally would trouble me, but I am too drunk to see the football field.
5:27 I call Southwest Airlines: "I'm sorry, sir. Those tickets have been
confirmed and are non-refundable and non-transferrable."
5:37 I try to start a fight with every person behind the concession counter.
As it turns out, the Alamodome has a policy that no beer can be sold when
there is less than 10 minutes on the game clock. I am enraged by this
policy. I ask loudly: "Why the fuck didn't you announce last call over the
fucking PA system??!!"
5:49 Back in my seats, I am slumped in my chair in defeat. All of a sudden,
the Texas crowd goes absolutely nuts. "Whazzis?," I mutter, awaking from my
coma, "Iz we winnig? Did wez scort?" Alas, the answer is no, we were not
winning and we did not score. The largest (by far) cheer of the day from
the
Texas faithful occurred when the handlers were walking back to the tunnel
and Bevo stopped to take a gargantuan shit all over the letters "S", "K",
and "A" in the "Nebraska" spelled out in their end zone.  I cheer wildly.

I pick up the empty Traveler bottle and stick my tongue in it. I am thirsty.
6:16 Nebraska fans are going berserk as I walk back to the truck. I would
taunt them with some off-color remarks about their parentage, but I am too
drunk to form complete sentences. With my last cognitive thought of the
evening, I take solace in the fact that if we had not beaten them in
October, they would be playing Florida State for the national
championship.
6:30 Back in the car. On the way back to Austin for the 8:00 Texas-Arizona
tip off. We can still salvage the day! I crack open a beer.  *It is warm.

I don't care.
7:12 We have stopped for gas. I am hungry. I go inside the store. I walk
past the beer frig. I notice a Zima. I've never had a Zima. I wonder if it's
any good. I pull a Zima from the frig. I twist the top off and drink the
Zima in three swallows. Zima sucks. I replace the empty bottle in the frig.
7:17 There is a Blimpie Subs in the store. I walk to where the ingredients
are, where the person usually makes the sub. There is no one there. I lean
over the counter and scoop out half a bucket of black olives. I eat them.

I am still hungry. I lean further over the counter and grab approximately
two
pounds of Pastrami. I walk out of the store grunting and eating Pastrami.
The patrons in the store fear me. I don't care.
8:01 We are in South Austin. I have been drinking warm beer and singing
Brooks and Dunn tunes for over an hour. My truck-mate is tired of my
singing. He suggests that perhaps Brooks and Dunn have written other good
songs besides "You're Going to Miss Me When I'm Gone" and "Neon Moon" and
that maybe listening to only those two songs, ten times each was a bit
excessive. Perhaps, he suggests, I could just let the CD play on its own.

I tell him to fuck off and restart "Neon Moon."
8:30 We arrive at the Erwin Center. My truckmate, against my loud and
profane protestations, parks on the top floor of a nearby parking garage.

I
tell him he's an idiot. I tell him we will never get out. I tell him we may
as well pitch a fucking tent here. He ignores me. I think he's still pissed
about the Brooks and Dunn tunes. I whistle "Neon Moon" loudly.
8:47 I am rallying. I have 4 warm beers stuffed in my pants. We're going to
kick the shit out of Arizona.
9:11 Halftime score: Texas 31, Arizona 29. I am pleased. I go to the
bathroom to pee for the 67th time today. I giggle to myself because of the
new opportunity to do "the bathroom Brice." There are no Arizona fans in the
bathroom. I am disappointed. I tell myself (out loud) that I have a
"Niiiiiice cock." No one is amused but me.
9:41 I walk to the bathroom while drinking Bud Light out of a can.  Needless
to say, they do not sell beer at the Erwin Center,much less Bud Light out

of
a can. I am stopped by an usher: "Where did you get that, sir?" I tell him
(no shit): "Oh, the cheerleaders were throwing them up with those little
plastic footballs. Would you mind throwing this away for me?" I take the
last swig and hand it to him. He is confused. I pretend I'm going to the
bathroom, but I run away giggling instead. I duck into some entrance to
avoid the usher, who is now pursuing me. I sneak into a large group of
people and sit down. The usher walks by harmlessly. I am giggling like a
little girl. I crack open another can of Bud Light.
9:52 I am lost. In my haste to avoid the usher, I have lostmy bearings. I
have no ticket stub. I cannot find my seats. Texas is losing.
10:09 Texas is being screwed by the refs. I am enraged. I have cleared out
the seats around me because I keep removing my hat and beating the
surrounding chairs with it. A concerned fan asks if I'm OK and perhaps I
shouldn't take it so seriously. I tell him to fuck off.
10:15 After the fourth consecutive "worst fucking call I have EVER seen," I
attempt to remove my hat again to begin beating inanimate objects.  However,
on this occasion I miscalculate and I thumbnail myself in my left eyelid,
leaving a one-quarter inch gash over my eye. I am now bleeding into my left
eye and all over my shirt. "Perhaps," I think to myself, "I'm taking this a
bit seriously."
10:22 I am standing in the bathroom peeing. I'm so drunk I am swaying and
grunting. I have a bloody napkin pressed on my left eye. My pants are
bloody. I have my (formerly) white shirt wrapped around my waist. I look
like I should be in an episode of Cops.
10:43 Texas has lost. I put my bloody white shirt back on my body and make
my way for the exits. I am stopped every 20 seconds by a good
samaritan/cop/security guard to ask me why I am covered in blood, but I
merely grunt incoherently and keep moving.
10:59 With my one good eye, I have located the parking garage. I walk up six
flights of stairs, promise that when I see my friend I will punch him in the
face for making me walk up six flights of stairs, find the truck, and
collapse in a heap in the bed of the truck. I look around and notice that
traffic is lined up all the way around the garage, six whole flights, and

no one is moving. I take a nap.
11:17 I awake from my nap. I see my friend in the driver's seat. I lift my
head to look out the bed of the truck and notice that traffic is lined up
all the way around the garage, six whole flights, and no one is moving.  I
am too tired to punch my friend. I call my friend a "Stupid cocksucker."
11:31 I lift my head to look out the bed of the truck and notice that
traffic is lined up all the way around the garage, six whole flights, and no
one is moving. I call my friend a "Stupid cocksucker."
11:38 I lift my head to look out the bed of the truck and notice that
traffic is lined up all the way around the garage, six whole flights, and no
one is moving. I call my friend a "Stupid cocksucker."
11:47 I lift my head to look out the bed of the truck and notice that
traffic is lined up all the way around the garage, six whole flights, and

no one is moving. I call my friend a "Stupid cocksucker."
11:58 I am jostled. The truck is moving. I lift my head to look out the bed
of the truck and notice that traffic is beginning to move on the second
floor. I jump out of the truck, walk to the edge of the parking facility,
and pee off the sixth floor onto the street below. My friend looks at me
like I just anally violated his minor sister. I turn around and pee on the
front of his truck while singing the lyrics to "Neon Moon."
12:11 We are moving. We are out of beer. I jump from the truck and go from
vehicle to vehicle until someone gives me two beers. I am happy. I return to
my vehicle.
12:26 We have emerged from the parking facility. We make our way to my
apartment and find Ed sitting on the couch with a freshly opened bottle of
Glenlivet on the coffee table in front of him. We are all going to die
tonight.
12:59 We have finished three-quarters of the bottle of Glenlivet. We decide
it would be a wonderful idea to go dancing at PollyEsther's. Ed has to pee.
He walks down the hall to our apartment and directly into the full length
 mirror at the end of the hall, smashing it into hundreds of pieces.  We
giggle uncontrollably and leave for PollyEsther's.
1:17 The PollyEsther's doorman laughs uncontrollably at our efforts to enter
his club. "Fellas," he says in between his fits of spastic laughter, "I've
 been working this door for almost a year. I've been working doors in this
town for almost 5 years. And I can honestly say that I ain't never seen
three drunker mother fuckers than you three. Sorry, can't let you in." We
attempt to reason with him. He laughs harder.
1:44 We find a bar that lets us in. We take two steps in the door and hear
"Last call for alcohol!" I turn to the group and mutter: "See, dat wasn't
that fuckin' hard. Day don't fuckin' do that at the Awamo...the awaom...the
alab...fuck it, that stadium we was at today..." We order 6 shots of tequila
and three beers.
2:15 Back on the street. We need food. We hail a cab to take us the two and
one half blocks to Katz's. The cab fare is $1.60. We give him $10 and tell
him to keep it.
2:17 There is a 20 minute wait. We give the hostess $50. We are seated
immediately.
2:25 We order two orders of fried pickles, a Cobb salad, a bowl of soup, two
orders of Blueberry blintzes, two Reuben sandwiches, a hamburger, two cheese
stuffed potatoes, an order of fries, and an order of onion rings.
2:39 The food arrives. We are all asleep with our heads onthe table. The
waiter wakes us up. We eat every fucking bit of our food. Most of the
restaurant patrons around us are disgusted. We don't give a fuck. The tab is
$112 with tip.
2:46 I'm sleepy.
9:12 I wake up next to a strange woman. She is the bartender at Katz's.
She is not pretty.
> >
>

 - att1.htm


Contact: ?Jean Munoz ???????????????FOR IMMEDIATE RELEASE
????????916-447-8186 ???????????????????June 26, 2001

ENERGY PRODUCERS? POWER UPDATE

SACRAMENTO . Jan Smutny-Jones, Executive Director of the Independent Energy
Producers Association, will brief members of the media on California?s
rapidly changing electric market during a teleconference Wednesday, June 27
at 11:00 a.m.

What: ???Press Availability Teleconference
 ???
When: ?Wednesday, June 27, 2001
????????????11:00 a.m. PDT

Call In #: ??1-800-374-2393
????????????????Conference I.D: Independent Energy Producers (IEP)

Who: ???Jan Smutny-Jones, Executive Director of the Independent Energy
Producers Association

# ????????# ????????#


Quantity Limits- For SCE and PG&E, previously approved BFM limitations are
the following:
SCE
Limits for BFM products including retail energy transactions, and daily and
balance of the month BFM products:
Retail Energy markets are limited at SCE's net short position which is a
maximum of
 Q1: 2,200 MW, Q2 2,200 MW, Q3: 5,200 MW, Q4: 3,000 MW
Participation ion daily and balance of the month BFM products are limited to
amounts above 1,000 MW SCE's net short position.

PG&E
Limits for BFM products including retail energy transactions, and daily and
balance of the month BFM products:
Retail Energy markets are limited at PG&E's net short position which is not
disclosed. However it is reasonable to assume that it is at least 3,000 MW
for the summer quarters given that PG&E had previously filed asking for a
limit of 3,000 MW.
 Participation in daily and balance of the month BFM products are limited to
amounts above 1,000 MW PG&E's net short position.

SDG&E BFM limits approved in Advice Letter 1234-E
Monthly and Quarterly Forward Market:  1900 MW July-September, 1700 MW all
other months
Daily and Balance of Month quantities will not exceed 1000 MW more than the
limits in the forward markets
Ancillary Services  will not exceed 90% of SDG&E's forecast ancillary
services for the month or the quarter.
SDG&E's limits are ultimately limited to the load to customers under 20 kW.

---------------------- Forwarded by Bruno Gaillard/SFO/EES on 08/04/2000
04:13 PM ---------------------------

Bruno Gaillard
08/03/2000 06:39 PM
To: David Parquet/SF/ECT@ECT, Tim Belden/HOU/ECT@ECT, Robert
Badeer/HOU/ECT@ECT, Jake Thomas/HOU/ECT@ECT, Michael McDonald/SF/ECT@ECT,
Greg Wolfe/HOU/ECT@ECT, Mona L Petrochko/SFO/EES@EES, Jeff
Dasovich/SFO/EES@EES, Paul Kaufman/PDX/ECT@ECT, Susan J Mara/SFO/EES@EES,
Sandra McCubbin/SFO/EES@EES, Roger Yang/SFO/EES@EES, Dennis
Benevides/HOU/EES@EES
cc:
Subject: Bilateral Contracts for SCE, PG&E and SDG&E

Both SCE and PG&E have been authorized to purchase energy, capacity, and
ancillary services through bilateral contracts.
Quantities are limited to previously authorized limits in the forward market
(the PX Block Forward Markets)
The contracts must expire on or before 12/31/05.
For both PG&E and SCE, these contracts will be subject to limited
reasonableness review.
PG&E will not be allowed to enter into such contracts after the transition
period ends (3/31/02). The Commission will continue e to oversee the
procurement practices on a quarterly basis.
This was an emergency motion, so it is reasonable to assume that both PG&E
and SCE can enter into such transactions immediately.

SDG&E is authorized to enter into bids for 6*16 delivery period or a 7*24
delivery period for terms of 8/00 through 12/00 or 8/00 through 3/01.
SDG&E will submit bids to buy energy a levelized price for both terms.
SDG&E will bid only for small commercial and residential customers under 20kW
The quantities are limited to the quantities that they had approved in the
BFM participation spelled out in advice letter 1234-E. I do not have a copy
of that advice letter off hand but will provide you with the information
tomorrow.

We will provide you with more details soon.

If you have any questions please do not hesitate to contact me.

Attached are the decision related to the above issues.


This is preliminary.  I'm supposed to get with our finance folks tomorrow to
get it finished.  This is ok to send to NW with that understanding.

Kay


Dan,

Attached below is another Netting Agreement that this counteparty would like
to have executed.  This is mainly an active Canadian counterparty (where we
have all contracts executed with ECC) but they also do business with ENA.
The exposures are getting significant enough where they are needing netting
arrangements.

Please take a look at this draft that they have forwarded below.  If you find
it unacceptable, let me know and I will communicate it to the counterparty
and forward ours.  They initiated this and preferred we view their "simple"
document.

Thanks,

Veronica

---------------------- Forwarded by Veronica Espinoza/Corp/Enron on
08/17/2000 05:18 PM ---------------------------

"Jill Yow" <Jill_Yow@pancanadian.ca> on 08/17/2000 05:17:54 PM
Please respond to Jill_Yow@pancanadian.ca
To: veronica.espinoza@enron.com
cc:

Subject: Net Settlement Agreement

Veronica,

As discussed, please find attached a copy of our Net Settlement
Agreement for your review.

Should you have any questions, please don't hesitate to call me at (403)
268-7999.

Thank you,
Jill Yow

 - Enron North America Corp..doc


I've reviewed the IGS market development agreement pursuant to your request.
It expires 2/29/00.  The agreement requires the parties to meet 90 days prior
to that date for the purpose of discussing an extension but does not obligate
us to agree to any such extension.

As you know, I have a conflict tomorrow at 10, but would be happy to provide
any other information you need for the meeting.


I'll be there.  Thanks.


Reservation status has changed. Details of the reservation are listed below:
ASSIGNMENT_REF = 29808
SELLER_CODE = AZPS
SELLER_DUNS = 958982563
CUSTOMER_CODE = EPMI
CUSTOMER_DUNS = 848921276
AFFILIATE_FLAG = 0
PATH_NAME = W/AZPS/AZPS-AZPS/FOURCORNE345 - PNPKAPS230//
POINT_OF_RECEIPT = FOURCORNE345
POINT_OF_DELIVERY = PNPKAPS230
SOURCE = FOURCORNERS
SINK = PRESCHEDULE
CAPACITY = 25
CAPACITY_REQUESTED = 25
SERVICE_INCREMENT = HOURLY
TS_CLASS = FIRM
TS_TYPE = POINT_TO_POINT
TS_PERIOD = OFF_PEAK
TS_WINDOW = FIXED
TS_SUBCLASS = WHEEL
NERC_CURTAILMENT_PRIORITY = Nerc Priority 1
OTHER_CURTAILMENT_PRIORITY = Default
START_TIME = 04/04/2002
STOP_TIME = 04/05/2002
CEILING_PRICE = 1.95
OFFER_PRICE = 1.95
BID_PRICE = 1.95
PRICE_UNITS = $/mW
PRECONFIRMED = YES
ANC_SVC_LINK = N/A
ANC_SVC_REQ = N/A
POSTING_REF = 0
SALE_REF =
REQUEST_REF =
DEAL_REF =
NEGOTIATED_PRICE_FLAG =
STATUS = CONFIRMED
STATUS_NOTIFICATION = lisa.gang@enron.com
STATUS_COMMENTS =
TIME_QUEUED = 04/03/2002

TIME_OF_LAST_UPDATE = 04/03/2002
PRIMARY_PROVIDER_COMMENTS =
SELLER_COMMENTS =
CUSTOMER_COMMENTS = PLEASE (503)464-5070
SELLER_NAME = AZPS
SELLER_PHONE = 602.250.1128
SELLER_FAX = 602.250.1155
SELLER_EMAIL = oasisadm@apsc.com
CUSTOMER_NAME = Enron Power Marketing, Inc.
CUSTOMER_PHONE = (713)853-3801
CUSTOMER_FAX = (713)646-8272
CUSTOMER_EMAIL = bill.rust@enron.com
REASSIGNED_REF = 0
REASSIGNED_CAPACITY = 0


----- Forwarded by Jeff Dasovich/NA/Enron on 02/09/2001 01:30 PM -----

	MBD <MDay@GMSSR.com>
	02/09/2001 12:12 PM

		 To: "'Jeff Dasovich  Enron SF'" <jdasovic@enron.com>
		 cc:
		 Subject: Strike the last two sentences of Section 80110 that currently rea
ds:

 <<subscription_.doc>>

Jeff, here is the latest version of the coalition's language.  There is a
call at 3pm to day with the coalition to discuss presenting it to Bowen.
Mike

 - subscription_.doc


No problem

	<Suzanne_Nimocks@mckinsey.com>
	12/07/2000 02:18 PM

		 To: skean@enron.com
		 cc:
		 Subject: Tomorrow's meeting

I realized that we'll have quite a few people there tomorrow: Rick, Mary ,
Jeff,  you, me, Jon.  Do you have a problem if Dan comes too, or would you
rather not.

+-------------------------------------------------------------+
| This message may contain confidential and/or privileged     |
| information.  If you are not the addressee or authorized to |
| receive this for the addressee, you must not use, copy,     |
| disclose or take any action based on this message or any    |
| information herein.  If you have received this message in   |
| error, please advise the sender immediately by reply e-mail |
| and delete this message.  Thank you for your cooperation.   |
+-------------------------------------------------------------+


-----Original Message-----
From: 	"Glover, Rusty" <rglover@halff.com>@ENRON
Sent:	Friday, December 14, 2001 10:04 AM
To:	SHELLEY (E-mail); LARRY OSBORNE (E-mail); KAK (E-mail); JENNIFER (E-mail); GREG & DONELLE (E-mail); DON & LINDA (E-mail); Farmer, Daren J.; BRAD DAVIS (E-mail); ANDREA & MICHAEL (E-mail)
Subject:	Makenzi at the Halff Christmas Party

 <<DSCN0580.JPG>>  <<DSCN0584.JPG>>  <<DSCN0585.JPG>>  <<DSCN0588.JPG>>  <<DSCN0592.JPG>>  <<DSCN0601.JPG>>

 - DSCN0580.JPG
 - DSCN0584.JPG
 - DSCN0585.JPG
 - DSCN0588.JPG
 - DSCN0592.JPG
 - DSCN0601.JPG


Thanks for the note, except of course for the last comment, why don't you
just go seat in row 100 - alright.  Megan and I had a great time and enjoyed
having you guys come out..  I love going out there during the summer.  We are
going to arrange a ski weekend on President Day Weekend this February - so
make plans to be laughed at while skiing.  I didn't mean laughed at - I meant
having a fun time.  Talk to you soon.
Ben


Janie/Mike:

As you know, EPMI has been buying gas from the West Gas Desk for Harbor Cogen.  We dispatch this plant and buy their electricity.  Over the winter the Gas Desk was selling them (us) gas at Gas Daily Mid-Point plus $.05/MMBtu, based on consumption.  Since they have not operated that much there is not much money at stake.  With higher summer usage and the greater volatility at the border, however, this price is no longer fair for the Gas Desk.

So, a couple weeks ago, I proposed a price increase to Harbor that would have them paying Gas Daily Mid-Point plus $.15/MMBtu still based on consumption.  They have been calling around and have an alternative deal, I think with Amoco that would have them paying Gas Daily Mid Point plus $.10/MMBtu based on scheduled volumes, not consumption.  We have to decide this week if we want to keep selling them gas or let them go to Amoco.

I hate to give up business, but it seems like we should unless we get a fair price.

Attached is a summary of a new structure that I think would retain the deal.  It changes the volume from scheduled versus consumption, and has them paying index plus $.10/MMBtu.  Schedules would be due by 8:30 and the volumes could not change over weekends.  I would suggest that it is better to keep this deal if I can get them to agree to the attached structure.  Please look it over and see what you think.  I will call later today to discuss.

Chris


the attachment?

Sara Shackleton
Enron North America Corp.
1400 Smith Street, EB 3801a
Houston, Texas  77002
713-853-5620 (phone)
713-646-3490 (fax)
sara.shackleton@enron.com

	Cheryl Nelson@ENRON
	Sent by: Cheryl Nelson@ENRON
	01/10/2001 03:54 PM

		 To: aneela.chavania@enron.com; eddy.daniels@enron.com;
samantha.boyd@enron.com
		 cc: sara.shackleton@enron.com
		 Subject: Brokerage Agreements - Checklist

Hi Aneela & Eddy:

Attached please find the current Checklist of Information required to open
such accounts.

I have replaced Sara as the attorney coordinating the opening of brokerage
aggrements.  Thus, you can address all questions and correspondence to me,
instead of Sara.    You can call me at x5-4693.


Ken

What is Ajilon's full legal name? For instance, Ajilon Technoloigies Company
or Ajilon Corporation, etc.
The legal name is necessary for this document.

- Thanks

 -----Original Message-----
From:  "Keefer, Ken" <kkeefer@ajilon.com>@ENRON
[mailto:IMCEANOTES-+22Keefer+2C+20Ken+22+20+3Ckkeefer+40ajilon+2Ecom+3E+40ENRO
N@ENRON.com]
Sent: Monday, May  21, 2001 11:18 AM
To: Allario, John
Subject: RE: NDA for Agilon

John,

Is there any additional information regarding the NDA name change that would
need to be provided beyond what has already been identified?

Thanks,

Ken

-----Original Message-----
From: John.Pavetto@enron.com [mailto:John.Pavetto@enron.com]
Sent: Monday, May 21, 2001 10:59 AM
To: kkeefer@ajilon.com
Cc: John.Allario@enron.com
Subject: RE: NDA for Agilon

Please feel work John Allario.

Regards

    -----Original Message-----
   From:   "Keefer, Ken" <kkeefer@ajilon.com>@ENRON

[mailto:IMCEANOTES-+22Keefer+2C+20Ken+22+20+3Ckkeefer+40ajilon+2Ecom+3E+40EN
RON@ENRON.com]

   Sent:   Monday, May 21, 2001 10:52 AM
   To:     Pavetto, John
   Subject:  RE: NDA for Agilon

   We may have some confusion here as the company name should be:

   Ajilon LLC
   Attn:  Gary Preston

   I am unable to find any internal reference to a "Paul S. Galant" and
   Agilon
   Technologies is a different company.

   -----Original Message-----
   From: John.Pavetto@enron.com [mailto:John.Pavetto@enron.com]
   Sent: Monday, May 21, 2001 10:36 AM
   To: kkeefer@ajilon.com
   Subject: FW: NDA for Agilon

   -----Original Message-----
   From:     Allario, John
   Sent:     Monday, May 21, 2001 8:53 AM
   To:       Jones, Tana
   Cc:       Pavetto, John
   Subject:  NDA for Agilon

   Tana

   We would like an NDA for the following counterparty:

   Agilon Technologies, Inc.
   Attn:  Mr. Paul S. Galant
   14180 Dallas Parkway
   Dallas, TX  75240
   gpreston@agilon.com

   Nature of business - Enron Net Works L.L.C. is hoping to have Agilon
   perform Transaction Hub Service functions for EOL.  Agilon has software
   that would fit nicely on top of EOL and help our trading counterparts
   more
   easily download and create their own trading reports as a result of
   their
   transacting with EOL.

   Please email the NDA to me and you can send the hard copy out directly
   to
   Mr Galant.

   No know legal contact at Agilon yet.

   Muchas Gracias Herrin Jones!

   Johan

   John Allario
   Enron Net Works L.L.C.
   713-853-4587 (o)
   713-562-8684 (c)
   john.allario@enron.com


The report named: East P/L Totals <http://trv.corp.enron.com/linkFromExcel.asp?report_cd=1&report_name=East+P/L+Totals&category_cd=1&category_name=EAST&toc_hide=1&sTV1=1&TV1Exp=Y&current_efct_date=10/29/2001>, published as of 10/29/2001 is now available for viewing on the website.


fyi...

 -----Original Message-----
From: 	Calcagno, Suzanne
Sent:	Wednesday, October 10, 2001 4:17 PM
To:	Goodell, Scott; Taylor, Craig; Lamadrid, Victor; Wood, Tracy
Cc:	Superty, Robert
Subject:	SOUTHERN NATURAL FILES $245 MILLION PROPOSAL TO BOOST CAPACITY

From Inside FERC (Oct. 8th)--pls let me know if you want more detail or would like to see the FERC filing.  Will keep you posted as the project progresses through FERC.

Suzanne
============================================================================================================
SOUTHERN NATURAL FILES $245 MILLION PROPOSAL TO BOOST CAPACITY
To serve local distributors, industrial users and power generators, Southern Natural Gas Co. filed with FERC last week to build $245 million worth of compression, pipeline looping and other facilities to transport a total of 359,891 Mcf/day. The project would be constructed in two phases.

The expansion would start moving 320,714 Mcf/day by June 1, 2003, said the Oct. 1 application (CP02-1 et. al.). In the project's second phase, Southern Natural would install additional facilities to move 39,177 Mcf/day by May 1, 2004. Phase one includes 114.5 miles of looping in Mississippi, Alabama and Georgia, which would be built in 11 segments that range in length from 3.41 miles to 16.74 miles. Pipe diameters would range from 24 inches to 36 inches. Phase two includes 8.8 miles of 30-inch-diameter looping in Georgia that would be
constructed in two segments of 4.8 miles and 4.0 miles.

Southern Natural proposed installing a total of 76,930 horsepower of compression, of which 11,280 hp would replace existing compression facilities that have deteriorated or otherwise become obsolete. Phase one includes ten compression units ranging in size from 3,550 hp to 15,000 hp. Under phase two, one 4,730 hp unit would be installed. Furthermore, Southern Natural proposed abandoning six compressors that generate a total of 9,930 hp.

All 359,891 Mcf/day of the capacity has been subscribed, the application said. During an open season held between Dec. 15 and Jan. 26, firm service agreements were reached with Southern Co. Services Inc., 97,950 Mcf/day, Calpine Energy Services LP, 95,000 Mcf/day, SCANA Resources Inc., 93,046 Mcf/day, Effingham County Power LLC, 58,766 Mcf/day, the City of Austell, Ga., 6,366 Mcf/day, Morgan Stanley, 5,400 Mcf/day, Proctor & Gamble, 1,763, and Kimberly-Clark, 1,600 Mcf/day.

Southern Natural asked FERC to allow it to roll in the cost of the expansion in its next rate proceeding "based on the considerable benefit to the overall rates of existing customers." Revenues generated from the new contracts are expected to exceed project costs by approximately $154 million, thus the expansion would result in "a significant benefit" to current shippers, Southern Natural said. In addition to the financial benefits, existing shippers will enjoy operational benefits as well, said the pipeline. "The combination of additional compression and new loop pipeline represents a significant enhancement to system reliability for all shippers delivering gas" in Southern Natural's market area, the
application said. Furthermore, Southern Natural promised that service to existing shippers would not be degraded as a result of the project.


Mark's synopsis pretty well says it all.  Once again, the CPUC is in a panic
and is attempting to change the rules in the middle of the game.  I'm not
sure I can make as clear a connection as Mark has between the actions of
interstate pipelines, particularly Transwestern, who, basically, are allowed
to charge just a tariff rate for upstream transport, and the huge dislocation
of basis spread between producing area and California border.  Therefore, I
don't necessarily see us being sullied by the El Paso issue.  I think our
biggest PR problem is probably our affiliation with Enron Online.

We'll continue to monitor this situation.  One thing is clear... fireworks
will certainly be forthcoming when the QF's are being paid on a formula
weighted predominantly with basin pricing, rather than border prices.  Not to
be be too esoteric here, but remember, there are a number of factors at
play.  QF's by contract are obligated to produce electricity when called on.
They are paid capacity payments by the utilities for that purpose.  It will
be interesting to see how many of the QF's tell Edison, PG&E, SDG&E, et al.
to go "fly a kite" when they know that if they produce a MW of electricity,
their commodity payments will put them under water.

---------------------- Forwarded by Jeffery Fawcett/ET&S/Enron on 12/05/2000
09:11 AM ---------------------------

mbaldwin@igservice.com on 12/04/2000 05:48:56 PM
To: "Jeff Fawcett" <jfawcet@enron.com>, "Susan Scott" <sscott3@enron.com>
cc: "Michael McGowan" <michael.mcgowan@enron.com>

Subject: FW: R.99-11-022 - ALJ Cooke's Draft Decision, Ruling, All-Party
Notice - Section 390

Team,  thought you would find this somewhat interesting
and?explanatory?of?California's  near? term panic . Our  California
Commission? is predisposed to do almost anything to stem the  tide of higher
energy prices. Their latest manifestation of complete melt-down  comes in the
form of attempting to modify electric QF payments by abandoning the  current
gas index methodology utilized by all three utilities. Essentially, the
proposed decision would?immediately (effective 12/1) abandon the old
California border gas indexes in favor of adopting a "proxy gas price".?
This new proxy gas price would apply to all three utilities, PG&E, SCE and
SDG&E. On a temporary basis, the gas index used for eventual electric QF
payments will be an gas index consisting of? ( i ) 10 % of the simple
average of three border indices at Topock ( Btu Daily, NGI, Natural Gas
Week)  and? (ii ) 90% of the SoCal Gas Core Wacog published monthly in
Schedule  G-CS or (in the case of PG&E) 90 % of their core published WACOG .?
The  resultant reduction in electric QF payments is several hundreds of
Millions of  dollars just for? December alone.
?
So  what if anything does this mean to TW ?? Clearly, TW's short term desk
maybe be affected. If Cal border numbers run 14 - 20 dollars and power
payments  are based upon PG&E Wacog of $7.50 gas demand for electric
generation  will? moderate. Next, the heat level on the cause of why basin to
border  price spreads are over $10 is not longer just a Commission vs.. EPNG
issue. The  entire California QF population becomes a huge stakeholder. The
never ending  search for a "bad Guy" escalates. TW needs to be careful?from
becoming  painted with a broad brush. TW is not one of the Southwest bad
Guys. TW's pipe  is not oversold, is point to point firm, widely held, useful
to California's  utilities etc.
?
If any  of this is useful and you want to further explore to potential
ramifications,  please call .? Mark, IGS
?
-----Original Message-----
From: Gwen Soong  [mailto:igsinc@ix.netcom.com]
Sent: Monday, December 04, 2000 8:23  AM
To: Mark Baldwin
Subject: FW: R.99-11-022 - ALJ Cooke's  Draft Decision, Ruling, All-Party
Notice - Section 390

?
-----Original Message-----
From: Gallardo, Teresita C.  [mailto:tcg@cpuc.ca.gov]
Sent: Friday, December 01, 2000 2:58  PM
To: 'jweisgall@aol.com'; 'rcsstl@cdmnet.com'; 'dnorris@sppc.com';
'mcmannes@aol.com'; 'lgurick@calpx.com'; 'woodrujb@sce.com';
'gbarnes@sempra.com'; 'bfinkelstein@turn.org'; Ramos, Julio J.;
'dgrueneich@gralegal.com'; 'ktilton@gralegal.com'; 'alr4@pge.com';
'bcragg@gmssr.com'; 'eke@aelaw.com'; 'jsqueri@gmssr.com';
'bloomje@la.whitecase.com'; 'jkarp@whitecase.com'; 'lys@aelaw.com';
'edoneill@dwt.com'; 'lindseyhowdowning@dwt.com'; 'ssmyers@hooked.net';
'tomb@crossborderenergy.com'; 'pmcdonne@wenet.net'; 'jcrossen@apx.com';
'tridam@mlode.com'; 'plenv01@northcoast.com'; 'dkk@eslawfirm.com';
'bellery@spi-ind.com'; 'mpa@aelaw.com'; 'dws@keywaycorp.com';
'vwatkins@pira.com'; 'crochlin@socalgas.com'; 'ewheless@lascd.org';
'douglass@arterhadden.com'; 'robinsc@sce.com'; 'jleslie@luce.com';
'edward.c.ryan@monsanto.com'; 'robert.turner@engageenergy.com';
'ewills@globalfrontiers.com'; 'daipm@daioildale.com'; 'rboyd@enron.com';
'ed@apx.com'; 'rschmidt@bartlewells.com'; 'aod@newsdata.com';
'maclean@sf.whitecase.com'; 'alexm@calpine.com'; 'billw@calpine.com';
'rjszymanski@powerworksinc.com'; 'steve.huhman@southernenergy.com';
'rbw@mrwassoc.com'; 'difellman@energy-law-group.com'; 'rmccann@cal.net';
'blaising@braunlegal.com'; 'abb@eslawfirm.com'; 'etiedemann@kmtg.com';
'steve_ponder@fpl.com'; 'dbranchcomb@hesinet.com'; Stevens, Maria E.; Quan,
Edwin; Wilson, Gregory A.; Loewen, James; Cooke, Michelle; Sabino, Pearlie
Z.;  'jhoffsis@energy.state.ca.us'; 'jmathis@edisonmission.com';
'fspasaro@socalgas.com'; 'napedersen@jonesday.com'; 'cread@omm.com';
'dfollett@sempra.com'; 'bjeider@earthlink.net'; 'millerja@sce.com';
'jleslie@luce.com'; 'mshames@ucan.org'; 'mtierney@sdge.com';
'dhmaynor@worldnet.att.net'; 'furutanj@efawest.navfac.navy.mil';
'mflorio@turn.org'; Scarff, James E.; 'imoosen@gralegal.com';
'phanschen@mofo.com'; 'rschmidt@bartlewells.com'; 'aod@newsdata.com';
'david@mbvlaw.com'; 'jsqueri@gmssr.com'; 'bloomje@la.whitecase.com';
'chilen@llgm.com'; 'edwardoneill@dwt.com'; 'lindseyhowdowning@dwt.com';
'ssmyers@hooked.net'; 'rumla@earthlink.net'; 'igsinc@ix.netcom.com';
'gtbl@dynegy.com'; 'wbooth@booth-law.com'; 'rbw@mrwassoc.com';
'difellman@energy-law-group.com'; 'askaff@energy-law-group.com';
'tomb@crossborderenergy.com'; 'brbarkovich@earthlink.net';
'rmccann@cal.net';  'cmkehrein@ems-ca.com'; 'bob@sierracc.com';
'lwhouse@el-dorado.ca.us';  'bradylaw@pacbell.net'; 'abb@eslawfirm.com';
'abb@eslawfirm.com';  'pstohr@dbsr.com'; 'njohnson@ciwmb.ca.gov';
'dbranchcomb@hesinet.com';  'scohn@smud.org'; 'malcantar@aandellp.com';
'wgibson@nwppc.org';  'dws@keywaycorp.com'; 'mbrubaker@consultbai.com';
'rboyd@enron.com';  'foothill@lmi.net'; 'fosterbc@sce.com'; 'frl3@pge.com';
'wbyrne@forenergy.com.';  'jmeith@minasianlaw.com'; Stevens, Maria E.;
Minkin, Angela K.; Schumacher,  Brian D.; Danforth, Christopher; Lafrenz,
Donald J.; Ghazzagh, Farzad; Walker,  Glen; Econome, Janet A.; Ajello, Julian
E.; Halligan, Julie; Tan, Lee-Whei;  Ziering, Mark; Cooke, Michelle;
Kinosian, Robert; Sarvate, Sarita; Linsey,  Steve; Thompson, Thomas W.;
Meyer, William;  'kgriffin@energy.state.ca.us'
Cc: Gallardo, Teresita  C.
Subject: R.99-11-022 - ALJ Cooke's Draft Decision, Ruling,  All-Party Notice
- Section 390

<<CPUC01-#84763-v1-I8907004_R9911022_Cooke_Ruling.DOC>>
<<CPUC01-#84823-v1-R9911022_Cooke__All-Party_Notice.DOC>>
<<CPUC01-#84805-v1-R9911022_Cooke_Comment_Dec_.DOC>>

 - CPUC01-#84763-v1-I8907004_R9911022_Cooke_Ruling.DOC
 - CPUC01-#84823-v1-R9911022_Cooke__All-Party_Notice.DOC
 - CPUC01-#84805-v1-R9911022_Cooke_Comment_Dec_.DOC


Colleen, thanks for the update - as another part of the nat gas value chain,
traded transportation, with and without EOL should be a priority.  However, I
think we have to ensure that we have rules and procedures accepted by the
FERC that will allow the market to work.

Jim, can you ensure that Colleen and Julie have the regulatory support needed
to ensure that the market gets set up appropriately.

Thanks.

Regards
Delainey
---------------------- Forwarded by David W Delainey/HOU/ECT on 10/28/2000
12:22 PM ---------------------------

	Enron North America Corp.

	From:  Colleen Sullivan                           10/26/2000 10:03 AM

To: David W Delainey/HOU/ECT@ECT
cc:
Subject: Transportation Status

Scott Neal told me that you asked recently where we stood on development of a
transportation market in light of 637.  I would be happy to meet with you and
let you know in more detail what I have been working on, but here is a quick
synopsis.

We are putting new transportation products out on EOL--this should be ready
for December business (assuming Lavo has no objections--I just sent him the
information on the product).  They are simple products with no computerized
interaction between EOL and Sitara or EOL and the pipeline bulletin boards
(which we are still required to post through per the pipeline tariffs).
Quite honestly, I have no idea how much activity these will generate since
each product still has the potential for being "biddable" on the pipeline
EBBs and there is not an easy solution around that.  Also, all completed
transactions still must be posted on the EBBs and confirmed by the pipelines
before the deal is actually completed.  This product does not make the
release process any simpler; however, it does make it more visible by having
bids and offers out on EOL, where people are more likely to be looking than
the pipeline EBB.

The vision is to have the entire bidding and confirmation process through the
EBBs automated, which would encourage a significant increase in trading
activity for transportation, but there are several important infrastructure
steps we must take first--you know, minor things like creating a
transportation position screen in Sitara and getting the pipelines' EDI
(Electronic Data Interchange) mechanisms in working form.  We are in testing
with 9 pipelines as of today.

Also, as I'm sure you are aware, Julie Gomez is working with several
pipelines to put their available IT (interruptible) space out on EOL (the
last I heard this should happen for January business), and then I understand
that she plans to work with EOL to allow third parties to put transportation
bids and/or offers out on EOL in an "Altra-like" system--meaning ENA will not
always be a party to those transactions.

There are many changes occurring because of Order 637, but the pipelines are
still going through their compliance filings and there are alot of complaints
about those filings--which just means more time for implementation.

If you have any questions, please call me at x35514.


I'm working on a settlement issue with subject counterparty for December.  The unique id is 12596.  Can you send me Hafslund's detailed data for Dec 1?

Lisa