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February 19, 2002	 <http://oad.realmedia.com/RealMedia/ads/click_nx.ads/UMUK_Rigzone.WeeklyNewsletter/THURAYA01_RIGWNMW02/102150216415210>
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Current Oil and Gas Industry News
T! op Stories for the Past 7 Days
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OPEC Holds Output Steady <http://www.rigzone.com/news/article.asp?a_id=2648>
OPEC output levels are likely to remain the same throughout 2002 if there are no important changes in fundamentals or politics.

ONGC Still Wrangling Over Offshore Fields <http://www.rigzone.com/news/article.asp?a_id=2646>
ONGC is adamant about securing operatorship of three offshore fields it holds jointly with Enron Oil and Gas India Ltd.

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Exploration	  <http://www.rigzone.com/images/email/title_Corner.gif>
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Tesco Awarded Algerian Drilling Contract <http://www.rigzone.com/news/article.! asp?a_id=2645>
The Company has entered into an agreement with Steppe Forage, a major Algerian water well drilling contractor, to Casing Drill(TM) six water wells in western Algeria.

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Production	  <http://www.rigzone.com/images/email/title_Corner.gif>
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BP Announces GOM Pipeline Construction Plans <http://www.rigzone.com/news/article.asp?a_id=2653>
BP announced plans for the construction of three large-diameter crude oil pipelines to transport oil from the company's major discoveries in the deepwater Gulf of Mexico.

AOC and Kuwait Finalize Deal in March <http://www.rigzone.com/news/article.asp?a_id=2652>
Kuwait will finalize a deal in March with Japan's Arabian Oil Co Ltd on its role in Neutral Zone oil production after a 40-year concession expires in January 2003.

Jade Field Start-Up Delayed <http://www.rigzone.com/news/article.asp?! a_id=2651>
Phillips Petroleum has delayed the start-up of the Jade Field in the UK North Sea until late February.

Braemer Field Not Expected Onstream This Year <http://www.rigzone.com/news/article.asp?a_id=2647>
Marathon's Braemar gas and condensate field in the North Sea is unlikely to go onstream as scheduled in 2002.

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ExxonMobil Signs MOU with Papua New Guinea Government <http://www.rigzone.com/news/article.asp?a_id=2650>
Exxon Mobil Corporation has signed a MOU with the Government of PNG on the terms and conditions for developing and producing more than 6 trillion cubic feet of natural gas resources in the Southern Highlands of PNG.

Keppel Awarded Rig Upgrade Contract <http://www.rigzone.com/news/article.asp?a_id=2649>
! Keppel FELS Ltd has been awarded a $30 million rig upgrade contract by GlobalSantaFe.

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Conoco and Tesco Unveil Revolutionary Drilling Rig <http://www.rigzone.com/news/article.asp?a_id=2603>
Conoco and Tesco Corporation have jointly announced plans to construct three revolutionary drilling rigs using Tesco's proprietary Casing Drilling(TM) technology.

ExxonMobil Expects to Begin Work at Sakhalin in October <http://www.rigzone.com/news/article.asp?a_id=2600>
Exxon Neftegas, operator of Russia's Sakhalin-I oil and gas field, will begin drilling operations in two offshore deposits in October of this year.

Halliburton To Provide Its Services To Russia <http://www.rigzone.com/news/article.asp?a_id=2595>
Halliburton International Inc. and Sibneft, signed an agreement ! that will give Halliburton the ability to deploy all of its product service lines to the Russian oil and gas market.

Ottawa Could Open Coast to Offshore Drilling <http://www.rigzone.com/news/article.asp?a_id=2624>
Ottawa officials said they are prepared to consider a proposal to remove the long-standing moratorium on offshore oil and gas drilling in British Columbia.

El Paso Pulls The Trigger on Major GOM Pipeline <http://www.rigzone.com/news/article.asp?a_id=2618>
El Paso Energy Partners, L.P. will build and operate the Cameron Highway Oil Pipeline System, a major new 380-mile oil pipeline in the Gulf of Mexico.

Russian Environmentalists Seeking Sakhalin Drilling Ban <http://www.rigzone.com/news/article.asp?a_id=2639>
A Moscow court will hear a lawsuit in April filed by Russian environmental groups seeking to ban oil and gas projects off Sakhalin island in the Russian Far East.

Hugo Chavez Appoints New Head of PDVSA <http://www.! rigzone.com/news/article.asp?a_id=2594>
President Hugo Chavez on Saturday appointed Gaston Parra as head of state oil company PDVSA.

PanCanadian Drills Another Duster <http://www.rigzone.com/news/article.asp?a_id=2623>
PanCanadian drills its third duster offshore eastern Canada.

Amerada Hess Resumes Production at Ceiba <http://www.rigzone.com/news/article.asp?a_id=2616>
Amerada Hess Corporation announced that the Ceiba Field offshore Equatorial Guinea resumed oil production in late January and is now flowing at rates in excess of 50,000 barrels of oil per day.

National Oilwell Posts 2001 Record Revenues and Net Income <http://www.rigzone.com/news/article.asp?a_id=2604>
National-Oilwell, Inc. reported 2001 revenues and net income of $1747.5 million and $104.1 million ($1.27 per diluted share), up from $1149.9 million and $13.1 million ($0.16 per diluted s! hare) in the prior year.

Brunei Creates New State-Owned Oil Company <http://www.rigzone.com/news/article.asp?a_id=2634>
Brunei is set to play a bigger role in the global oil and gas scene under the newly established state-owned PetroleumBRUNEI.

Prosafe acquires the Polyconcord <http://www.rigzone.com/news/article.asp?a_id=2633>
Prosafe ASA has entered into an agreement with K/S Rasmussen Offshore A/S for the purchase of the semisubmersible accommodation and service rig Polyconcord.

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Hey Dad,

Did you talk to the better half?  I was thinking Trulucks but if you can't
attend I understand.

Let me know,

Eric


Dear HBS Alumni:
b3686a1.jpg
Spend an evening on the water in Galveston Bay!
Join your fellow alumni for the first social event of the year.  The HBS Club is sponsoring an evening cruise on Saturday October 6th on the Star Cruiser, a 90 foot luxury entertainment yacht.  Bring your spouse or a guest and enjoy dinner and drinks while cruising Galveston Bay. DATE:     Saturday, October 6, 2001
TIME:      6:30 pm to 7:00 pm Boarding; 7:00 pm to 10:00 pm Cruise
PLACE:   Star Fleet Marina, 280 Grove Road, Kemah, TX
COST:     Platinum Members:  No charge     Guests:  $65                 Gold Members:        $55              Guests:  $65                 Silver Members:       $65              Guests:  $70                 (Covers dinner, beer/wine bar and cruise)
RSVP:     RESERVATIONS REQUIRED By 5:00 pm on September 20, 2001  email dottie@kerr-solutions.com, phone (281) 424-3084, fax (281) 424-4770 or at www.hbshouston.org  To learn more about the Star Cruiser visit www.starfleetyachts.com .
Capacity is limited so please RSVP early.  Because we have to give a final headcount on September 21, cancellations cannot be accepted after this date.
To get to the Star Fleet Marina from Houston:  Take I-45 South and exit at the League City Exit (#23).  Turn Left under the Freeway onto FM 518.  After 3 miles, FM 518 will veer to the Right. DO NOT turn right.  Continue straight onto FM 2094. Go approximately 4 miles.  Turn Left onto Carolyn Street (100' before FM 2094 dead ends into HWY 146).  Carolyn Street veers left, then becomes Grove Road and dead ends into the marina. I hope you choose to join us for this fun event.
Best Regards,
Sean Daichman
President

Reservation
Saturday October 6, 2001 "Evening on the Star Cruiser"
Member Name:
Guest Name:
Platinum Members:     No charge        Guests: $65
Gold Members:           $55                 Guests: $65
Silver Members:          $65                 Guests: $75
Payment Method (Check one)
1. _____     Credit card on file
2. _____     Credit Card (Visa, MC) Number: ________________ Exp Date:  ______
3. _____     Cash or Check enclosed
RESERVATIONS REQUIRED.  Reservations accepted until 5:00 pm on September 20,
2001.  Fax this form to (281) 424-4770, e-mail dottie@kerr-solutions.com, or call (281) 424-3084.

Upcoming Events
?     September 6 - Breakfast Club Meeting with Orlando Sanchez
?     September 19 - Robert Miller, Chairman Metro Luncheon
?     September 20 - Breakfast Club Meeting at River Oaks Country Club
?     September 27 - Monthly Mixer
?     October 4 - Breakfast Club Meeting at River Oaks Country Club
?     October 11 - HBS Recruiting Mixer at St. Regis Hotel
?     October 18 - Breakfast Club Meeting at River Oaks Country Club
?     October 25 - Monthly Mixer
?     October 30 - Gerald Glenn, CEO Chicago Bridge & Iron Luncheon
?     November 1 - Breakfast Club Meeting at River Oaks Country Club
?     November 15 - Breakfast Club Meeting at River Oaks Country Club
?     November 29 - Bob Beauchamp, CEO BMC Software Luncheon
?     November 29  - Monthly Mixer
?     December 6 - Breakfast Club meeting at River Oaks Country Club
?     December 20 - Breakfast Club meeting at River Oaks Country Club
***************
Dottie Kerr (dottie@kerr-solutions.com)
Administrator for Harvard Business School Club of Houstonhttp://www.hbshouston.org/
 - b3686a1.jpg
 - 100601rsvp.doc


When are you coming to town to visit me?

What do you do all day?

What's going on in the world out there?


---------------------- Forwarded by Susan M Scott/HOU/ECT on 08/31/2000 07:57
PM ---------------------------

Susan M Scott
08/31/2000 07:56 PM
To: lnmay@aol.com
cc:
Subject: P&L


Gas Daily is a little short-staffed today, so I would like to ask that
everyone send their faxes as soon as possible, thanks.


Hi Patrice,

Here's what I have so far. The new company is not fully set up so I'm not able to see the volumes/dollars come across in Unify yet. This should be done by tomorrow and then I'll send you that information as well. Thanks!

Valerie Vela
Specialist, Gas Settlements
Enron Net Works LLC
t: 713.345.8749
f: 713.646.8420


Grant,

Your call. Any day would work for me.

Vince

---------------------- Forwarded by Vince J Kaminski/HOU/ECT on 02/29/2000
03:15 PM ---------------------------

Sevil Yaman <syaman@Bayou.UH.EDU> on 02/29/2000 12:17:44 PM
To: Vince.J.Kaminski@enron.com
cc: Grant.Masson@enron.com
Subject: Re: Thank You

Dr. Kaminski,
I can stop by any Thursday or Friday to meet Grant. I think that will
be great for me to understand better what you are doing in your group
and I will be doing this summer. Could you let me know which day would
work for you, please?

Sevil Yaman
Department of Economics
University of Houston
Houston, TX 77204-5882
(713) 743-3814 / 3817

On Thu, 24 Feb 2000 Vince.J.Kaminski@enron.com wrote:

>
> Sevil.
>
> We are looking forward to having you here.
> If you want, you can stop by one day and I shall introduce you
> to Grant Masson with whom you will be working this summer.
>
> Vince
>
>
>
>
>
> Sevil Yaman <syaman@Bayou.UH.EDU> on 02/23/2000 10:09:30 AM
>
> To:   vkamins@enron.com
> cc:
> Subject:  Thank You
>
>
>
> Hi Dr. Kaminski,
>
> Yesterday, I learned from Shannon Rogers at the associate-analyst program
> that I was offered a summer associate/internship position in your group. I
> am already very excited about this position and look forward to working in
> your group. Many thanks for your consideration.
>
>
> Sevil Yaman
> Department of Economics
> University of Houston
> Houston, TX 77204-5882
> (713) 743-3814 / 3817
>
>
>
>
>
>
>


ALJ just issued her recommendation.  It's 270 pages long - but she finds the PNW is a competitive market, rates were not unjust and unreasonable, and that no refunds should be ordered.  She finds that spot sales consist of 24x24 and "within a month and balance of the month" transactions.  I'll draft a summary and circulate.


Sorry, I have not replied.
Things have been very depressing with Enron going under!
I will talk with Pat tonight and figure out the best way to go forward.

Jim

-----Original Message-----
From: Mark Woita [mailto:mwoita@home.com]
Sent: Monday, November 26, 2001 1:08 PM
To: Schwieger, Jim
Subject: Cars

Hi Jim.

We have narrowed our choice of vehicles to two minivans: a Toyota Sienna and
a Chrysler Town & Country.

Surprisingly, Ben helped us eliminate SUV's from consideration. He prefers
the smoother ride of the minivan. It will be better for taking long trips.
The down side is he doesn't want to be seen driving a minivan once he turns
16. Ha! : )

We were able to help satisfy Anna (and Ben) by choosing a higher-end minivan that has
many "bells and whistles" on it, yet still costs less than an SUV.

We are leaning toward the Toyota, even though it is a bit smaller than the
Chrysler, because of its reliability and how it holds its resale value. The
Toyota dealer also has "$300 over invoice" sale on currently. Plus they told
Mark there will be additional financing incentives starting this Saturday.
Both the Toyota and Chrysler dealers have vehicles in inventory we can
choose from.

So, we hope to close the deal with the Toyota dealer this coming Saturday.
What do you think?

Love,
Linda

PS  We got a pkg. in the mail today from you.  Thanks!!  I will wait until the kids are here to open it.


FYI.  The attached briefing isn't great news for consumers in the Western
markets.  The key conclusion is that:

"CERA expects this shoulder season to differ from years past, however, with
power and gas markets producing strong year-over-year prices and little
relief from summer levels, even with normal September weather."

Jim

---------------------- Forwarded by James D Steffes/HOU/EES on 08/24/2000
11:40 AM ---------------------------

Margaret Carson@ENRON
08/23/2000 08:09 AM
To: James D Steffes/HOU/EES@EES, Rob Bradley/Corp/Enron@ENRON
cc:
Subject: Monthly Briefing: A Shoulder Month Without Shoulder Prices - CERA
Alert

fyi   a   very good recap  of upcoming  market trends..Marg
---------------------- Forwarded by Margaret Carson/Corp/Enron on 08/23/2000
08:08 AM ---------------------------

webmaster@cera.com on 08/22/2000 10:27:55 PM
To: Margaret.Carson@enron.com
cc:

Subject: Monthly Briefing: A Shoulder Month Without Shoulder Prices - CERA
Alert

**********************************************************************
CERA Alert: Sent Tue, August 22, 2000
**********************************************************************

Title: Monthly Briefing: A Shoulder Month Without Shoulder Prices
Author: Zenker, Snyder, Moritzburke
E-Mail Category: Alert
Product Line: Western Energy ,
URL: http://www.cera.com/cfm/track/eprofile.cfm?u=3014&m=1320 ,

Alternate URL:
http://www.cera.com/client/ce/alt/082200_18/ce_alt_082200_18_ab.html
**********************************************************************

As western markets continue to struggle through high August demand and prices
for both power and natural gas, September looms as the start of the fall
shoulder season. The shoulder season historically has brought the possibility
of a break in weather and a demand drop in both power and gas prices from
summer levels. CERA expects this shoulder season to differ from years past,
however, with power and gas markets producing strong year-over-year prices
and little relief from summer levels, even with normal September weather.

West-wide power loads will decline but will remain similar to those in June,
a month with high power prices. In addition, compared with June levels
hydroelectric capacity has dropped owing to reduced stream flows, leaving
more expensive gas-fired generation to replace declining hydroelectric
output. CERA expects occasional hot weather and higher gas prices to push
on-peak prices in the West to 244 percent over September 1999 levels.

Continued strong use of gas-fired generation in the West, as well as low US
storage inventories and tight supply demand balances, will keep the pressure
on gas prices. Topock prices are expected to average $4.45 per million
British thermal units (MMBtu) in September.

These high September gas and power prices are driven by

* Declining hydroelectric output. The months of September through November
represent the low point for hydroelectric output in the West, with rainfall
historically boosting output in December. Approximately 16,400 average
megawatts (aMW) will be available from hydroelectric facilities during the
three-month period. This represents a net reduction in capacity of 6,900 aMW
when compared with the recent June-August summer months and a reduction of
3,600 aMW when compared with September 1999 levels.

* Higher, more variable power demand. The Southwest and Southern California
still experience hot weather in September, and regional utilities typically
consider it possible that a year's peak load event will occur in September.
Spiking loads, however, can quickly retreat with a return to cooler weather.
Thus, power loads and power prices are expected to experience a high degree
of variability during September.

* High levels of gas-fired generation. Load growth and a declining
hydroelectric resource base will require gas-fired resources to serve
approximately the same level of demand as in June 2000, a month with similar
average demand and monthly average on-peak power prices in the $150-$178 per
megawatt-hour (MWh) range, depending on the region. This strong pull on
gas-fired plants will push deep into the generation resource base, driving
prices upward. An additional 1.7 billion cubic feet (Bcf) per day will be
required for gas-fired generators in the US West compared with September 1999
levels.

* Strong North American gas prices. Natural gas prices are expected to retain
most of this summer's peak levels, as North American supplies remain tight. A
market anxious about winter demand and price levels will also limit a price
retreat this fall. As a result, average September Henry Hub prices are
expected to trade around $3.95 per MMBtu. An active storm season could keep
Henry Hub prices near the $4.50 mark.

* Strong western basis differentials. The strong demand for gas to serve
gas-fired generation and storage concurrently will maintain western basis
differentials at high levels, especially in the California markets. CERA
expects a Topock-to-Henry Hub differential of $0.40 per MMBtu during
September. Extended operational problems associated with El Paso's pipeline
rupture would raise that outlook.

Regional Power Market Drivers
Hotter-than-normal August weather, transmission and generator outages, high
natural gas prices, and declining hydroelectric output all contributed to a
rise in power price levels during August. Southern California average power
prices in August have thus far exceeded July levels by an average of $90 per
MWh during the on-peak period and by $14 per MWh during the off-peak period.
Mid-Columbia power prices, bearing the brunt of fire-induced transmission
outages, experienced a jump from July price levels of $114 per MWh for the
on-peak period and $20 per MWh in the off-peak period.

Off-peak prices, which have averaged above $60 per MWh during the June-August
period, are clearly defined by the production cost of gas-fired resources.
On-peak prices during this same period, at over $100 per MWh in all regions
in all months, have reflected a significant premium at times over the cost of
the marginal system generator (see Table 1).

A return to normal weather should drive West-wide loads down by 8,300 aMW in
September from August levels. However, load growth and a return to normal
weather are expected to push loads up by 5,400 aMW when compared with
September 1999 levels. These greater loads, coupled with a reduction in
hydroelectric generation of 3,600 aMW from last September's levels, will
create supply tightness during September (see Tables 2 and 3).

Hydroelectric, coal, and nuclear generation together will be insufficient to
serve West-wide demand in September, even during much of the off-peak
periods, requiring gas-fired resources to meet a significant portion of the
load. Gas demand for power generation is expected to average 5.2 Bcf per day
in September, down from over 5.9 Bcf per day in August but up by a dramatic
1.7 Bcf per day compared with levels in September 1999.

September power prices will be defined by a floor set by the incremental cost
of gas-fired generation, approximately $50 per MWh, with prices frequently
higher as demand increases. As this summer has clearly demonstrated, prices
rise in a nonlinear fashion as supplies grow very tight. Hot weather-induced
loads should provide additional examples of this relationship. * Cooler- or
hotter-than-normal weather in September, coupled with the inherent high
variability of September loads, will produce a wide range of price outcomes.
Under normal weather, on-peak power prices are expected to fall in the
$113-$123 per MWh range, depending on location, representing a 244 percent
premium to year-ago September prices (see Figure 1).

The latest revision of the California Independent System Operator's (ISO's)
imbalance energy market cap down to $250 per MWh is expected to depress
market prices during any weather events in September. CERA expects the ISO
price cap to limit prices outside of California as well.

Pacific Northwest
Although demand levels in the Pacific Northwest are expected to retreat in
September by at least 1,100 aMW compared with those in the hotter-than-normal
month of August, the loss in available capacity from hydroelectric resources
will amount to 1,900 aMW over the same period (see Table 4). Thus, the
Pacific Northwest will be in an even more limited position to export power to
other regions. With transmission interties operating at below rated capacity
during this period, power prices in the Pacific Northwest will maintain their
tight relationship with those in Northern California. These price levels will
continue to support the operation of the region's limited quantity of
gas-fired generation. Mid-Columbia on-peak price levels are expected to
average $118 per MWh in September.

Off-peak power price levels in the Pacific Northwest will also receive a
boost from the strong markets to the south. The expected September level of
$54 per MWh represents the opportunity cost of power sales in surrounding
markets.

California
The fall months initiate a seasonal shift in price differentials that
separates the West into markets that lie north of transmission Path 15 and
those to the south. As in years past, hydro-depleted Northern California
should experience demand levels that must be served by generation resources
within the region. Exports from the Pacific Northwest dwindle, and energy
from the nuclear and coal-rich Southwest is constrained from entering
Northern California by Path 15 import limitations. This condition, which is
expected to persist from September through November, allows Northern
California to price at a premium. The expected monthly average on-peak
Northern California price of $123 per MWh incorporates this dynamic. Notably,
the California ISO is completing a process to remap the zones in California,
in part to capture locational price differences more effectively.

Southern California, like the Southwest, will typically experience hot
weather episodes in September. During these high demand periods, prices will
rise to peak levels as experienced this summer. In addition, California as a
whole should see average loads in September that are 4,600 aMW higher than
those of September 1999. Occasional cooler weather will sharply but
temporarily reduce daily prices. Southern California benefits from the
abundant export capacity of the Southwest during cooler weather in that
region, allowing prices to fall well below those in Northern California. An
$8 per MWh differential between the north and south portions of the state is
expected, with Southern California on-peak prices averaging $115 per MWh.

Off-peak prices of $53 and $47 per MWh for Northern and Southern California,
respectively, reflect the continued need for gas-fired resources to support
September off-peak loads.

Rockies and Southwest
An extended period of hot weather in July and August has boosted demand in
the Rockies, a region with growing saturation of residential air
conditioning. Limited transmission capacity and a dearth of cheaper exports
from surrounding regions have allowed the Rockies to price temporarily at a
premium to all other regions in the West.

A return to normal weather in September should restore the previously tight
relationship of Rockies prices to those in the North. Rockies prices are
expected to fall with loads, with a September monthly on-peak price average
of $113 per MWh and an off-peak price average of $43 per MWh.

CERA expects Southwest prices to be tightly connected to prices in Southern
California on a monthly average basis. The two regions generally experience
the same September weather patterns, and a strong 7,600 MW transmission link
between the two market centers allows them to balance loads with each other.
Strong gas prices and occasional market tightness-induced price run-ups will
maintain on-peak prices at the $115 per MWh level in September. Off-peak
prices will, like those in Southern California, be buoyed by the high cost of
gas-fired generation. A price level of $47 per MWh is expected for off-peak
prices.

Regional Gas Market Drivers
The summer competition for gas supply between power and storage continues in
North America, with gas prices reflecting the intensity of that competition.
Even as the summer power peak subsides in September across the United States,
the need to continue strong storage injections and the threat of storms in
the Gulf will keep prices high and volatile. The storage deficit now stands
at approximately 350 Bcf, and US storage inventories look likely to head into
winter at historically low levels. This critical storage situation will keep
prices high despite overall declines in power loads in September. CERA
expects a Henry Hub price of $3.95 per MMBtu during September.

In the West strong power loads and the potential for power peaks persist
through September, especially in California. Overall, total demand for gas is
expected to decline across the West from 10.1 Bcf per day during August to
9.8 Bcf per day during September (see Table 5). This load will tend to keep
intraregional differentials wide throughout the West during the month. The
recent price disconnects between the supply-rich Rocky Mountains and San Juan
Basin and demand-charged California will persist. October should bring some
change in this dynamic as heating loads in the Rockies begin to increase.

In general, winter will bring a dramatic shift in regional pricing
differentials throughout the West. The summer pressure on Rocky Mountain
supplies caused by high utilization rates on most export pipelines will be
relieved somewhat by regional heating loads. Declines in flows into the San
Juan Basin from the Rockies will take some downward pressure off prices in
the San Juan. On the other hand, healthy California storage inventories
should limit price premiums at Topock through the heating season. The
start-up of the new Alliance pipeline, which will draw gas to the Midwest,
will support prices in the Pacific Northwest and California.

California
Topock continues to be the premium pricing point in North America, although
differentials between Southern California and the Henry Hub subsided somewhat
from peak levels near $1.00 per MMBtu before this weekend's pipeline
explosion. Total imports into California reached record levels during July;
total imports of 5.8 Bcf per day eclipsed the previous high by 300 million
cubic feet (MMcf) per day (see Table 6). Pipeline capacity into the state
during the month ran at 83 percent utilization. So far in August, pipeline
capacity utilization is exceeding even that high rate, running at 85 percent.
These high rates of capacity utilization are putting pressure on gas prices
in Southern California, and the pressure should continue during September.

Total demand in California is expected to decline somewhat during September,
but continued strong power loads and low seasonal hydroelectric generation
will provide support. Total demand in the state should average 6.6 Bcf per
day, down only slightly from August's total of 6.8 Bcf per day. Flows into
the state between August and September are not likely to change
significantly, but price pressure should decline somewhat with demand. The
Topock differential to the Henry Hub should average approximately $0.50 per
MMBtu for September (see Table 7).
Storage inventories in the West are still healthy relative to levels in the
rest of the United States, but the storage surplus in the region has eroded.
In California, inventories are running lower than last year, and the deficit
in the state looks likely to widen during September. The end of injection
season storage inventories will determine the vulnerability of Topock
differentials to winter price spikes.

Pacific Northwest
Malin prices this summer have shown neither the strong premiums that Topock
prices have shown nor the wide discounts that supplies in the Rocky Mountains
and San Juan Basins have shown. So far this month, prices at Malin are
averaging a $0.25 per MMBtu discount to the Henry Hub. Pipeline capacity into
the region from the Rocky Mountains is running nearly full; flows on PGT out
of Alberta have averaged nearly 2.2 Bcf per day this month. Export capacity
out of the region on PGE GT NW is running close to capacity, and pipeline
constraints to the south combined with strong California demand are driving
the wide Malin-to-Topock differentials.

Continuing strong demand in the South will likely keep Topock prices strong,
and the wide north-south differentials within the West will likely hold
through September. In the Pacific Northwest demand is expected to climb
through September to 1.5 Bcf per day from 1.4 Bcf per day in August. This
demand level should keep Malin differentials from widening from current
levels. For September CERA expects Malin prices to average $0.10 per MMBtu
below the Henry Hub price.

Southwest
Prices in the San Juan Basin this summer have been left behind by rising
California demand. Although the westward pull on supplies is strong,
bottlenecks between California and the San Juan have led to disconnects
between San Juan prices and Topock prices. Pipeline capacity utilization
rates on Transwestern and the northern leg of El Paso reached 93 percent
during July, with less than 200 MMcf per day of excess pipeline capacity.
Increased flows from the Rockies on TransColorado and Northwest are
contributing to downward pressure on San Juan Basin supply, and in general,
the San Juan has followed Rocky Mountain prices rather than following prices
at Topock or the Permian Basin.

Unlike in the past two summers, the bottleneck has not allowed power demand
on the West Coast to support San Juan prices relative to Permian prices. The
differential between San Juan and Permian has averaged $0.50 per MMBtu so far
this month and $0.30 per MMBtu since June. Additional imports from the
Rockies into the San Juan have increased supply by 200 MMcf per day relative
to last summer, but these higher flows do not fully explain the disconnect.
Without much change in Southwestern or Rocky Mountains local demand, the San
Juan should continue to price at a wide discount during September. The San
Juan-to-Henry Hub differential is expected to average $0.60 per MMBtu. As in
the Rockies, differentials should narrow substantially in October.

Rocky Mountains
Downward pressures on Rocky Mountain prices intensified over the past month
as utilization rates on pipelines out of the region continued to climb.
Record heat and power generation levels have done little to boost gas demand
within the region; generation is still largely coal-based, and the demand
impact on gas of the additional load is minimal. CERA expects the heavy
discount-current Rocky Mountain-to-Henry Hub differentials are around $0.90
per MMBtu-to persist through September. Local area demand is not expected to
change during September. Substantial gain in local demand comes in October
with heating loads; October demand should average 1.4 Bcf per day, up from
August and September averages of around 1.2 Bcf per day.

Although the winter heating season will relieve pipeline pressures in the
Rockies, winter differentials are expected to stay in the $0.25 to $0.40 per
MMBtu range. Strong storage inventories will limit the connection with
broader North American markets this summer. Next summer, pressures on Rockies
supplies will likely intensify relative to this summer. Although pipeline
expansion projects have been announced-Trailblazer and Williams announced
expansion plans this summer-the new capacity will not be online to relieve
constraints next summer. CERA expects supplies within the Rocky Mountains to
increase by 300 MMcf per day next year.

Western Canada
After widening to over US$1.50 per MMBtu, the AECO-Henry differential has
begun to narrow somewhat; maintenance that has restricted flows has largely
been responsible for the jump from $0.84 per MMBtu in July. With current
supply able to fill the contracted pipe capacity and incremental volumes
having to pay full cost to flow, differentials are likely to persist in the
mid-US$0.70s per MMBtu for September. AECO is expected to be US$3.25 per
MMBtu (C$4.53 per gigajoule) for September. Even with the start-up of the
Alliance project, the contract nonrenewal on TransCanada is likely to
continue the two-tiered pricing dynamics of contracted versus uncontracted
pipeline costs. This will result in differentials that will range between
US$0.60 and US$0.75 per MMBtu throughout the winter.

Supply build in western Canada continues to languish behind last year's
levels. The pace of drilling (over 9,000 gas wells are expected this year)
should provide growth in the fourth quarter and into 2001. Supply is expected
to be flat with 1999 on an annual basis for this year and up at least 350
MMcf per day in 2001.

Sumas prices have been quite volatile, driven by both weather in the Pacific
Northwest and maintenance on the Westcoast system. For September, Sumas is
expected to be slightly more stable and to price at a modest premium to AECO
of US$0.05 per MMBtu.

**end**

Follow URL for PDF version of this Monthly Briefing with associated graphic
and tables.

*********************************************************
CERA's Autumn 2000 Roundtable event dates and agendas are
now available at http://www.cera.com/event
*********************************************************

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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=10/15/2001>, published as of 10/15/2001 is now available for viewing on the website.


Hey guys,

Well I'm back home in Houston looking out at our lovely skyline (okay, maybe
it's not that lovely but it is sunny here).  Anyway, I'm so glad I got the
chance to see all of you while I was in London.  It seemed as though all of
you are really enjoying your time in the UK - which is good to hear given the
fact I'm hoping to make it over there myself.  Hope the approaching close to
2000 finds everyone in good spirits.

Cheers,
Susan


When I tried to verbally confirm this deal, the counterparty has this deal
running for three months, December through February.  Could you check with
the trader and either change it or have him talk to the counterparty about
it.  Let me know.

Thanks!


There should be no credit on a TVA/Cin spread.   The correlation between the 2 markets is 95% plus.

 -----Original Message-----
From: 	Sacks, Edward
Sent:	Monday, October 08, 2001 9:23 AM
To:	Hardy, Trey; Evans, Casey; Presto, Kevin M.; White, Stacey W.; Vinson, Donald Wayne; Sturm, Fletcher J.
Cc:	Bradford, William S.; Ngo, Tracy; Buy, Rick; Rohauer, Tanya; Reasoner, Monica; Brown, Kortney
Subject:	PG&E Energy Trading - Power, L.P.

Please note the following addition to the domestic credit reserve for October 2001:

CP:  PG&E Energy Trading - Power, L.P.
Deal No: 806688 & 806689
EOL No: 1972890 & 1972891
Deal Date:  10/5/2001
Deal Specifics:  Sale / Buy (Basis)
Term:  1/1/2005 thru 12/31/2005
Volume:  50 MW/h Peak
Delivery Points:  Cinergy / Into TVA
Trader:  Fletch Sturm
Credit Reserve Amount:  $8,000 (eight thousand US dollars)

CP:  PG&E Energy Trading - Power, L.P.
Deal No: 806685 & 806686
EOL No: 1972884 & 1972885
Deal Date:  10/5/2001
Deal Specifics:  Sale / Buy (Basis)
Term:  1/1/2004 thru 12/31/2004
Volume:  50 MW/h Peak
Delivery Points:  Cinergy / Into TVA
Trader:  Fletch Sturm
Credit Reserve Amount:  $8,000 (eight thousand US dollars)

Comments or questions, please reply.

Ed Sacks


All is well here.   It sounds like you are very busy.  I glad you are taking
the options course - it will really benefit you.  Also,  Andrea Richards is
the person I
contacted with the Associate program to request that your first rotation be
in the Trading group - so we should be in good shape on that front.  Her
phone number is 713 853 6499 for your future reference.  Thanks for the
email, I look forward to seeing you this summer.

Scott

"Kevin B Murray" <kmurra1@lsu.edu> on 03/04/2001 12:20:04 PM
To: Scott.Neal@enron.com
cc:
Subject: update

Scott:

Greetings from LSU.  I sent you an email a few weeks ago, but perhaps you
didn't receive it.  No big deal.

I just wanted to drop you a line and let you know how I'm doing.  My last
semester is shaping up to be pretty tough.  The MBA class in Real Options
is, to say the least, tough!  I'm preparing for my mid-term right now, and
so far we've learned about Binomial trees, Sharpe ratios, the GOPOP model,
risk-neutral pricing, Stochastic Processes, Black-Scholes and Monte Carlo,
and pricing American, European, and exotic options.  What's also great
about the class is that our professor constantly uses Enron as an example
of how this stuff works in the real world.  It's a great class!

One of my other classes, Economic Forecasting, is challenging as well,
because I'm dealing with a software package, Eviews, for the first time.
Enough about the academics, though; I'm working hard and that's what I need
to be doing.

I've also started reading Reminiscences, and I find myself highlighting
lines on every page!  I figured I'd start with the less technical books
first, considering my workload.

I'm going to be in Houston looking for apartments this weekend, 3/9 - 3/11
with my roommate, Ed Brady, who will also be at Enron in July.  Let me know
how your schedule looks, and maybe we can get together.

Hopefully my getting into your fundamentals group or the new trading
rotation that you spoke of is still a high probability.  As I'm learning
more about options and futures in class, you're definitely right--I think
trading is where I want to be!

Thanks again and I hope to hear from you soon.  I hope all is well in
Houston.

Kevin


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pmguid:1c.1e3g.803w8


I will keep runing my AGA model (the molecule model) for awhile.  For the last
two weeks the numbers that came out from the model are in the lucky side.
See the following table.

The following figures shows the overall fit.

Zimin


BUSINESS HIGHLIGHTS

Coal Trading
The liquidity in trading of the Standard European Coal Agreement has
increased significantly over the last 6 weeks.  Many counterparties that
previously opted to stay on the sidelines finally chose to join the game.
Since the contract's inception at the beginning of the year, Enron has traded
a total of 5.3 million tons against the SECA contract, of which 3.8 million
tons has been traded via EnronOnline since July 2000.  We are 5.3 million
tons of a total traded market of 5.8 million tons.

Principal Investments
Tridium Inc., the leading provider of Internet-based automation
infrastructure solutions, announced the close of a $20 million round of
capital funding. The funds will be used to increase Tridium,s sales and
technical support offices in North America, expand its operations into Europe
and Asia, and enhance its technology and products. kRoad Ventures, L.P. and
Enron North America each contributed $10 million in venture capital.

Corporate Development
Allegheny Energy Supply Company, LLC, a wholly owned subsidiary of Allegheny
Energy, Inc., announced the signing of a definitive agreement under which
Allegheny Energy Supply will purchase three Enron natural gas-fired merchant
generating facilities. The acquisition is expected to close in the 2nd
quarter of 2001.

PERFORMANCE REVIEW

The deadline to provide feedback is Friday, November 17.  If you have been
selected to provide feedback on one of your fellow employees, please take the
time to fill out an evaluation online at www.pep.enron.com.

IN THE NEWS

"Enron Corp., already North America's biggest, buyer and seller of natural
gas and electric power is dead serious about its efforts to capture a big
slice of the $400 billion global trade in pulp, paper and lumber."
-Reuters News Service

2000 CHAIRMAN,S AWARD NOMINEES
Please join us in congratulating the ENA/EIM/EGM/ employees who have been
recognized as Chairman,s award nominees.

Congratulations to:

 Irma Alvarez  Alan Aronowitz  Rick Bergseiker  Carol Coats  Joya Davis
Rufino Durante
 Sue Foust  Julie Gomez  Barbara Gray  Jackie Griffith  John Harrison  Gerri
Irvine
 Kathy Benedict  Michael Kelley  Mike McConnell  Dave Nommensen Ina Norman
Juan Padron
 Veronica Parra  Michael Roberts  Rhonda Robinson Kevin Sweeney  Helen
Taylor  Stacey White

Extra kudos to BARBARA GRAY, who is a finalist for the 2000 Chairman,s
Award.  Barbara and ten other individuals are flying to San Antonio from
around the world to be honored at Enron,s annual Management Conference.  One
of these finalists will be recognized as the 2000 Chairman,s Award winner.

WELCOME
New Hires ENA/EIM/EGM
ENA ) Anil Chandy, Alejandra Chavez
EGM ) Marty Cates, JoAnne Underwood, Brad Miller

Transfers to ENA/EIM/EGM
ENA ) Mark Wadlington, Jennifer Blay-Smith, Georgian Landau, Kathryn Bussell,
John Coleman, Steven Gillespie, Clarissa Garcia, Ina Rangel, Farouk Lalji,
Eva Rainer, Chuchu Wang, Smith Day
EGM ) Gloria Solis, Carmella Jones, Nancy Haralson

LEGAL STUFF
The information contained in this newsletter is confidential and proprietary
to Enron Corp. and its subsidiaries.  It is intended for internal use only
and should not be disclosed outside of Enron.


Hi.  I'm interested in joining.  What do I need to do to join?

Thanks,

Kay


Janie

As we discussed, we would like you to consider adding the OXY point for Elk
Hills deliveries into SOCAL at the Gosford intertie to the "NGI Socal/PG&E
KRS" physical point. If you look on SOCAL's System Operations report our
deliveries are listed as "Elk Hills - Gosford Intertie". Our flows on this
pipeline typically range from 80MM to 165MM/day.

Our gas from  this point interconnects with the PG&E Kern River station gas
that then is delivered through Wheeler Ridge into SOCAL.

Separately we would also be very interested in an SOCAL In state Production
point on Enron OnLine.

Pat Mulhern


Start Date: 1/19/02; HourAhead hour: 22;  HourAhead schedule download failed. Manual intervention required.

    LOG MESSAGES:

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As you already know, it's that time again.  Since I am leaving on vacation
Friday morning, please use the system to input your suggested reviewers no
later than noon tomorrow (Thursday) so that I can approve them and get the
process started before I leave.  Sorry for the inconvenience.

Mark


Leaving voicemail with two comments: 1 ) Demand buydown: establish
participation threshold of 20 kw...residential inclusion is unnecessary and
will draw additional fire........2) Eliminating undue discrimination: we
should make clear that non-discrimination means all uses of transmission
system subject to FERC's jurisdiction shall be treated in a
non-discriminatory manner. Thanks.

From: Tom Briggs on 06/12/2001 11:42 AM
To: Linda Robertson/NA/Enron@ENRON, James D Steffes/NA/Enron@Enron, Richard
Shapiro/NA/Enron@Enron, Steven J Kean/NA/Enron@Enron, Sarah
Novosel/Corp/Enron@ENRON, John Shelk/NA/Enron@Enron
cc:

Subject: Draft Energy legislation

Attached please find draft legislation for Reliability and Demand Buy-Down.
The language is to be submitted to the DOE drafting team on Wednesday
afternoon.  Please provide comments and suggestions directly to me ASAP so
that I can make revisions for final submission.

Adiitional language on 1) interconnections, 2) FERC jurisdiction over
non-jurisdictional transmission services,3)PUCHA repeal and 4) Tribal land
ROW should be circulated later today.


FYI - I believe this is important.  According to Morgan (CES's CNG scheduler)
CES currently has about 7,000 dth of idle capacity.  I've had 3 people call
me today looking for CNG capacity for Jan 2000.

---------------------- Forwarded by Chris Germany/HOU/ECT on 12/27/99 03:50
PM ---------------------------

pdrexel@columbiaenergygroup.com on 12/27/99 03:15:16 PM
To: Chris Germany/HOU/ECT@ECT
cc:
Subject: Re: NIMO JAN 2000

Chris this is capacity we got from NIMO as part of a peaking deal with them,
they can call on gas delivered to their gate,they reimburse for all cost at a
north point gas daily price plus 100% transport.  We in essance can sell the
capacity off on a monthly basis (sell it delivered)  NIMO would not allow us
to
use this as part of our transport to our enduses though, we also have capacity
for that.

Chris_Germany@enron.com on 12/27/99 02:52:40 PM
Please respond to Chris_Germany@enron.com

To: John Hodge [NOTES.jwhodge]@LMSOV, Paul
Drexelius/CES/ColumbiaGas@COLUMBIAGAS
cc:

Subject: Re: NIMO JAN 2000

How much of the NIMO capacity (about 15,000 day of North to North) was
dedicated
to retail?

From what I'm seeing, the retail volumes are looking fairly small.

pdrexel@columbiaenergygroup.com on 12/27/99 02:39:46 PM

To:   Dan Junek/HOU/ECT@ECT, Chris Germany/HOU/ECT@ECT
cc:
Subject:  NIMO JAN 2000

Here are some more
---------------------- Forwarded by Paul Drexelius/CES/ColumbiaGas on
12/27/2000 02:45 PM ---------------------------

Heidi Boyd
12/27/99 02:25 PM

To: Morgan Sharifi/CES/ColumbiaGas@ColumbiaGas
cc: Noel Bartlo/CES/ColumbiaGas@ColumbiaGas, Paul
Drexelius/CES/ColumbiaGas@ColumbiaGas
Subject: NIMO JAN 2000

FINAL

Hi Morgan,

Please schedule the following (in DTH's) off of CNG to Niagra Mohawk:

Pooled  East Meter 20550 821/day
  West Meter 20500    421/ day

Balanced East Meter 20550 381/day
(firm)  West Meter 20500 430/day

Thanks!


I guess in the scheme of things one of the reasons you try not to go to
trial is to prevent this from happening.  Plus it takes a long time to
prepare for the case and it looks like your attorney wants to win.  Do you
want me to call Tonya and explain to her that going forward things are not
going to be pretty.  I think I can do this in a gentle and concerning way.
Or should I not be involved?
Love,
Mom


To:  Participants of the Enron Corp. Savings Plan
From:  Enron Benefits Department

Several weeks ago, we announced that beginning July 1, 2002, the company would again match employees' eligible contributions to the Enron Corp. Savings Plan ("the Plan").  We also announced that from July 1 through December 31, 2002, Enron would double the rate of the company match that was in effect prior to the suspension.  Based on your questions and feedback, we want to further clarify the double match and share with you some further modifications we are making to the administration of the match.

Doubling the Match
Doubling the match will accelerate the rate at which company matching contributions accumulate. However, the annual company matching contributions remain limited to 50 percent of an employee's pre-tax contributions, up to 6 percent of eligible compensation.

For example, assume a participant contributes the 2002 Federal pre-tax maximum of $11,000 to the Plan.  The company match in effect prior to its suspension was $.50 for each $1 contributed, so the maximum amount the employee would have received in company matching contributions would have been $5,500, or half of $11,000. With the double match, the same participant will receive $1 for each $1 contributed, but the match will not exceed $5,500.  Likewise, if a participant contributes $8,000 pre-tax during 2002, the company matching contribution would equal $4,000.

"Truing Up" the Match for Previous Contributions
Many participants in the Plan expressed concern that contributions to the Plan prior to July were not eligible for the reinstated company match.  To rectify this, we are modifying the administration of the match for the remainder of 2002.

Employees who were active as of December 31, 2001, and who participate in the Plan, will receive the double match for contributions made after July 1, 2002.  If at the end of 2002, the matched amount falls short of the maximum level possible based on the participant's annual pre-tax contributions to the Plan, the company will "true up" their match for 2002 to ensure the company contributions equal what would have been received had the match not been suspended.

For example, if an active employee's annual pre-tax contribution to the Plan will reach $11,000, and on July 1 the employee has already contributed $7,000, the remaining employee pre-tax contribution allowed will be $4000.  With the double match, the employee will receive $4,000 in company matching contributions between July and December, but will be $1,500 short of the company matching contributions he or she would have otherwise received.  On December 31, 2002, the employee's company matching contributions would be trued up with $1,500.

New Hires and Rehires After January 1, 2002
Any participants in the Plan hired or re-hired after January 1, 2002, will not be eligible for the double match.  Instead, they will receive the same match level in effect prior to suspension of the company match.  However, at the end of the year, they too will receive a true up to reach the maximum company match contributions for their annual pre-tax employee contribution.

Terminations Prior to December 31, 2002
If a Plan participant's employment is terminated involuntarily prior to December 31, 2002, the true up will take place as early as practical after termination.  The total amount of company matching contributions, including any true up, will be based on year-to-date contributions up to the time the participant is terminated.

If a Plan participant resigns voluntarily, he or she is not eligible for a true up, but will receive the double match on any pre-tax contributions made to the Plan between July 1 and his or her termination.

Participating in the Plan
Active Enron employees who are not currently participating in the Enron Corp. Savings Plan have until 3:00 p.m. CST on Thursday, June 27, 2002 to enroll in the Plan for their first July payroll contribution to be matched.  The same deadline applies to active participants in the Plan who may wish to increase their Savings Plan contribution rate in time for the first July payroll.  (For now, participants can only increase their contribution rate to the current maximum of 15 percent of their base salary.  After July 1, participants will be able to increase their contribution rate to the new maximum of 50 percent.)

To enroll in the Savings Plan or make a change to your current contributions, please log on to <<http://resources.hewitt.com/enron>>, or call the Benefit Service Center at 1-800-332-7979, option 3.


One of my flat screens will not reset and there is an unacceptable amount of static coming through.  Does anyone know of any tricks to fix this problem.  (Yes, I tried turning it off and back on again.)

Regards,

Jon


Matt-

 Hey there!  Have you recovered from the Big Bash yet??  Heard you put on a
kickass party...I heard ALL the details..:)  Anyway,  as it is now close to
January, Max wants me to send an email to you to pass on to all the ushers
(Peder, Ryan, Scott &  Merlin) since you have their email addresses.
Florida in January is pretty busy, so you definately want to book your
hotel reservations NOW...you don't need a deposit yet, I don't think, you
just need to hold a room.  Here is the info. on the hotel where everyone is
staying (where we got group rates), also this is where the Rehearsal Dinner
& the Sunday brunch are...the wedding is down the street, so you guys may
just want one rental car for all of you.  I think Thursday afternoon  is
when you will all go to the Tux place in North Miami to try on your tuxes &
make sure that the measurments are right when they still have enough time
to make any adjustments.  Friday, during the day, Max will have something
planned for you guys...

Please start getting your measurements now & we will send you another email
when we find the place for you to call in your measurements in Miami.  Call
with any questions (303) 832-8160....The hotties in Miami are waiting for
you...

The Miami Beach Ocean Resort
3025 Collins Avenue, Miami Beach
1-800-550-0505

*Say you are with the Harris/Schrutt wedding for group rates of:
$160/night - city view      $200/night - ocean view

If you need a travel agent, we have used June Schram with Young Travel
previously at 1-800-426-9968 & again,  say you are with our wedding
party...

Take care & be safe.....Jen


As you know there are several litigations pending against Ecogas, EZ Products
and/or Enron (or a combination) which could be problematic to our current
strategy of selling the assets to PNE.  They are as follows (with
comments/status provided):

Wisvest - both PNE and Ecogas are working towards a settlement/restructuring
which will include them releasing Ecogas from all obligations and dismissal
of their pending suit.  We're trying to get this completed prior to closing.
Tom Hall - Ecogas owes Tom $41K (Tom says $46K) for which we've offered to
settle with thim pari-passu with all other creditors at 50 c/$ ($21K).  He
has rejected the offer and is planning to move forward with depositions,
etc...  Our plan per my conversation w/ Lisa yesterday is to escrow the money
($21K) we offered in the Settlement sent to him last Friday, 12/1.
Lyon Credit/United Hudson Bank - I am trying to contact them to see if I can
get them to either dismiss the suit or settle for $25K or less.
WMI/Davis St. - Richard is supposed to be contacting WMI's legal to discuss.
Victoria Sterling - I am trying to contact her to see if she'll settle for
$25K or less.
ISCO (has sued EZ Products, Ecogas and Enron) - Richard is supposed to
contact their legal counsel to discuss merits of suing Enron.

Is there anything else we should be doing to mitigate potential problems if
we can't get any of them to settle/dismiss their suits?  Who is handling
responses, filings, pleadings, etc... for each of these cases while they're
status is uncertain?  Currently, we have no counsel re: Victoria Sterling and
ISCO.  I'm not sure who's doing what on Wisvest, Tom Hall or Lyon Credit.
Previously, Milbank Tweed was handling WMI but I haven't seen or heard of
anything being done so I'm not sure about this either.

Doug Daniels at Bracewell has encouraged us on several occasions to run our
strategy by bankruptcy counsel in the event they won't settle and end up
putting Ecogas into bankruptcy.  Per my discussion with Lisa yesterday, she
does not feel the cost is warranted.


please look at this.

 -----Original Message-----
From: 	Bradford, William S.
Sent:	Monday, November 19, 2001 8:57 AM
To:	Kitchen, Louise; Shankman, Jeffrey A.
Subject:	FW: Prepayment Request for Equiva - 11/21/01

FYI.  Let's discuss.

Bill

 -----Original Message-----
From: 	Moran, Tom
Sent:	Monday, November 19, 2001 8:51 AM
To:	Bradford, William S.; Mcginnis, Stephanie
Subject:	Prepayment Request for Equiva - 11/21/01

Equiva is looking for a $1,588,860 pre-payment on Wednesday, 11/21 to cover an MTBE cargo in NYH.  They will not consider any open credit and since we have already pre-paid them for crude in December our argument is falling on deaf ears.

tm


John,
Below is Don Black's contact information.

Have a great Thanksgiving

 -----Original Message-----
From: 	Black, Don
Sent:	Wednesday, November 21, 2001 12:07 PM
To:	Brooks, Loretta
Subject:	my contact numbers

Wednesday night through Thursday am

cell	713 516 1384
mom's	318 640 4288

Thursday through Sunday

cell	713 516 1384
home	713 463 9673


---------------------- Forwarded by Melissa Rodriguez/HOU/ECT on 11/16/2000
12:13 PM ---------------------------
From: Maria Sandoval on 11/16/2000 10:45 AM
To: Elizabeth_Gutierrez@eott.com @ ENRON, Chantelle Villanueva/HOU/ECT@ECT,
Elizabeth Soto/HOU/ECT@ECT, Andrea R Guillen/HOU/ECT@ECT, Melissa
Rodriguez/HOU/ECT@ECT, Brenda Barreda/HOU/EES@EES, Phenicia
Olivier/HOU/ECT@ECT, Pamela Sonnier/HOU/ECT@ECT, Brenda
Flores-Cuellar/NA/Enron@Enron
cc:
Subject: Re: Fwd: FW: 8 true friends(p.s. whats up to all my girls/???):)

---------------------- Forwarded by Maria Sandoval/HOU/ECT on 11/16/2000
10:43 AM ---------------------------

Elizabeth_Gutierrez@eott.com on 11/16/2000 10:12:20 AM
To: Victoria_G_Martinez@eott.com, llkey@altavista.com,
rebecca_padfield@aimfunds.com, melissa_casas-walker@aimfunds.com,
Rosahernandez@pennzoil.com, Maria.Sandoval@enron.com, yvasquez@bcm.tmc.edu,
krvasquez@yahoo.com
cc:
Subject: Re: Fwd: FW: 8 true friends(p.s. whats up to all my girls/???):)

Elizabeth Ann Gutierrez
Sr. Accounting Clerk
(713) * 993-5515  / Fax (713) * 402-2753
Elizabeth.Gutierrez@EOTT.com

bject: Fwd: 8 true friends
> >
> >
> >
> >
> >> > > Subject: FW: 8 true friends
> >> > >
> >> > >
> >> > >
> >> > >
> >> > > > > 8 true friends
> >> > > > > I'LL JUST TAKE IT AS A HINT IF I DON'T GET
> >> > THIS BACK
> >> > > > > How many people actually have 8 true friends?
> >> > > > > Hardly anyone I know!
> >> > > > > But some of us have All Right friends and Good
> >> > friends!!! You have
> >> > been
> >> > > > > Tagged by the Friendship  Angel
> >> > > > >                             (\0/)
> >> > > > >                              /_\
> >> > > > > Which means you are a great friend!! You will
> >> > Have Good Luck For Two
> >> > > > >Years  if you send this to 8 people or more and
> >> > if this is sent back to
> >> > > you
> >> > > > >then you know that you are a true friend......
> >> > > > >You must send it in 5 minutes or your good luck
> >> > will
> >> > > > >be broken!!
> >> > >
> >> > > > > If this is sent to you it means you are a good
> >> > true friend.
> >> > > > >
> >> > > > >
> >> > > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> > >
> >> >
> >> >
> >>
> >>
> >
> >
> >
>
>
>--------------------------------------------------------------------------
>
>Why is College Club the largest and fastest growing college student site?
>Find out for yourself at http://www.collegeclub.com
>
>

_________________________________________________________________________
Get Your Private, Free E-mail from MSN Hotmail at http://www.hotmail.com.

Share information about yourself, create your own public profile at
http://profiles.msn.com.


Given the current tremendous energy market volatility and as we stretch
resources to make our commercial goals for 2000, we think it would be
appropriate to postpone the ENA 2000 Offsite to early next year.  I trust
this meets with your approval and thanks for all the hard work.

Regards
Dave and John


One minor point:  the response to the first data request implies that all
employees went through the PRC process in 2000.  I am not sure this is
accurate.  It's fair to say that most did, but I believe that the field
employees who are organized into self-directed work teams do not go through
the PRC process.


1/00 Plan Allocations for RC 1497 - Farmer:

15%  Gas Network Services
84% Gas Network Trading
1%   Gas Network Development -->  Time spent on Project Sally was primarily
determining the estimated number of employees required to perform the
Trading Support functions and reading the deal memorandum.

Daren


Stupid me I forgot to enclose the pictures because I was too busy messing
with staying on-line!

But here ya go!

_______________________________________________________
Send a cool gift with your E-Card
http://www.bluemountain.com/giftcenter/

 - Nik9.jpg
 - Nik.jpg


---------------------- Forwarded by Eric Bass/HOU/ECT on 01/25/2001 07:58 AM
---------------------------

"K. Bass" <daphneco64@bigplanet.com> on 01/25/2001 05:34:12 AM
Please respond to "K. Bass" <daphneco64@bigplanet.com>
To: "Larry W. Bass" <lwbthemarine@bigplanet.com>, Eric Bass
<Eric.Bass@enron.com>
cc:
Subject: MATT DRUDGE -- DRUDGE REPORT 2000c

?

?http://www.drudgereport.com/wh93a.htm
 - MATT DRUDGE -- DRUDGE REPORT 2000c.url


CALIFORNIA  SITUATION CLARITY IMPROVING; MOST LIKELY OUTCOME FAVORABLE FOR
ALL
* While we do not expect a direct rate increase or removal of the rate
freeze for EIX or PCG out of the California Public Utility Commission
meeting today, we are encouraged by the conciliatory tone of recent
comments.
* In our view, acerbic rhetoric has finally given way to pragmatic
reconciliation and it now appears that California utilities are on the path
towards effectively receiving the rate increases they require to remain
solvent.
* We believe this has implications not only for the health of the
affected utilities, but also for the Growth Energy Merchants and Competitive
Generators.
* While the credit risk associated with utilities' power market
purchases have not been solved yet, the credit risk in the California market
has eased somewhat.
* While trading may be choppy as the final California remedy is
hammered out, we recommend the purchase of the Growth Energy names
throughout any near-term weakness possible as a result of the process.
* Decision expected today at 4:00 PM EST.

 <<CA Situation Improving12-21-00.pdf>>

Raymond C. Niles
Power/Natural Gas Research
Salomon Smith Barney
(212) 816-2807
ray.niles@ssmb.com

s

Raymond C. Niles
Power/Natural Gas Research
Salomon Smith Barney
(212) 816-2807
ray.niles@ssmb.com

s

 - CA Situation Improving12-21-00.pdf


At the request of Sara Shackleton, attached is our form of Letter of Credit.


[IMAGE]

Thank you for using our automated self service password reset option.

The user id and password in SAP (Apollo Production and HR Production), eHRonline, iBuyit and iPayit are all synchronized.  When you reset your password in eHRonline, it automatically synchronizes the password in the other systems.

Please follow the steps to reset and synchronize your passwords.

1.        Go to ehronline.enron.com
2.       Click on the [IMAGE] button
3.       Enter your User Id (SAP Personnel Number) and temporary password (located at the bottom of this email)
4.       You will then be asked to change your password
5.       Enter your new password twice
6.       Once you have successfully changed your password in eHRonline, you have synchronized your password for SAP (Apollo Production and HR Production), eHRonline, iBuyitand iPayit
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 THIS IS A GENERATED EMAIL - DO NOT REPLY!

IF YOU NEED FURTHER ASSISTANCE, CONTACT THE ISC HELP DESK AT:  713-345-4727

The password for your account: P00560008   has been reset to: 12691118

Go to eHRonline now: http://ehronline.enron.com

 - C.DTF


Please join me in congratulating the following East Power team members on
their recently announced promotions:

 Rogers Herndon (Director to VP)
 Dana Davis (Director to VP)
 Rob Benson (Manager to Director)
 Doug Gilbert-Smith (Manager to Director)
 Terri Clynes (Manager to Director)
 John Llodra (Manager to Director)
 Matt Lohrenz (Sr. Specialist to Manager)
 Chris Dorland (Associate to Manager)
 Doug Sewell (Associate to Manager)
 Gautam Gupta (Associate to Manager)
 Carla Compean (Analyst to Analyst III)
 Dave Ryan (Sr. Specialist to Manager-Trading Support)
 Kayne Coulter (Sr. Specialist to Manager-Trading Support)
 Larry Valderrama (Sr. Specialist to Manager-Trading Support)
 Jason Choate (Specialist to Sr. Specialist)
 Tamara Black (Asst. Admin II to Sr. Admin)


Thanks for the update.  Andy Zipper is working on a structure that will allow
the brokers to access our site as you've pointed out.  I'll have Andy contact
you and John on this topic.

Jeff

Chris Glaas
11/16/2000 12:25 PM
To: Jeffrey A Shankman/HOU/ECT@ECT
cc: John L Nowlan/HOU/ECT@ECT, Andy Zipper/Corp/Enron@Enron
Subject: Re: EOL and the brokers

My views are as follows:
We have lost business on what I am doing (dated brent vs frontline IPE) to
ICE. For the future we need something more to combat ICE and other systems.
Getting the brokers on our side could be the answer. The benefits I can see
are:
a. We will reach a wider crowd using the brokers. Today there are companies
who will not turn on our system despite personal visits and other marketing.
They seem to prefer speaking to brokers.
b. We could gain neutrality if the broker could transact on EOL on behalf of
the customer. The biggest problem when I speak to customers seems to be that
by dealing with Enron on EOL the customer is afraid of giving us to much of
information of what they are doing.
c. The brokers are scared for the future. They think they are about to die
out due to electronic trading. Enron should be able to strike a good deal
with the broker. Maybe even get paid ?
d. Enron would gain a free marketing force thru the brokers.

regards
chris glaas

To: Chris Glaas/LON/ECT@ECT
cc: John L Nowlan/HOU/ECT@ECT, Andy Zipper/Corp/Enron@Enron

Subject: Re: EOL and the brokers

Get with Nowlan and talk to Andy Zipper on this.  There are a number of
options for us with brokers, and Andy has been involved in this aspect of our
business for some time.   I'd like to hear your views.  Thanks.

Jeff

Chris Glaas
11/14/2000 01:06 PM
To: Jeffrey A Shankman/HOU/ECT@ECT, John L Nowlan/HOU/ECT@ECT, Chris
Mahoney/LON/ECT@ECT
cc:
Subject: EOL and the brokers

I have been contacted by ICAP and Man regarding different co-ops between EOL
and the services provided by these brokers. Icap wants Enron to be the market
maker for the ICAP electronic system (swap-net) , MAN wants to represent EOL
to the market and act as a principal between Enron and Man customers.

There are benefits and draw-backs using the brokers. I have my views on the
matter.

Jeff, what is our policy for EOL regarding working with the brokers?

regards
chris glaas


Here are some bullets briefly describing the FERC audit high points.  I think the scope is "right on the money" and the timing is reasonably good also.  The text of the audit solicitation follows the bullets.  I've made contact with Andy Sakallaris, head of FERC procurement, to attend the pre-bid conference next Tuesday (assuming it is held, since expressions of interest thus far have been from CA based firms unwilling to make the trip to DC).  Ray

Audit description-  FERC seeks to take all appropriate steps for prospective improvements in California markets; accordingly, an independent operational audit of the CAISO will be performed to determine any areas in which the CAISO could enhance its effectiveness in fulfilling its responsibilities in operating the transmission system under its control and administering real-time energy markets.

Scope- Provide a comparison of the CAISO's actual operations and its FERC tariff and determine whether the CAISO's operations are adequately transparent to market participants.

Audit period- 10/1/00-10/1/01

Deliverables timing- Draft report due on January 9, 2002; final report due January 16, 2002.

Audit schedule-  Begins on November 1, 2001, and ends no later than January 4, 2002.

Pre-proposal conference- A conference is scheduled for prospective offerors at FERC next Tuesday; FERC will give a brief explanation of the requirements and clarify any questions asked.

PART: U.S. GOVERNMENT PROCUREMENTS
SUBPART: SERVICES
CLASSCOD: R--Professional, Administrative and Management Support
  Services
OFFADD: Federal Energy Regulatory Commission (FERC), 888 First
  Street, NE, Washington, DC 20426
SUBJECT: R--OPERATIONAL AUDIT OF CALIFORNIA INDEPENDENT SYSTEM
  OPERATIOR. INC. CAISO
SOL FERC02RMT22071
DUE 102601
POC Charlotte Handley, 202-219-1156 or Andrew Sakallaris,202-219-1150
DESC: This is a combined synopsis/solicitation for commercial
  items prepared in accordance with the format in Subpart 12.6,
  as supplemented with additional information included in this
  notice. This announcement constitutes the only solicitation;
  proposals are being requested and a written solicitation will
  not be issued. FERC02RMT22071 is issued as a request for proposal
  and all provisions/clauses are those in effect through FAC
  97-27. This solicitation is unrestricted under NAICS number
  561. Statement of Work: I. BACKGROUND. The California electricity
  market has experienced great stress from Summer 2000 to Summer
  2001, with demand outstripping supply, wholesale prices rising
  dramatically, and key market participants becoming financially
  unstable. As a result, the California Independent System Operator,
  Inc. (CAISO), which operates the electricity transmission grid
  throughout most of California, was forced to adapt to rapidly
  changing circumstances. During all of this, the CAISO worked
  hard to ensure system reliability. Under the Federal Energy
  Regulatory Commission's market mitigation plan, wholesale prices
  stabilized in California in Summer 2001. The Commission seeks
  to take all appropriate steps for prospective improvements
  in California markets, including improvements to help the CAISO
  in effectively performing its increasing responsibilities.
  Accordingly, an independent operational audit of the CAISO
  will be performed to determine the areas, if any, in which
  the CAISO could enhance its effectiveness in fulfilling its
  responsibilities in operating the transmission system under
  its control and administering certain real-time energy markets.
  II. SCOPE OF WORK. The Independent Public Accounting (Contractor)
  firm shall perform an operational audit of the CAISO processes,
  practices, and procedures in accordance with Generally Accepted
  Government Auditing Standards (GAGAS). The Contractor shall
  provide a comparison of the CAISO's actual operations and its
  Commission tariff (procedures and tariff can be found at www.caiso.com).
  The Contractor shall ascertain whether the CAISO's operations
  are adequately transparent to market participants. To the extent
  possible, the Contractor shall also ascertain whether the CAISO's
  procedures and operations are consistent with the most effective
  business practice. III. AUDIT PERIOD. The audit of the CAISO
  shall cover the period commencing October 1, 2000, through
  October 1, 2001. IV. DELIVERABLES. The contractor must provide
  the Contracting Officer's Representative (COR) with a draft
  and final report detailing the findings, operating deficiencies
  and/or major observations and recommendations. These reports
  and other deliverables must be provided to the COR by the close
  of business on the following dates: 1) Draft Report - January
  9, 2002 2) Final Report - January 16, 2002. V. SCHEDULE. The
  operational audit will commence on November 1, 2001, and it
  must be completed no later than January 4, 2002. The contractor
  shall meet with the COR to discuss the audit no later than
  November 6, 2001. The contractor must provide the Commission
  with an operational audit plan no later than November 14, 2001.
  A detailed operational audit plan will be submitted to the
  COR for review, feedback, and approval. The COR or designated
  representative will review the plan. VI. Working Papers. The
  contractor shall prepare and provide a copy of work papers
  in accordance with GAGAS. All work papers shall include the
  purpose, sources of information, the procedures performed,
  results thereof, and conclusions as appropriate for the planning,
  internal control, compliance, and substantive testing phases.
  For all findings, work papers shall clearly show the condition
  or problem, criteria, cause, effect, and recommendation for
  improvement. All working papers shall be cross-referenced to
  audit programs, summaries, and final audit report. These documents
  will become the property of the Commission. During the course
  of the audit or upon completion of the audit work, the Contractor's
  audit report and work papers shall be subject to access and
  review by the Commission. A preproposal conference is scheduled
  for prospective offerors at FERC on Tuesday, October 16, 2001,
  at 10:00 am at 888 First Street, NE, Washington, DC 20426,
  Room 3M-3. FERC will give a brief explanation of the requirements
  and clarify any questions asked. Questions submitted in advance
  to A. Sakallaris (andrew.sakallaris@ferc.fed.us) is appreciated
  and preferable. Contractual, technical, and legal representatives
  will be on hand to answer any questions. Bring no more than
  three representatives and E-mail or phone A. Sakallaris, 202-219-1150
  to indicate the number and names of individuals attending.
  If unable to attend, E-Mail A. Sakallaris and provide the point
  of contact's mailing and E-mail address and FERC will arrange
  to deliver any additional information that may become available
  as a result of the pre-proposal conference. All offerors and
  subcontractors will complete and submit with their proposals,
  either the Organizational Conflicts of Interest (OCI) representation
  or the OCI disclosure (not both). Complete and submit the OCI
  Questionnaire. Request OCI information from A. Sakallaris.
  See DOE clauses 952.209-8 OCI-Disclosure and 952.209-72 OCI.
  Same/similar language will be incorporated into the resultant
  contract. Period of Performance: From approximately November
  1, 2001 to January 16, 2002. FAR Provision 52.212-1, Instructions
  to Offerors-Commercial (Oct 2000), applies. Addendum to FAR
  52.212-1 SUBPARAGRAPH (b) Reply by e- mail the proposal to
  FERC, ATTN: C. Handley, Division of Procurement, FA-12, 888
  First St, NE, Wash DC 20426, e-mail: charlotte.handley@ferc.fed.us.
  It is our intent to evaluate based on initial proposals. Offerors
  shall submit five copies of their price and technical proposal,
  signed by an official authorized to bind the offeror, at the
  above address no later than 2:00 PM local time, Friday, October
  26, 2001. Price Proposal: Addendum to FAR 52.212-1 SUBPARAGRAPH
  (b)(6): The price proposal shall be completely separate from
  the technical proposal. Offerors must breakout pricing by month
  and provide (1) labor categories (2) corresponding firm-fixed-price,
  fully loaded labor rates (3) proposed number of hours estimated
  for each labor category (4) Other Direct Costs as applicable
  (subcontractor and travel). Supporting details shall also be
  provided as appropriate (e.g., travel destinations, number
  of trips, computer time, discounts offered (excluding prompt
  payment)). Addendum to FAR 52.212-1 SUBPARAGRAPH (c) The offeror
  agrees to hold the prices in its offer firm for 120 calendar
  days. Provision 52.212-2, Evaluation-Commercial Items (Jan
  1999), applies. Addendum to FAR 52.212-2 SUBPARAGRAPH, (a)
  Technical Proposal: Past Performance (30 points). Ensure that
  the company names, points of contact and phone numbers are
  current. The Offeror and each subcontractor proposed must each
  select three references to complete a "Contractor Past-Performance
  Evaluation." All areas of the sheet must be filled in. If an
  answer to a specific question is not provided, the applicable
  area must be annotated with the reason why (e.g. "Reference
  failed to provide an answer"). Higher scores will be assigned
  for contracts that are at least similar in size and complexity.
  FERC may obtain and evaluate information from sources other
  than those provided by the offeror. FAR 15.305(a)(2)(iv) states
  "In the case of an offeror without a record of relevant past
  performance or for whom information on past performance is
  not available, the offeror may not be evaluated favorably or
  unfavorably on past performance." For the purposes of this
  evaluation not being evaluated favorably or unfavorably means
  the offeror will receive a rating of "good or acceptable" on
  company past performance. To obtain a copy of the past performance
  form to be completed by the Offeror's references, request from
  A. Sakallaris by email. The Offeror will be responsible and
  ensure that the references submit or reply by e-mail their
  completed response to C. Handley, located at the above address
  by 2:00 PM local time, October 26, 2001. Offerors should also
  notify the references that FERC may be contacting them regarding
  the past performance information. Prior Audit Experience (25
  points). The offeror must cover in its proposal the extent
  of prior related experience in electric bulk power markets,
  and the ability to effectively and efficiently conduct this
  operational audit in accordance with GAGAS. The proposal must
  include previous and/or current experience, within the last
  3 years, where the offeror has performed audits similar in
  terms of size and complexity of this requirement. Higher scores
  will be assigned to those offerors who have demonstrated successful
  experience in electric bulk power markets within the last three
  years. To be acceptable, the services must have been satisfactorily
  performed and at least similar in terms of size and complexity
  to the work required under this contract. Understanding the
  Statement of Work (20 points). The proposal must clearly demonstrate
  in sufficient and precise detail the offeror's expertise in
  understanding and analyzing independent system operator tariffs,
  market operations and services, and transmission issues. The
  offeror must describe its ability to perform a comprehensive
  and thorough analysis of the electric bulk power market operated
  by the CAISO. Higher scores will be assigned to those offerors
  who demonstrate an understanding and greater knowledge of independent
  system operator tariffs, market operations and services, and
  transmission issues. Higher scores will also be assigned to
  offerors who demonstrate a comprehensive understanding of bulk
  power markets like those operated by the CAISO. Audit Methodology
  and Quality Control (15 points). The technical proposal must
  include the audit methodology and must address each phase of
  the audit. The proposal must identify specific aspects of each
  phase and explain how each phase/aspect is related. The offeror
  must include estimated completion times for each phase of the
  audit and address critical completion dates. The technical
  proposal must describe the audit approach to documenting systems
  and internal controls, and effective procedures, including
  consideration of risk and materiality, to determine the extent
  of audit testing. Quality control is an important part of the
  technical proposal. The proposal must demonstrate the offeror's
  internal quality control procedures. The proposal must include
  a copy of the firm's latest peer review report, comments, and
  the response to the peer review report. Higher scores will
  be assigned to those offerors who demonstrate and offer a sound,
  valid, effective, and innovative audit methodology that reflects
  an understanding of the statement of work. "Valid" entails
  the use of techniques that are known to be feasible with respect
  to the area addressed; "Effective" refers to the workability
  and appropriateness of the methodology. "Innovative" means
  the development and application of a novel, yet valid technique
  that will increase the effectiveness of the approach. Higher
  scores will be assigned to offerors who demonstrate sound and
  effective internal quality control procedures. Professional
  Qualifications (10 points). The offeror must describe in its
  proposal: 1) the professional qualifications of the staff that
  will be assigned to this contract and 2) demonstrate that it
  has sufficient resources to perform the audit and qualified
  staff to perform critical tasks necessary to support the audit.
  The written response must also include the following information
  for all staff participating on the audit: Labor Category (i.e.,
  Partner, Manager, etc.); CPA certification date (if applicable);
  Other applicable certification(s); Total years of audit and/or
  other experience; Advance degree(s) obtained; and Total years
  employed by the offeror. Higher scores will be based on offeror's
  educational background, recent work experience, and certifications
  obtain by their staff. In particular, higher scores will be
  given to those who offer recent experience with independent
  system operator tariffs, market operations and services, transmission
  issues, and bulk power markets like those operated by the CAISO.
  Addendum to FAR 52.212-2 SUBPARAGRAPH (a). Technical and past
  performance, when combined, are more important than price.
  However, award shall be made to the offeror whose proposal
  is determined to best meet the needs of the Government after
  consideration of all factors i.e., provides the "best value."
  "Best value," for the purpose of the contract is defined as
  the procurement process that results in the most advantageous
  acquisition decision for the Government and is performed through
  an integrated assessment and trade-off analysis between technical
  and price factors. Include a completed copy of Provision at
  52.212.3, Offeror Representations and Certifications-Commercial
  Items (May 2001) with offer. Clause 52.212-4, Contract Terms
  and Conditions-Commercial Items (May 2001), applies. Addendum
  to FAR 52.212-4: 1. 52.252-2 Clauses Incorporated By Reference
  (FEB 1998). This contract incorporates one or more clauses
  by reference, with the same force and effect as if they were
  given in full text. Upon request, the Contracting Officer will
  make their full text available. Clauses are as follows: 52.217-8
  and 52.217-9. Clause 52.212-5, Contract Terms and Conditions
  Required To Implement Statutes or Executive Orders-Commercial
  Items (May 2001) applies. Addendum to FAR 52.212-5: The following
  clauses are incorporated by reference: 52.203-6 with A1; 52.219-4;
  52.219-8; 52.222-21; 52.222-26; 52.222-35; 52-222-36; 52.222-37;
  52.225-13; 52.225-15; 52.225-16; 52.232-33; 52.239-1. E-mail
  questions to C. Handley at charlotte.handley@ferc.fed.us. no
  later than October 19, 2001. E-Mail C. Handley of your intent
  to submit a proposal no later than October 19, 2001.
LINKURL: andrew.sakallaris@ferc.fed.us
LINKDESC: Click here to request copies of OCI questionnaire and <andrew.sakallaris@ferc.fed.us>
  the past performance form
EMAILADD: charlotte.handley@ferc.fed.us
EMAILDESC: charlotte.handley@ferc.fed.us <mailto:charlotte.handley@ferc.fed.us>
CITE: (W-282 SN5102V8)