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COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES NOVEMBER 07, 2001 Notice ID: 3248 5 - NO RESPONSE REQUIRED This notice is an update to the October 26, 2001 notice regarding the turbine at Lanham Compressor Station.
Due to unforeseen circumstances, the return to service date has been delayed until approximately the last week of November.
If you have any questions, please feel free to contact your Customer Services Representative.
| TCO - LANHAM COMPRESSOR STATION |
You have received this message because someone has attempted to send you an e-mail from outside of Enron with an attachment type that Enron does not allow into our messaging environment.
Your e-mail has been quarantined and is being held at the MailSweeper server.
Sender: edu@activeworlds.com
| An Inbound Message For You Has Been Quarantined |
The TCO book is buying 1,000 dth per day from Power Gas Marketing at Trco-Young Women's Creek.
Effective 11/9/01, CNG began restricting receipts from Trco-Leidy.
We are taking 543 dth into CNG, VNG has 543 dth of primary receipts at Leidy on CNG.
STEVIE, till further notice, the VNG book needs to sell the New York Book 453 dth of Trco Non NY, use deal 1165693.
The transport usage ticket is 1165849, and the buy from TCO is deal 1165737.
GOOD LUCK!
| Transco Z6 activity for 13th. |
Here are my notes from today's call.
As with Monday, I've focused on getting them out as quickly as possible rather than taking extra time to re-organize them by subject.
Enron's business has been grouped into three buckets: Core, Non-core, and Under Review.
Core: Wholesale energy business in North America and Europe, retail energy, pipelines Non-core: Broadband, water, and international assets (i.e.
EGAS).
Enron has approx.
$8Bn in investments in these assets, and they have produced 'dismal' returns.
Enron will be exiting these businesses and will attempt to wind them up in an orderly fashion.
An aggressive divestiture program has been set in motion for these assets.
Under Review: EGM, EIM.
These businesses are being closely examined to determine whether they have a reasonable chance of long-term viability.
Required resource levels are being carefully studied.
Following review, Enron will move the different portions of these businesses to core or non-core as the analysis dictates.
Approximately $800MM of asset sales are under contract and expected to close in the fourth quarter.
These include a gas LDC in Brazil, EcoElectrica, and our Indian E&P assets.
Enron is in active pursuit of an additional private equity infusion of $500MM-1Bn.
Given the current environment, raising equity in the public markets would be 'inefficient', McMahon says.
Short-term liquidity is provided by the $3Bn of credit drawn upon a few weeks ago, the $1Bn of new debt, and the $1.5Bn equity infusion from Dynegy.
Longer-term, the proceeds from the sale of PGE will provide liquidity.
Asset sales over the next year will be used to pay down debt.
McMahon described the major off-balance-sheet vehicles: Marlin was set up to hold Azurix assets.
It was initially capitalized with $950MM of 144a debt and $125MM of equity (raised from Enron and institutional investors).
The debt is supported by the equity and by Azurix' assets.
Enron is obligated to cover any deficit at the time the debt becomes due on 3/17/03 (the 'Enron topup' obligation).
The 3/17/03 date is accelerated in the event that Enron is rated below-investment-grade by any one of the three major agencies.
The primary asset of Marlin is Wessex Water.
As long as Wessex is worth at least $2.6Bn, there will be no Enron topup required.
If we take a 25% haircut to present book value, Enron will have to provide $650MM in consideration upon retirement of the debt.
This $650MM would hit Enron cash, income, and equity balances.
Osprey contains energy-related assets and 'other assets'.
It was initially capitalized with $2.4Bn of 144a debt and $220MM in equity (ENE and institutionals).
As with Marlin, the entity is an asset-backed structure with an Enron topup guarantee.
The debt is supported by a) the assets; b) $1Bn of convertible preferred ENE (convertible into 50MM shares of ENE common); and c) additional ENE common as needed for topup.
Assuming the same 25% hypothetical haircut to current book value, Enron would have to deliver approx.
$600MM of topup funds--which would hit ENE cash, income, and equity.
The debt must be retired by 9/17/02, with the same cut-to-junk early trigger provision as Marlin.
| Highlights from ENE Analyst Conference Call 11/14 |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES NOVEMBER 20, 2001 Notice ID: 3284 5 - NO RESPONSE REQUIRED NOTE: The following is being provided by Columbia as notice to all of its shippers of potential outages or reductions in available capacity in the identified portions of the system due to construction activities, routine maintenance, modifications, tests or repairs undertaken to protect the integrity and performance capability of its storage and transmission facilities.
The information provided below is subject to change for numerous reasons, including but not limited to, third-party controlled events and decisions, weather, work schedules, equipment availability, force majeure events, etc.
Thus, while Columbia is willing to provide this notice and update it periodically as necessary, Columbia is unable to represent and warrant that the specific activities will occur, or that they will occur on or near the specified dates.
SUBJECT: LINE SM-123 Columbia anticipates that November 26, 2001, Line SM-123 will be back in service.
The restriction of 0 non firm will be lifted.
The following receipt points will be affected: Equitable Gas: Beaver Creek (H1) Hi Hat (F3) CNR Pipeline: Boldman (CNR02) Conoway (CNR03) Johns Creek (CNR08) Canada (CNR09) Canada (CNR10) Stafford (CNR11) Thacker/Majestic (CNR12) Briar Mtn.
(CNR13) Huff Creek (CNR14) Conoco: Grant (P1) The same is true with respect to any Appalachian production flowing directly into Columbia's Line KA between Columbia's Boldman Compressor Station and Columbia's Huff Creek Compressor Station as well as production flowing into Columbia's Lines SM-116, KA-15, PM-3 and PM-17.
If you have any questions, feel free to contact your Customer Services Team.
| TCO - LINE SM-123 |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES NOVEMBER 21, 2001 Notice ID: 3285 5 - NO RESPONSE REQUIRED SUBJECT: CAPACITY UPDATE EFFECTIVE FOR THURSDAY, NOVEMBER 22, 2001 THERE ARE NO CHANGES FROM PREVIOUS DAY Effective Thursday, November 22, 2001, capacities will be as follows: Excess MDWQ Available + ISS Withdrawals Available SIT Withdrawals Available Imbalance Drawdowns Available Excess MDIQ NOT Available + ISS Injections NOT Available SIT Injections NOT Available Imbalance Paybacks NOT Available PAL Lends/Unparks Available PAL Parks/Loan Paybacks NOT Available + Call Gas Control 24 hours in advance at (304) 357-2606 to request approval.
Non-firm receipt capacity will be as follows: TENNESSEE: Brinker (B12) 20,000 Broad Run (B9) 450,000 Cambridge (B10) 0 Dungannon (B11) 20,000 Highland (B17) 0 Milford (B18) 20,000 North Greenwood (B22) 0 Unionville (B15) 50,000 TEXAS EASTERN: Delmont (C16) 10,000 Eagle (C22) 20,000 Hooker (C9) 20,000 Pennsburg (C23) 20,000 Windridge (C12) 20,000 NATIONAL FUEL: Independence (M1) 0 Ellwood City (L1) 15,000 TRANSCO: Downingtown (E3) 2,500 Emporia I (E13) 60,000 Rockville (E2) 60,000 Dranesville (E1) 50,000 EQUITABLE GAS: Hi Hat (F3) 0 KENTUCKY WEST VIRGINIA (KYWV): Beaver Creek (H1) 0 CNR PIPELINE: Boldman (CNR02) 0 Conoway (CNR03) 0 Johns Creek (CNR08) 0 Canada (CNR09) 0 Canada (CNR10) 0 Stafford (CNR11) 0 Thacker/Majestic (CNR12) 0 Briar Mtn.
(CNR13) 0 Huff Creek (CNR14) 0 Wiser (827280) 0 CONOCO: 0 Delta Natural Gas (819288) 0 Grant (P1) 0 NOTE: ANY APPALACHIAN PRODUCTION FLOWING DIRECTLY INTO COLUMBIA'S LINE KA BETWEEN COLUMBIA'S BOLDMAN COMPRESSOR STATION AND COLUMBIA'S HUFF CREEK COMPRESSOR STATION AS WELL AS PRODUCTION FLOWING INTO COLUMBIA'S LINES SM-116, KA-15, PM-3, AND PM-17 IS 0 NON-FIRM.
ALGONQUIN: Ramapo (R1) 25,000 ANR: Paulding/Cecil 30,000 (F1, A2) LEBANON AGGREGATE 100,000 (A4, F2, C4, D3) TOLEDO AGGREGATE 100,000 (A3, F4, 734462) COLUMBIA GULF: (801) TCO-Leach 700,000 Internal point non-firm capacity will be as follows: Lanham 0 Delivery capacity (non-firm) will be as follows: TRANSCO: Martins Creek 10,000 (MLI E5) Young Woman's Creek 10,000 (MLI E9) ALGONQUIN: Hanover 0 (MLI R2) EQUITRANS: Fallen Timber 31,000 (MLI K1) Waynesburg-Rhinehart 20,000 (MLI K2) OPT-30 will be available in all market areas.
OPT-60 will be available in all market areas.
Market Area delivery capacity (non-firm) will be as follows: Operating Area 1 Market Area 33 30,000 Market Area 34 20,000 Operating Area 2 Market Area 20 No Restrictions Operating Area 3 Market Area 15 No Restrictions Market Area 16 No Restrictions Market Area 17 No Restrictions Market Area 18 No Restrictions Market Area 19 No Restrictions Operating Area 4 Market Area 21 10,000 Market Area 22 10,000 Market Area 23 20,000 Market Area 24 10,000 Market Area 25 No Restrictions Market Area 29 No Restrictions Operating Area 5 Market Area 02 No Restrictions Market Area 07 No Restrictions Operating Area 6 Market Area 10 No Restrictions Market Area 11 No Restrictions Market Area 12 No Restrictions Market Area 13 No Restrictions Market Area 14 No Restrictions Operating Area 7 Market Area 01 No Restrictions Market Area 03 No Restrictions Market Area 04 No Restrictions Market Area 05 No Restrictions Market Area 06 No Restrictions Market Area 08 No Restrictions Market Area 09 No Restrictions Operating Area 8 Market Area 26 No Restrictions Market Area 27 No Restrictions Market Area 32 No Restrictions Market Area 35 No Restrictions Market Area 36 No restrictions for southern part of Market Area 36.
Primary receipts/deliveries only for gas delivered in the northern portion of Market Area 36.
Market Area 38 No Restrictions Market Area 39 No Restrictions Market Area 40 No Restrictions NOTE: GAS DELIVERED IN THE NORTHERN PORTION OF MARKET AREA 38 OR THE NORTHERN PORTION OF MARKET AREA 36 MUST BE RECEIVED FROM TENNESSEE GAS PIPELINE AT HIGHLAND.
Operating Area 10 Market Area 28 No Restrictions Market Area 30 No Restrictions Market Area 31 No Restrictions If you have any questions, please contact your Account Representative.
| TCO - CAPACITY UPDATE EFFECTIVE FOR NOVEMBER 22, 2001 |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES NOVEMBER 21, 2001 Notice ID: 3286 5 - NO RESPONSE REQUIRED SUBJECT: TCO - DECEMBER 1, 2001 RETAINAGE RATE (FUEL AND UNACCOUNTED FOR VOLUMES) Columbia Gas Transmission has filed for a reduction in the following retainage rate (fuel and unaccounted for volumes) effective December 1, 2001.
Transportation Retainage Rate 2.447% Although FERC has not taken any action on the filing, we anticipate receiving approval.
Please make the appropriate adjustments to your December 1, 2001 nominations.
If you have any questions, please contact your Account Representative.
| TCO - 12/01/01 RETAINAGE RATE (FUEL & UNACCOUNTED FOR VOLS) |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES NOVEMBER 21, 2001 Notice ID: 3287 5 - NO RESPONSE REQUIRED SUBJECT: CAPACITY UPDATE EFFECTIVE FOR FRIDAY, NOVEMBER 23 THROUGH SUNDAY, NOVEMBER 25, 2001 THERE ARE NO CHANGES FROM PREVIOUS DAY Effective Friday, November 23 through Sunday, November 25, 2001, capacities will be as follows: Excess MDWQ Available + ISS Withdrawals Available SIT Withdrawals Available Imbalance Drawdowns Available Excess MDIQ NOT Available + ISS Injections NOT Available SIT Injections NOT Available Imbalance Paybacks NOT Available PAL Lends/Unparks Available PAL Parks/Loan Paybacks NOT Available + Call Gas Control 24 hours in advance at (304) 357-2606 to request approval.
Non-firm receipt capacity will be as follows: TENNESSEE: Brinker (B12) 20,000 Broad Run (B9) 450,000 Cambridge (B10) 0 Dungannon (B11) 20,000 Highland (B17) 0 Milford (B18) 20,000 North Greenwood (B22) 0 Unionville (B15) 50,000 TEXAS EASTERN: Delmont (C16) 10,000 Eagle (C22) 20,000 Hooker (C9) 20,000 Pennsburg (C23) 20,000 Windridge (C12) 20,000 NATIONAL FUEL: Independence (M1) 0 Ellwood City (L1) 15,000 TRANSCO: Downingtown (E3) 2,500 Emporia I (E13) 60,000 Rockville (E2) 60,000 Dranesville (E1) 50,000 EQUITABLE GAS: Hi Hat (F3) 0 KENTUCKY WEST VIRGINIA (KYWV): Beaver Creek (H1) 0 CNR PIPELINE: Boldman (CNR02) 0 Conoway (CNR03) 0 Johns Creek (CNR08) 0 Canada (CNR09) 0 Canada (CNR10) 0 Stafford (CNR11) 0 Thacker/Majestic (CNR12) 0 Briar Mtn.
(CNR13) 0 Huff Creek (CNR14) 0 Wiser (827280) 0 CONOCO: 0 Delta Natural Gas (819288) 0 Grant (P1) 0 NOTE: ANY APPALACHIAN PRODUCTION FLOWING DIRECTLY INTO COLUMBIA'S LINE KA BETWEEN COLUMBIA'S BOLDMAN COMPRESSOR STATION AND COLUMBIA'S HUFF CREEK COMPRESSOR STATION AS WELL AS PRODUCTION FLOWING INTO COLUMBIA'S LINES SM-116, KA-15, PM-3, AND PM-17 IS 0 NON-FIRM.
ALGONQUIN: Ramapo (R1) 25,000 ANR: Paulding/Cecil 30,000 (F1, A2) LEBANON AGGREGATE 100,000 (A4, F2, C4, D3) TOLEDO AGGREGATE 100,000 (A3, F4, 734462) COLUMBIA GULF: (801) TCO-Leach 700,000 Internal point non-firm capacity will be as follows: Lanham 0 Delivery capacity (non-firm) will be as follows: TRANSCO: Martins Creek 10,000 (MLI E5) Young Woman's Creek 10,000 (MLI E9) ALGONQUIN: Hanover 0 (MLI R2) EQUITRANS: Fallen Timber 31,000 (MLI K1) Waynesburg-Rhinehart 20,000 (MLI K2) OPT-30 will be available in all market areas.
OPT-60 will be available in all market areas.
Market Area delivery capacity (non-firm) will be as follows: Operating Area 1 Market Area 33 30,000 Market Area 34 20,000 Operating Area 2 Market Area 20 No Restrictions Operating Area 3 Market Area 15 No Restrictions Market Area 16 No Restrictions Market Area 17 No Restrictions Market Area 18 No Restrictions Market Area 19 No Restrictions Operating Area 4 Market Area 21 10,000 Market Area 22 10,000 Market Area 23 20,000 Market Area 24 10,000 Market Area 25 No Restrictions Market Area 29 No Restrictions Operating Area 5 Market Area 02 No Restrictions Market Area 07 No Restrictions Operating Area 6 Market Area 10 No Restrictions Market Area 11 No Restrictions Market Area 12 No Restrictions Market Area 13 No Restrictions Market Area 14 No Restrictions Operating Area 7 Market Area 01 No Restrictions Market Area 03 No Restrictions Market Area 04 No Restrictions Market Area 05 No Restrictions Market Area 06 No Restrictions Market Area 08 No Restrictions Market Area 09 No Restrictions Operating Area 8 Market Area 26 No Restrictions Market Area 27 No Restrictions Market Area 32 No Restrictions Market Area 35 No Restrictions Market Area 36 No restrictions for southern part of Market Area 36.
Primary receipts/deliveries only for gas delivered in the northern portion of Market Area 36.
Market Area 38 No Restrictions Market Area 39 No Restrictions Market Area 40 No Restrictions NOTE: GAS DELIVERED IN THE NORTHERN PORTION OF MARKET AREA 38 OR THE NORTHERN PORTION OF MARKET AREA 36 MUST BE RECEIVED FROM TENNESSEE GAS PIPELINE AT HIGHLAND.
Operating Area 10 Market Area 28 No Restrictions Market Area 30 No Restrictions Market Area 31 No Restrictions If you have any questions, please contact your Account Representative.
| TCO - CAPACITY UPDATE EFFECTIVE FOR NOVEMBER 23-25, 2001 |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES NOVEMBER 21, 2001 Notice ID: 3288 5 - NO RESPONSE REQUIRED SUBJECT: CAPACITY UPDATE EFFECTIVE FOR MONDAY, NOVEMBER 26, 2001 CHANGES ARE INDICATED WITH AN * Effective Monday, November 26, 2001, capacities will be as follows: Excess MDWQ Available + ISS Withdrawals Available SIT Withdrawals Available Imbalance Drawdowns Available Excess MDIQ NOT Available + ISS Injections NOT Available SIT Injections NOT Available Imbalance Paybacks NOT Available PAL Lends/Unparks Available PAL Parks/Loan Paybacks NOT Available + Call Gas Control 24 hours in advance at (304) 357-2606 to request approval.
Non-firm receipt capacity will be as follows: TENNESSEE: Brinker (B12) 20,000 Broad Run (B9) 450,000 Cambridge (B10) 0 Dungannon (B11) 20,000 Highland (B17) 0 Milford (B18) 20,000 North Greenwood (B22) 0 Unionville (B15) 50,000 TEXAS EASTERN: Delmont (C16) 10,000 Eagle (C22) 20,000 Hooker (C9) 20,000 Pennsburg (C23) 20,000 Windridge (C12) 20,000 NATIONAL FUEL: Independence (M1) 0 Ellwood City (L1) 15,000 TRANSCO: Downingtown (E3) 2,500 Emporia I (E13) 60,000 Rockville (E2) 60,000 Dranesville (E1) 50,000 The restriction of 0 non firm has been lifted.
* EQUITABLE GAS: Hi Hat (F3) 0 * KENTUCKY WEST VIRGINIA (KYWV): Beaver Creek (H1) 0 * CNR PIPELINE: Boldman (CNR02) 0 * Conoway (CNR03) 0 * Johns Creek (CNR08) 0 * Canada (CNR09) 0 * Canada (CNR10) 0 * Stafford (CNR11) 0 * Thacker/Majestic (CNR12) 0 * Briar Mtn.
(CNR13) 0 * Huff Creek (CNR14) 0 * CONOCO: Grant (P1) 0 * Wiser (827280) 0 Delta Natural Gas (819288) 0 ALGONQUIN: Ramapo (R1) 25,000 ANR: Paulding/Cecil 30,000 (F1, A2) LEBANON AGGREGATE 100,000 (A4, F2, C4, D3) TOLEDO AGGREGATE 100,000 (A3, F4, 734462) COLUMBIA GULF: (801) TCO-Leach 700,000 Internal point non-firm capacity will be as follows: Lanham 0 Delivery capacity (non-firm) will be as follows: TRANSCO: Martins Creek 10,000 (MLI E5) Young Woman's Creek 10,000 (MLI E9) ALGONQUIN: Hanover 0 (MLI R2) EQUITRANS: Fallen Timber 31,000 (MLI K1) Waynesburg-Rhinehart 20,000 (MLI K2) OPT-30 will be available in all market areas.
OPT-60 will be available in all market areas.
Market Area delivery capacity (non-firm) will be as follows: Operating Area 1 Market Area 33 30,000 Market Area 34 20,000 Operating Area 2 Market Area 20 No Restrictions Operating Area 3 Market Area 15 No Restrictions Market Area 16 No Restrictions Market Area 17 No Restrictions Market Area 18 No Restrictions Market Area 19 No Restrictions Operating Area 4 Market Area 21 10,000 Market Area 22 10,000 Market Area 23 20,000 Market Area 24 10,000 Market Area 25 No Restrictions Market Area 29 No Restrictions Operating Area 5 Market Area 02 No Restrictions Market Area 07 No Restrictions Operating Area 6 Market Area 10 No Restrictions Market Area 11 No Restrictions Market Area 12 No Restrictions Market Area 13 No Restrictions Market Area 14 No Restrictions Operating Area 7 Market Area 01 No Restrictions Market Area 03 No Restrictions Market Area 04 No Restrictions Market Area 05 No Restrictions Market Area 06 No Restrictions Market Area 08 No Restrictions Market Area 09 No Restrictions Operating Area 8 Market Area 26 No Restrictions Market Area 27 No Restrictions Market Area 32 No Restrictions Market Area 35 No Restrictions Market Area 36 No restrictions for southern part of Market Area 36.
Primary receipts/deliveries only for gas delivered in the northern portion of Market Area 36.
Market Area 38 No Restrictions Market Area 39 No Restrictions Market Area 40 No Restrictions NOTE: GAS DELIVERED IN THE NORTHERN PORTION OF MARKET AREA 38 OR THE NORTHERN PORTION OF MARKET AREA 36 MUST BE RECEIVED FROM TENNESSEE GAS PIPELINE AT HIGHLAND.
Operating Area 10 Market Area 28 No Restrictions Market Area 30 No Restrictions Market Area 31 No Restrictions If you have any questions, please contact your Account Representative.
| TCO - CAPACITY UPDATE EFFECTIVE FOR NOVEMBER 26, 2001 |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES NOVEMBER 21, 2001 Notice ID: 3289 5 - NO RESPONSE REQUIRED SUBJECT: REVISED - TCO CAPACITY UPDATE EFFECTIVE FOR MONDAY, NOVEMBER 26, 2001 CHANGES ARE INDICATED WITH AN * Effective Monday, November 26, 2001, capacities will be as follows: Excess MDWQ Available + ISS Withdrawals Available SIT Withdrawals Available Imbalance Drawdowns Available Excess MDIQ NOT Available + ISS Injections NOT Available SIT Injections NOT Available Imbalance Paybacks NOT Available PAL Lends/Unparks Available PAL Parks/Loan Paybacks NOT Available + Call Gas Control 24 hours in advance at (304) 357-2606 to request approval.
Non-firm receipt capacity will be as follows: TENNESSEE: Brinker (B12) 20,000 Broad Run (B9) 450,000 Cambridge (B10) 0 Dungannon (B11) 20,000 Highland (B17) 0 Milford (B18) 20,000 North Greenwood (B22) 0 Unionville (B15) 50,000 TEXAS EASTERN: Delmont (C16) 10,000 Eagle (C22) 20,000 Hooker (C9) 20,000 Pennsburg (C23) 20,000 Windridge (C12) 20,000 NATIONAL FUEL: Independence (M1) 0 Ellwood City (L1) 15,000 TRANSCO: Downingtown (E3) 2,500 Emporia I (E13) 60,000 Rockville (E2) 60,000 Dranesville (E1) 50,000 The restriction of 0 non firm has been lifted.
* EQUITABLE GAS: Hi Hat (F3) * KENTUCKY WEST VIRGINIA (KYWV): Beaver Creek (H1) * CNR PIPELINE: Boldman (CNR02) * Conoway (CNR03) * Johns Creek (CNR08) * Canada (CNR09) * Canada (CNR10) * Stafford (CNR11) * Thacker/Majestic (CNR12) * Briar Mtn.
(CNR13) * Huff Creek (CNR14) * CONOCO: Grant (P1) * Wiser (827280) 0 Delta Natural Gas (819288) 0 ALGONQUIN: Ramapo (R1) 25,000 ANR: Paulding/Cecil 30,000 (F1, A2) LEBANON AGGREGATE 100,000 (A4, F2, C4, D3) TOLEDO AGGREGATE 100,000 (A3, F4, 734462) COLUMBIA GULF: (801) TCO-Leach 700,000 Internal point non-firm capacity will be as follows: Lanham 0 Delivery capacity (non-firm) will be as follows: TRANSCO: Martins Creek 10,000 (MLI E5) Young Woman's Creek 10,000 (MLI E9) ALGONQUIN: Hanover 0 (MLI R2) EQUITRANS: Fallen Timber 31,000 (MLI K1) Waynesburg-Rhinehart 20,000 (MLI K2) OPT-30 will be available in all market areas.
OPT-60 will be available in all market areas.
Market Area delivery capacity (non-firm) will be as follows: Operating Area 1 Market Area 33 30,000 Market Area 34 20,000 Operating Area 2 Market Area 20 No Restrictions Operating Area 3 Market Area 15 No Restrictions Market Area 16 No Restrictions Market Area 17 No Restrictions Market Area 18 No Restrictions Market Area 19 No Restrictions Operating Area 4 Market Area 21 10,000 Market Area 22 10,000 Market Area 23 20,000 Market Area 24 10,000 Market Area 25 No Restrictions Market Area 29 No Restrictions Operating Area 5 Market Area 02 No Restrictions Market Area 07 No Restrictions Operating Area 6 Market Area 10 No Restrictions Market Area 11 No Restrictions Market Area 12 No Restrictions Market Area 13 No Restrictions Market Area 14 No Restrictions Operating Area 7 Market Area 01 No Restrictions Market Area 03 No Restrictions Market Area 04 No Restrictions Market Area 05 No Restrictions Market Area 06 No Restrictions Market Area 08 No Restrictions Market Area 09 No Restrictions Operating Area 8 Market Area 26 No Restrictions Market Area 27 No Restrictions Market Area 32 No Restrictions Market Area 35 No Restrictions Market Area 36 No restrictions for southern part of Market Area 36.
Primary receipts/deliveries only for gas delivered in the northern portion of Market Area 36.
Market Area 38 No Restrictions Market Area 39 No Restrictions Market Area 40 No Restrictions NOTE: GAS DELIVERED IN THE NORTHERN PORTION OF MARKET AREA 38 OR THE NORTHERN PORTION OF MARKET AREA 36 MUST BE RECEIVED FROM TENNESSEE GAS PIPELINE AT HIGHLAND.
Operating Area 10 Market Area 28 No Restrictions Market Area 30 No Restrictions Market Area 31 No Restrictions If you have any questions, please contact your Account Representative.
| REVISED TCO - CAPACITY UPDATE EFF FOR NOVEMBER 26, 2001 |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES NOVEMBER 26, 2001 Notice ID: 3291 5 - NO RESPONSE REQUIRED SUBJECT: TCO CAPACITY UPDATE EFFECTIVE FOR TUESDAY, NOVEMBER 27, 2001 CHANGES ARE INDICATED WITH AN * Effective Tuesday, November 27, 2001, capacities will be as follows: Excess MDWQ Available + ISS Withdrawals Available SIT Withdrawals Available Imbalance Drawdowns Available Excess MDIQ NOT Available + ISS Injections NOT Available SIT Injections NOT Available Imbalance Paybacks NOT Available PAL Lends/Unparks Available PAL Parks/Loan Paybacks NOT Available + Call Gas Control 24 hours in advance at (304) 357-2606 to request approval.
Non-firm receipt capacity will be as follows: TENNESSEE: Brinker (B12) 20,000 Broad Run (B9) 450,000 Cambridge (B10) 0 Dungannon (B11) 20,000 Highland (B17) 0 Milford (B18) 20,000 North Greenwood (B22) 0 Unionville (B15) 50,000 TEXAS EASTERN: Delmont (C16) 10,000 Eagle (C22) 20,000 Hooker (C9) 20,000 Pennsburg (C23) 20,000 Windridge (C12) 20,000 NATIONAL FUEL: Independence (M1) 0 Ellwood City (L1) 15,000 TRANSCO: Downingtown (E3) 2,500 Emporia I (E13) 60,000 Rockville (E2) 60,000 Dranesville (E1) 50,000 CNR PIPELINE: Wiser (827280) 0 DELTA: Delta Natural Gas (819288) 0 ALGONQUIN: Ramapo (R1) 25,000 ANR: Paulding/Cecil 30,000 (F1, A2) LEBANON AGGREGATE 100,000 (A4, F2, C4, D3) TOLEDO AGGREGATE 100,000 (A3, F4, 734462) COLUMBIA GULF: (801) TCO-Leach 700,000 Internal point non-firm capacity will be as follows: Lanham 0 Delivery capacity (non-firm) will be as follows: TRANSCO: Martins Creek 10,000 (MLI E5) Young Woman's Creek 10,000 (MLI E9) ALGONQUIN: Hanover 0 (MLI R2) EQUITRANS: Fallen Timber 31,000 (MLI K1) Waynesburg-Rhinehart 20,000 (MLI K2) OPT-30 will be available in all market areas.
OPT-60 will be available in all market areas.
Market Area delivery capacity (non-firm) will be as follows: Operating Area 1 Market Area 33 No Restrictions * Market Area 34 No Restrictions * Operating Area 2 Market Area 20 No Restrictions Operating Area 3 Market Area 15 No Restrictions Market Area 16 No Restrictions Market Area 17 No Restrictions Market Area 18 No Restrictions Market Area 19 No Restrictions Operating Area 4 Market Area 21 No Restrictions * Market Area 22 No Restrictions * Market Area 23 No Restrictions * Market Area 24 No Restrictions * Market Area 25 No Restrictions Market Area 29 No Restrictions Operating Area 5 Market Area 02 No Restrictions Market Area 07 No Restrictions Operating Area 6 Market Area 10 No Restrictions Market Area 11 No Restrictions Market Area 12 No Restrictions Market Area 13 No Restrictions Market Area 14 No Restrictions Operating Area 7 Market Area 01 No Restrictions Market Area 03 No Restrictions Market Area 04 No Restrictions Market Area 05 No Restrictions Market Area 06 No Restrictions Market Area 08 No Restrictions Market Area 09 No Restrictions Operating Area 8 Market Area 26 No Restrictions Market Area 27 No Restrictions Market Area 32 No Restrictions Market Area 35 No Restrictions Market Area 36 No restrictions for southern part of Market Area 36.
Primary receipts/deliveries only for gas delivered in the northern portion of Market Area 36.
Market Area 38 No Restrictions Market Area 39 No Restrictions Market Area 40 No Restrictions NOTE: GAS DELIVERED IN THE NORTHERN PORTION OF MARKET AREA 38 OR THE NORTHERN PORTION OF MARKET AREA 36 MUST BE RECEIVED FROM TENNESSEE GAS PIPELINE AT HIGHLAND.
Operating Area 10 Market Area 28 No Restrictions Market Area 30 No Restrictions Market Area 31 No Restrictions If you have any questions, please contact your Account Representative.
| TCO - CAPACITY UPDATE EFF FOR NOVEMBER 27, 2001 |
The attached list shows all counterparties who are signed up to execute on EOL but are not.
This list contains counterparties designated to trade in all the different commodities, not just gas.
You can cross reference this list with the one I previouly sent.
The list ranks the companies by those who trade the most with Enron (non-EOL trades) to the least.
It also shows the date they received their execute status from EOL, which can help determine the companies you plan to use a cut-off stategy with.
This list is a few months old so some of these counterparties may now be trading on EOL, but not many.
Any questions, give me a call.
33310.
| Execute list |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES NOVEMBER 26, 2001 Notice ID: 3293 5 - NO RESPONSE REQUIRED SUBJECT: CAPACITY ALLOCATION-TIMELY NOMINATION CYCLE FOR NOVEMBER 27, 2001 PLEASE NOTE THAT ALL ALLOCATIONS ARE SUBJECT TO CHANGE BASED ON THE RECEIPT OF ANY NEW NOMINATIONS OR INTRADAY NOMINATIONS.
RECEIPTS: KA-1 LINE (819288 AND 827280): There is no capacity for IPP customers.
There is no capacity for ITS customers.
There is no capacity for secondary firm customers.
INTERNAL CONSTRAINT: LANHAM: There is no capacity for IPP customers.
There is no capacity for ITS customers.
There is no capacity for secondary firm customers.
Excess MDWQ Available + ISS Withdrawals Available SIT Withdrawals Available Imbalance Drawdowns Available Excess MDIQ NOT Available + ISS Injections NOT Available SIT Injections NOT Available Imbalance Paybacks NOT Available PAL Lends/Unparks Available PAL Parks/Loan Paybacks NOT Available + Call Gas Control 24 hours in advance at (304) 357-2606 to request approval.
Columbia Gas Transmission has completed allocating all of its receipt and delivery points for the gas day of November 27, 2001.
You may now view the quantities you are authorized to flow on November 27, 2001.
On the Internet NAVIGATOR, view Nominations, Scheduled Quantity, Scheduled Quantity for Service Requestor-Summary, Nominations to be Viewed, and select Reduced Nominations.
The quantities confirmed to flow for your account are available on the Internet NAVIGATOR after 5:30 p.m. Eastern Time on Monday, November 26, 2001.
If you have any questions, please contact your Account Representative.
| TCO- CAPACITY ALLOC-TIMELY NOMINATION CYCLE NOV. 27, 2001 |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES NOVEMBER 26, 2001 Notice ID: 3294 5 - NO RESPONSE REQUIRED Please be aware that the Navigator Nomination Program will be updated the morning of Tuesday, November 27, 2001 to reflect the new December 1, 2001 Columbia Gas Transmission transportation retainage rates.
Nominations that have already been input into Navigator for December will be revised to reflect the new rates based on the existing delivered quantity.
After this change is implemented, customers should verify that December nominations are correct.
If you have any questions, please contact your Customer Services Representative.
| TCO - DECEMBER NOMINATIONS |
For 11/25: Cypress cut of 2154 .0721= $155.30 Dom.
Retail cut of 2750 $198.28 Tiger cut of 175 $12.62 VPEM cut of 875 $63.09 $429.29 For 11/26: Cypress cut of 1732 .0721= $124.88 +$155.30 Dom.
Retail cut of 2750 $198.28 +$198.28 Tiger cut of 175 $12.62 +$12.62 VPEM cut of 875 $63.09 + $63.09 $398.87 + $429.29 = $828.16 For 11/27: Cypress Park 3886 .0721= $280.18 Dom.
Retail 5500 $396.55 Tiger 350 $25.24 VPEM 1750 $126.18 $828.15 Joann
| CUT VOLUMES @ VNG CITYGATE |
This is the US Gas customer list.
Customers are divided up by their EOL status.
TRAD means they are trading on EOL, EXEC means they are signed up and can trade on EOL, and PROS means they have not signed up for EOL.
If anyone has any questions, please call me at 33310.
| US Gas Report |
Critical Migration Information: 1.
Your scheduled Outlook Migration Date is THE EVENING OF : May 17th 2.
You need to press the "Save My Data" button (only once) to send us your pre-migration information.
3.
You must be connected to the network before you press the button.
4.
If a POP-UP BOX appears, prompting you to "ABORT, CANCEL OR TRUST SIGNER" please select TRUST SIGNER.
5.
Any information you Add to your Personal Address Book, Journal or calendar after you click on the button will need to be manually re-added into Outlook after you have been migrated.
6.
Clicking this button does not complete your migration to Outlook.
Your migration will be completed the evening of your migration date.
Failure to click on the button means you WILL NOT get your Calendar, Contacts, Journal and ToDo information imported into Outlook the day of your migration and could result in up to a 2 week delay to restore this information.
If you encounter any errors please contact the resolution center @ 713-853-1411
| 3 - URGENT - TO PREVENT LOSS OF INFORMATION |
Current Notes User: To ensure that you experience a successful migration from Notes to Outlook, it is necessary to gather individual user information prior to your date of migration.
Please take a few minutes to completely fill out the following survey.
Double Click on document to put it in "Edit" mode.
When you finish, simply click on the 'Reply With History' button then hit 'Send' Your survey will automatically be sent to the Outlook 2000 Migration Mailbox.
Thank you.
| 2- SURVEY/INFORMATION EMAIL 5-17-01 |
OUTLOOK EMAIL NOTIFICATION Your Date of Migration is: May 17th YOU WILL BE UNABLE TO SEND E-MAIL unless you take the following action: Please go through your Notes email and clean out as many old/un-needed email items as possible BEFORE your date of migration.
After you are migrated to Outlook you will only be allocated 100MB of total Mailbox space.
If more than this amount of data is migrated to Outlook YOU WILL NOT BE ABLE TO SEND E-MAIL until it is below the 100MB limit.
Cleaning up your Notes email now will prevent this from happening to YOU.
Enron's messaging platform is migrating from Lotus Notes to Microsoft Outlook 2000 worldwide.
You will be accessing Outlook for all of your email functions.
WHY IS ENRON MIGRATING TO OUTLOOK 2000?
Many factors contributed to the decision to migrate from Lotus Notes to Microsoft Exchange/Outlook.
The most prominent factors were: ?
Significant advantages to moving to a product that is more integrated with current Enron apps (Windows 2000, Office and Internet Explorer) ?
More efficient Shared PC and Roaming User features ?
Improved support and integration for Palm/CE devices ?
Instant Messaging capabilities WHAT IS BEING MIGRATED TO OUTLOOK 2000?
?
Email Messages.
From the date of your scheduled migration, the last (30) thirty days of your Email will be converted for use in Outlook.
?
All your folders in Notes you use to store email messages in.
?
To Do Items ?
Journal Items ?
Calendar Entries dating from (1) one year in the past to (10) ten years in the future will be converted.
?
Address Books, but NOT your Distribution Lists that you created.
You will need to re-create these in Outlook.
Thank you,
| 1-URGENT - Outlook Email Notification (new) |
The Homestead precedent agreements are going out this week.
They should be self explanatory but please call your account manager or me with any questions or if you need clarifications.
Thanks again for your interest in our project.
Mike
| Homestead Expansion - Update |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES NOVEMBER 27, 2001 Notice ID: 3286 5 - NO RESPONSE REQUIRED SUBJECT: TCO - DECEMBER 1, 2001 RETAINAGE RATE (FUEL AND UNACCOUNTED FOR VOLUMES) Columbia Gas Transmission has filed for a reduction in the following retainage rate (fuel and unaccounted for volumes) effective December 1, 2001.
Transportation Retainage Rate 2.447% Although FERC has not taken any action on the filing, we anticipate receiving approval.
Please make the appropriate adjustments to your December 1, 2001 nominations.
If you have any questions, please contact your Account Representative.
| TCO - 12/01/01 RETAINAGE RATE (FUEL & UNACCOUNTED FOR VOLS) |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES NOVEMBER 27, 2001 Notice ID: 3296 5 - NO RESPONSE REQUIRED SUBJECT: AUCTION OF FTS, SST, AND FSS CAPACITY Columbia Gas Transmission has posted the following offers of FTS, SST, and FSS capacity.
Additional details of this capacity may be found in the Columbia Internet NAVIGATOR system under the Capacity Release Folder, Offers, Offers Summary, Offer Type, Capacity Auctions, under the following offer numbers: Offer Rate Receipt No.
Schedule Point Delivery Point 34284 FTS Leach Market Area 8 34285 FTS Delmont Agg.
Market Area 36 34286 SST Stow Market Areas 1, 8, 9 34287 FSS 34282 SST Stow Market Areas 1, 3, 5, 8, 9, 15 34283 FSS 34288 SST Stow Market Areas 1, 7 34289 FSS 34290 SST Stow Market Area 26 34291 FSS 34280 FTS McClellandtown Agg.
Market Area 26 34278 FTS Delmont Agg.
Market Area 36 34279 FTS Delmont Market Area 27 34316 SST Stow Market Areas 2, 4, 6 34317 FSS 34318 SST Stow Market Area 1 34319 FSS 34320 SST Stow Market Areas 1, 35 34321 FSS 34299 FTS Leach Market Area 5 34300 FTS Lebanon Market Area 6 34301 FTS Lebanon Market Area 6 34302 FTS Leach Market Area 8 34303 FTS Leach Market Area 8 34304 FTS Leach Market Area 9 34305 FTS Leach Market Area 10 34306 FTS Leach Market Area 10 34307 FTS Leach Market Area 12 34308 FTS Leach Market Area 15 34309 FTS Leach Market Area 19 34310 FTS Alexander Agg.
Market Area 32 34311 FTS Highland Market Area 38 34312 FTS Crossroads Market Area 1 34313 FTS Dungannon Market Area 4 For additional information, please contact your Account Representative or your Customer Services Team.
| TCO - AUCTION OF FTS, SST, AND FSS CAPACITY |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES NOVEMBER 27, 2001 Notice ID: 3073 5 - NO RESPONSE REQUIRED SUBJECT: SECONDARY POINT PRIORITY ALLOCATION Following is the current secondary point priority allocation methodology.
Please contact your Customer Services Represesentative or Account Manager with any questions.
Operating Area 1 Market Area 33 - Market Areas 17, 19, 30, 31 Market Area 34 - Market Areas 17, 19, 30, 31, 33 Operating Area 2 Market Area 20 - Market Areas 19, 23, 25, 26, 35 Operating Area 3 Market Areas 15, 16, 17, 18, 19 - None Operating Area 4 Market Area 21 - Market Areas 19, 23, 25, 26, 28, 29, 30, 31, 35 Market Area 22 - Market Areas 19, 23, 25, 26, 28, 29, 30, 31, 35 Market Area 23 - Market Areas 19, 25, 26, 28, 29, 30, 31, 35 Market Area 24 - Market Areas 17, 19, 28, 29, 30, 31 Market Area 25 - Market Areas 19, 26, 35 Market Area 29 - Market Areas 17, 19, 28, 30, 31 Operating Area 5 Market Area 2 - Market Areas 7, 8 Market Area 7 - Market Area 8 Operating Area 6 Market Areas 10, 11, 12, 13, 14 - None Operating Area 7 Market Areas 1, 3, 4, 5, 6, 8, 9 - None Operating Area 8 Market Area 26 - Market Areas 19, 35 Market Area 27 - Market Areas 19, 26, 35 Market Area 32 - Market Area 19 Market Area 35 - Market Area 19 Market Areas 36, 38, 39 - Market Area 35 Market Area 40 - None Operating Area 10 Market Area 28 - Market Areas 17, 19, 30, 31 Market Area 30 - Market Areas 17, 19, 31 Market Area 31 - Market Areas 17, 19 The points available on a secondary priority basis are subject to change due to system operations or flexibility considerations.
| SECONDARY POINT PRIORITY ALLOCATION |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES NOVEMBER 27, 2001 Notice ID: 3298 5 - NO RESPONSE REQUIRED SUBJECT: CAPACITY ALLOCATION-TIMELY NOMINATION CYCLE FOR NOVEMBER 28, 2001 PLEASE NOTE THAT ALL ALLOCATIONS ARE SUBJECT TO CHANGE BASED ON THE RECEIPT OF ANY NEW NOMINATIONS OR INTRADAY NOMINATIONS.
RECEIPTS: KA-1 LINE (819288 AND 827280): There is no capacity for IPP customers.
There is no capacity for ITS customers.
There is no capacity for secondary firm customers.
INTERNAL CONSTRAINT: LANHAM: There is no capacity for IPP customers.
There is no capacity for ITS customers.
There is no capacity for secondary firm customers.
Excess MDWQ Available + ISS Withdrawals Available SIT Withdrawals Available Imbalance Drawdowns Available Excess MDIQ NOT Available + ISS Injections NOT Available SIT Injections NOT Available Imbalance Paybacks NOT Available PAL Lends/Unparks Available PAL Parks/Loan Paybacks NOT Available + Call Gas Control 24 hours in advance at (304) 357-2606 to request approval.
Columbia Gas Transmission has completed allocating all of its receipt and delivery points for the gas day of November 28, 2001.
You may now view the quantities you are authorized to flow on November 28, 2001.
On the Internet NAVIGATOR, view Nominations, Scheduled Quantity, Scheduled Quantity for Service Requestor-Summary, Nominations to be Viewed, and select Reduced Nominations.
The quantities confirmed to flow for your account are available on the Internet NAVIGATOR after 5:30 p.m. Eastern Time on Tuesday, November 27, 2001.
If you have any questions, please contact your Account Representative.
| TCO- CAPACITY ALLOC-TIMELY NOMINATION CYCLE NOV. 28, 2001 |
Currently, we are unable to use IT to serve Ogy at Doyle on Transco.
I have devised a super scientific method for pricing VNG space for Ogy.
Poke all the holes in it you want.
Use the following formulas to determine the price to Ogy The higher of St 65 Offer plus $.35 TCO Offer plus $.14 Good Luck
| OGY using VNG capacity |
John, Scana Energy Marketing bought an additional 823 dt per day from Enron North America at $4.765.
The term is from May 2, 2001 through May 31, 2001.
The delivery point is TCo Pool.
Thanks.
| Additional Gas Purchases for May 2001 |
John, I met with Con-Ed last week.
They asked if Market Link @ Leidy was going to be good liquid point to buy long term supply.
I told them that I didn't think so but would do a little research for them.
I know you worked pretty hard on this one.
Do you have an overview/summary that I could look at including some rough economics.
| MarketLink |
We will be releasing new version of the Stack Manager and the EnronOnline website tonight .
The following are the changes 1.
Changes to Stack Manager: 1.1 Changes to toolbar icons: To facilitate further development of the system, it has been found necessary to change the toolbar icons at the top of the Stack Manager.
The attached file shows the old icon and its new replacement.
Next to each image below is the description of the function that is executed as well as the short cut key that is mapped to the same function: 1.2 New Functionality - Auto Suspend The Auto Suspend function allows traders to set an absolute price change from a price level at which you would like the system to automatically suspend a specific product.
This function is useful if your products use automatic price resets.
To activate this feature: 1.
Select a product and click on Product Properties 2.
Check the Enable box 3.
Enter the Price Check and Suspend at +/- values 4.
Click Update Example: a trader Enables Auto Suspend and selects a $35.00 Price Check and a suspension level of +/- $5.00: The system will suspend the product when the mid price is above $40.00 or below $30.00 You will need to enter a new Price Check or disable the Auto Suspend function to reactivate this Product if the Auto Suspend is triggered.
Please note the system checks for any products that need to be suspended once a minute.
2.
Changes to EnronOnline Website (These changes will be rolled out in phases over the next week and will be available to all customers only by Friday 5/4/01) The following enhancements have been made to the EnronOnline Website: 2.1 Today's Transactions Float Window: In order to float the window, right click on the Today's Transactions section, click on the Float Window option.
Sort Ordering: Click on the column heading to change the sort order.
Linked Transactions: You can display the linked Transactions in an expanded or collapsed view.
To do so, right click in the Transaction display area and select full Expand or Full Collapse.
2.2 Submission Box The submission box has been modified in order to show a space between each set of "zeros" for the volume the customer wants to sell/buy.
Savita
| VERY IMPORTANT ENRONONLINE STACK MANAGER CHANGES |
John, To confirm our deal in writing, Scana Energy Marketing bought 2,047 dt per day at $5.33 for the month of May 2001.
The delivery point is CNG Southpoint (or Dominion Southpoint).
A formal agreement will be mailed in the next few days.
Thanks.
| Gas Purchases for May 2001! |
The memo attached summarizes a structured deal that the market has shown some interest.
Essentially, this deal allows an LDC to defer payment for gas and avoid carrying costs (which may result in a dollar for dollar benefit to your customer's bottom line).
We have done two of these deals to date.
ENA has interest in additional deals (albeit not an infinite appetite) if the structure allows us to move them off the balance sheet.
Please review the memo and target any of your customers that may have an interest.
Each deal will require a new quote from credit and from the cost of funds group.
Gas structuring is set up to structure these deals and develop them through to execution.
Please call me with any questions at x36751
| Structure for Storage Loans / Deferred Payment Deals |
Ruth, I have confirmed the meeting with Williams to discuss the Athens and Hart Co. projects for 3:00 on Wednesday.
Location TBA.
We will meet with Allen Smith and Orlando (Alvarez?).
Regarding the Midway project in St. Lucie County (and other sites as well) we need to get a rough estimate on the estimated schedule for completion.
In particular, we need to know whether it is possible to get gas to the Midway site by May 2002.
Is there any way we can talk to someone today about this?
Thanks.
| Georgia and Florida Projects |
Judy: You can use my office on Saturday, December 9 from 9:00 AM to Noon.
My office is EB3878a and the extension is 3-6911.
Jeff Hodge
| Super Saturday - Associate/Analyst Program |
Ruth: In follow-up to our telephone conversation, I am confirming that it is my analysis of the purchase agreement between CES and ENA that ENA must refund to CES any transportation refunds it gets relating to the CES transportation contracts that relate to activity prior to January 1, 2000.
Likewise, if there are costs relating to such contracts prior to January 1, 2000, those are the responsibility of CES.
I hope this helps to clarify the situation.
Jeff
| Columbia Energy Services Corporation |
I thought it might be a some help if I distributed a red-lined version of this document prior to tomorrow's meeting.
I hope you find this of some use.
Jeff
| Producer Services Agreement |
Below is the information for opening the utility accounts in your name.
The phone and cable will be disconnected on Nov. 5, and the water, gas and electricity will be disconnected on Nov. 6.
(If you make the calls prior to these dates and give them the Nov. 6th date, then the water, gas and electricity will not actually be turned off in the house.)
| 3527 Yupon misc. |
AOPA ePilot Subscribers, Please disregard the message at the top of this morning's issue f "AOPA ePilot" that suggested that your AOPA membership was bout to expire or that it was your last issue of the newsletter.
oliday computer gremlins conspired to erroneously send the essage to most "ePilot" subscribers this morning.
Again, please disregard the message.
We apologize for the error nd will work to assure that it does not happen again.
Thank you or your patience and please have a happy new year.
Sincerely,
| AOPA ePilot Correction |
AOPA ePilot Subscribers, Let's try this one more time.
Our last correction message came through with some letters missing.
Here (we sure hope) is a version that you can read: Please disregard the message at the top of this morning's issue of "AOPA ePilot" that suggested that your AOPA membership was about to expire or that it was your last issue of the newsletter.
Holiday computer gremlins conspired to erroneously send the message to most "ePilot" subscribers this morning.
Again, please disregard the message.
We apologize for the error and will work to assure that it does not happen again.
Thank you for your patience and please have a Happy New Year.
Sincerely,
| AOPA ePilot Correction |
Keith: I had sent to you on August 14, an email regarding the extension of your L1A visa.
Please let me know if you wish to renew this before it expires on February 11, 2002?
If so, I will need you to complete the visa questionnaire form I sent to you and return to me with the required documents.
Please advise soonest.
Thanks
| L1A Visa Extension - Keith Holst |
Attached is a summary of my notes at the Socal meeting regarding revised window procedures.
No hand-outs were provided.
Calculation of Receipt Point Capacity Topock 540 mmcf/d Ehrenberg 1250 mmcf/d Needles 800 mmcf/d Wheeler 800 mmcf/d New Receipt Points Kramer Junction 200 mmcf/d Hector Rd 50 mmcf/d Both will be available around Feb 1 Basis of Pro-Ration-Current Windows Calculation Currently, Gas Control provides total receipt point capacity comprised of demand forecast and injection capability and compares to maximum amount of gas that can enter system.
Gas Select prorates interstate's receipt capacity based on prior day's nominations.
New Calculation, Changes and Display Based on operational maximum with adjustments for maintenance.
SoCal ist aking and applying the current formula for Wheeler Ridge to all the points.
Any changes to operational maximum will probably be due to maintenance and posted on Gas Select.
Customer will choose which points it wants to reduce receipts.
Operating maximums will equal demand forecast plus injections.
Demand forecast will rely on Gas Control weather forecast.
They use Weather Bank as one of their tools.
OFO Declaration Name changes from overnomination Can declare before any Cycle Provide 2 hour notice Post on Gas Select Show OFO Calculation on Gas Select Windows Reason to set windows was to set limits to prevent too much gas from coming into system Calculation based on noms which does not work well.
Lots of complaints.
People were complaining that it restricted access to the system.
Eliminating point specific calculation.
Open system to Max Oper.
Limits or Contractual Limits.
Will continue to operate Wheeler Ridge under Aug 1 procedures.
No changes to Wheeler Ridge.
Due to the need to maintain operational control, an OFO will be declared when scheduled volumes are greater than the max operating capacity on any cycle.
Replace windows with operational maximum volumes.
If CPUC approves comprehensive settlement, will post 5 days of information to anticipate OFO's Now customers will elect which point they will back off instead of using windows.
Scheduling Changes-Nov 1 Gas Select is being rebuilt and will be an internet system in mid-2002 .
No direct dial-up.
Rollover noms-noms will be copied from cycle to cycle Copy confirmed noms All noms will be rolled over-will not be at discretion of 3rd party.
However, can still make changes.
Can still upload new files.
2 Hour Notice Socal will provide 2 hour notice on Gas Select of OFO.
Other methods include leaving message on Socal Hotline (213-244-3900) and list of e-mail messages that can go directly to pagers.
Gas Select is official notification.
Courtesy notification is hot line and e mail.
Gas Select is a subscriber- based system mandated by CPUC and must get regulatory change to make free.
OFO's are going to be system wide and not customer specific.
OFO's can be declared intraday.
Once OFO declared, it will be kept for entire day.
Concerned that if call off, will have to put back on.
Don't want to go back and forth.
This decision may be reconsidered once they see how it works.
Many times Socal see an increase of 200 mmcf/day between Cycle 3 and 4 so they are concerned.
Scheduled vs. Capacity-Declare OFO Nominations may not exceed 110% of expected usage.
Expected Usage is defined as usage for the same day for the prior week.
Can revise expected usage.
No interruptible storage injections allowed during OFO.
Use Elapsed Pro-Rata Rules Expected Usage-cut nominations to 110% of expected usage so will use same day of the prior week as proxy.
Generators need to revise expected usage.
Acceptance of changes are at the discretion of SoCal.
Flow Day Diversions don't go into effect until after Cycle 4.
Gas Control will determine if flow day diversion will be allowed.
If call OFO after cycle 3 or 4 and have interruptible storage injections, such storage will be prorationed back under the elapsed prorata rules.
Many people were concerned that interruptible storage will be severely compromised.
If OFO called , Interruptible Storage could be cut under the elapsed prorata rules as follows: Cycle 1 Nom 1000 ; 0 cut Cycle 2 Nom 1000; 666 cut Cylce 3 Nom 1000; 500 cut Windows will only be implemented during cycle 4 if OFO callled after cycle 3 and no improvement is realized.
Will allocate prorata.
Will use latest scheduled volume and will pro rate by receipt point.
In other words, if OFO declared during Cycle 1 and no relief after 3 cycles, Socal will window Cycle 4 and prorata cut.
Parties will determine what gets cut on all the other cycles.
For penalty purposes, actual burn from 12 o'clock to 12 o'clock will be used to calculate penalties or MAXDQ if not metered.
For OFO, assume supply delivereis day before and burn is the same day for the prior week.
Declare OFO on prior day's scheduled volume.
For an evening declaration-will use most recent available scheduled volumes.
For example: Flow Day 10/4 10/3 Scheduled Volumes Cycle 1 Cycle 2 Cycle 2 Intraday 1 Cycle 3 evening cyle 2 on 10/4 Cycle 4 Intraday 1 on 10/4 In other words, will look at evening cycle 2 scheduled volumes on the 3rd for declaring OFO on cycle 1 for the 4th.
; look at intra day 1 for the 3rd in declaring OFO for cycle 2 on the 4th; look at evening cycle 2 on 10/4 in declaraing OFO for Cycle 3 on the 4th; look at intraday 1 on the 4th in declaraing OFO on cycle 4 for the 4th.
Winter Balancing Rules Effective Nov 1-March 31 No changes.
All customers must comply.
Minimum delivery requirements 50% of daily usage over 5 day period; (Nov 1-5;6-10;) 70% of daily usage depending on storage level 70% daily usage implemented when storage levels equal 20 bcf above peak day min 90% of daily usage depending on storage level 90% rule implemented when storage levels equal 5 bcf plus peak day min.
Look at storage graph on Gas Select.
Posted 24 hours in advance if the minimum daily is changed.
If go to 70% , current 5 day cycle must end completely, before new % goes into effect.
Must increase storage inventory by 1 bcf above the 70% before going back to 50% rule.
Once 90% rule implemented, will return to 70% as soon as operationally feasible, Contracted Marketer's customer usage and delivereies are aggregated in one balancing account.
Core Aggregation-subject to 50% daily throughout entire winter period based on DCQ.
Core-50% of daily throughput for the enitre period,; (Patrick Brown group) Not subject to 70% and 90% rules.
2 types of gas count toward daily obligation- firm storage withdrawal and flowing gas.
As-available storage and imbalance trading do not count.
Burn=measured daily usage thru electronic measurement, Min DQ-used if customer does not have electronic measurement.
Customer assessed GIMB charge if total deliveries is less than 50% of total burn over 5 day period.
Customer purchases gas at daily balancing stand-by rate under G IMB Rate Schedule which is 150% of highest Socal Border price per NGI Gas Daily plus franchise fees and other charges.
Rate is posted at end of every month.
OFO can be declared during undernom season (winter season)
| Socal Window Meeting |
Below is the information for opening the utility accounts in your name.
The phone and cable will be disconnected on Nov. 5, and the water, gas and electricity will be disconnected on Nov. 6.
(If you make the calls prior to these dates and give them the Nov. 6th date, then the water, gas and electricity will not actually be turned off in the house.)
| 3527 Yupon misc. |
Hi Keith, Please continue with the supplements.
We will have to have your mom pick them up and mail them to you.
Give her a call and I will get them ready.
Thanks,
| Dr. Schnieder |
Dear Keith, It was a pleasure to meet you and your colleagues in gas / power trading last week.
I was very impressed by the quality of people that I met during my visit and remain interested in working for your organization.
Please find attached that report that I prepared for BC Gas on Weather Derivatives.
Unfortunately, I do not have the spreadsheets and the graphs on my hard drive.
Enjoy your vacation in November (hopefully you'll be able to select a less rainy location that Vancouver).
I hope to hear from your team soon.
Sincerely,
| Thank you note from Vancouver |
Keith, I changed the report information as you requested.
Please let me know if there are additional changes you need.
On some of the storage points the current balance information is not available.
I will work towards getting these, in the meantime let me know what else would be needed.
ES
| Storage Sample |
Smarter Living Deal Alert!
Tuesday, November 20, 2001 Happy Thanksgiving from Smarter Living!
This special edition of Deal Alert!
contains information about last-minute holiday airfares and car rentals, plus European getaways for winter travel.
Headed to the airport this week?
Read on for our top tips on how to pack and what to expect when you get there.
Have an enjoyable and safe holiday!
************************ Sponsor *************************** GET EVEN BETTER TRAVEL DEALS WITH HOTWIRE HOT-FARES!
(sm) Use your flexibility to save even more on airfare, hotels and car rentals.
Hotwire works with quality travel companies to negotiate special Hot-Fares(sm) -- deals you can?t find anywhere
| Smarter Living Deal Alert! |
We will hold off transferring any physical positions desk to desk until the end of bidweek.
After NX1, we will transfer positions at a daily EOL Index mid price.
Please monitor my book and others to make certain DEC deals are not being transferred prior to NX1 at an IF monthly or GD daily mid price.
Thanks,
| DEC physical |
Hi Keith, Just thought I would see if you are still with Enron, and lo and behold!
there is your name.
I hope that all is going well for you.
I haven't looked closely, but I assume that you are still in Houston.
Do you like it?
All is well with me.
I'm living in Oxford, England, and am now working part time with a little company called Enron Direct.
The part time comes because I have a beautiful little 2 year old daughter, and she keeps me very busy.
Write back if you get a chance.
Crystal ps what is (little) Jon's last name?
Does he still work for Enron in Houston also?
Crystal And I don't mean Lavorato!
| Hi! |
The monthly "New Generation in WSCC" report for October is complete.
The method of distribution for this report has changed and the reports will no longer be distributed electronically.
To receive a hard copy of the report, please send me your name, location, and the name of your administrative assistant (If you have not already done so).
As always, please report any errors / inaccuracies to me as soon as possible.
Thanks,
| October New Gen Report |
Hey there!
I went to jeep at lunch.
The guy is giving me a good price on the car.
However, he is trying to screw me on the price of my car.
He is telling me that the price of the car purchased from the dealership is as follows... Manuf price $23,668 +sun roof- $704.00 +destination charge $600.00 + a few addl charges$364.00 Total price $25,336 That is pretty consistent with what I show for the price.
Possibly taking off a few of those fees but that is pretty minimal...
I am thinking that I should sell my car myself... What do you think.
Please see the attached file.
This is how the guy is trying to screw me.
| jeep |
NGI's Daily Gas Price Index published : September 26, 2001 Kern River Shippers to See Rate Decrease Oct. 1, More in 2002 Finally, some good news: a unit of Williams said Tuesday that firm transportation rates will drop by as much as 36.5% for all original shippers on its Kern River natural gas transmission system beginning Monday (Oct. 1).
The lower rates will be implemented under Kern River's previously approved extended-term rate program.
Williams, which developed a strategy to lower rates in response to customer requests as part of its rate-reduction settlement in 1999, projects more rate reductions next May, when the costs and revenues of the 2002 expansion are reflected in rates.
"The extended-term rate program was designed to provide long-term, firm shippers with an option to pay lower, more market-responsive rates today in return for extending their contract terms," said Kirk Morgan, director of business development.
Bruce Warner, manager of rates and planning for Tulsa-based Williams, said the company had looked at its "financial situation and found that if customers could live with longer contracts, we could live with lower rates.
The lower rates will be offset by lower depreciation expenses and will not negatively impact Kern River's financial performance."
Williams' gas pipeline unit is one of the largest-volume transporters of natural gas in the United States.
Its gas pipeline unit's Kern River Gas Transmission, based in Salt Lake City, operates a 922-mile system delivering Rocky Mountain and Canadian natural gas to markets in California, Nevada and Utah.
| NGI Article: Kern River Shippers to See Rate Decrease Oct. 1, More in 2002 |
Hi, Tripmakers is a discount travel agency in Los Angeles.
We offer "Last Minute Discount " on domestic and international travel.
We can save you up to 50 % on most reservations.
We offer you from LAX TO SYD for 1590 $ plus tax on MALAYSIA AIR .
This fare for is weekday travel.
The airlines charge $ 20 each way for weekends.
This is a quote subject to availability of flight.
Please contact us for flight availability at 1 - 800 335 9268 or e-mail to tripmaker@earthlink.net Thanking You
| FARE |
Ho, ho, ho, how about sending me your mailing address so I can send you our Christmas letter by snail mail next year (the PROPER way to do it, according to Carla).
Until then, please see the attached .doc or .pdf file for our annual Christmas letter.
Happy holidays, and best wishes!
Alan
| Merry Christmas from Alan & Carla |
Dear Keith, What's more romantic than travel?
Valentine's day is coming and that means it's time to start planning a getaway with your sweetie.
Travelocity has a ton of great deals to help make your travel fantasy a reality.
Save with unprecedented low fares like Caribbean Cruises for $279, New York luxury hotels for $130 per night, and Vegas weekends for as little as $33!
So go ahead--book that escape now.
And still have enough left
| Real Deals From Travelocity.com |
This NetClub offer includes: 1) Lucky Fares 51 / including Amtrak Connections* 2) The Holiday Gift Offer (just one more day to book!)
3) Icelandair Holidays 4) Icelandair Reservations - Business Class Special (Philadelphia to Europe w/Amtrak - Icelandair) 5) Cellhire USA - Now you can stay in touch... 6) Icelandair/Hertz Car Rental and Icelandair Hotels.
7) British Booking Center - Harry's Magical Ride Around Britain, plus more!
8) icelandtotal.com - All You Want To Know About Iceland.
| Lucky Fares 51 - from 129usd each way |
Due to the holiday, on Friday, December 21 traders will have to use a Custom strip to trade Power deliverable on Wednesday, December 26.
These Custom strips will be used to calculate a separate set of Power Indices which will be published on Friday afternoon along with our regular Daily Power Indices.
!
!
Please call our Help Desk at 770 738 2101 or a member of our Power Sales Team with any questions.
!
| Power Indices for December 26 |
Dear Volunteers, I am hosting a reception for our board and committee members at my home on Thursday, June 21, 2001.
FOR FUN ONLY!
It will begin at 6:00pm.
More information will be coming to you by mail.
I look forward to seeing you there.
I promise not to be serious, or make you work, or even ask you to THINK!
Angela angela.blanchard@neighborhood-centers.org
| Board Reception |
Attached for your information is a memo that we plan to send out to employees worldwide Monday afternoon or Tuesday morning discussing the Policy Committee's cost saving recommendations.
To the extent there are unique aspects of these policies as they apply to your business unit, please follow up with a further communication to your employees.
We will send you a list of frequently asked questions that deal with systems issues.
Thank you.
| Cost Savings Memo |
Per discussions with Steve Harris we have re-estimated volumes and costs for a smaller version of Project Red Rock.
We have studied two scenarios and the results are as follows.
70 mmcf/d Case Requires PGT-25 compressor installation at TW Stations No.1 and No.2.
Estimated cost = $48,000,000 120 mmcf/d Case Requires PGT-25 Compressor installation at TW Stations No.
1, No.
2 and No.
3.
Estimated cost = $72,000,000.
GE has informed us that absent a substantial commitment from Enron by June 13, they will be forced to stop all work on the 4 PGT-25 compressor packages for Project Red Rock.
If we elect to restart this work at a later date, the original delivery dates (Nov-Dec 2001) will not be feasible.
We have proposed to GE that Enron make an irrevocable commitment for 2 or 3 PGT-25 Compressors by June 13, and GE continue to preserve the original delivery dates for the uncommitted balance.
They have indicated that this will be an acceptable arrangement through the end of June.
With no further commitment from Enron for the balance of the original order by June 30, GE would stop all work on the uncommitted portion of the order.
This would preserve our required In-Service date for 150 mmcf/d through the end of June, and of course, would preserve the required In-Service date for a reduced Project Red Rock.
If, by the end of June we have not committed to the balance of the compressor order, I believe that we may be able to scale back the purchase of the uncommitted PGT-25 Compressors packages.
The PGT-25 Compressor package consists of a Gas Generator (LM 2500) and a skid mounted Gas Compressor/Power Turbine.
The reason for long manufacturing lead-time is the Gas Compressor/Power Turbine.
We may be able to purchase the PGT-25 Compressor package without an LM-2500 Gas Generator.
LM-2500 Gas Generators are much easier to come by on short notice.
The cost of the Gas Compressor/Power Turbine, without an LM 2500 Gas Generator, is about $4,000,000.
The cost of the LM 2500 Gas Generator is about $5,500,000.
We have not discussed this with GE at this time but I believe it is feasible to preserve project delivery options.
We are preparing a communication to send to GE affirming our election to make an irrevocable commitment on some portion of the original order.
We will release that communication to GE next week if you wish to proceed on either of these alternatives.
I will not be in the office this coming Monday but Jerry will be available to followup.
| Project Red Rock Update and Alternatives |
We are planning on the following schedule for the upcoming business review in Omaha.
The goal of the meeting is to encourage discussion about the focus and direction of each of Northern's Marketing teams rather than simply presenting material.
With this in mind we are planning to have smaller meetings and divide the discussion in to four sessions.
In additon to Stan, Dan, Rod (if available) and myself, we will have only those people listed below at each session.
10:00 - 11:15 - Topic: Power, Business Development and Acquisitions (plus long term South End Strategy) - Participants: John Dushinske, Mike Stage, Chuck Wilkinson, Mike McGowan, Shelly Corman 11:15 - 12:00 - Topic: LDC Accounts and relationships - Participants: Bill Fowler, Frank Semin, Bob Stevens 12:00 - 1:00 - Topic: Overall Commercial / Regulatory Strategy (SLA, 637, Rate Case) - Participants - Mary Kay Miller, Steve Kirk, Kent MIller, Drew Fossum, Shelly Corman 1:00 - 2:00 - Topic: Storage, Pricing & Structuring, Risk Management - Participants: Kent Miller, Jo Williams, Sue Neville, Lee Ferrell We will follow up with a more detailed outline prior to the meeting.
Please let me know if you are unable to attend.
Thanks,
| Schedule for June 21st business review in Omaha. |
Here are the bullets for your discussion w/ Kevin regarding EBS interest in service from EAMR.
EAMR/EBS OPPORTUNITIES ?
Asset Management Services provided by EAMR will generate costs savings for EBS.
?
EBS assets under consideration - Cable Duct and ROW Signal Amplification Re-gen facilities (located approximately 50 mile intervals) Customer Terminal locations ( Buildings, HVAC Maintenance) POP's "Point of Presence" ( Electronic Switching) ?
Services to be provided Operations/Maintenance Fleet Management Material Management Safety Technical Services Environmental ROW Communications Computerized Maintenance Management System Crisis Management/Emergency Response Damage Prevention ?
Preliminary estimate of cost savings at approximately $2 million annually.
EAMR would propose to share those savings with EBS.
?
EAMR would absorb some of the existing EBS operations employees that are necessary to achieve required skill levels for EBS facilities.
Approximately 40% of EBS ROW is in proximity to pipeline assets.
| Talking points w/ Kevin Hannon |
I received some news today about the referenced matter from FBI Special Agent Carl Wake.
Mr. Wake called to verify the name of the EOTT entity that was the victim of Todoroff's activities.
In response to my question as to when we could expect an indictment, Mr. Wake said it should be very soon because the FBI has started seizing some of Todoroff's assets.
According to Mr. Wake, Todoroff has 2 less vehicles than he did at the beginning of the week due to the FBI seizures.
Mr. Wake indicated that Todoroff's assets are being seized in advance of his indictment through an administrative process.
I will attempt to learn more about this process.
As some of you know, Todoroff is attempting to sell his home that is located a few blocks from our former office.
Mr. Wake was well aware of Todoroff's efforts to sell his home.
According to Mr. Wake, the home was constructed in 1997, and Todoroff is seeking a sale price in excess of $1,000,000.
Mr. Wake also indicated he wants to continue his investigation with respect to the payments Todoroff received from one of EOTT's trading counterparties in late 1997 and 1998.
He is developing that matter as a separate investigation, and he thinks it may be a much larger matter involving several individuals.
Lori, Mr. Wake indicated that he would like to compare the records he obtained from the trading counterparty to our records.
I know you were working on obtaining position reports for this time period.
As soon as those are obtained, I want to schedule a meeting with Mr. Wake in order that he may advance that investigation.
| Todoroff Prosecution--CONFIDENTIAL/SUBJECT TO ATTORNEY-CLIENT PRIVILEGE |
The following reports have been waiting for your approval for more than 4 days.
Please review.
Owner: John L Garrison Report Name: DECEMBER 2001 Days In Mgr.
Queue: 4
| Expense Reports Awaiting Your Approval |
The following reports have been waiting for your approval for more than 4 days.
Please review.
Owner: John L Garrison Report Name: DECEMBER 2001 Days In Mgr.
Queue: 5
| Expense Reports Awaiting Your Approval |
The Bankruptcy Court has approved our sale of the IM Project to AEP.
The C= ourt's formal order will be entered sometime Friday morning.
With this app= roval, we expect to close the sale either Friday or Saturday.
Approval was= conditioned upon our agreement to the following procedures with respect to= the net sale proceeds (approximately $108mm): =20 =09-=09$25mm will be returned to Enron (repayment of the post-petition work= ing capital loans made to EW);=20 =09-=09$10mm will be retained by EW for working capital to use over the nex= t 2 weeks;=20 =09-=09$78mm (the remaining balance) will be set aside in a restricted acco= unt of EW, pending approval by the creditor's committee of the use of those= funds for payment of existing obligations and for ongoing working capital = by EW.
=20 We have until 15 January to obtain creditors' committee approval for the us= e of the remaining balance, at which time if no approval is obtained, we ca= n ask the BK Court to rule on the matter.
Obtaining creditors' committee a= pproval will require that we (a) demonstrate that the continued operation o= f EW as a going concern is in the bankruptcy estate's best interest (becaus= e it will enhance or at least maintain the value of EW for sale) - this dem= onstration will need to be made by Enron (Mark) and CSFB (Matt), and will n= eed to include an overview of EW's value on sale, including arguments why t= here is significant value in the EW - Americas business unit notwithstandin= g the short-term issues facing the US business, and an update on the sale p= rocess; and (b) demonstrate the legitimacy of EW's current obligations and = future working capital needs - this will need to be done by Umanoff and Wes= tbeld (we initially projected that we would need approximately $54mm of the= $78mm through the end of Q1, a likely closing date for sale of EW; Mike an= d his team will be scrubbing these numbers over the next week).
We are tar= geting early in the week of Jan 7 to make our case to the creditors' commit= tee, although no firm date has been set.
One final note - a representative of GE attended the BK court hearing and i= s aware that our request to use the remaining balance to pay our past due o= bligations (including $9mm owing to GE) was denied pending implementation o= f the above procedure.
We can expect continued pressure from GE.
Call me with any questions.
| Indian Mesa Sale - Bankruptcy Court Approval |
I will be out of the office starting late this afternoon and will not be back in the office until Monday January 7th.
I will be out of town on starting the 1st of January and will be returning to town on January 5th.
My contact information is below in blue.
I will be checking voice mail regularly and will be carrying the Blackberry.
I may not have email access other than the Blackberry.
A list of people to contact for certain matters is below: Tracy Geaccone (X37372) EGS Cash, Planning, or Forecasting and Coordination of same with Corporate Morris Brassfield (X67006) ETS Operations Support Jim Saunders (X33532) ETS Accounting Pam Daily (X36135) EGS Space Planning, Move Coordination Have a very Happy, Safe and Prosperous New Year!
| Out of the Office |
Stan and Danny, here is a recap of activities in Gas Logistics this last week including Gas Control activity.
I will send you an update again on Wednesday (Jan. 2).
Have a great weekend.
Please give me call if you have any questions.
(Ext.
7637) Thanks.
Lynn
| Weekly Report for Gas Logistics |
This is a notice to inform you that the server where your Outlook mailbox resides is scheduled for an outage tonight.
Your mailbox will be temporarily unavailable starting anytime after 11pm and may continue to be unavailable until 1 a.m., when all server maintenance work have been completed.
Outlook Web Access (OWA) will also be unavailable during this time.
Blackberry users: Message delivery may be delayed for a few minutes.
If you have any questions, please call the Resolution Center at x31411.
| CORRECTION: Outlook Outage - Friday, December 28, 2001 |
The Indian Mesa sale closed last night in NY.
Our team did a great job.
All we have to do now is convince Enron's creditor's committee to let us use the net proceeds through a sale of the wind company!
Regarding the sale, we are wrapping up today the revised '01 numbers and the '02 and '03 projections and expect we will have the teaser done for a Monday distribution as planned.
Happy New Year.
Adam
| Indian Mesa/Aura |
The following reports have been waiting for your approval for more than 4 days.
Please review.
Owner: John L Garrison Report Name: Previous Statement Credits/New Trip Days In Mgr.
Queue: 6
| Expense Reports Awaiting Your Approval |
The following reports have been waiting for your approval for more than 4 days.
Please review.
Owner: Joseph R Hartsoe Report Name: Joe11/13/01 Days In Mgr.
Queue: 6 Owner: George B Stanley Report Name: GBS 102301 AMEX Days In Mgr.
Queue: 4
| Expense Reports Awaiting Your Approval |
The following reports have been waiting for your approval for more than 4 days.
Please review.
Owner: Joseph R Hartsoe Report Name: Joe11/13/01 Days In Mgr.
Queue: 7 Owner: George B Stanley Report Name: GBS 102301 AMEX Days In Mgr.
Queue: 5
| Expense Reports Awaiting Your Approval |
In reviewing the key items of your business review with Jeff Skilling, he had some issues with your new Broadband business.
Please provide me with some more detail as follows: It was mentioned that we had spent around $13 million thus far on dark fiber.
How much of the resultant capacity has been sold?
Are we laying the dark fiber at risk?
In other words are we taking a long position in dark fiber.
What is our capacity situation today?
Do you have a business plan for this new venture..ie what is the anticipated capital expenditures annually for this venture.
Who are the customers?
What is the expected return?
What is the payback on our investment, etc.
Who approved the formation of this new venture and the capital commitment?
Anything else that will help me get a clear understanding of what we have and where we are going with it.
| Broadband Business |
Stan would like to offer out the following Astros tickets (4 tickets per game) for the month of April, for business or personal use, as follows: Thursday, April 5, vs. MIL @ 7:05PM (short notice!)
Friday, April 6, vs.
PIT @ 7:05PM Saturday, April 7, vs.
PIT @ 1:35PM Sunday, April 8, vs.
PIT @ 1:35PM Sunday, April 22, vs. STL @ 7:05PM Monday, April 23, vs. ATL @ 7:05PM Tuesday, April 24, vs. ATL @ 7:05PM Wednesday, April 25, vs. ATL @ 7:05PM Friday, April 27, vs. FLA @ 7:05PM Saturday, April 28, vs. FLA @ 1:35PM Sunday, April 29, vs. FLA @ 1:35PM First come, first served.
Thanks,
| STAN'S ASTROS TICKETS FOR THE MONTH OF APRIL |
This is to advise you that we are still working on your individual issues regarding the lack of representation in your specific areas on the Associate PRC Committee.
I will keep you posted on the outcome.
Thanks,
| ASSOCIATE PRC |
Just a brief note to thank you for the Enron/Astros Opening Day Caps!
They are very nice, and I do appreciate the gesture.
Thanks again,
| 2001 Enron Field Opening Day Caps |
The Red Rock expansion needs to get approval at the May 1st Board meeting.
The procedure is to submit it to the Finance Committee of the Board for approval .
Assuming the Finance Committee approves the project they would recommend it to the Board for approval.
By this memo, I am requesting that Rod coordinate with Rick Buy to get it on the Finance Committee agenda.
I will be in town for both the Board meeting and the Finance Committee meetings.
If formal presentations are required at the Finance Committee we can decide who should do them.
It is my understanding that no presentation needs to be done at the Board meeting.
I will check with Jeff to see if he wants a formal presentation to the Finance Committee or if he will do it himself.
| Red Rock expansion |
This is a friendly reminder of this weekend's Theatre Under The Stars Event, of which you and your spouse will be sitting with Stan and Debbie Horton.
This 2001 Gala will be honoring The Humphreys Foundation and takes place on Saturday, April 21, at the Wortham Theater Center with cocktails beginning at 7:00PM in the Grand Foyer, seated dinner at 8:00PM in the Grand Foyer, and a special dancing performance by the Humphreys School of Musical Theatre at 9:30PM in the Cullen Theater.
This is a black tie event; valet parking will be available.
Have a great evening!
Cindy
| THIS WEEKEND'S TUTS EVENT |
I would appreciate if each of you could provide a brief (one-page or less) bullet point summary of the week's activity by close of business each Friday.
You can send either via e-mail or fax.
Jeff has his staff meetings on Monday mornings and it would help me keep him abreast of key activities in your respective areas.
I don't need anything elaborate.
Thanks,
| WEEKLY BUSINESS ACTIVITY UPDATES |
Ms. Conners: Thank you for your recent letter regarding my personal financial situation.
I do appreciate your concern and interest; however, I have a very qualified financial advisor who handles ALL of my personal financial needs.
Please remove my name from your written correspondence/phone call contact list.
Sincerely,
| LETTER DATED APRIL 18, 2001 |
The game was awesome.
Our tickets were directly behind homeplate.
Debbie said she could see me on every pitch and knew that I left the bootom half of the 8th inning.
She said I never picked my nose once on camera.
Pretty good, huh.
Have a good day.
Talk with you later.
By the way, your car is done.
They had no problem removing the oil filter at all.
They only had to wriggle it a little bit.
Love, Daddy
| Good morning |
Sounds like you are having a tough week with all the Exchange/Outlook outages.
Hang in there.
The problems will be resolved.
Also, we still like you!
| Tough Week |
Golf is scheduled for 2pm Saturday.
Lousy start time but evidently they have a tournament of some sort on Saturday morning.
Let me know if you can play or not.
It is only you and I.
Phone numbers are: work 713.853.6177.
Home 281.320.1240.
Also please email your phone numbers for future reference.
No one has them.
| Golf |
I am on for golf on Saturday if anyone is interested.
Tom, can you make the T time?
Saturday morning early is better for me.
830 to 9.:00 am start
| Golf |
Q2 earnings report looks very good!
Congratulations.
I will keep it quiet until you are sure of the numbers.
We should let Causey and Hayslett know for planning purposes ASAP.
Given the recent events related to the proposed sale do you think it is even worth discussing the Benefits issue with Corporate?
Also, have we finalized all of the divestiture/retention deals?
Have a good week.
Thanks.
| Weekly Report |
After returning home and reviewing the material handed out at the PGE business review, there are two areas that I think I need to understand better.
The first is PGE's energy positions going forward and the financial exposures to changing prices.
The second is the rate case.
I would be happy to return to Portland to get a more in depth review with a much smaller cast of players.
I am open to suggestions from you.
Given the status of the divestiture process, Jeff wants to make sure he (and subsequently I) have a good handle on these two important issues.
Thanks!
| Business Review |
You and I need to sit down and discuss in some detail John Ale's contract and yours.
Let me know when a good time would be.
thanks
| Emplyment issues |
Just a reminder about tomorrow's meeting at the Houston Four Seasons Downtown Hotel from 1:00 to 3:00PM with John Somerhalder and others.
The meeting room has been changed to The Travis Room.
The dress attire for this meeting will be business casual.
Thanks,
| MAY 11 ALASKA PIPELINE MEETING |
This is to advise you that we have canceled next Monday's (May 21) 9:15AM ETS Staff Meeting and will resume the following week on Tuesday (May 29) from 9:30 to 11:00AM in 49C2.
NOTE: Next week, in the absence of our staff meeting, Stan would like you to send him (via electronic mail) brief, updated bullet points.
Let me know if you have any questions or concerns.
Thanks,
| ETS Staff Meeting Schedule Changes for the Remainder of May |
Debbie has to be downtown for other reason on May 24th.
Could you meet with her about 4:15pm at my office.
I will schedule a conference room for your meeting with Debbie.
Perhaps yopu could come around 3:45pm and I could go over any and all changes that I have on tem prior to your meeting with Debbie.
| Estate planning |
Corporate comp is relooking at your contract based on our converstion..ieyou would be entitled to severance payment eqyual to 2 year salary and bonus should you decide to leave the company provided that all or substantially all of the Azurix assts other than ?Wessex and Azurix Bu7enos Aires are sold.
I will meet with Jim Derrick today to discuss John Ale.
With regard to Beckett and Glasford; their agreements provide for retention bonuses provided they stay until September 16th.
If they voluntarily leave before that they get nothing.
There is no employment agreements in place that link anything to comparable positions titles or anything else.
Should we move them over to Enron in Director positions and they are subsequently offerred positions elsewhere in Enron ( once we dispose of non-Wessex and ABA assets) at Director positions, then they have a choice of accepting those positions or voluntarily terminating.
Since there is no contractual agreements with these two I do not want to offer any kind of enhanced severance payments to them.
I have contacted Ben Glisan regarding Glasford and he is polling his people about their view on an appropiate placement for him.
I will talk with you when you return.
Thanks.
| Employee issues |
This is to advise you that we will have next Tuesday's ETS staff meeting from 10:00 to 11:00AM in 49C2.
Since we will have only one hour, please be prepared to rapidly high-light only your key items for the week.
Thanks,
| MAY 29th ETS STAFF TIME CHANGE |
I would appriciate if you would send to me each week the PGE Position Report.
Also, at your convenience I would like to spend some time via telephone to run through the report to make sure I understand just what is being reported.
I'll have my assistant call to set-up the phone call early next week.
Also, to whom in Risk Management do you send the position report?
Thanks.
| PGE Position Report |
Peggy: Considering where we are in the divestiture process, I don't think it is the right time to have PGE contract for and administer the Health and Welfare Benefits noted in your memo dated 04/20/01.
In addition, it is likely that a potential buyer would want PGE to come under its own Health and Welfare Benefits.
Switching now could entail having PGE employees being under three Plans in a relatively short period of time.
Stan
| HEALTH & WELFARE BENEFITS |
Ken: It is my understanding that we must get approval from the Office of the Chairman to utilize the company aircraft for personal use.
My family is holding a Holiday Reunion in Atlanta December 18-23.
Debbie and I would like to fly to Atlanta and back on Friday, December 22, with our children.
The twins, Jason and Jessica, are a little bit too young yet to try the commercial airlines, which is why I am requesting to use a company aircraft.
Of course, we would only secure a plane if it is NOT needed for business purposes that particular day and would be subject to company policy on all charges.
No problem if this doesn't work!
Stan
| PERSONAL USE OF COMPANY AIRCRAFT |
Thank you for a very successful holiday party.
Debbie and I thoroughly enjoyed the evening.
Your hard work definitely paid-off for our entire organization.
I would like to host a lunch for the committee, after the holidays, as a way of thanking you.
I will have Cindy coordinate your schedules.
| ETS HOLIDAY PARTY |
FYI....we have added Dan Dienstbier to the Northern Border Partners' Audit Committee.
SEC rules dictated that we add another member, and Dan Whitty and Gerald Smith wanted someone with an operations background.
Dan also serves on Dynegy's Board, but neither Bill Cordes (President of Northern Border) nor I saw a conflict.
Stan
| NORTHERN BORDER PARTNERS |
The Board of Directors of GISB decided yesterday at their quarterly Board of Directors meeting to continue discussions with EEI and other interested groups regarding the formation of an Energy Standards Board.
Stan Horton, GISB's Chairman, stated "while there are many differences between the approaches advanced by GISB and EEI, there are also alot of similarities."
GISB is hoping to respond to the stawman advanced by EEI by the end of January.
GISB is also seeking input from other interested industry segments on the two proposals which have been advanced thus far.
| GISB press release |
This is to advise you that we will NOT have ETS Monday morning staff meetings on December 18 or December 25.
Please make note that the next ETS Staff Meeting will be held on Tuesday, January 2, 2001 at 9:30AM in 49C2.
And then on January 8, we'll resume our regular schedule of having our staff meetings on Monday mornings at 9:15AM.
Regards and Happy Holidays,
| ETS MONDAY MORNING STAFF MEETINGS |
Well, folks, one should never use the word 'final' around here!
Friday's PRC meeting room location at the Hotel Sofitel has been changed to the Opera Room!
Cindy
| REVISED ROOM LOCATION FOR ETS YEAR-END PRC MEETING |
This is an email to let you know that the February 2002 release is available on www.rdionline.com.
If you do not want to receive this email, please reply with Unsubscribe in the body of the email.
Thank You!
| NEWGen February 2002 release |
Kevin, We need to start actively pinging other shippers (Duke, SW Gas, Salt River Project, Sempra) to lock down Sun Devil transport agreements.
Also, we should organize a communication plan for the San Juan producers + plant operators and organize a roll-out.
Let's form a strategy and then recruit Kim W and company to help promote.
| Sun Devil - next steps |
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