input stringlengths 93 39k | output stringlengths 1 117 |
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Neither EWS/RAC/EGF employees nor family members or others living in their household or financially dependent on the EWS/RAC/EGF employee may purchase or sell securities of any entity (or derivatives thereof) listed on the Restricted List for your or their personal or related accounts or recommend the purchase or sale of such securities to any person, except with the prior approval of the Compliance Department in consultation with the ENA Legal Department.
In addition to the trading restrictions above, should you at any time possess non-public material information about any public company, you, your family members and anybody that is financially dependent on you, are restricted from trading in that issue, and you may not disclose the non-public material information to anyone that does not have a business need to know.
With respect to investments in privately held companies, you are responsible for complying in all respects with the policy entitled "Conflicts of Interest, Investments, and Outside Business Interests of Officers and Employees" in the July, 2000 Enron Corp. Code of Ethics.
Please consult the Compliance Department with any questions you may have regarding a potential investment in a privately-held company.
Company Name Stock Symbol 3 TEC Energy Corp. TTEN Active Power ACPW Adrian Resources ADRRF Applied Terravision Systems, Inc. TER CanFibre Group Ltd. CFGL Carrizo Oil & Gas Inc. CRZO Catalytica Energy Systems, Inc. CESI Crown Energy CROE CyNet, Inc. CYNE Enserco Energy Service Company, Inc. ERC eSpeed, Inc. ESPD FuelCell Energy, Inc. FCEL Hanover Compressor Co. HC ICE Drilling Enterprises Inc. IDF Impact Energy IEY Industrial Holdings, Inc. IHII Kafus Environmental Industries, Inc. KS KCS Energy KCS Nakornthai Strip Mill Public Co Ltd NSM SET Paladin Resources PLC PLR LD Southwest Royalties SWROY Syntroleum Corp. SYNM Tejon Ranch Corp. TRC TransCoastal Marine Services, Inc. TCMS Verado VRDO The Restricted List is solely for the internal use of EWS/RAC/EGF.
No one may engage in discussions regarding whether a security is or is not on the Restricted List with persons outside EWS/RAC/EGF without specific clearance from the Compliance Department in consultation with the ENA Legal Department.
No employee of any Enron Business Unit may engage in the trading of any Position for the benefit of any party other than an Enron Business Unit (whether for their own account or for the account of any third party) where such Position relates to (i) any financial instrument, security, financial asset or liability which falls within such employee's responsibility at an Enron Business Unit, or (ii) any other commodity not covered by (i) included in any Commodity Group.
Position shall mean, collectively, the risk components (including, but not limited to, price risk, basis risk, index risk, credit risk and liquidity risk) of all products (commodities, financial instruments, securities, equities, financial assets or liabilities) which have been authorized for trading in the Enron Corp. Risk Management Policy, any of the Enron Corp. Policies or approved for trading through any amendments to this Policy.
The prohibitions listed above do not replace or modify the policies set forth in EWS's Policies and Procedures Regarding Confidential Information and Securities Trading, Enron Corp.'s Risk Management Policy, or Enron Corp.'s Code of Ethics .
Should you have any questions regarding the above, please contact me at ext.
31939
| Restricted List |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES JUNE 06, 2001 Notice ID: 2782 5 - NO RESPONSE REQUIRED SUBJECT: AUCTION OF FTS AND ISS CAPACITY Columbia Gas Transmission has posted the following offers of FTS 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 32602 FTS Direct App Market Area 5 32603 FTS Leach Market Area 5 32629 FTS Milford Market Area 21 32604 FTS Leach Market Area 1 32605 FTS Leach Market Area 5 32606 FTS Leach Market Area 5 32607 FTS Crossroads Market Area 5 32633 FTS Leach Market Area 7 32609 FTS Leach Market Area 8 32610 FTS Crossroads Market Area 8 32611 FTS Leach Market Area 8 32612 FTS Leach Market Area 9 32613 FTS Crossroads Market Area 9 32614 FTS Leach Market Area 10 32615 FTS Leach Market Area 12 32616 FTS Leach Market Area 15 32617 FTS Leach Market Area 19 32618 FTS AO4 Alexander Market Area 32 Agg.
32620 FTS Leach Market Area 5 32621 FTS Leach Market Area 8 32622 FTS Leach Market Area 9 32623 FTS Leach Market Area 12 32625 FTS Leach Market Area 15 32631 FTS Highland Market Area 38 32638 ISS For additional information, please contact your Account Representative or your Customer Services Team.
| AUCTION OF FTS AND ISS CAPACITY |
Per VNG's request, ENA released 700 dt of CGAS capacity to Nabisco effective 1/1/2001 - 12/31/2001.
Yesterday, CGAS informed me that Nabisco has not paid any of their bills.
CGAS was under the impression that ENA should be paying Nabisco's bill.
I told CGAS to find chat with the company doing the nominations for Nabisco and to keep me informed.
| VNG capacity released to Nabisco |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES JUNE 08, 2001 Notice ID: 2788 5 - NO RESPONSE REQUIRED SUBJECT: CAPACITY UPDATE EFFECTIVE FOR MONDAY, JUNE 11 2001 CHANGES ARE INDICATED WITH AN * Effective Monday, June 11, 2001, capacities will be as follows: Excess MDWQ Available + ISS Withdrawals Available SIT Withdrawals Available Imbalance Drawdowns Available PAL Lends/Unparks Available Excess MDIQ Available + ISS Injections Available SIT Injections Available Imbalance Paybacks Available PAL Parks/Loan Paybacks Available + Call Gas Control 24 hours in advance at (304) 357-2606 to request approval.
Receipt capacity will be as follows: TENNESSEE: Brinker (B12) 20,000 Broad Run (B9) 450,000 Cambridge (B10) 20,000 Dungannon (B11) 50,000 Highland (B17) 25,000 Milford (B18) 15,000 North Greenwood (B22) 0 Unionville (B15) 50,000 TEXAS EASTERN: Delmont (C16) 0 Eagle (C22) 30,000 Hooker (C9) 50,000 Pennsburg (C23) 50,000 Windridge (C12) 50,000 NATIONAL FUEL: Independence (M1) 10,000 Ellwood City (L1) 10,000 TRANSCO: Downingtown (E3) 5,000 Emporia I (E13) 120,000 * Rockville (E2) 65,000 Dranesville (E1) 60,000 ALGONQUIN: Ramapo (R1) 50,000 ANR: Paulding/Cecil 105,000 (F1, A2) LEBANON AGGREGATE 195,000 (A4, F2, C4, D3) TOLEDO AGGREGATE 225,000 (A3, F4, 734462) COLUMBIA GULF: (801) TCO-Leach 2,218,000 Internal point non-firm capacity will be as follows: Lanham No Restrictions Delivery capacity (non-firm) will be as follows: TRANSCO: Martins Creek (MA 21) 25,000 Young Woman's Creek 15,000 (MA 36) ALGONQUIN: Hanover (MA 22) 166,000 EQUITRANS: Fallen Timber (MA 35) 35,000 (MLI K1) Waynesburg-Rhinehart 30,000 (MA 26) (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 Market Area 38 No Restrictions Market Area 39 No Restrictions Market Area 40 No Restrictions 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.
| CAPACITY UPDATE EFFECTIVE FOR MONDAY, JUNE 11, 2001 |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES JUNE 08, 2001 Notice ID: 2790 5 - NO RESPONSE REQUIRED SUBJECT: CAPACITY ALLOCATION-TIMELY NOMINATION CYCLE FOR JUNE 9-11, 2001 PLEASE NOTE THAT ALL ALLOCATIONS ARE SUBJECT TO CHANGE BASED ON THE RECEIPT OF ANY NEW NOMINATIONS OR INTRADAY NOMINATIONS.
RECEIPT: LEBANON AGGREGATE: JUNE 9, 2001: There is no capacity for new IPP customers.
IPP customers nominating increases received 107.493% of their June 8, 2001 flowing volumes or their June 9, 2001 nominated quantities, whichever was less.
JUNE 10, 2001: There is no capacity for new IPP customers.
IPP customers nominating increases received 101.034% of their June 9, 2001 flowing volumes or their June 10, 2001 nominated quantities, whichever was less.
JUNE 11, 2001: There is no capacity for new IPP customers.
IPP customers nominting increases received 108.29% of their June 10, 2001 flowing volumes or their June 11, 2001 nominated quantities, whichever was less.
Excess MDWQ Available + ISS Withdrawals Available SIT Withdrawals Available Imbalance Drawdowns Available PAL Lends/Unparks Available Excess MDIQ Available + ISS Injections Available SIT Injections Available Imbalance Paybacks Available PAL Parks/Loan Paybacks 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 days of June 9-11, 2001.
You may now view the quantities you are authorized to flow on June 9-11, 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 Friday, June 8, 2001.
If you have any questions, please contact your Account Representative.
| CAPACITY ALLOC-TIMELY NOMINATION CYCLE FOR JUNE 9-11, 2001 |
Mr. Hodge, Eric Boyt mentioned that you would assist in making sure my resume was forwarded to the right people regarding the Legal Specialist position posted on the Enron website.
I want to take this opportunity to thank you for doing so.
You will find a copy of my resume attached below.
I worked as a consultant in the Law Department of one of the larger Energy companies here in Houston for over two years.
In this role, I assisted in the management of three FTC document productions regarding mergers and acquisitions, gathered relevant documents to assist in the divestiture process related to these mergers, and also monitored a docket of over 100 cases.
These cases involved bankruptcy, environmental, garnishments, employment, and other general litigation issues.
Additionally, I was responsible for monthly status reports to the client regarding my team's work efforts and conducted in-depth interviews of several of the business units as part of the merger productions.
Recently, I have been working on document reviews to assist in building economic damages models.
Again, I would like to thank you for your attention to this matter.
If you
| Legal Specialist Position |
See attached items (clean and redline), including a general flow chart.
Tax: I am providing you a copy as a heads up in respect of consideration of Canada tax issues.
Stephen, these issues were previously developed when we closed the PGE master.
Can you provide to me a short memo describing the resolution of the issues (my recollection is that resolution resulted in a post agreement tax letter agreement to be devised by you and tax counsel at Blakes.)
Accounting: Information purposes.
Joel: Financing issues.
Others: Please review and comment on what is hopefully close to a final draft.
Thank you everyone.
| Draft of Master Netting Agreement Form |
Kevin, Here are the Firm GTC's with and without collateral and with and without signature lines.
I have also attached a redlined version.
I will send the spot GTC's shortly.
Please call me with any questions.
Stacy
| EOL Firm GTC |
Kevin, Here are the Spot GTC's - with and without collateral, with and without signature lines and a redlined version.
Please call me if you have any questions.
Stacy
| EOL Spot GTC's |
Hi, am going to copy you on the penalty language and sample confirm with penalty language I sent to Matt Fleming today.
I will follow up and forward to you, a sample of a normal fully-managed confirmation.
I think the "normal" confirm could easily be duplicated.
I will also send a more complex version that I think will have to be done by Legal.
See below for penalty language info.
Thanks, Christy
| Tier -- Penalty Language |
Here is a confirmation that I have played around with and added some appropriate wordng like I would add if I were doing a deal that involved 10 percent or 20 percent swing, differernt pricing, etc.
I don't think I have ever had a deal where we had different pricing involving the swing language, so I made one up for you.
Let me know if this helps.
| Confirmation |
Mr. Hodge, At the recommendation of Eric Boyt, I forwarded you a copy of my resume last month in hopes of getting it passed on regarding a legal analyst position posted on the Enron web site.
I appreciate your efforts to forward it on to the people who posted the position.
I am writing to request that if you are aware of any other openings that could use a person with my skills set, I would greatly appreciate it if you could forward on my resume.
In case you lost the previous email, I will attach my resume to the bottom of this email.
Again, I want to thank you for all of your assistance.
| Employment Opportunities |
<<enron 2.doc>> Mark Hagan Financial Advisor Retirement Planning Group of North Dallas Please be advised this is not an official confirmation of a buy or a sale.
You will receive the official confirmation via mail within the next 3 business days.
Thank You.
****************************************************** Notice Regarding Entry of Orders and Instructions: Please do not transmit orders and/or instructions regarding your UBSPaineWebber account(s) by e-mail.
Orders and/or instructions transmitted by e-mail will not be accepted by UBSPaineWebber and UBSPaineWebber will not be responsible for carrying out such orders and/or instructions.
Notice Regarding Privacy and Confidentiality: UBSPaineWebber reserves the right to monitor and review the content of all e-mail communications sent and/or received by its employees.
- enron 2.doc
| Thought this might be of some interest |
Attached is a clean CSA, only change is to date as of today.
Attached are a clean and relined MNA for final review.
Troy, I will call after 1 to get your final approval and coordinate execution of the documents.
| Enron Master Netting |
Jeff: Please find attached Calpine/TBG's proposed revisions to the drafts of the Enron-TBG Release and related documents.
These are in clean and blacklined form to facilitate your review.
Kindly forward these to any other Enron personnel you deem appropriate.
Please note that Calpine's representatives are seeing these drafts for the first time now.
Regards, Dave Metcalfe PS: Sorry for the delay... <<Enron-TBG Enfolio Master V3.doc>> <<BLACKLINE -Enron-TBG Enfolio Master 1-3.doc>> <<Enron-TBG Confirmation -4000 a day V3.doc>> <<BLACKLINE -Enron-TBG Confirmation -4000 a day 1-3.doc>> <<Enron-TBG Confirmation -8500 a day V3.doc>> <<BLACKLINE -Enron-TBG Confirmation -8500 a day 1-3.doc>> <<Enron-TBG Release V3.doc>> <<BLACKLINE -Enron-TBG Release 1-3.doc>> - Enron-TBG Enfolio Master V3.doc - BLACKLINE -Enron-TBG Enfolio Master 1-3.doc
| Enron-TBG Release, Enfolio and Transaction Documents |
Mary Cook has requested that you attend a meeting tomorrow morning (Tuesday, October 30) from 10:00 to 11:00 in EB38C2 to discuss master netting agreements.
The directive Mary has presently been given is that we will be preparing various master netting agreements and she would like to solicit as much additional help as she can.
If the directive changes before the meeting tomorrow, we will advise everyone.
Please review the below attachments prior to the meeting if your schedule allows.
Thanks!
| Meeting regarding Master Netting Agreements |
Dear Jeff: Thanks for your time earlier today.
Attached, please find the draft GISB and special provisions for each of Enron North America Corp. and Enron Canada Corp.
If you can forward the drafts for the Canadian entity to your counterpart in the Calgary office, I'd greatly appreciate it.
You may coordinate with me to finalize the agreements.
If you have any questions, or if I may be of further assistance, please feel free to contact me at your convenience.
Kind Regards,
| Enron GISB drafts |
Jeff, this Agreement should replace the GISB and any other gas agreement between the parties.
The collateral language is incorporated into the document.
Also, with respect to the Collateral Agreement for Duke Energy Merchants LLC ("DEM"), Duke would like to propose assigning all of the Enron transactions with DEM into one Enron entity and then using the form of collateral agreement submitted to ENA (with some tweaking to allow for a Guaranty from Duke Capital Corporation) to cover the transactions between the Enron counterparty and DEM.
Duke can present a list of companies which it has outstanding transactions with if Enron would like.
Please let me know if you have any questions in this regard.
Thanks - Joe (See attached file: DETM Master 10-29-01.doc) - DETM Master 10-29-01.doc
| Master Gas Agreement |
Tim, Please forward to me any charts, models, etc that you think be useful.
Also, can we plan on speaking at 9:00 am Houston time?
Thanks,
| TXU Contract |
This is an automatically generated Delivery Status Notification.
Your message has been successfully relayed to the following recipients, but the requested delivery status notifications may not be generated by the destination.
SStonestreet@nisource.com
| Delivery Status Notification (Relay) |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES OCTOBER 29, 2001 Notice ID: 3225 5 - NO RESPONSE REQUIRED SUBJECT: CAPACITY ALLOCATION-TIMELY NOMINATION CYCLE FOR OCTOBER 30, 2001 PLEASE NOTE THAT ALL ALLOCATIONS ARE SUBJECT TO CHANGE BASED ON THE RECEIPT OF ANY NEW NOMINATIONS OR INTRADAY NOMINATIONS.
RECEIPTS: ALLOCATIONS DUE TO LONG WALL MINING OF LINE SM-123: For the following MLI points: There is no capacity for IPP customers.
There is no capacity for ITS customers.
There is no capacity for secondary firm customers.
There is no capacity for overruns.
Equitable Hi Hat MLI F3 KYWV Beaver Creek MLI H1 CNR Boldman MLI CNR02 CNR Conoway MLI CNR03 CNR Johns Creek MLI CNR08 CNR Canada MLI CNR09, CNR10 CNR Stafford MLI CNR11 CNR Thacker/Majestic MLI CNR12 CNR Briar Mtn.
MLI CNR13 CNR Huff Creek MLI CNR14 Conoco Grant MLI P1 TENNESSEE: BRINKER: New IPP customers received equal shares of October 30, 2001 available capacity.
LEBANON AGGREGATE: There is no capacity for new IPP customers.
Flowing IPP customers received 155.686% of their October 29, 2001 flowing volumes or their October 30, 2001 nominated quantities, whichever was less.
TCO-LEACH: New IPP customers received 41.591% of their October 30, 3001 nominated quantities.
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 Available + ISS Injections Available SIT Injections Available Imbalance Paybacks Available PAL Lends/Unparks Available PAL Parks/Loan Paybacks 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 days of October 30, 2001.
You may now view the quantities you are authorized to flow on October 30, 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, October 29, 2001.
If you have any questions, please contact your Account Representative.
| TCO- CAPACITY ALLOC-TIMELY NOMINATION CYCLE OCT. 30, 2001 |
John, Can you get me a fixed price for the following volumes delivered to the WGL citygate for these months?
Dec. 2001 22,800 MMBtu per month Jan. 2002 26,600 MMBtu per month Feb. 2002 22,800 MMBtu per month Mar.
2002 22,800 MMBtu per month Thank you
| Firm fixed price for WGL delivered gas |
TP1 sold 2000 dth to the New England book for November via EOL.
The price is NX1 + .445.
The point should be South Commack.
As of 10:44 am this deal had not loaded into Sitara for November.
| Iroq for November |
1.
John Hodge has agreed to pay Index plus1/4 cent for the metered production to ENA Upstream.
I will prepare a spreadsheet monthly to calculate the origination.
John did mention that there is baggage associated with the metered production, such as calls with MarkWest and EES.
If we really want to trade the metered production (i.e.
asking for I + 4 cents), he wants to transfer the baggage to us.
2.
How will physical fixed prices be handled?
With whom do I deal with?
Currently, when I fix prices for metered production, John Hodge takes the risk into his book.
3.
I have sent the Wellhead GTC contracts to Rudwell Johnson in Credit.
If he OKs, we can send new contracts to the producers.
Who is to prepare and mail the new contracts?
4.
Once new contracts are in place, Terry Franklin can create new deals in Sitara.
5.
There was discussion when Grass was still here that the metered production from EES would be moved into the ENA Upstream book.
I was talking to Barry Vanderhorst w/EES last night.
I believe that this is a distinct possibility.
I told Barry to contact Fred Lagrasta about this option.
There are two people in the Dublin, Ohio office that handle the EES gas, Jim Javins and Heidi Griffith.
| Appalachian Supply to Wellhead Bood |
John: It ended upbeing a crazy day.
Included are thepoints that we would like to quote.
BG&E is not going to be taking bids until this morning, so if you could refresh your numbers I would like to try to get some of these.
Call me if you have any questions.
You can either call me or e-mail me your mumbers.
Thank you much!
Rickey - NEG request for quote for BG&E for Nov 01.doc
| NDR Group RFQ for Nov 2001 |
Kam/Alejandra, This deal should probably be zero effective Nov 2001.
I believe it's a dupe to 139683 on CGAS..Volumes now are zero on 139693.
It's a sale to Hopewell that was created in December 1999 but it has a hedge N59964 and a demand charge attached to it that should be taken out.
THANKS
| Deal 139693 |
John, New Power Company disagrees with the rate invoiced to them on deal # 1143735 for Nov. 2001.
ENA billed New Power a rate of IF CGAS Appal.
+ $.21.
New Power claims the rate should be NYMEX + $.21.
Can you confirm what the correct rate should be?
Thanks,
| 11/01 Price Discr - New Power |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES OCTOBER 18, 2001 Notice ID: 3193 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 between October 25th and October 27th, Line SM-123 will be taken out of service due to long-wall mining activity.
Columbia estimates the line to be out of service for twenty-one (21) days.
The start date and duration of the outage is contingent upon the actual timing and progress of the long-wall mining activity.
Given the level of firm commitments in this area, Columbia believes that there will be no available capacity for interruptible transportation.
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.
| LINE SM-123 |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES OCTOBER 16, 2001 Notice ID: 3184 5 - NO RESPONSE REQUIRED COLUMBIA GAS TRANSMISSION CORPORATION NOTICE OF OPEN SEASON Midwest Project October 16, 2001 OVERVIEW Columbia is conducting an open season in conjunction with CMS Panhandle Companies ("CMS Panhandle") that would path natural gas supplies from the MidContinent production and Chicago Hub areas into Ohio.
Columbia's system is connected to CMS Panhandle via multiple points in western Ohio.
Columbia intends to offer this as a "seamless" service, whereby Columbia would manage the nomination and billing service for this linked path between CMS Panhandle and Columbia.
Due to the multiple transportation paths available into Columbia's system via the CMS Panhandle system, Columbia is requesting that interested parties submit their requests for capacity and service in accordance with the terms set forth below.
In the event the preferred receipt path is beyond the service that can be provided by either CMS Panhandle or Columbia, Columbia may look to extend the supply path, as necessary, by including other transportation providers.
LENGTH OF OPEN SEASON The open season period will commence on Friday, October 12, 2001, and close at 4:30 p.m. E.T.
on Friday, December 14, 2001.
During the open season, interested parties desiring service should submit a request form in accordance with the minimum requirements set forth in this notice.
SERVICE DESCRIPTION Subject to the terms of this open season and depending on the interest expressed through completed request forms, Columbia will evaluate the possibility of using either existing or new capacity for service under its Firm Transportation Service ("FTS") Rate Schedule from its west receipt points into Ohio, located at Crossroads, Cecil, Maumee, and Lebanon.
The open season targets Market Areas 1 through 9 and 15 in Ohio and Northern Kentucky, respectively.
Columbia would also consider requests for summer service (April-October), where practical.
Columbia also will evaluate non-binding proposals from existing customers to turn back firm capacity under existing service agreements that may reduce the amount of capacity for which facilities would need to be constructed.
However, any such proposal(s) would have to be compatible with the specific terms of any project that Columbia may ultimately propose.
CONTRACT TERM/SERVICE COMMENCEMENT The suggested minimum contract term that Columbia will consider is ten (10) years.
The minimum term will depend on the need, or not, for new facilities to be constructed.
Parties submitting a request form should indicate a preferred service commencement date, with the earliest commencement date being December 31, 2001 (if existing capacity on the Columbia, CMS Panhandle, and, if necessary, other transportation providers, can be used to accommodate the requested service).
RATES Rates will be derived in accordance with Columbia's and CMS Panhandle's FERC Gas Tariff, based upon an evaluation of requests for service and capital expenditures necessary to meet such requests.
PARTICIPATION IN THE OPEN SEASON To participate in Columbia's open season, interested parties desiring service should submit a request, which includes the following items, by 4:30 p.m. E.T.
on Friday, December 14, 2001: 1.
One completed request form (attached), with specific attention to the primary term of service, service commencement date, total capacity requested, and the desired receipt and delivery point(s); 2.
One completed Credit Application Form (attached), to be submitted only by interested parties that do not currently receive service from Columbia.
REQUEST FORM ASSESSMENT/FINALIZING SERVICE ARRANGEMENTS Upon the close of the open season, Columbia will assess the requests for service.
Columbia will evaluate the system and capital requirements necessary to provide requested service and develop rates and terms and conditions of service based on the required system enhancements.
If, in Columbia's sole discretion, there is enough interest to justify going forward, Columbia will notify parties that submitted request forms as to their award of any existing or expansion capacity.
In the event requests for capacity exceed the amount of expansion capacity that Columbia can economically construct and make available, available expansion capacity will be allocated on a non-discriminatory basis.
All parties awarded capacity will be required to enter into binding precedent agreements and service agreements with Columbia, CMS Panhandle, and, if necessary, other transportation providers to complete the path.
Such agreements must be executed and returned to Columbia, CMS Panhandle, and other transportation service providers, as deemed necessary, within a designated period of time; otherwise, an award of capacity will be subject to rejection.
All binding precedent agreements and service agreements entered into as a result of the open season must reflect an arm's-length transaction between the requesting party and Columbia, CMS Panhandle, and other transportation service providers, as deemed necessary.
Following the return of executed agreements, Columbia may reallocate any remaining available capacity (if any), but will not be obligated to do so.
During the open season, affiliates of Columbia shall be required to request capacity on the same basis as non-affiliates; that is, an affiliate's request shall be evaluated using the same criteria used to evaluate non-affiliates' requests.
To effectuate a seamless service for nomination and billing purposes, Shippers will name Columbia as agent for Shipper under any necessary upstream transportation agreements on CMS Panhandle.
RESERVATIONS These procedures and the attached forms are provided solely to enable interested parties to submit a request for an award of capacity.
Neither this open season notice, the attachments herein, nor information provided in response to questions or requests about these procedures shall constitute an enforceable agreement.
Columbia reserves the right to not make any capacity available, to conduct additional open seasons, to determine the size, scope, and cost of the project, to not consider requests that do not provide a sufficient level of detail to aid in the development of a proposed project, and to reject or accept materials it receives after the close of the open season.
COLUMBIA CONTACT
| NOTICE OF OPEN SEASON |
MAKE PLANS NOW to ATTEND the PREMIER ENERGY EVENT of 2002!
12th ANNUAL NESA ENERGY EXPO April 29 through May 2, 2002 George R. Brown Convention Center Houston, Texas *Register by Friday, February 15, 2002 and your name will be entered into a drawing for tickets to see BROOKS & DUNN at the Houston Livestock Show and Rodeo on Tuesday, February 19.
LIMITED NUMBER of NESA ENERGY GALA TICKETS available prior to March 15, 2002.
NESA Members and Energy Expo Exhibitors are receiving this advance notice of Registration Information for Energy Expo 2002 - make sure to respond as soon as possible to guarantee availability!
| NESA ENERGY EXPO 2002 |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES OCTOBER 10, 2001 Notice ID: 3172 5 - NO RESPONSE REQUIRED SUBJECT: AUCTION OF FTS CAPACITY Columbia Gas Transmission has posted the following offers of FTS 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 33760 FTS Leach Market Area 1 33761 FTS Lebanon Market Area 1 33762 FTS Leach Market Area 4 33763 FTS Leach Market Area 5 33764 FTS Leach Market Area 5 33765 FTS Kenova Agg Market Area 5 33766 FTS Lebanon Market Area 6 33767 FTS Leach Market Area 7 33768 FTS Leach Market Area 8 33769 FTS Kenova Agg Market Area 8 33770 FTS Leach Market Area 8 33771 FTS Leach Market Area 8 33772 FTS Leach Market Area 9 33773 FTS Leach Market Area 10 33774 FTS Leach Market Area 10 33775 FTS Leach Market Area 12 33776 FTS Leach Market Area 15 33777 FTS Leach Market Area 15 33778 FTS Leach Market Area 19 33779 FTS Alexander Agg Market Area 32 33780 FTS Highland Market Area 38 For additional information, please contact your Account Representative or your Customer Services Team.
| TCO-AUCTION OF FTS CAPACITY |
John, I have reviewed the contracts (Asset Agreement and the GPA) and here are my= thoughts regarding your request.
In short, the agreements do not specific= ally address capacity being needed by third parties.
ENA does have a right= to all of their capacity free and clear of all encumbrances.
Last year we= did discuss this issue (the interruptible VNG customers wanting to take re= leases of VNG capacity), but at the time Jim Scabareti indicated that he wa= s going to play hard ball with his interruptible shippers in year 2 (i.e.
n= ow), since VNG was really getting tight on assets due year-on-year load gro= wth and no new capacity additions.
He gave the assets up last year because= he did not want to have any noise at the VSCC when the VSCC was considerin= g the affiliate relationship between VNG and AGLES.
However, as I reflect = on it now, it seems to me that VNG (aka Sequent) really needs to weigh heav= ily the decision to release any assets to third parties through this winter= (interruptible or otherwise).
At a minimum, any releases should be done r= ecallable based on weather forecasts based on some HDD amount.
The profit = sharing provision is the same for years 1 and 2.
My suggestion is that you do the following: (1) remind Sequent about the de= liverability issue facing VNG and (2) develop a plan with Sequent for talki= ng to Customers, so as to minimize any VSCC risk since the VSCC thinks Sequ= ent is VNG's asset manager.
=20 Mark Breese is back in the office tomorrow and I will confer with him as we= ll.
You might seek Jeff Hodge's thoughts as well.
If you have any questio= ns, please ask.
Regards,
| VNG transportation capacity |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES OCTOBER 08, 2001 Notice ID: 3163 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: 2002 TENTATIVE OUTAGE SCHEDULE In February 2002, Columbia's Line BM-22 in Martin Co., KY will be out of service due to Highway relocation for three (3) days resulting in a reduction of approximately 23,000 Dth/d of production flowing through Kermit Compressor.
This includes the following lines: P-94, V-55 and BM-18.
In the spring of 2002, contingent upon the mining activity, Columbia's Line KA will be out of service for three (3) days due to a coal mining relocation tie in.
Approximately 100,000 Dth/d of Appalachian production west of the May Fork valve on Line KA will be shut in.
In the spring of 2002, Columbia's Boldman Compressor located in Pike Co., KY, will have one unit down for approximately two (2) months for annual maintenance which results in a 15,000 Dth/d flow reduction.
Affected is Equitable's Hi-Hat (F3) pipeline, CNR's Boldman (CNR02) pipeline, and Appalachian production located on Columbia's Lines PM-3 and PM-17.
In May-June 2002, Columbia's Line's BM-18, Line VM-141 and Line V-55 will be out of service for five (5) days due to a relocation for WV Rt.
52 in Mingo Co., WV.
The affect, if any, on production is being evaluated.
In July 2002, Line 1711 will be out of service for three (3) days due to a relocation of the Monongahela River crossing tie in.
The affect, if any, on production is being evaluated.
The following outages affect Equitable's Beaver Creek (H1) pipeline, and Appalachian production from Columbia's Boldman Compressor Station to Columbia's Huff Creek Compressor Station on Line KA, including Line KA-15.
In March 2002, Columbia anticipates an outage of three (3) days on Columbia's Line SM-116 as a result of coal mining activity.
In addition to the above listed production, Conoco's Grant (P1) pipeline and Appalachian production located on Line SM-116 will be affected.
In June 2002, Columbia's Grant Compressor located in Mingo Co., WV will have one unit out of service for six (6) days which will result in a 50,000 Dth/d flow reduction.
In August 2002, Columbia's Huff Creek Compressor located in Wyoming Co., WV will be out of service for one (1) week due to annual maintenance.
In the fall of 2002, Columbia's Line KA will be out of service for three (3) days due to relocation for a highway expansion project on Rt.
119.
The relocation is between Johns Creek and Canada, which will result in 100,000 Dth/d of production shut in west of the May Fork valve setting.
| TCO - 2002 TENTATIVE OUTAGE SCHEDULE |
Stevie, per J.Hodge NIMO ticket #1089776 s/b 1,774 instead of the 1,724 on the ticket.
So i reduced your volume(delivered to citygate) from 447 to 398 on ticket #1009016 for the 6th ONLY.
I did not change the tickets because i did not want to leave you out of balance, so please update Monday.
thanks
| CNG |
The migration of UNIX home directories and applications (Solar) scheduled for this weekend has been moved to the weekend of October 13 and 14, 2001.
Further information as to times and problem escalation procedures will be posted early next week.
Bob Ambrocik Enterprise Storage Team EB 3429F x5-4577 bob.ambrocik@enron.com
| Solar Migration - DATE CHANGE - VERY IMPORTANT |
Kelly, I received a Revision in Estimates of Monthly Metered Supplies from CNR for JML Oil & Gas for the month of October.
The original estimate was 109,718 Dth on Contract 12, Sitata #283294 (per the CNR Oct01 Estimates supplied by Terry Franklin).
This volume should be reduced to 69,551 per the revision faxed to me by Cath Clark.
However, I would make the change effective next Tuesday for the balance of the month with cash price stron for the weekend.
Please call if you have questions.
John
| Oct Estimate Revision: JML Oil |
In order to bring better legal coordination and standardization to Enron's Risk Assessment and Control (RAC) group, we have formed a new legal group, which will initially include Lisa Mellencamp (Finance), Marcus Nettelton (Power Trading), Carol St. Clair (Broadband/Power Trading), Mary Cook (Financial Swaps), Peter Keohane (Canada), Ed Essandoh (Retail), Paul Darmitzel (Retail) and Elizabeth Sager (Power Trading) (Team Leader).
This group will focus on, among other things, managing Enron's exposures with bankrupt counterparties, working out credit solutions with distressed counterparties and standardizing our overall credit practices.
The initial members in this group have been drawn from Enron's numerous legal groups in order to gain a broader perspective.
Each of these members will provide support to this new group in addition to their current responsibilities.
Within RAC, Michael Tribolet will focus on distressed counterparties, in conjunction with Bill Bradford, who continues to manage the Credit Risk Management group.
Please join us in supporting the efforts of this new group.
| New Legal Team to Assist RAC |
During the weekend of October 6 and 7, 2001 the Enterprise Storage Team will be migrating all production users off the current hardware (Solar) that houses their home and application directories (no production databases are affected, but client software will be) to new hardware.
This migration requires a total system outage of approximately 6 hours.
The outage will occur Saturday night - beginning at 7:00 PM and will last until Sunday morning at 1:00 AM.
All users will need to be logged off during this time period.
In order to validate the migration, production users need to test access to their home directories and applications on Sunday, October 7, 2001.
If you do you experience any difficulties after the migration with access to home directories or applications, please call the resolution center at 713 853-1411.
The resolution center will notify the appropriate resources.
The following attachment is a list of the mount points affected.
Bob Ambrocik Enterprise Storage Team EB 3429F x5-4577 bob.ambrocik@enron.com
| Solar Migration - Third Notice - Time Change!!!!! |
Happy New Year!
NESA is kicking off our 2002 calendar of events with a mixer on Thursday, January 31 from 5:00 p.m. until 8:00 p.m. downtown at the Boaka Bar!
The Boaka Bar is located at 1010 Prairie, right next to the Mercury Room.
Make plans now to join us - there's no cover and your first drink is FREE!
Take this opportunity to renew your dues, and encourage your colleagues to join as well!
Everyone who sponsors new members between today and January 31 will be entered into a special drawing for HOUSTON TEXAN tickets (must be present to win!)
You can bring those new members with you and they can register at Boaka Bar, so mark your calendar for Thursday, January 31 and meet us downtown!
You can RSVP to this email just to let us know you're coming and include the name of your guest if you're bringing one!
| MEMBERSHIP MIXER - JANUARY 31, 2002! |
Dear John, Good Morning.
Thanks again for the winter quote last night, your quote was very competitve with the others I have received.
I am hoping that customer will make a decision by Thursday.
I have another favor to ask of you, I have attached a "prosepctive" customers load profile below for you to review.
This customer is also behind 5-2 and is looking for a NYMEX plus applicable basis quote for 1 year out of Nov 01.
They also need firm delivery to this gate.
I know we spoke yesterday about the issue that you may not be able to quote the summer.
Please let me know if this issue has been resolved.
If not, please sumbit winter only and I will see what I can do.
I appreciate your help in advance and I look forward to bringing more business your way.
Sincerely,
| Additional Quote for "prospective" customer behind COH 5-2 |
John, Checking in on TCO cap we talked about last week (to Market Areas 2 and 25).
Any word on what you have available for Nov - Mar?
And, the ROFR element?
Call me.
Paul
| TCO cap |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES OCTOBER 01, 2001 Notice ID: 3144 5 - NO RESPONSE REQUIRED SUBJECT: LINE SM-123 Due to long-wall mining activity occurring under Columbia's Line SM-123 in Mingo County, WV, the line will be taken out of service.
Columbia anticipates this outage to begin in late October 2001 and run through approximately mid-November 2001.
However, the start date and duration of the outage is contingent upon the actual timing and progress of the long-wall mining activity.
Given the level of firm commitments in this area, Columbia believes that there will be no available capacity for interruptible transportation.
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.
| LINE SM-123 |
John, Do you think you we be able to submit a quote for the facility behind COH 5-2 and/or the facility behind COH 7-3.
I am hoping to have all responses in by tomorrow morning and then, make a decision.
I hope to hear from you soon.
Also, if you did not receive the load profiles on these two facilities, I have attached them below.
Reminder: They are looking for firm supply to the gate at a NYMEX based price.
Thanks,
| COH 5-2 and COH 7-3 |
Good morning, John, When you get a free minute, can you check to see if you have come up with any pricing on those winter deals we discussed last week?
I appreciate your time.
Thanks
| Winter pricing |
Hello, I am looking for supply for two facilities in Ohio.
The first is located behind COH 7-3 and the second facility is located behind COH 5-2.
They are looking for firm supply to their respective gates.
I have attached their load profile below.
I am looking for a Nymex plus applicable basis quote.
Please let me know if you are able to bid on one if not both facilities.
I look forward to hearing from you soon.
Sincerely,
| Customers in COH |
As far as I can discern from my limited due diligence, the Bridgeline interests have not been pledged or encumbered by Enron and it does not appear that they have been directly affected by the Bankruptcy.
Let me know if anything else needs to be rundown quickly.
Jordan
| Bridgeline |
Hi Jeff, I was cleaning off the desk of one of my coworkers who was laid off and found two letters from KeySpan that she had not handled.
They were both from Charles Daverio, KeySpan Utility Services LLC as agent for The Brooklyn Union Gas Company.
One letter is a termination of a master agreement between ENA and The Brooklyn Union Gas Company, dated 12/01/88, with the termination effective 10/31/04.
The other is an alternative contract quantity election effective 11/01/01 for a master agreement dated 12/08/88.
I cannot locate either of these agreements in our system.
KeySpan Utility Services LLC, as agent or otherwise, is not set up in the Global Counterparty system at all.
None of our Brooklyn Union agreements even come close in date to the ones referenced in these letters.
In light of our current situation, I wanted to check with you to see if you knew anything about either agreement being referenced.
I certainly do not wish to call the counterparty and it probably does not even matter at this point.
I do plan to send these documents to the file room, but without a contract number to file them under, the file room will not know what to do with the documentation.
Please advise.
Thanks,
| KeySpan agreements |
I have gotten a call from Roger Mock, CEO of American Public Energy Agency, regarding a series of transactions.
In 1999 we (ENA through Enron Natural Gas Marketing Corp.) entered into a 12-year prepay.
We got approximately $297MM in cash up front, with delivery obligations at various delivery points, including NNG-Demarc, Rockies, TW-SJ, NIT, Topock and Sumas over the life of the deal.
Currently the end users are Clark Public Utility District (Washington State), City of Glendale (California), City of Pasadena Water and Power Department (California), and Sacramento Municipal Utility District (California).
It is my understanding that ENGMC is not currently in bankruptcy.
I am sending down to Mike's attention a CD with the project documents on it.
I apologize in advance for the absence of a table of contents, but I felt lucky just to get the information.
Teresa Bushman may have a hard copy of the documents.
| APEA Gas Prepay Transaction |
Hi all!
I am writing an article for the March/April 2002 Trends on the Section's public service activities.
If you would like your committee's public service activities highlighted in the article, just drop me a short E-mail and let me know what you're doing, and I'll include it in the article.
Please E-mail your information to me by COB Monday, 12/17.
Thanks.
Happy holidays!
8-) Dana Bivins Brown, Chair Public Service Task Force ABA Section of Environment, Energy, and Resources - TEXT.htm
| Trends article |
When: Thursday, December 13, 2001 1:30 PM-2:30 PM (GMT-06:00) Central Time (US & Canada).
Where: ECS 6716 *~*~*~*~*~*~*~*~*~* Please note, This meeting is in reference to the email sent to all of you this morning from Laura Luce.
Please accept this invite, as it will automatically populate onto your schedules.
Thank you,
| Contract Review |
Jeff, Mary Alba in Client Services forwarded two letters for me to handle.
One is a Letter In Lieu of Transfer and Division Orders from Linder and Dunhill regarding certain properties they sold to Dunhill Resources I, LLC as of 11/01/01.
I have requested an executed copy from the counterparty, but I have not received it yet.
Also received was a Notice of Assignment of Proceeds between Aquila and Dunhill with payment instructions.
We are supposed to execute and return this one to Aquila.
There are seven November Physical Forward transactions that I believe are affected by these notices.
There are also three December deals with Linder.
Are they still valid deals?
Please review the letters and let me know how to proceed.
An 8 page fax is on the way.
Thanks,
| ENA Upstream and Linder Oil Company--Dunhill--Aquila |
Jeff, Stacey forwarded the termination agreement to me to process, and I just wanted to let you know that there were only 4 active contracts to be terminated.
1.
Enfolio Master Firm Purchase/Sales Agreement (April 1, 2001) between NUIU and ENA -- 96058789
| NUI Utilities, Inc. (NUIU) and NUI Energy Brokers, Inc. (NUIEB) |
Jeff, I left a voice mail message for you yesterday about our role as agents for the Tenaska IV's Cleburne plant.
I wanted to make sure that you got the message.
Please give me a call when you get a chance (3-6905).
D
| Cleburne Plant - Tenaska IV |
Just spoke with Jeff Gossett and he told me that all deal information we've given him so far has been handled.
We're hoping to have one more batch of data today for them to move.
He hasn't had any problems yet and can get all the deals moved very quickly.
I'll keep you posted.
SBR x30569
| progress |
Terry Kain with Keyspan Energy Services is looking for a copy of their contract with ENA.
I didn't ask him any questions.
I just told him that someone would contact him.
His number is 516-256-2611.
| Keyspan |
2001 was a year full of surprises and challenges.
Thanks for your confidence, friendship, cooperation and support.
Merry Christmas and Happy New Year to all of you.
"Abra?os", Sami Arap
| greetings |
This is the official notice to sign up for our golf pool.
It is now in its 12th year, the 3rd using Yahoo.
Rules are described below.
Necessary action: Let me know of your intention to participate by getting me your initial ante of $25 before January 2, 2002.
Most of you have amount left over from last year that can be applied.
We welcome new recruits, as long as they ante and have the commitment to participate all year long.
The initial ante, which will serve as collateral, is due in the first week or any time the manager's collateral is more than $5.00 insufficient.
After receipt of the collateral, the remainder of the year's accounting is by credit.
The fee for entering each week is the greater of $5 or $2 per million of event prize money.
Participation is mandatory except for three "vacation" weeks which require you to set all of your players as "reserve" or notify the members in advance of the deadline.
The pool of entry fees will be distributed proportionally by each manager's credits for the week.
Credits will come from three sources: (1) Margin; (2) Rank among the managers for the week; and (3) Handicap.
For the weeks until Yahoo starts (probably with Pebble Beach) we will use a spreadsheet method as follows: A list of eight golfers must be submitted to me by 8:00am (Central Time) on Thursday.
Managers will get points by dividing their listed golfer's winnings by the sum of one plus the number of managers who have listed that golfer.
For the above Margin component, a pool of credits (equal to 100 per participating manager) will be distributed proportionally by each manager's points in excess of half of the average points.
For the above Rank component, a pool of credits of equal size to the margin pool will be distributed such that each position is 41.4% higher that the next lower.
(For you actuaries, this is from the square root of two; the ratio doubles with every two steps up.)
For the above Handicap component, the points are 0.0014 * (average team score) * ( $ in the hole at the start of the week 2 )?After Yahoo is up and running, the procedure will remain the same as last year.
You will need to make your picks according to the Yahoo website and managers will get points according to the site's scoring.
?For the above Margin component, each manager's margin will be their Yahoo points in excess of half of the average points.
?For the above Rank component, a pool of credits of equal size to the margin pool will be distributed such that each position is 41.4% higher that the next lower.
(For you actuaries, this is from the square root of two; the ratio doubles with every two steps up.)
?For the above Handicap component, the points are 0.0014 * (average team score) * ( $ in the hole at the start of the week 2 ) Rules may be modified for weather delays, nonstandard tournament formats, or other special situations.
Do You Yahoo!?
Send your FREE holiday greetings online at Yahoo!
Greetings .
| call for sign up - Diehards 3 |
As everyone is aware, Peoples provided notification to Enron MW, L.L.C.
of its desire for credit support or termination effective December 28th of the Master Physical Agreement between EMW and PGL.
Richard and I met with Raulie, Dave and Tim this morning to discuss the implications of the termination and our ability to continue to fulfill our obligations regarding the deals that are subject to the Master.
After much discussion, they (PGL) have agreed to delay any termination until either the end of January or February (they are going to discuss internally which makes more sense).
Therefore, unless a higher power overturns our agreement, PGL intends to issue a letter amending their previous notification/assurance letter.
If anyone has any questions or comments, please let Richard or me know at your earliest convenience.
Thanks - Gregg
| Enron MW/Peoples Master |
Ed and Bill: Per Leslie reeves, we did receive a payment from LG&E Energy Marketing so the only issue remaining on them is whether the LC has been renewed.
As Ed reported, El Paso renewed their LC so there is nothing to do on that.
With respect to Enserco, I faxed the proposed new LC to ed and spoke with Don Perkins, their credit manager (303) 568-3255.
I told him that he may be receiving a call from you regarding Fortis, the Issuer.
I also told him that drawing condition #1 would have to change to take out the reference to delivery of natural gas and he agreed.
He was also going to talk to Lynn Evans, his attorney, about the procedures that need to be followed under 'Special Instructions" as I do not think that we should be sending anything to Fortis.
More to come tomorrow.
Ed: Please e-mail me, Sara and Jeff a description of where things stand with Niagara based on their payment today as it sounds complicated and may require us to piece together all of the contracts we have with them before deciding how to proceed.
Did you have any luck confirming the status of the Chase LC?
Sara, Let's meet in the morning.
We also will probably here from Lyn Evans, Enserco's lawyer.
| LC Update |
To All: Attached is the list of Enron entities and Hess entities to be included in the Master Collateral/Netting Agreement.
Jeff- Can we please prepare 2 Enfolios, one for Amerada Hess Corp. and Hess Energy Trading Company, LLC.
The Cross Default amounts in each contract should be $100 MM for ENA and the respective Hess entity.
The collateral and MAC provisions will be contained in the Master Netting Agreement.
Frank- Please include Hess Energy Trading Company UK Limited, as agents for Hess Energy Trading Company, LLC in the Master Netting Agreement.
The proposed Power of Attorney for this entity was sent to you earlier today.
Thank you all for the help and please call if you have any questions.
| Hess.xls |
Dear Jeff: Just to follow up on my voice-mail message of this morning, please let me know the status of Enron's review of the GISB drafts sent to you on Monday, October 29th?
We consider these negotiations a top priority and would like to finalize the GISBs with Enron North America Corp. and Enron Canada Corp. on an expedited basis.
Please contact me to discuss.
Kind Regards,
| status of GISB negotiations |
Kelley, I am writing to you to follow up on our discussion last week regarding disclosure of counterparty names for price verification purposes.
Can you give me the name and contact information for the person within your company that would work with us to put a Confidentiality Agreement in place.
Jeff Hodge is our lawyer who will work on this for Enron.
Jeff can contacted at 713 853-6911 or by email at jeffrey.t.hodge@enron.com.
Thanks for you assistance.
| confidentiality agreement |
Ken, Attached is the Agreement with my comments redlined over your changes.
Sorry for the delay Please review and let me know if you have any questions.
By copy of this email, I am requesting David Marshall to review the insurance section (Section 11) and provide any comments he may have.
| Comments to O&M Agreement |
Jeff and Deb, Please use the attached form of Adoption agreement when dealing with Gas Masters; it adds a missing "of" in Section 4 and it Triangularizes the Set Off provision, which we think will ultimately be a positive feature in "selling" the form to a counterparty.
.
.
especially a counterparty who already has a power and/or financial master in place with ENA/EPMI.
Please let me know if you have any questions regarding the attached.
Steve
| Final Form of Adoption Agreement for Gas |
Enclosed is a worksheet for Total Gas & Electric.
Suzanne mentioned she would be working on the drafting of this document.
When a draft is ready, please provide me with a copy.
Many Thanks, Max Sonnonstine x5-8261
| Total Gas & Electric Master Physical |
Jeff, I will be meeting with the Texas land office on Thursday morning and would like to send them the attached tomorrow for their review prior to the meeting.
The attached is a Letter of Understanding (drafted by me based on your prior letter of understanding).
It is specific to the Kathleen Ann storage field and includes the current owner of the field as a third party to the letter.
If at all possible, I would like you (or your designee) to review, modify and resend to me so that I can send it to the land office tomorrow.
Thanks,
| Kathleen Ann Storage Field |
Per your request, attached are the EnronOnline General Terms & Conditions for firm gas.
Please let me know if you want the spot GTC's as well.
The difference between the two firm GTC's is a provision allowing Enron to call for a letter of credit from the counterparty.
This collateral GTC is used for those counterparties designated by Credit.
Legal has been working with the EOL team to get new versions of the GTC's in place with EOL counterparties that do not have masters.
This effort was recently put on hold at the request of the EOL team.
Please let me know if you have any questions.
Stacy
| EOL GTC |
****************************************************************** This email and any files transmitted with it from the ElPaso Corporation are confidential and intended solely for the use of the individual or entity to whom they are addressed.
If you have received this email in error please notify the sender.
****************************************************************** - COLFFLPayout.xls
| COLFFL Payout Schedule |
Jeff - Attached is the confirmation for the original deal, VA6791.1.
We never received a signed copy back from the counterparty.
The unwind deal, leg 2, has not been confirmed yet.
What do we need to do with respect to that?
| Superior Natural Gas - confirmation |
Have we gotten started on this one yet?
I have done all the due diligence on contracts gtys, etc.
I actually provided Carol with a binder a few months ago with all the back up.
I probably want to change the collateral thresholds.
Let's discuss this morning when you have a moment.
Thanks!
| Williams MNA |
Pursuant to our discussion yesterday regarding the above, please find below for your consideration a suggested revision to MAC/Credit Rating trigger definition to used in all future master trading agreements or confirmations in which Enron Corp's credit rating is part of a MAC/Credit Rating trigger.
"Material Adverse Change" means (i) with respect to [Enron Trading Entity], Enron Corp. (or its successor or its successor's parent company) shall have long-term, senior, unsecured debt not supported by third party credit enhancement that is rated by S&P below "BBB-" [also insert Moody's as appropriate]; I understood yesterday that we may also need to consider changing the definition of Credit Support Provider in the ISDA's.
I suspect that if "Credit Support Provider" is defined as Enron Corp. in the relevant Master, then the corresponding changes noted above would also need to be made.
Your further thoughts regarding this issue are welcomed.
Please provide me your comments to the above language by tomorrow so we can start implementing a revised definition in our agreement templates.
Regards, Alan
| Draft of revised definition of Material Adverse Change/Credit Rating Trigger |
When: Tuesday, November 20, 2001 11:00 AM-2:00 PM (GMT-06:00) Central Time (US & Canada).
Where: EB4335 *~*~*~*~*~*~*~*~*~* Hello, I would like to invite you to come by and check out the new Ready2Go Testing location!
The Ready2Go Program is still going strong, thanks to your participation and helping me spread the word.
Come by any time between 11:00 AM and 2:00 PM and bring a friend!
Sincerely,
| Ready2Go Open House |
When: Monday, November 26, 2001 11:00 AM-12:00 PM (GMT-06:00) Central Time (US & Canada).
Where: ECN1841 *~*~*~*~*~*~*~*~*~* Meeting Agenda Project status/update Home page a.
Logo b.
Colors c. Background Security - Roles & Privileges Data Model *************************************************************************************
| Project Status |
Master Netting Group: I just want to personally thank all of you for all of your hard work the past few weeks in addressing our counterparties' requests for Master Netting Agreements.
We have been able to sign up a number of them as a result of your efforts and have managed to keep certain counterparties from cutting us off in trading.
Thanks again for your efforts and for putting up with one fire drill after another!
Hopefully we all learned alot in the process.
| Message from Carol St. Clair |
Although this is definitely not the best way to announce it, today is my last day at Enron Canada Corp. and I wanted to let you know that it has been a real pleasure working with you over the last couple of years.
I apologize for letting you know by e-mail instead of giving you a call.
Unfortunately, the mechanics of my employment change required me to avoid phoning you all earlier.
Just so you know, I am returning to my old job in the world of private practice at Bennett Jones LLP here in Calgary.
I do not have my new e-mail address or phone number yet but you can reach me at the main switchboard at (403) 298-3100 starting December 3, 2001.
My mugshot, direct line and e-mail address should be appearing on the Bennett Jones website (www.bennettjones.ca) within the next month.
In the meantime, I will be taking a couple of weeks to spend with my wife and 3 month old son Jimmy.
I wish nothing but the best for you and if you ever find yourself in the Great White North of Calgary, please give me a call.
All the best,
| Personal News |
Mr Fletcher: Per the request of David Jones, attached please find a revised version of the Master Firm Purchase/Sale Agreement between Enron North America Corp. and Yankee Gas Serives Company with incorporates your comments.
Also attached is a letter amending the Letter of Understanding which moves the deadline for entering into definitive agreements to December 3, 2001.
Please secure execution of the letter and return to Jeff Hodge at fax number (713) 646-3490.
He will secure execution on behalf of ENA and fax you the letter.
Should you have any questions, please page me at (713) 761-4336.
| Documents |
Jeff: I realize that there is nothing anyone can say right now that can improve t= he situation, but I can only imagine what you have been through the past fe= w weeks as the Company virtually went into a financial free fall.
While I = think the Dynegy deal was the only real alternative that we had to work wit= h under the exigent circumstances at hand, I can imagine how painful this w= hole thing must be for you in light of your longevity with the Company and = everything you have built there from a professional standpoint.
It almost = has seemed surreal each day watching the Company's financial condition dete= riorate so suddenly; as I watched everyday's new developments, I kept refle= cting on the fact that it was only a bit more than a month ago that you and= I were speaking with one another at the EWS Legal Conference with virtuall= y no hint of what was to come.
Although we have not worked directly togeth= er much over the past few years, I feel like I know you pretty well "throug= h" all of the many EWS lawyers that I work with and frequently "bumping" in= to you in the hallways "on 38".
It always has been fairly apparent to me h= ow much effort, thought and sweat equity you have put into EWS and the EWS = legal group and I have always considered you one of the pillars of the EWS = legal group.
From my standpoint as well, in light of the extensive working= relationship I have been fortunate to have with Enron and many of its lawy= ers over the past 6-7 years, it has been very hard to witness the Company's= difficulties and the relentless barrage of negative news and publicity eve= ryday in the Wall Street Journal and the New York Times, particularly since= I know that virtually everyone I have worked with at the Company is of the= highest caliber, character and integrity.
To see the Company tarnished h= as been vry tough to watch.
Although it may be hard to see it right now, l= et's hope that some good comes out of this incredibly difficult situation a= nd that the integration with Dynegy goes well.
I would think that your ski= ll set would be valued highly by Dynegy, particularly in light of its heavy= focus on gas and power trading.
Hang in there, Jeff.
Perhaps the next ti= me I am in town, we could catch up for lunch again.
Best regards.
| Are you hanging in there? |
There will be a meeting Wednesday, Nov. 28th from 1:00 to 2:30 in ECS- 06100 (new bldg.)
Subject is "Deal" Contract Process.
Please contact Lisa Lunz if you are unable to attend.
Thanks!
| Mtg. - Deal Contract Process |
Attached is Enron North America Corp.'s suggested revisions to your pro forma confidentiality agreement.
Please review and let us know if the suggested revisions are approved.
Thanks for your help,
| Confidential Agreement Revisions -- Rio Bravo Pipeline Open Season |
Attention Blackberry User: You are receiving this notification to alert you that e-mail services to your Blackberry device will be unavailable between the hours of 8:45 a.m. and 12 midnight CST on Sunday, November 25th for maintenance.
During this outage, email services to the Blackberry handheld will be interrupted, however, pin-to-pin paging will not be affected.
If you have additional questions regarding this outage, please contact the North American Resolution Center at 713-853-1411.
Thanks for your cooperation and understanding, Enron Global Messaging
| Blackberry Outage |
Congratulations go out to the Cartel for winning this year's Superbowl.
The Cartel beat the River Rats with a final score of 87 to 73.
Everybody who won money this year go bug Matt about it as I am not handling the finances of the league!
Scott while your collecting your money, tell Matt to get your name put on the trophy.
Eric ****************************************************************** This email and any files transmitted with it from the ElPaso Corporation are confidential and intended solely for the use of the individual or entity to whom they are addressed.
If you have received this email in error please notify the sender.
******************************************************************
| Congratulations to the CARTEL! This year's COLFFL Superbowl Champ ion! |
Jeff, I work with Jennifer Fraser and was asked to contact you with regards to a fuel oil call that we sold Hydro Quebec a while ago.
I would like to find out whether or not we are in the notification period (I think we are) and what kind of paper work that needs to get done if we are.
Regards,
| Hydro Quebec |
I have some of your mail and I am not sure of your location.
If you would like to stop by ESC06406 and pick it up or give me a call and I can forward it to your assistant that would be great.
Thanks,
| Mail |
In the course of negotiating a master close-out netting agreement with J Aron/Goldman Sachs, they have now requested that after signing the Netting Agreement that we turn our attention to negotiating a Master Gas Purchase and Sale Agreement (I assume two, one for US and one for Canada) to replace the GTCs currently used for the US and Canadian trades.
Tanya: Could you have the appropriate person in Credit prepare a credit worksheet so Jeff/Peter's teams can prepare the draft Masters?
Thanks, Alan
| J Aron Gas Master |
Just wanted to check to be sure you have all of the following in your shop for responses: 1.
ExxonMobil 2.
Blake & Belden 3.
US Dept of Interior 4.
Newark Group Also, Bill wants to change the standard response letter (and redo Total Fina Elf letters).
He no longer is comfortable making the last statement.
Please give me a call to discuss.
Thanks for your help.
Tanya
| Letters of response |
Kevin, Attached please find an intial draft of a purchase and sale agreement for the MEGS pipeline (Project Pluto).
The document is based on the form of the agreement that was used when we purchased the asset.
For review purposes, I have also included a comparison version to show the differences between the agreements.
There are several issues that we need to discuss.
As a summary, these include: - In the purchase and sale agreement, you will note areas (e.g., the recitals, schedules and exhibits) where I have noted that further text remains to be drafted.
In particular, we need to discuss those schedules that identify what documents and contracts we have disclosed to Duke, given that LJM at one point in time was the indirect beneficial owner of this asset through it's one time ownership of MEGS LLC (see Section 3.15 disclosure statement); - Sections 2.2, 3.10 and 11 require Jerry Seade's tax review; - Whether for credit purposes, we need some form of payment guaranty / commitment letter from the parent company of Duke Energy Field Services (see section 7.4(g)); - The assignment agreements that will be required for the Gathering, O&M and Guaranty Agreements.
Per the terms of the Gathering and O&M Agreements, no counter-party consents are required; however, a consent will be necessary for the Guaranty Agreement.
I would suggest that we try to meet later this afternoon to discuss this agreement (I am tied up until 1:30 or so.)
Thanks.
Comparison Version:
| Asset Purchase and Sale Agreement for MEGS Pipeline (Project Pluto) |
Enclosed is a Master Firm worksheet for J. Aron.
This agreement is between ECC and J. Aron.
There appears to be no physical gas traded with ENA.
Give me a call with any questions.
Thanks,
| J. Aron Master Firm |
Attached is a list of RSVP's I have received so far for the seminar.
Already we have 44 attendees, not including LLGM attorneys.
If you see that anyone you invited and know is coming is missing from the list, please let me know.
And please continue to forward me any RSVP's that you receive.
| Cyber seminar responses |
Jeff: here's the SOCO netting agreement that I've negotiated with Rob Markham for physical power.
please give me a call with any questions.
Note that I followed up on the power receivable when I negotiated this agreement and will forward the executed agreement to Lech Kalembka so that he can take care of filing any required financing statements.
leslie
| SOCO Netting Agreement |
Good Afternoon, The following two counterparties are requesting a netting agreement with ENA: Kennedy Oil, and Independent Production Company, Inc.
The netting agreement should cover physical sales and purchases, and MTM.
These are both standard netting agreements, not master netting.
Both companies sell us gas under a first purchaser agreement and / or GTC's, and will begin buying back gas.
For Independent the contract # is 96023736, and for Kennedy 96052164.
I have contact names and phone numbers if you need them.
Give me a call with any questions.
Thanks,
| Independent Production & Kennedy Oil |
PLEASE NOTE THAT THE MASTER NETTING MEETING WILL BE AT 11:00 (CDT) RATHER THAN 10:00 AT ECN 791.
SORRY FOR INCONVENIENCE.
Esmeralda, please be sure we keep conference room until 12.
Thanks.
| READ! CHANGE OF TIME FOR MEETING: MASTER NETTING |
We are buying the following Tenn transport from the pipeline for the winter.
I just did the deals so I don't have the contract numbers.
Term Demand Comm MDQ Nov .18 .02 3893 Nov-Jan .20 .02 2500 Feb-Mar .20 .02 2500 The Primary delivery point is CGAS - Broad Run.
The primary receipt point is meter #010698 in 500L.
We will be able to use any zone 1 receipt point but we only be able to use Broad Run as our delivery point.
| Tenn Transport |
Congratulations go out to the Cartel and the River Rats who both advance to the Superbowl game next weekend.
Eric ****************************************************************** This email and any files transmitted with it from the ElPaso Corporation are confidential and intended solely for the use of the individual or entity to whom they are addressed.
If you have received this email in error please notify the sender.
******************************************************************
| COLFFL Superbowl Game! |
EFFECTIVE 12/1/01 - RB Robertson & Sons is canceling his contract with Enron for approx 1,000/day metered production.
Reason: With fixed prices in the $3.50-$3.70 range, Roc and his investors want to lock -in for a period greater than one year.
He will sign a contract with Dominion Field Services.
| RB Robertson & Sons |
as you know back in march i restructured the commodity price for calp from tco pool gas daily avg + $0.05 to the higher gas daily posting of tco pool from either the day they actually consumed the gas or the gas daily posting two days in the future +$0.05.
as i recall at the time we talked about granting origination but couldn't figure out how to do it given calp's peaking dispatch.
i asked jim willis to calculate the savings between the two postings only the future gas daily price posted higher than the price on the actual consumption day.
the total realized savings due to my restructuring is $38,500 for the april-august time period.
i am going to have jim calculate the sep savings.
i will forward the spreadsheet to you.
as you know calp wasn't dispatched much this summer and thus the actual saving isn't huge.
however, given their intraday call rights on 40MM/d of tco pool the potential savings was tremendous.
additionally, calp is paying us an administrative monthly demand charge of $6,128.
during the course of the year i spent a considerable amount of time doing management duties as well per our agreement with them.
last year i spent 3 weeks alone creating and drafting the annual report required by the bankers.
i have spent an considerable amount of time purchasing fuel oil during the winter as they burn it and also during the summer to refill the storage tanks.
the time i have spent on purchasing oil on their behalf wasn't just a quick phone call and you're done like it is in gas.
i spent a tremendous amount of time on learning who the players are, on oil specs, scheduling, storage, pipeline allocations.
also when you buy oil you don't buy a defined volume.
you buy a volume plus or minus 10%.
i had to keep tract of oil volumes and volume resolutions.
the list goes on and on.
guess what, i have started the process again.
if you feel that these contributions are not worthy of origination, then i need to know that.
i'm going to be out tomorrow.
we can discuss on friday.
thanks robin
| calp |
John- I have been helping David Draper to review the NYSEG positions we currently have, and accurately reflect our exposure, based on LDC restrictions.
The one factor that I hope you can help with is the physical constraints in delivering gas to NYSEG off of certain pipes.
It appears as if most of our position is based upon deliveries off CNG, which I don't believe has any physical constraints.
However, we also have small positions requiring us to deliver off of TCO, Iroquois and Algonquin.
Based on the pricing I see in RGS, there is obviously some issue with delivering off of TCO in the winter.
I'm wondering if you can help explain this, as well as any other issues you are aware of here.
It's probably easiest to talk through it rather than e-mail about it, but I assumed you were trading.
You can call me at x35514 when you have some time.
(If David has already contacted you about this, let me know and you don't have to repeat yourself.)
| NYSEG |
As you are aware I forwarded and offer to VNG that included 4 transactions whereby ENA would sell quantites to Sequent.
In addition, I requested that Sequent provide ENA with an offer to serve the Hopwell transaction ( did not tell VNG that it was Hopewell, just described the general service).
Dana Grams told me last week that they were concerned about entering into an agreement to get back their assets, because they felt we may file bancruptcy at which point they would get the assets back for "free".
This is a lame excuse and I generally told him so.
I told him that we were not going to give back the assets and if he wanted them back we needed to get the same or better value to terminate our deal early.
He said they would revisit the arrangement and let me know.
I will keep you posted.
Frank
| VNG update |
In preparation for the upcoming move to Enron Center South we are moving your Home Directories to a new trading cluster.
WHAT YOU NEED TO DO: This will occur for you this EVENING after 6PM.
We will need to restart your computer in order to complete this action.
Please log out or your computer by 6PM, if the machine is not logged off we will reboot the machine in order to complete these actions.
Save your data before going home this evening.
If you have outstanding circumstances that we should address, please reply to this e-mail and we will change our schedule accordingly.
HERE ARE A FEW OF THE BENEFITS OF THIS ACTION: Newer, more stable environment More disk space available for common data Faster network connections HOW THIS WILL EFFECT YOU: If you are a laptop user and have to work at home, you should save any work to your 'C:' drive on the laptop.
DO NOT use the "My Documents" folder.
When you return to work and reconnect to the network, any changes made to files/folders in the "My Documents" folder may be deleted from the laptop.
Laptops reconnecting to the network for the first time will receive a synchronization error.
RESOLUTION: Please call the Resolution Center (x3-1411) and they will correct the problem ASAP.
We will have additional Technicians available on the floor if the Resolution Center has any problems.
| IMPORTANT! Actions this evening. |
I borrowed 19903 from Egan for today's gas day and I need to pay it back by Friday.
For tomorrow, I am going to over nominate Leach.
After the cuts, if any, I want to back off of Leach and take the gas to Egan to payback back part of my balance.
Here are the deal numbers and volumes.
Deal Current Vol After Cuts Comment 1149149 21,000 10,000 Moves gas from CGLF Leach to TCO Leach.
1143923 31,000 20,000 Mainline to Leach Transport 1143924 49,798 38,469 Onshore to Mainline - volume may be off a little, just need to balance mainline 1161116 7,707 ????
Onshore to Egan Hub transport and desk to desk.
Move the onshore balance to Egan Hub.
I may be out this afternoon.
I think we should wait until tomorrow morning to adjust these tickets, UNLESS KELLY, you feel comfortable about CGAS not allocating Leach.
Thanks for your support.
| CGLF for tomorrow |
Nelson & John, Terry Franklin has prepared an Appalachian Estimated TCo Metered Production for Nov 01 schedule which she will provide you.
This represents our attempt at calculating the origination dollars (at TCo Index + 1/4 cent) attributable to the TCo Metered Production.
I'm not exactly sure how to create a transfer from John Hodge's book to the Wellhead book for these dollars ($14,981).
Terry will also provide the same format to capture DTI metered production origination.
John
| Nov 01 - TCo Metered Production Origination |
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