input stringlengths 93 39k | output stringlengths 1 117 |
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Hi: I heard back that many of you have been unable to open the original solicitation letter I sent to you because of the links involved with the mail merge.
So, I removed the links and am resending it to you in hopes that it works this time.
I have gotten requests from many of you to resend letters via fax, etc.
to various businesses.
I am more than happy to do that for you.
Unless you tell me otherwise, in the interest of time, I am signing your names to those letters and faxing them.
However, if you want to use the attached letter on your own, feel free.
Thanks,
| Solicitation Letter |
Tracy: Attached is the revised expense analysis.
The OBA revaluation is included in the UAF number, but I am also attaching a breakout FYI.
Jan X53858
| Expense Analysis |
Tracy, Here is the Azurix information you requested.
I have not sent it to Corp so you need to include it in your information.
Let me know if you have questions.
Jeff
| Information Request |
Tracy For VP level & above, I had the team pull by individual a recap of payroll information from SAP.
This extract shows all the "current" payroll buckets that contain some type of reportable compensation.
We then took that information & broke it into "fixed " and "variable" pay components.
The attached spreadsheet provides you an individual/job group summary for the "fixed" vs. "variable" pay components on a consolidated basis.
The "variable" pay amounts include ad-hoc payments for options, annual/retention bonus payments, tax settlements/refunds, etc.
Based on our conversation, my sense is that for budgeting purposes, you will need to utilize the "fixed" total amounts.
PLEASE NOTE - while the "fixed" pay components have been annualized, the "variable" pay components represent only those amounts recorded in the payroll system to date.
Also, I understand there may be changes to the flex dollar amounts - but I do not yet know the details.
I've checked with Executive Compensation to determine whether there might be a change in the Flexperq amounts - am still waiting for input.
I will advise you of any changes I hear with regard to these elements.
Additionally, on the fixed side, you should also budget some merit dollars - I would suggest 4-5%.
We do not know the amount yet - but I think that should be consistent with past practice.
Tracy - if you need anything else, please let me know.
REgards/JD
| VP/Above - 2002 Budget |
November 20, 2001 HOLIDAY COUPONS FOR OUR PREFERED PAST CUSTOMERS!
********************************************* Tracy, This is our third holiday season here at WickedCoolStuff.com and we would like to take this moment to express our thanks to you for being one of our loyal customers.
Read on!
Later in this e-mail there are some valuable coupons...
But saving money isn't the only reason to visit us!
Check out: 1) HOLIDAY HAPPENINGS 2) NEW STUFF!
3) CHRISTMAS ORNAMENTS 4) THE COUPONS 1) HOLIDAY HAPPENINGS This year WickedCoolStuff.com is proud to welcome Jingle Belle, Santa's teenage daughter, as our holiday host!
Jing (as she's known to her friends) puts her own twist on her Dad's holiday traditions... And we like anyone who's twisted!
Check out Jingle Belle's Online Comics, Jing's Gift Guide and, of course: The Jingle Belle Wacky Wobbler!-- A Wicked Cool Exclusive!
| Wicked Cool Holiday Coupons! |
I had a meeting with Dan Pribble and Barney Brasher this morning reviewing the current status of the TW Operation forecast.
It appears, at this point in time, that we have been able to clear up and cover all the unplanned expenditures, except for a remaining stretch of approximately $1,000,000.
We are working with all entities within ETS Operations on NNG and TW to find ways and means to cover this remaining stretch between the two companies (TW) and (NNG) during the month of December.
Since late October, Barney and his team have uncovered expenses on TW in the amount of approximately $3 million that was not covered in the Fourth Quarter forecast.
We have cleaned up all but the remaining $1 million.
Dan and Barney have both held meetings face to face with the parties involved in forecasting, or lack of it, and are implementing corrective actions.
We really appreciate the massive effort all personnel are taking to help alleviate this situation and we within OSS have implemented tighter controls and reviews on all the Business Units.
We will initiate weekly flash reviews and monitor closely the processing of all expense invoices during the month of December.
If you have any futher insights of means to relieve this situation, please advise.
Morris
| TW Forecast |
This is the final of the files.
It is the middle dates 2002 Plan Forecast file.
Again, look at the "Summary" tab.
If you have any questions about the files, please call me on my cell phone at (281) 639-6125.
I will turn it on after this final e:mail is sent.
Jeanette Doll
| #4 - files you requested |
For those outside of the Houston office, I forgot to provide the call in bridge number for our meeting on Thursday at 10:00 AM.
The call in number is: (800)711-8000, user code 8536845.
Thx, Ron
| Property User Group Meeting |
Mary, I'm sending this on Kim's behalf since her Outlook is overloaded.
Please see attached schedules for Operations and OSS.
We have not reduced our expenses from Plan at this point.
With the reorganization, we are not comfortable reducing our costs until we have completed a thorough analysis.
If you have any questions, please call Kim or me.
Thanks, Elaine
| O&M Estimates |
When: Tuesday, November 27, 2001 2:30 PM-3:30 PM (GMT-06:00) Central Time (US & Canada).
Where: Conf.
Room Oma 525 *~*~*~*~*~*~*~*~*~* We have several questions regarding the remaining work that needs to be done to complete NBP's O&M models in Adaytum, ETS progress on its O&M models in Adaytum and getting actuals into Adaytum once the O&M models are completed.
Tracy -- Please let me know what phone number to use to reach the Houston attendees and I will initiate the conference call.
| Update on NBP's Progress with Adaytum |
How does this look?
Also, I did change some numbers in the excel spreadsheet: The Ignacio to Blanco subscription levels were pulling from the row excluding ROFR capacity in the supporting sheet.
I changed it to be consistent with the other capacities (which include ROFR capacity).
Shelley had made some assumptions about East of Thoreau capacity subscription, such as, the USGT 400,000/d contract would remain subscribed (it doesn't have ROFR) and she had included the extension of 2-3 other contracts that don't have ROFR.
These contracts were then dropped after 2005.
I continued the extensions through 2006.
I changed the East of Thoreau capacity to 750,000/d from 850,000/d.
| Capacity Subscription Strategy |
Per the conversation in Steve's staff meeting yesterday, I double checked with Property Accounting and they verified that the funds in the amount of $291,861 were released on 11/6.
If there is anything else you need, please let me know.
Thanks!
| Agave I/C |
Tracy: I did a preliminary Weekly for Steve since he will be on vacation the rest of this week.
I will do another one tomorrow.
Just wanted to give him a look at where we are since we did not do a Weekly last week.
Please review and if it is OK I will give it to Steve.
Thanks!
| TW Weekly for November 30, 2001 |
Tracy, Would you please let Palu know if you have any changes to the bullets.
I am going to leave her a message and ask her to post them tomorrow.
Thank you,
| Weekly Bullets - TW COMMERCIAL SUPPORT TEAM |
Hi, Attached are some of the questions we would like to chat about in our meeting.
Omaha folks, I'll bring a copy to the meeting.
Thanks,
| Questions for the meeting @ 2:30 |
Tracy, Omaha needs me to be onsite to help them complete there O&M model.
Rita was able to help them make the model changes they required, but they need someone to explain and train them in the use of the entire model and dataflow.
I am planning on spending next week in Omaha.
Please let me know if you have any concerns.
Hoang Vo
| Omaha |
Hi Tracy, I've been thinking of you since Enron's in the news all the time now.
I bet it is stressful around there now.
How are you doing?
How was your Thanksgiving?
We were in Houston last weekend after Thanksgiving & took my parents to Galveston for the weekend.
Dylan got his first ear infection so I wasn't able to see anyone but Stephanie.
Email me back.
Bye, Dana
| Hi Tracy! |
Hello Tornado Parents, Attached, is the Game schedule for our U-7 Tornados team.
As you an see most of our games are on Friday pm and I think three of them are on Sat mornings.
For the games, try to mark your calenders so you arrive at least 15 min.
before the start of the game.
The kids have been great and we are really going to have some fun.
Thanks for signing them up for soccer.
I'm really looking forward to a good season.
| Tornado's Game Schedule |
I met with Rod this morning and he reviewed and revised the category of the capital projects.
Please see attached spreadsheet for the new information.
Once again I will let you determine how you want to present the number on the capital form so you can account for rounding for the different projects.
Sorry this is even later but I am working as fast as I am able.
I am preparing booklets with the capital project write ups for each functional area and will have them to you today.
Steve I will work with you on how you want to handle.
cvb
| Capital Projects |
Hi everyone.
I have yet another request for which I need your input.
Causey is reviewing his budgets/direct reports, and would like to get the most current headcount numbers for the accounting groups in your business unit(s).
What I mean by accounting groups includes everyone whose superior ultimately reports to Causey.
For instance, this would include the traditional Accounting/Reporting departments, Tax departments, and Transaction Support departments.
It should NOT include any settlements/mid-office groups (for example, Sally Beck's world).
I say "department" because I don't want just accountants, but everyone who is in that dept, i.e.
admins, clerks, etc.
If you have a question on any unique situation, please just give me a call and we'll discuss.
The data needs to be as recent as possible.
Hopefully, I can get this as of July 31/August 1.
If you have more recent data, that would be great.
At a bare minimum, I need total headcount as described by group (acct, reporting, tax, etc.)
It would also be useful to get as much detail as possible, i.e.
by sub-group, by personnel level, etc., but I know that may be a challenge given the timing of the request.
Additionally, if you can provide me with a "current estimate" for the groups you report, that would be ideal.
I know that the official CE doesn't go to that level, but I'm betting that most of you have something that projects your G&A by cost center (or group/dept) for 2001, as of the 2nd CE.
The headcount information is a must have, and the 2001 cost estimate is secondary, although I'd like to ask everyone to strive to provide both.
If you can't provide estimated costs for the groups you report, please call me so we can discuss.
Speaking of the timing, I need this by Wednesday, August 29 at 12 noon.
This will be given to Rick on Thursday morning, so I'll need some time to consolidate the data and to ask you all any further questions.
If you have any questions, please give me a call.
Thanks,
| Request: Current Headcount |
Tracy is losing most of her TW team to other jobs.
Palu is going to Opera= tions Support for a promotion, Jeanette Doll is going to the Rates crew and= Jan Moore has expressed a desire to make a change as well (I think I have = those all straight).
I would like to consider this a development opportun= ity for someone on the high potential list to see what they can do in a dif= ferent role.
The role is important as it is the key representative of ou= r group facing the TW commercial team full time, Tracy needs to be able to = count on this person to lead when she is not available.
The names that co= me to mind off that list are Henry Baker, Dana Jones, Sophie Patel, Greg Sc= hlender, Deelyn Pool, and Robert Geheb.
I would like Tracy to interview= these people (by phone if necessary) and to decide who should be offered = this opportunity.
If there is someone on this list that you no longer su= pport as a high potential employee, please let the group know ASAP.
If th= ere is someone else on the list that we need to consider please let us know= as well.
For Brian and Laura: Could you make any recommendations from the ETS lists?
| Personnel Requirement |
I just wanted to confirm the timing on the third current estimate.
We are planning to send this the week of the 17th, as early as possible in the week.
For October, we will be sending the normal monthly cash flow forecast.
Let me know if this is ok with you, thanks!
| 3rd current estimate |
Attached is a file showing depreciation for NNG Commercial after excluding depreciation for the capital dollars associated with rate case settlement (lines 13-16).
The 2002 depreciation is calculated to be $4.379 million.
I think philosophically it s a good idea to track capital projects within NNG Commercial based on the life of the contracts used to justify the project.
I don't think Neubauer is quite there yet.
My concern is that we have developed an IBIT target for 2002 by using a 2001 number that does not include depreciation.
It seems that we ought to offset the 01 starting point by the amount of the 02 depreciation.
Lets talk further with Rod.
| Depreciation |
Well, that didn't work.
Neither Thursday nor Friday at 2:00 will work.
I'll try one more time for this week.
Please let me know by noon, Thursday if you can not make any of these times: 9:00 CST, Friday, 8/31 10:00 CST, Friday, 8/31 11:00 CST, Friday, 8/31 I will send a note by end of day, Thursday confirming the time and giving the dialing information.
Thanks,
| La Plata to Bloomfield Drag Reducing Agent Conference Call |
Below are the times for the O&M/Capital Review with Stan scheduled for Wednesday, September 5, 2001 in EB49C2.
Commercial 8:30 - 9:30 AM Gas Logistics 9:30 - 10:00 AM Information Technology 10:00 - 10:30 AM Operations 10:30 - 11:30 AM Northern Border Pipeline 11:30 - 12:30 PM Legal, HR, Reg Affairs 12:30 - 1:00 PM F & A 1:00 - 1:30 PM If for some reason there is a problem with your appointed time please send Tracy Geaccone or myself an email.
Thank You,
| O&M/Capital Review with Stan |
Your Offered Servcie is setup on Transcontinental Gas Pipe Line Corporation.
Service Class - Transportation Pathed Rate Schedule: FTA-R Firm Any problems, please call me.
Marlene D. Hilliard
| Offered Service |
BUSINESS HIGHLIGHTS Enron Industrial Markets EIM has recently formed a Forest Products Origination team led by Rob Saltiel to pursue structured transactions.
Typically, these deals employ a combination of physical supply/offtake, price risk management and/or finance to bring value to Enron and our customers.
Priority commodities include pulp, newsprint, recycled papers, linerboard, and lumber.
Response to the new team's efforts has been positive, as many of the Forest Products companies have needs for commodity and capital solutions that are currently unavailable.
Enron Freight Markets During its first month in the over-the-road (OTR) trucking business, Enron Freight Markets has completed over 120 spot OTR trades.
On Friday, March 18, there was a shortage in the Houston outbound market and capacity was selling for $1.65 per mile.
By comparison, average market price has stayed in the $1.05-$1.10 per mile range in recent weeks.
EnronOnline On May 23, Enron Corp. announced that it completed its one-millionth transaction on EnronOnline, the world's largest web-based e-commerce platform for commodities.
As an online extension of its successful wholesale energy business, EnronOnline began transacting natural gas and electricity on November 29, 1999.
Since that time, the company has extended the platform to approximately 1500 wholesale commodity products ranging from energy-related commodities to bandwidth, metals, forest products, plastics, petrochemicals, and weather and credit derivatives.
Approximately 60 percent of all Enron transactions are now conducted online, and the cost of processing the transactions has been reduced by 75 percent.
EnronOnline Statistics Below are the latest figures for EnronOnline as of May 23, 2001 ?
Total Life to Date Transactions > 1 million ?
Life to Date Notional Value of Transactions > $600 billion IN THE NEWS Enron Corp. Chief Executive Officer Jeff Skilling likes to say that the nation's leading energy merchant was ready for the Internet long before there was anything.com.
Enron's business of buying and selling commodities - by phone or fax - was a natural fit for the Web.
The challenge now is to get the new broadband Internet trading unit on solid footing by proving that bandwidth can be traded like a commodity.
BusinessWeek e.biz/May 14,2001.
WELCOME New Hires EGM - Gregory Sharp, David Cho EIM - Rosie Carrizal-Moulinet, Thomas Mathieu ENA - John Poppa, Brandy Powell Transfers (to or within) EGM - Rhonna Palmer NUGGETS & NOTES Travel tips of the week: 1) Fly Coach.
Elite members of frequent flyer programs are often upgraded to first class at no additional charge.
2) Consider Alternate Airports.
If you live within driving distance of two or more airports, examine fares for each airport carefully.
Sometimes special fares are offered for flights into specific airports.
LEGAL STUFF The information contained in this newsletter is confidential and proprietary to Enron Corp. and its subsidiaries.
It is intended for internal use only and should not be disclosed.
| EnTouch Newsletter |
Rita, Tennessee pipeline has provided us with a summary of volumetric balances per contract.
We are currently trying to work with them to clear out these imbalances and/or parked gas that is on their system for ENA and ENA Upstream.
I will provide a copy of the summary for you when you return.
Can you please review our data and verify if we have the same numbers and what dollars, if any, we owe for the specific volume amounts that are in question.
Thanks for your help.
| Tenn Pipeline - Volumetric Balances |
Happy Over the Hump Day, Unfortunately, ISS is unavailable today.
The attractive pricing we are seeing is generating maximum firm injections.
IT is available and I can move 100,000dth between Niagara and Leidy.
A number of other paths are open and I am ready to work with any of you on a particular path of interest to your market.
| Capacity as of May 30th |
Would you prefer to do a June conference call as opposed to a meeting?
We have the 19th and 21st available for a meeting at the Marriott, but if schedules are hectic, the conference call seemed to work nicely.
Thanks!
| Meeting or phone call |
Begining 6/4/01 most North American Gas and Power quotes will be displayed on and transactable from the TRUEQUOTE trading platform.
Please call me if you have any questions or need more information.
Thanks.
Savita X31787
| EnronOnline Quotes on TRUEQUOTE |
Hi Everyone, I am in the process of updating my Capacity Release Offer notification listing.
Please provide me with the following information: Name Company Telephone No.
Fax.
No.
E-mail If you no longer require notification of KeySpan's Capacity Offers, but would like to recommend someone else, please let me know.
Thanks, Anne
| Updating Capacity Release Offer Listing |
Sharathon 2001 The dates for Sharathon are Thursday, July 12, Friday, July 13, and Saturday, July 14.
Sharathon will begin at 6am on Thursday morning and will end on Saturday at midnight.
*Please arrive 30 minutes before your shift begins.
Volunteer[PARA]Duty Description[PARA] Thursday[PARA]Shifts[PARA] Friday[PARA]Shifts[PARA] Saturday[PARA]Shifts[PARA] Age[PARA]Requirement[PARA] [PARA][PARA] Answer Phones Answer phone line and write pledges on pledge forms 6am- 10am[PARA]10am-2pm[PARA]2pm-6pm[PARA]6pm-10pm[PARA]10pm-2am[PARA]2am-6am[PAR A] 6am- 10am[PARA]10am-2pm[PARA]2pm-6pm[PARA]6pm-10pm[PARA]10pm-2am[PARA]2am-6am 6am- 10am[PARA]10am-2pm[PARA]2pm-6pm[PARA]6pm-12am[PARA] Must be at least 21 years old.
Data[PARA]Entry[PARA] Enter information from pledge forms into computer.
[PARA]*Minimum[PARA]typing speed [PARA]of 45 WPM 10am-2pm[PARA]2pm-6pm[PARA]6pm-10pm 10am-2pm[PARA]2pm-6pm[PARA]6pm-10pm 10am-2pm[PARA]2pm-6pm[PARA]6pm-12am Must be at least 21 years old[PARA] Batch[PARA]Preparation Get monthly and one-time totals by adding up amount on pledge forms.
[PARA]*Must know 10key by touch.
8am-10am[PARA]10am-2pm[PARA]2pm-6pm[PARA] 6pm-10pm 8am-10am[PARA]10am-2pm[PARA]2pm-6pm[PARA]6pm-10pm 8am- 10am[PARA]10am-2pm[PARA]2pm-6pm[PARA]6pm-12am Must be at least 21 years old[PARA] Mail[PARA]Room Stuff envelopes and file them in alphabetical order.
10am-2pm[PARA]2pm-6pm[PARA]6pm-10pm 10am-2pm[PARA]2pm-6pm[PARA]6pm-10pm 10am-2pm[PARA]2pm-6pm[PARA]6pm-10pm Must be at least 16 years old.
[PARA] Prayer[PARA]Warrior Pray in the KSBJ Chapel for Sharathon 6am- 10am[PARA]10am-2pm[PARA]2pm-6pm[PARA]6pm-10pm[PARA]10pm-2am[PARA]2am-6am 6am-10am[PARA]10am-2pm[PARA]2pm-6pm[PARA]6pm-10pm[PARA]10pm-2am[PARA]2am-6am 6am- 10am[PARA]10am-2pm[PARA]2pm-6pm[PARA]6pm-12am[PARA] Must be at least 18 years old.
[PARA][PARA][PARA] Tour Guide Give tours of the KSBJ studios.
10am-2pm[PARA]2pm-6pm 10am-2pm[PARA]2pm-6pm 10am-2pm[PARA]2pm-6pm[PARA] Must be at least 18 years old.
[PARA] Frequently Asked Questions 1.
HOW DO I SIGN UP?
Fill out registration form below.
2.
Can I bring my child with me during my volunteer time?
Unfortunately we do not have daycare.
So we ask that you do not bring your children with you.
If you have a teenager that is 16 years old or older, they will be able to work in the mail room but they must sign up.
3.
Can our church group volunteer together?
Yes, as long as space is provided.
So sign-up asap.
4.
Do I have to sign-up before Sharathon or can I just show up?
You must sign-up ahead of time.
5.
How long are the shifts?
Most shifts are 4 hours long with the exception of the last shift on Saturday which is 6 hours long.
We ask that you arrive 30 minutes before you shift starts so you can be trained.
6.
Can I volunteer in more than one area?
Yes, as long as you sign-up for them before Sharathon.
7.
When my volunteer time is over, can I volunteer for another shift?
No due to limited space in our building.
However, if you want to sign-up ahead of time for more than one shift, you may.
8.
Do I have to stay for the complete 4 hours shift?
Yes, we expect you to stay for the complete shift.
However, we do want you to have an enjoyable experience.
So you will get refreshments and breaks when you need them.
9.
Can my spouse and I volunteer together?
Yes as long as both of you sign up.
10.
I have never volunteered before will there be training?
Yes.
We ask that you arrive 30 minutes before your shift begins so that you may be trained.
11.
Can I bring my spouse, a family member or friend with me when I volunteer?
If they have not signed-up to volunteer or if they are not going to volunteer during your shift, we ask that you do not come with you due to limited space in our building.
12.
I have volunteered for several Sharathons, do I have to arrive early for training also?
Yes, because there have been a few changes this year due to EFT(Electronic Funds Transfer).
However, if you would like to train others, please let us know when you sign-up and we will have a special training session for you.
13.
I am unable to make it to KSBJ, can I volunteer from my home, church, or a different location?
No, all Sharathon volunteers must come to the KSBJ studios.
However, you can pray wherever you are at for the KSBJ staff, volunteers, and listeners.
14.
Where do I go, when I get to KSBJ?
Go in front doors of KSBJ, sign-in at the front desk.
Put on a name tag.
A KSBJ employee will be there to instruct you where you need to go.
15.
Where is KSBJ located?
KSBJ is located in Humble, TX.
The address is 327 Wilson Road, Humble, TX 77338.
From Hwy 59, take the Bush Airport/Will Clayton Parkway Exit.
Go east on Will Clayton Parkway to the second light.
(The second light is at the corner of Will Clayton Parkway and Wilson Road) Make a left on Wilson Road.
KSBJ is located on Wilson Road, on the right just pass the first light.
Sharathon Registration Form Name: Date Submitted: Daytime Phone Number(s): Email address: Schedule available to work: Volunteer Duty: *If you have any questions, please call Charlotte at (281)446-5725 ext.204 or send email to cestrada@ksbj.org.
| Sharathon Reminder |
HAPPY Friday (Go Devils).......... No Interruptible storage on our system for the weekend.
The rising temperatures are eating into our excess injectibility.
Interruptible transportation is available.
I realize that the spread between Niagara and Leidy is tight in June but July basis has been attractive.
I am able to set up contracts for next month now.
Have a great weekend.
| Capacity for June 9-11th |
Hello Chris: I am just curious to find out if you are planning to release the 35,465 dth back to Boston Gas this month.
Please let me know.
Thanks.
Ivy
| Capacity release |
Steve, This email is to notify Columbia Gas Transmission of Enron North America's intention to exercise our right of first refusal for the subject contract.
By this notification, Enron does not agree to continue the agreement beyond the current expiration date or match the highest value bid in any subsequent auction.
If you have any questions concerning this notification, please feel free to call me at (713) 853 - 7276.
Thanks for your help,
| FTS Agreement 67207 |
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 |
You have an electronic contract awaiting your review and execution.
Use the Execute Electronic Contracts screen to print and electronically execute a Request(s) for service To Print/Execute Electronic Contracts: 1.
Click on the Contracts folder 2.
Select the Execute Electronic K from the Contract Administration Drop Down menu 3.
Select the service requester from the Service Requester drop down menu 4.
Choose the print option of either View Later or E-mail.
4a.
If View Later is selected then the contract can be printed from the Utility folder: View Report Selection 4b.
If Email is selected then the contract will be emailed to the address displayed in the Email Address Field.
This field will default to the email address currently associated with the Navigator Id that is currently logged on the system.
You may change the designation of where the contract is to be sent by typing in a different email address 5.
Click on Retrieve 6.
To print a contract, place a check in the Print Contract select box beside the Bid/Request No.
that you want to print 7.
To execute your contract, place a check in the Execute select box beside the Bid/Request No.
that you want to execute.
Note: It is strongly recommended that you print your contract prior to execution.
You can select the print option independent of the execution option; that way you may review the printed contract then if the terms were agreeable, return to this screen to execute the contract 8.
Click on Submit.
8a.
After the contract is executed the screen will display the contract number assigned and the date it was executed 8b.
The executed contract information will be displayed on the screen for one full day following the date it was executed Note only those Navigator Ids with execution authority may electronically execute a contract.
The contract must be executed before the "Execute by Date" expires.
This document was created by TCOAPPS in the DB2P subsystem in job IPAT0100, job number 06687, program AT12000
| Columbia Contract Awaiting Your Execution |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES OCTOBER 26, 2001 Notice ID: 3218 5 - NO RESPONSE REQUIRED SUBJECT: REVISED-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 33975 FTS Leach Market Area 6 33974 FTS D3 Market Area 3 33976 FTS Leach Market Area 8 33978 FTS AO5 Market Area 36 33958 FTS Leach Market Area 5 33959 FTS Kenova Agg Market Area 5 33960 FTS Lebanon Market Area 6 33961 FTS Leach Market Area 8 33962 FTS Kenova Agg Market Area 8 33973 FTS Leach Market Area 9 33963 FTS Leach Market Area 9 33964 FTS Leach Market Area 10 33965 FTS Leach Market Area 10 33966 FTS Leach Market Area 12 33967 FTS Leach Market Area 15 33968 FTS Leach Market Area 15 33969 FTS Leach Market Area 19 33970 FTS Alexander Agg Market Area 32 33971 FTS Highland Market Area 38 34041 FTS Crossroads Market Area 1 For additional information, please contact your Account Representative or your Customer Services Team.
| TCO-REVISED-AUCTION OF FTS CAPACITY |
max, Sorry I don't understand the invoices.
I can help with contract pricing for the supply agreements for the plant.
Maybe Rick Hill can help.
He is very knowledgable on this plant.
Call me at 37177 and I can discuss the supply agreements.
Robin
| tenaska invoices |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES OCTOBER 25, 2001 Notice ID: 3214 5 - NO RESPONSE REQUIRED SUBJECT: CAPACITY ALLOCATION-TIMELY NOMINATION CYCLE FOR OCTOBER 26, 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 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 October 26, 2001.
You may now view the quantities you are authorized to flow on October 26, 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 Thursday, October 26, 2001.
If you have any questions, please contact your Account Representative.
| TCO- CAPACITY ALLOC-TIMELY NOMINATION CYCLE OCT. 26, 2001 |
COLUMBIA GULF TRANSMISSION COMPANY NOTICE TO ALL INTERESTED PARTIES JUNE 24, 2002 Notice ID: 3845 5 - NO RESPONSE REQUIRED Columbia Gulf Transmission is auctioning 47,395 dth/d of onshore firm capacity from Venice to Rayne, Louisiana at CGT's maximum onshore FTS-2 transportation rate.
This capacity will be available July 1, 2002, with bids due by 2:00 p.m. (Central Time) on June 24, 2002.
Details of this capacity auction may be found in the Columbia NAVIGATOR system under the capacity release folder, offer number 36798.
For additional information please contact Janice Felton at (713) 267-4210 or Martha Blake at (713) 267-4213 or Brian Lamb at (713) 267-4251.
| CGT - FTS-2 Capacity Auction |
I guess we all do care about the AGA number.
If the number is low due to the increasing difficulty companies are having injecting gas, I believe it.
Our system is very full right now.
Therefore, no excess injections for tomorrow.
IT through Concord for 100,000 dth.
Excess withdrawal's and IAS gas is available for 100,000 dth.
| Capacity for the 26th |
Dear Colleague: Are you keeping up to date on plant outage information - nuclear or fossil - now that the Nuclear Regulatory Commission status report is no longer being published?
Here is the plant outage information you would have received on Energy Argus in the last two weeks.
If outage information is important to you, please contact info@energyargus.comfor more information!
Date Time Headlines 10/24/01 14:13 ECAR Plant Watch: DPL Energy's 610-MW coal-fired JM Stuart unit 3 in Ohio now back online, a source close to the plant told Argus 10/24/01 13:56 Wisconsin nuclear plants running at reduced capacity on transmission line repairs 10/24/01 13:13 MAIN Plant Watch: Wisconsin Public Service's 535 MW Kewaunee 1 to stay off line for refueling outage until "at least Thanksgiving," a source close to the plant told Argus.
The outage began Sept. 25 and is expected to last 9 weeks for a steam generator replacement.
10/24/01 12:44 PJM Plant Watch: Exelon's 1,152 MW Peach Bottom 2 in hot standby following a main generator trip at 11:10 EST Oct. 23 due to a malfunction of a circuit panel.
Investigations are ongoing and repairs have yet to begin, a source close to the plant told Argus.
10/24/01 12:33 SERC Plant Watch: Southern Company's 900 MW Hatch 1 above 20 pct and ramping up.
Unit tripped off Oct. 23 from 100 pct.
10/24/01 12:26 MAIN Plant Watch: Wisconsin Electric's 525 MW Point Beach 1 nuclear unit remains at reduced capacity, 67 pct, due to a transmission wire reduction.
Unclear when restriction will be lifted.
10/24/01 12:18 UPDATE: MAPP Plant Watch: Xcel Energy's 570 MW Monticello nuclear unit remains off line after an automatic trip Oct. 23 caused by a worker bumping into an instrument that automatically trips the plant during a seismic event.
Details on restart not immediately available, however, a source close to the plant said that start up is not expected to take long.
10/24/01 11:39 MAPP Plant Watch: Xcel Energy's 570 MW Monticello nuclear unit shut Tuesday.
Details on restart not immediately available 10/24/01 11:30 MAPP Plant Watch: Xcel Energy's 594-MW coal-fired Allen S. King plant in Oak Park Heights, Minn. shut 10 p.m. local time Tuesday on valve problem.
Plant seen back up Thursday or Friday, sources close to the plant told Argus 10/24/01 10:24 MAIN Plant Watch: Wisconsin Electric's 525 MW Point Beach 1 nuclear unit reduced to 67 pct from 80 pct on Tuesday 10/24/01 10:23 MAPP Plant Watch: Alliant Energy's 598 MW Duane Arnold at 49 pct, rising after unplanned work Oct. 17 and repairs to pump seal 10/24/01 9:51 ECAR Plant Watch: Cinergy 625-MW coal-fired Gibson Station unit 4 shut Wednesday, sources close to the plant told Argus.
Reason, length of outage at plant near Princeton, Ind.
unclear 10/24/01 8:10 ECAR Plant Watch: DPL Energy's 610-MW coal-fired JM Stuart unit 3 in Ohio remains shut after booster pump snag late Monday.
Unit seen back up to full power by 14:00 EST, source close to the plant told Argus 10/23/01 16:20 Energy Argus Nuclear Plant Fall 2001 Refuel Table 10/23/01 12:59 ECAR Plant Watch: Cinergy's coal-fired Beckjord 245-MW unit 5, 461-MW unit 6 both units shut for maintenance.
New Richmond, Ohio's unit 5 shut early October, unit 6 more recently, source close to the plant told Argus 10/23/01 12:21 ECAR Plant Watch: DPL Energy 610-MW coal-fired JM Stuart unit 3 in Ohio shut late Monday on booster pump snag, may be back by early Wednesday.
610-MW unit 1 shut Oct. 19 for two weeks of work, source close to the plant told Argus 10/23/01 12:07 MAIN Plant Watch: Exelon Nuclear's 1,220 MW Braidwood 2 at 85 pct, performing maintenance on main generator 10/23/01 11:43 ECAR Plant Watch: Cinergy coal-fired 1,400-MW Miami Fort units 5, 8 shut for maintenance.
Unit 8 shut since Sept. 29 for two-month outage; unit 5 shut earlier, sources close to the Hamilton, Ohio plant told Argus 10/23/01 11:24 MAPP Plant Watch: Alliant Energy's 598 MW Duane Arnold at 8 pct, rising after unplanned work Oct. 17 and repairs to pump seal 10/23/01 11:19 MAIN Plant Watch: Wisconsin Electric's 525 MW Point Beach 1 nuclear unit reduced to 80 pct 10/23/01 10:52 SERC Plant Watch: TVA's Cumberland coal-fired 1,300-MW unit 1 remains shut for 50-day maintenance outage that began mid-September.
About 20 days of work remains, source close to the plant told Argus 10/23/01 9:51 SPP Plant Watch: Entergy's 940 MW River Bend 1 at 100 pct, exited refueling outage Oct 12 10/22/01 15:40 MAPP Plant Watch: Alliant Energy's 598 MW Duane Arnold is in start up, exiting maintenance outage that shut the plant down Oct. 17 10/22/01 10:24 MAIN Plant Watch: Exelon Nuclear's 1,220 MW Braidwood 2 at 78 pct, performing maintenance on main generator 10/22/01 10:21 MAIN Plant Watch: Exelon's 830 MW Dresden 2 entered refueling outage Oct. 20 10/22/01 9:48 SERC Plant Watch: Duke's 1,130 MW Catawba 2 in start up, exiting a refueling outage that began Sept. 15 10/22/01 9:46 SERC Plant Watch: Southern Company's 900 MW Hatch 2 is expected to begin ramp up Tuesday night, exiting a refueling outage that began Sept. 15 10/19/01 9:19 MAIN Plant Watch: Wisconsin Electric's 525 MW Point Beach 1 returned to 100 pct after reducing power due to transmission problems in the area 10/17/01 12:20 MAIN Plant Watch: Wisconsin Electric's 525 MW Point Beach 1 reduced to 70 pct.
Plant was asked to reduce power due to transmission problems in the area, helping to prevent lines from overloading 10/17/01 12:16 MAPP Plant Watch: Alliant Energy's 598 MW Duane Arnold 1 shut after 6 a.m. due to an electrical problem, source close to the plant told Argus.
Plant will remain shut for about a week to perform work on a recirculation pump that had been planned for early November 10/17/01 11:05 MAIN Plant Watch: Commonwealth Edison's 1,220 MW Braidwood 2 at 65 pct, performing maintenance on main generator 10/16/01 14:52 MAIN Plant Watch: Commonwealth Edison's 1,220 MW Braidwood 2 at 72 pct, performing maintenance on main generator 10/16/01 14:50 MAIN Plant Watch: Exelon's 830 MW Dresden 2 at 85 pct, in coastdown to October 20 refueling outage 10/16/01 14:49 MAIN Plant Watch: Commonwealth Edison's 1,220 MW Braidwood 1 at 100 pct, unit exited refueling outage Oct. 12 10/16/01 10:06 ECAR Plant Watch: First Energy's 923 MW Beaver Valley 2 at 90 pct, reduced power for maintenance 10/16/01 9:13 SPP Plant Watch: Entergy's 940 MW River Bend 1 remains at 80 pct, holding here for testing until Friday, Oct. 19, a source close to the plant told Argus 10/15/01 14:01 WSCC Plant Watch: Arizona Public Service Company's 1,270 MW Palo Verde 3 at 0 pct, defueled 10/15/01 13:59 WSCC Plant Watch: Southern California Edison's 1,200 MW San Onofre 2 went off line over the weekend for repairs, and should be back on line by Nov. 2, the company told Argus.
10/15/01 13:55 WSCC Plant Watch: Arizona Public Service Company's 1,140 MW Palo Verde 2 off line to replace control element assemblies.
The unit, which was shut down Oct.10, should be back by early November, said the company.
10/15/01 13:19 SERC Plant Watch: Virginia Power's 822 MW Surry 1 entered refueling outage over weekend, a source close to the plant told Argus 10/15/01 12:24 MAIN Plant Watch: Wisconsin Public Service Corp's 535 MW Kewaunee 1 remains off line in refueling outage 10/15/01 10:30 FRCC Plant Watch: FP&L's 760 MW Turkey Point 3 still in cold shutdown, defueled.
Refuel outage began Sept. 29.
All other FP&L nuclear units, Turkey Point 4 and St. Lucie 1 & 2, are at 100 pct 10/15/01 10:24 FRCC Plant Watch: Florida Power's 890 MW Crystal River 3 at 0 pct, remains shut for refueling outage that began Oct. 3, source close to the plant told Argus 10/15/01 9:11 SPP Plant Watch: Entergy's 940 MW River Bend 1 at 80 pct, holding here for testing.
The plant is expected to return to full power sometime tomorrow, a source close to the plant told Argus 10/15/01 9:02 SERC Plant Watch: Southern Company's 900 MW Hatch 2 remains in a maintenance outage that began Sept 15, and is expected to last until Oct. 25 10/15/01 9:02 SERC Plant Watch: Georgia Power's 1,160 MW Vogtle 1 at 99 pct 10/15/01 9:01 SERC Plant Watch: Southern Company's 900 MW Hatch 2 remains in a maintenance outage that began Sept 15, and is expected to last until Oct. 25 10/15/01 8:17 Energy Argus Nuclear Plant Fall 2001 Refuel Table 10/12/01 10:51 SPP Plant Watch: Entergy's 940 MW River Bend 1 at 15 pct, will synch to the grid later today, and is expected to be 100 pct Oct 14, a source close to the plant told Argus 10/12/01 9:52 SERC Plant Watch: Georgia Power's 1,160 MW Vogtle 1 at 99 pct 10/12/01 9:51 SERC Plant Watch: Southern Company's 888 MW Farley 2 at 99 pct 10/12/01 9:49 SERC Plant Watch: Southern Company's 888 MW Farley 1 remains in refueling outage entered Oct. 6.
Outage is expected to last 31 days, until Nov. 6, a source close to the plant told Argus 10/12/01 9:46 MAIN Plant Watch: Exelon's 830 MW Dresden 2 at 87 pct, in coastdown to October 20 refueling outage 10/12/01 9:44 SERC Plant Watch: Southern Company's 900 MW Hatch 2 remains outage that began Sept 15, and is expected to last until Oct. 25 10/12/01 9:23 SERC Plant Watch: Duke's 1,130 MW Catawba 2 remains in refueling outage entered September 15 10/12/01 9:00 ERCOT Plant Watch: Houston Power and Light's 1,300 MW South Texas 2 at 100 pct If you would prefer not to receive further messages from this sender: 1.
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| Power Plant Outages Information! |
October 24, 2001 To: Transcontinental Gas Pipe Line Corporation Customers and Shippers Re: System Imbalance Notice Please be advised that Transco has been experiencing excessive negative transportation imbalances (deliveries in excess of receipts) on its system throughout the month.
Effective immediately, shippers are advised to avoid any additional negative imbalances and return to a balanced position.
Absent voluntary compliance, it may become necessary for Transco to suspend make-up deliveries for the remainder of the month.
Additionally, effective October 26, 2001 and until further notice, Transco will institute more restrictive practices at its pooling points.
Transco will reduce the 4% tolerance currently allowed at its pooling points to 1% or 1,000 dts for Shippers with negatively scheduled imbalances (i.e.
deliveries into the pools are less than receipts away from the pools).
Shippers with positively scheduled imbalances at their pools will be held to the 4% tolerance levels.
Transco will not enforce these pool imbalance tolerances during the timely nomination cycle; however, Shippers are expected to balance their pools to the limits identified above by the ID2 nomination cycle.
Transco may proactively decrease markets to bring them in line with supplies at pooling points.
| System Imbalance Notice |
COLUMBIA GULF TRANSMISSION COMPANY NOTICE TO ALL INTERESTED PARTIES JUNE 24, 2002 Notice ID: 3845 5 - NO RESPONSE REQUIRED Columbia Gulf Transmission is auctioning 47,395 dth/d of onshore firm capacity from Venice to Rayne, Louisiana at CGT's maximum onshore FTS-2 transportation rate.
This capacity will be available July 1, 2002, with bids due by 2:00 p.m. (Central Time) on June 24, 2002.
Details of this capacity auction may be found in the Columbia NAVIGATOR system under the capacity release folder, offer number 36798.
For additional information please contact Janice Felton at (713) 267-4210 or Martha Blake at (713) 267-4213 or Brian Lamb at (713) 267-4251.
Columbia Gulf Transmission is auctioning 47,395 dth/d of onshore firm capacity from Venice to Rayne, Louisiana at CGT's maximum onshore FTS-2 transportation rate.
This capacity will be available July 1, 2002, with bids due by 2:00 p.m. (Central Time) on June 24, 2002.
Details of this capacity auction may be found in the Columbia NAVIGATOR system under the capacity release folder, offer number 36798.
For additional information please contact Janice Felton at (713) 267-4210 or Martha Blake at (713) 267-4213 or Brian Lamb at (713) 267-4251.
| CGT - FTS-2 Capacity Auction |
No on-system capacity available, that includes excess injections or deliveries to Distribution City Gate.
IT through Concord is available for tomorrow's gas day for up to 100,000 dth.
Have any of you gotten a better handle on the pricing we saw late yesterday?
Gas Daily quoted trader's who thought there was some unexplained buying go on.
| Capacity for the 24th |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES OCTOBER 23, 2001 Notice ID: 3202 5 - NO RESPONSE REQUIRED SUBJECT: CAPACITY UPDATE EFFECTIVE FOR WEDNESDAY, OCTOBER 24, 2001 NO CHANGES FROM THE PREVIOUS DAY Effective Wednesday, October 24, 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) 300,000 Cambridge (B10) 20,000 Dungannon (B11) 20,000 Highland (B17) 15,000 NOTE: GAS RECEIVED AT HIGHLAND MUST BE DELIVERED IN THE NORTHERN PORTION OF MARKET AREA 38 OR THE NORTHWEST LATERAL OF MARKET AREA 36, DIRECTLY NORTH OF HIGHLAND.
Milford (B18) 20,000 North Greenwood (B22) 0 Unionville (B15) 50,000 NOTE: EFFECTIVE THURSDAY, AUGUST 16, 2001, ANY SHIPPER UTILIZING A CONTRACT THAT HAS A PRIMARY RECEIPT POINT(S) WITH THE FOLLOWING POINTS, MUST UTILIZE THESE POINTS: Brinker (B12) Cambridge (B10) Dungannon (B11) Highland (B17) Milford (B18) Unionville (B15) TEXAS EASTERN: Delmont (C16) 0 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) 0 Dranesville (E1) 0 ALGONQUIN: Ramapo (R1) 75,000 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 No Restrictions 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 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 OCTOBER 24, 2001 |
Hello everyone, My husband Ryan is going to be participating in the American Heart Walk on November 3.
He is walking on behalf of our daughter, Sydney, who was born in May of this year with Congenital Heart Disease.
If anyone would like to sponsor us with a cash donation, we would be very appreciative.
I will be accepting donations today and tomorrow.
This is a wonderful organization whose research saves lives like Sydney's every day.
All donations are matched by Enron and are 100% tax deductible.
Please help this worthwhile cause if you can.
Thanks,
| American Heart Walk |
Everybody got alot accomplished today on our firedrill.
Yeah Team!
Here's a quick update: Maria, located the missing "DRI Operating" agreements and correspondence.
See the fax I sent to your computer.
The bad news, it is a 1 year, evergreen agreement with 60 days notice by either party prior to the end of the contract year (i.e.
60 days notice prior to October 31, 2002) to terminate.
Looks like paying them for post petition gas and reject the contract may be the best answer for the estate.
She also uncovered another listing of global contract numbers that may be the key to finding the other missing agreements in LiveLink.
Chris, has been reviewing Wade's TCO data and comparing it to pipeline gathering invoices.
I can't answer your question about whether we are making money yet, but we are getting really close to the answer.
He is getting all the data together for the sales pitch now, so that everything will go smoothly next week.
He is also attacking all the other companies that relate to the producers.
Wade & Robin & Chris are working on the Dominion producers to try to see if they can approximate the high level summary retroactive reallocation volume adjustments that Chris has prepared.
I will forward you Wade's email from Dominion that says that any additional detail is tied up in bankruptcy court.
When they get done, we will be able to approximate what the $ impact is in pushing the producers back to 12/3/02.
Your paralegal & Maria really made alot of progress on finding the contracts.
I think we are up to a 100% success ratio going forward.
They still need to go back and try to find the missing ones.
We sent you a "big gift" of contracts to your D.C. office for Monday delivery.
NY Ed begged me to make sure that the DRI letter gets out on Friday.
I told him that he was going to have to argue 120 new cases in front of the court.
Hee Hee Our Ed is taking vacation on Friday, June 28th.
We will need to make sure everything gets done so that the letter can be signed on Thursday.
I did not get anything done on the other things we discussed yesterday.
Have a great weekend, Ruth
| Appalachian Producers Update |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES OCTOBER 17, 2001 Notice ID: 3190 5 - NO RESPONSE REQUIRED SUBJECT: REVISED 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 33843 FTS Leach Market Area 6 33844 FTS Leach Market Area 25 33845 FTS Leach Market Area 8 33846 FTS AO5 Market Area 36 33827 FTS Lebanon Market Area 1 33828 FTS Leach Market Area 5 33829 FTS Kenova Agg Market Area 5 33830 FTS Lebanon Market Area 6 33831 FTS Leach Market Area 8 33832 FTS Kenova Agg Market Area 8 33833 FTS Leach Market Area 8 33834 FTS Leach Market Area 9 33835 FTS Leach Market Area 10 33836 FTS Leach Market Area 10 33837 FTS Leach Market Area 12 33838 FTS Leach Market Area 15 33839 FTS Leach Market Area 15 33840 FTS Leach Market Area 19 33841 FTS Alexander Agg Market Area 32 33842 FTS Highland Market Area 38 33860 FTS Leach Market Area 4 For additional information, please contact your Account Representative or your Customer Services Team.
| TCO-REVISED AUCTION OF FTS CAPACITY |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES OCTOBER 17, 2001 Notice ID: 3189 5 - NO RESPONSE REQUIRED SUBJECT: CAPACITY ALLOCATION-TIMELY NOMINATION CYCLE FOR OCTOBER 18, 2001 PLEASE NOTE THAT ALL ALLOCATIONS ARE SUBJECT TO CHANGE BASED ON THE RECEIPT OF ANY NEW NOMINATIONS OR INTRADAY NOMINATIONS.
Excess MDWQ Available + ISS Withdrawals Available SIT Withdrawals Available Imbalance Drawdowns Available PAL Lends/Unparks Available Excess MDIQ Not Available + ISS Injections Not Available SIT Injections Not Available Imbalance Paybacks Not 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 October 18, 2001.
You may now view the quantities you are authorized to flow on October 18, 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 Wednesday, October 17, 2001.
If you have any questions, please contact your Account Representative.
| TCO- CAPACITY ALLOC-TIMELY NOMINATION CYCLE OCT. 18, 2001 |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES OCTOBER 17, 2001 Notice ID: 3188 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 33843 FTS Leach Market Area 6 33844 FTS Leach Market Area 25 33845 FTS Leach Market Area 8 33846 FTS AO5 Market Area 36 33827 FTS Lebanon Market Area 1 33828 FTS Leach Market Area 5 33829 FTS Kenova Agg Market Area 5 33830 FTS Lebanon Market Area 6 33831 FTS Leach Market Area 8 33832 FTS Kenova Agg Market Area 8 33833 FTS Leach Market Area 8 33834 FTS Leach Market Area 9 33835 FTS Leach Market Area 10 33836 FTS Leach Market Area 10 33837 FTS Leach Market Area 12 33838 FTS Leach Market Area 15 33839 FTS Leach Market Area 15 33840 FTS Leach Market Area 19 33841 FTS Alexander Agg Market Area 32 33842 FTS Highland Market Area 38 For additional information, please contact your Account Representative or your Customer Services Team.
| TCO-AUCTION OF FTS CAPACITY |
COLUMBIA GULF TRANSMISSION COMPANY NOTICE TO ALL INTERESTED PARTIES OCTOBER 17, 2001 Notice ID: 3187 5 - NO RESPONSE REQUIRED Columbia Gulf Transmission is auctioning 10,250 dth/d of available firm capacity on the mainline.
This capacity is from Rayne, Louisiana to Leach, Kentucky at CGT's maximum FTS-1 transportation rate.
This capacity will be available starting November 1, 2001, with a maximum term of 20 years and a minimum term of two years.
Bids must be received by 9:00 a.m. (Central Time) October 24, 2001.
Details of this capacity auction may be found in the Columbia NAVIGATOR system, under the capacity release folder, offers icon, offer summary, offer type, capacity auction, offer number 33801.
| CGT - FTS-1 Capacity Auction |
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 |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES OCTOBER 16, 2001 Notice ID: 3185 5 - NO RESPONSE REQUIRED SUBJECT: CAPACITY ALLOCATION-TIMELY NOMINATION CYCLE FOR OCTOBER 17, 2001 PLEASE NOTE THAT ALL ALLOCATIONS ARE SUBJECT TO CHANGE BASED ON THE RECEIPT OF ANY NEW NOMINATIONS OR INTRADAY NOMINATIONS.
Excess MDWQ Available + ISS Withdrawals Available SIT Withdrawals Available Imbalance Drawdowns Available PAL Lends/Unparks Available Excess MDIQ Not Available + ISS Injections Not Available SIT Injections Not Available Imbalance Paybacks Not 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 October 17, 2001.
You may now view the quantities you are authorized to flow on October 17, 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, October 16, 2001.
If you have any questions, please contact your Account Representative.
| TCO- CAPACITY ALLOC-TIMELY NOMINATION CYCLE OCT. 17, 2001 |
There were no new entries for June 19, 20 or 21, 2002.
Attached is the Master Termination Log, which has shaded any changes to previous entries.
Please note the following: The following has been on the Master Termination Log as "Y" for a valid termination and has now been marked as "N": Norampac Inc. ENA ISDA (06/04/1999) The early termination date for the following have changed: Growmark, Inc. ENA various option contracts (financial) Nordea Bank Norge ASA ENA ISDA (02/10/1999) (f/k/a Christiania Bank OG Kreidtkasse ASA)
| Master Termination Log |
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 |
October 10, 2001 To: Transcontinental Gas Pipe Line Corporation Customers and Shippers Re: Transcontinental Gas Pipe Line Corp ACA Filing On August 31, 2001 Transcontinental Gas Pipe Line Corporation (Transco) filed revised tariff sheets in Docket No.
RP01-540-000 to reflect a decrease in its Annual Charge Adjustment (ACA) from $0.0022 to $0.0021 per Dth.
The Commission issued a letter order dated September 26, 2001 accepting Transco's filing effective October 1, 2001.
| Transcontinental Gas Pipe Line Corp ACA Filing |
Deal # 271273 (ENA - IM ME New England) had been flagged as the primary desk but has a stop date of 9/30/01.
Does this deal number need to be extended or has the primary desk changed for the PALs contract on IROQ starting with October?
Deal # 835134 is the TP1 deal # for this contract.
Thanks,
| IROQ PALS contract 125099 |
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 |
COLUMBIA GAS TRANSMISSION CORPORATION NOTICE TO ALL INTERESTED PARTIES OCTOBER 04, 2001 Notice ID: 3154 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 33719 FTS Milford Market Area 21 33720 FTS Leach Market Area 1 33721 FTS Lebanon Market Area 1 33722 FTS Leach Market Area 4 33723 FTS Leach Market Area 5 33724 FTS Leach Market Area 5 33725 FTS Kenova Agg Market Area 5 33726 FTS Lebanon Market Area 6 33727 FTS Leach Market Area 7 33728 FTS Leach Market Area 7 33729 FTS Leach Market Area 8 33730 FTS Leach Market Area 8 33731 FTS Kenova Agg Market Area 8 33732 FTS Leach Market Area 8 33733 FTS Leach Market Area 8 33734 FTS Leach Market Area 9 33735 FTS Leach Market Area 10 33736 FTS Leach Market Area 10 33737 FTS Leach Market Area 12 33738 FTS Leach Market Area 15 33739 FTS Leach Market Area 15 33740 FTS Leach Market Area 19 33741 FTS Alexander Agg Market Area 32 33742 FTS Highland Market Area 38 33716 ISS For additional information, please contact your Account Representative or your Customer Services Team.
| TCO-AUCTION OF FTS AND ISS CAPACITY |
NGI's Daily Gas Price Index Breaking News : posted Oct 2, 9:35 AM El Paso's Offshore Pipe From Nova Scotia To NY On Track El Paso Corp. said Tuesday that because of increased drilling activity near Sable Island, it is on track to develop a $1.6 billion pipeline to transport natural gas supplies off the coast of Nova Scotia to markets in Canada and the northeastern part of the United States.
The proposed Blue Atlantic Transmission System, anticipated to be in service by the fourth quarter of 2005, would be 750 miles long, and its 36-inch pipe would carry up to 1 Bcf/d along a subsea route from the southern coast of Nova Scotia to landing points in New York and New Jersey.
Noting that El Paso was pleased with the initial feasibility study, E. Jay Holm, CEO of El Paso Eastern Pipeline Group, said the company was "confident" it could develop an effective plan.
Meanwhile, Maritimes & Northeast Pipeline, the only existing system from offshore Nova Scotia to New England, has embarked on its own major expansion program designed to increase capacity on its system to 2 Bcf from 500 MMcf/d by 2010.
The Scotian Shelf currently has proven reserves of more than 6 Tcf, but experts believe it could contain 10 times that amount.
El Paso clearly has its eyes set on some of those volumes, but it will have battle with Maritimes, which already has commitments from the Sable Offshore Energy Project and PanCanadian Petroleum.
"The subsea configuration offers several advantages over a land-based alternative," said Holm, "including minimal environmental impact, significant reduction in community disturbances, and anticipated transportation routes substantially less than $1 a dekatherm for firm deliveries to the New York and New Jersey markets, as well as reduced rates for deliveries to the province of Nova Scotia."
Holm said that the "anticipated rates are significantly less than that of any known current or proposed alternative project to provide firm transportation to these regions."
Blue Atlantic would offer economic benefits to Nova Scotia by creating the first access to natural gas in the province's southwestern region and would address the "continuing increasing demand" for natural gas along the U.S. East Coast, said El Paso.
Natural gas demand along the East Coast is expected to increase an additional 685 MMcf/d by 2005, and will grow to an incremental 2 Bcf/d by the end of the decade.
El Paso plans to open an office in Halifax and has already retained Halifax-based Jacques Whitford Environment Ltd. as well as U.S.-based ENSR Corp. to begin the environmental work.
Also, El Paso is evaluating bids on providing overall project management services to assist in siting and design of the pipe and related facilities.
Soon, El Paso plans to enter into negotiations with potential shippers and conduct an open season to determine capacity demands before the end of this year.
It also is seeking input from various regulatory and government organizations, and is working with local communities involved and special interest groups to ensure issues are addressed about the project.
"This is an ambitious project and our goal is to identify various stakeholders and involve them during all phases of the development process," said Holm.
When the route has been selected, Blue Atlantic will proceed with obtaining the necessary approvals from both Canadian and U.S. regulatory officials, and El Paso said it expects filings will begin by the end of 2002.
| El Paso's Offshore Pipe From Nova Scotia To NY On Track |
Good Morning, Due to a computer "bug" within AGA's systems, AGA will release their report TOMORROW, Thursday at 2:00 EST.
Just a reminder to get your AGA estimates in by Noon EST (11:00 CST) TOMORROW.
Last Year +77 Last Week +91 Thank You,
| BNP PARIBAS Commodity Futures Weekly AGA Survey |
Hey guys, Would you please ck the Oglethorpe deal from July 2000 - Dec 2000?
Is there supposed to be a cashout booked in Sitara for these months?
Oglethorpe over paid their invoice every month.
I believe that Doug told me the extra was for the cashout that was not invoiced.
Thanks
| Oglethorpe |
COLUMBIA GULF TRANSMISSION COMPANY NOTICE TO ALL INTERESTED PARTIES JUNE 21, 2002 Re: East Lateral Line 300 - Line Lowering Project Notice ID: 3839 5 - NO RESPONSE REQUIRED Columbia Gulf Transmission (CGT) will be performing a line lowering project on a portion of its East Lateral Line 300 beginning on June 24, 2002.
This project is expected to take seven days to complete.
The only location to be impacted by this project is 4119 - AEP/Equitable Storage.
This location is impacted because it is solely connected to Line 300.
While this work is being performed, CGT will be unable to accept nominations for delivery to or receipt from this location.
A revised notice will be posted once the work has been completed and CGT is able to resume accepting nominations for this location.
| Critical,CAPACITY CONSTRAINT,20020624,COLUMBIA GULF,007854581,East Lateral Line 300 - Line Lowering Project |
NYMEX announced this afternoon that it will begin trading EFS in natural gas tomorrow.
Please read the following memo.
Notice # 01-366 October 31, 2001 TO: All NYMEX Division members All NYMEX Division cleating members
| (01-366) Introduction of EFS Trading in Natural Gas |
Chris, I remember you mentioning us getting together sometime in the near future so that you could explain the whole NYPA deal.
Now that bid week is over, my time is pretty flexible.
Let me know a good time for you.
Thanks,
| NYPA |
Hello Everyone, I hope you are all doing well.
We will begin Giving Tree 2001 later this month.
Giving Tree is when we allow listeners to submit names of people who are in need.
Then we announce those needs on the air.
Listeners that can meet those needs call in and we match them up together.
Last year over 300 families were helped.
We are in need of volunteers to help us with this project.
We need data entry volunteers and phone volunteers.
Volunteers are needed to volunteer 3 hours a week for the duration of Giving Tree.
You can volunteer more than once a week if you would like to.
Please email or call me if you are able to be a Giving Tree Volunteer, or if you have any questions about being a Giving Tree Volunteer.
Thanks,
| KSBJ Volunteer Opportunities |
Chris, For path #17 and #21, could you tell me what the demand charges should be?
The two are different but are the same locations.
Also, we have #21 through mar-2005, structuring thinks it should be through Apr-2005.
Thanks
| transport |
Greetings, I understand from a conversation with John Allocca of KeySpan that Enron intends to release back to Boston Gas the 35,679 Dth/d beginning July 1, non-recallable, through 4/1/07 (the end date of the original release to Enron).
The capacity can be posted, confirmed and awarded via our bulletin board.
Ivy can walk you through the release and it can be done in about 5 minutes.
The capacity will revert back to its original contract, Boston Gas R-420-01.
Please call me if you have any questions, or if we are in error regarding this matter.
Regards,
| release of Iroquois capacity |
Notice to all Dominion Transmission shippers: Effective for the gas day of Sunday, June 23, 2002, until further notice, there will be no interruptible transportation capacity or non-PL1 transportation capacity available along the PL-1 system.
This restriction to Primary PL-1 deliveries to Primary delivery points is so that Dominion Transmission can perform pipeline pigging operations during this time.
All interruptible and secondary deliveries along the PL-1 system will be reduced to zero effective for the gas day of June 23, 2002, at 10:00 ECT (9:00 CCT).
Please contact your Customer Analyst if you have any questio
| PL- 1 CAPACITY RESTRICTION |
Deal # 271273 (New England) ended 9/30/01.
I changed the start date for Deal # 835134 (TP-1) to 10/1/01 and flagged it as the primary desk.
PAL Balance = 2,301 dths BF
| IROQ - PAL contract |
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 |
The ICE experienced a momentary connection loss to all users.
The system i= s now reconnected.
If you are experiencing any problem, please log out and= back in to rectify.
We apologize for the inconvenience.
IntercontinentalExchange = = = = = = = = = = = = =
| *** Notice *** |
Are you interested in going to this?
Some of my co-workers are going and asked if we want to sit at the table with them.
It's this Sat night at the Radisson Hotel Astrodome 6:00 pm reception and cash bar 7:30 pm dinner music, dancing, & "other activities" ii
| Williams Holiday Dinner Dance |
Was any capacity released under this contract in November?
There is no deal number in Sitara with a demand fee for this contract for November forward.
Deal # 429424 has IM - Market East as the Agent.
If we need to pay a transport fee for this contract, then a new deal needs to be set up.
Please let me know as soon as possible.
Thanks,
| VNG - TENN - Contract #47 |
Rita, Ruth and Chris have been working on gathering information on the Appalachian producers.
Chris has been working with Wade Price on obtaining actualized volumes.
I know that I handed over the invoice files for Equitrans and Norse to you sometime last week or maybe Monday.
I believe that I did not mention to you when we might need a response.
Have you had a chance to verify any of the information or locate any of the missing documents?
Ruth plans to go in front of the BTRC on Thursday.
If we are in fact missing invoices and/or imbalance statements for Equitrans, Norse, Somerset and EasternStates-can you please let me know.
We need to contact somebody in their shops and request this information as soon as possible.
Thanks again
| Equitrans-Other |
i spoke with sharon soderman at kn regarding receipt point into centana.
the quote for july 02 to aug 04 at midcon-spindletop is Inside Ferc Ship Channel flat for 10,000 dth/day.
of course, they can't transact with ena.
| centana |
NEW E-SCRIPT PRINT FUNCTION You can now do print screens on E-Script.
To take advantage of this new feature, in the menu file, click on: file, and print screen MAY 2002 IMBALANCE VOLUMES May 2002 Imbalance Volumes are now available to view on-line.
They may be viewed in ESCRIPT through the Flowing Gas/Imbalance Window.
If you have any questions, please contact me, John Lester at 304/627-3141 or Doug Barr at 304/627-3827.
PL- RESTRICTION The work schedule for the pigging of the PL-1 system that was originally scheduled for Monday, June 10, 2002, has been changed to Wednesday June 12, 2002.
This notice replaces the previous notice posted on Tuesday June 4th.
The implementation of this restriction on Wednesday means that there will be no interruptible transportation capacity or non-PL1 transportation capacity available along the PL-1 system.
This restriction will also require that all deliveries at that time on the PL-1 system be made to their primary delivery point.
All interruptible and secondary deliveries along the PL-1 system will be reduced to zero effective for the gas day of June 12, 2002, at 10:00 ECT (9:00 CCT).
Please give me a call if you have any questions.
LATE SHIFT & WEEKEND DUTY JUNE 8 through JUNE 14, 2002 To contact the Transportation Analyst working the late shift or weekend, call 1-800-895-8899 You will have access to Analyst on duty or the E-Script helpline.
| CUSTOMER UPDATE |
Please check into deals 332163 and 340305 for sales invoices to Midland Cogen.
Max Doner thought these deals would not trigger activity anymore per your note to him on 5/13.
I see where these deals were updated by you on that date.
Are the deals legit, or are the triggers generated legit.
Please let me know ASAP.
Thanks WRP
| Deal for Midland Cogen w triggers |
Reminder we will be taking next week off and resume the following Tuesday, June 11.
Chris may be taking some time away from the study, but hopefully will come join us later in the summer.
If you know anyone who may be interested in coming, please invite them and let me know.
We will be starting "Practical Christian Living" study.
Try to memorize John 17:3.
Thx!
Bill
| Next Meeting June 11 |
Could one of you tell me how much gas we delivered to American Public Energy Agency in Dec 2001?
in 2002 if any?
I don't have a good way to search for deals but I did find 2 deals on Northern Natural Gas at the Demarc point.
All of the information is below.
It appears that both deals were pathed on contract 105515.
There are 2 deals in Sitara for sales to American Public Energy Agency.
Deal 310424 Term through 4/30/2011 Volume ??
It appears that all volumes on this deal were taken to 0 in Sitara on 12/18/2001.
However, the volume pathed in Unify for this deal in Dec 2001 is 7,000 dth per day for the 1st - 4th and the 31st, a total pathed volume of 35,000 dth for the month.
No volumes were pathed for the 5th - 30th.
Pipeline Northern Natural Gas Deal 310690 Term through 5/31/2008 Volume 5,250 dth per day from 6/1/2001 through 5/31/2002.
The volume pathed in Unify for this deal in Dec 2001 is 5,250 dth per day for the 1st - 4th and the 31st, a total pathed volume of 26,250 dth for the month.
No volumes were pathed for the 5th - 30th.
Pipeline Northern Natural Gas
| American Public Energy Agency |
Ruth, Attached is my list of questions.
Some might be repetitive, but just wanted to cover all my points.
If I think of any others, I will let you know.
Maria PS..File is located under our transportation folder
| questions for legal |
Kay, I am trying to track down any information that may be in Legal's files on the JM Huber producer netback transaction.
My guess is that it would be either Jeff Hodge's or Gerals Nemec's files.
This deal was done by the deal makers in ENA's Denver Office.
I believe that the decision to assume or reject the Wyoming Interstate Company transportation capacity might impact the settlement of the JM Huber deal9s).
Thanks for your help,
| Wyoming Interstate Company Motion -- JM Huber Producer Netback Deal |
If you no longer would like to receive email from Kase, please reply with UNSUBSCRIBE in the subject line Kase Logo Learn Technical Analysis Two Full Days July 17-18, 2001 Early Bird Discount until June 14, 2001 Houston, Texaswww.kaseco.com Energy Traders, Marketers and Buyers.
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| Learn Technical Analysis, Early Bird Special for Houston Class |
Attached final (?)
numbers for invoice ??
We will need to cash out (ENA buy) the 12 dt remaining balance.
Can you review prior to departing ?
Also to confirm 5/3 - purchased 4250 at gate at $4.90.
| OGY for APR |
Hello All- Attached above are the cover letter and proposed tariff sheets filed by Texas Eastern yesterday for a June 1 effective date.
The rate changes reflect under recoveries in their ASA account which tracks their cash-out mechanism and increased cost of system fuel.
The underrecovery in the ASA account has increased from $22,000 to over $22,000,000 over the period September 1--March 31.
Texas Eastern claims that this is largely a result of the gaming of their currently monthly cash-out (which will likely be changed to weekly in their 637 proceeding).
As a result, Texas Eastern is seeking a waiver of the annual filing period in order to begin collecting the underrecovery through a surcharge that would amount to as much as $.0354 from ELA-M3.
Texas Eastern proposes to begin recovery in June so as to extend the recovery period from 12 months (Dec-Nov) to 18 months (Jun-Nov), which will lower the level of the surcharge.
| Change in Tetco Rates for June 1 |
New Ziff Energy Group Conference Storage 2001-2002: A Source of Stability or Chaos?
North American Gas Storage Conference June 22, 2001 Houston Sponsored by Williams, Alberta Energy Company & NESA/HEA Timely Summer is looming.
And that means you will have to make critical decisions about your natural gas storage strategy for Summer and Winter Peak 2001-2002.
Get the information you need at Ziff Energy's new natural gas storage conference.
North American gas industry leaders from the utility, trading, pipeline and storage sectors in each of the storage regions will deliver timely, relevant information you can use.
Focused Agenda This concentrated one-day program is focused on today's pressing storage questions.
Expert panels in each of three sessions will offer practical answers.
Speakers confirmed to date include: Session 1: Supply Shortage or Storage Inefficiencies: Last Winter's Saga Byron Wright, VP, El Paso Corporation David Manning, Senior VP, Corporate Affairs, Keyspan Energy Jim Thompson, Industry Analyst, EIA, DOE David Modesett, Vice President, Axia Energy Session 2: The Changing Storage Paradigm: Dynamic Storage Service vs.
Seasonal Fill
| Energy NEW Gas Storage Conference - Houston, June 22 |
Mark- Sorry for the delay in getting this to you...I've been struggling to find some more concrete information to rest an analysis on, but until we see Transco's supplemental testimony and the Commission Staff's "top sheets", it's very hard to predict where the case will come out.
Following, however, are some known variables that will effect the outcome of Transco's proposed increase: Rate of Return on Equity Transco filed for a 15.05% equity return (compared with the 12.4% recently affirmed by the FERC in the RP97-71 docket).
Transco based their filed number on a restructured "proxy group", which was revised by their witness to include Kinder Morgan, ElPaso Energy Partners, and Northern Border Partners (these were added to ElPaso, Enron and Williams).
Adding these entities has the effect of raising the high end of the range of DCF returns from 14.56& to 17.52% The effect of the 260 basis point increase to return on equity amounts to $61million, or approx.
27% of the requested increase.
Protests on this issue were filed chiefly by the New York PSC and PSE&G.
The NYPSC Protested mainly the change in the structure of the proxy group, citing the fact that the new entities added by Transco's witness are owned in substantial part by existing members of the proxy group.
The NYPSC asked for an expedited hearing on the development of a new proxy group--FERC declined to establish an expedited hearing but did set this issue for the hearing to be conducted before Judge Harfield.
| Transco Rate Case |
We have a sale to CES on ANR on Jan 13th - deal 149430.
The volume is 34,248 dts and the price is $2.22.
I did not Bill CES for this deal.
According to Tom Donohoe, CES owed ANR the gas and we paid it back in January.
Tom said CES was going to pay us for this.
Should I bill the Retail group for this?
It looks more like a wholesale transaction.
| Jan CES deal |
Please unsuspend and bill the following Jan CES deals Deal Pipe volume Amount Comment 145311 ANR 5071 11992.92 we billed the Trunkline piece of this deal.
145317 ANR 37975 89810.88 145319 ANR 16275 38490.38 Still researching the following deals Deal Pipe volume Amount Comment 149430 ANR 34248 76030.56 sent email to Tom Donoho to research.
I will be in after lunch.
I may try to send you more deals.
| CES Jan Billing |
There is a sale to CES for a volume of 34,248 dts, deal 149430.
It has your name on it.
My conterpart at CES does not recognize it.
According to Unify the downstream k# is 94946.
If you did this deal, do you remember who you did the deal with?
Thanks.
| Jan CES deal |
According to Kimat this is flash to actual stuff now.
I made these adjustments today for Nov 30th.
Joann, Alvin, the deals listed below are bookouts.
| P&L |
We have a 5,000 day purchase from Bay State that we can take at CNG/Trco Leidy or at CNG South pool meter 10002.
The deal number is 418282.
Could we put this deal number on the CNG and/or Trco sheet?
We currently have this deal baseloaded to CNG South Pool.
We need to call Bay State if we move it.
My contact at Bay State is Stacey Djukic 219-853-4320.
I gave Stacey Angie's number as a contact.
If we can't get in touch with Stacey, then talk to Robin.
| Bay State deal |
The CES/CEM CNG Appalachian production is still flowing into the CES/CEM gathering and transmission contracts.
Unless someone objects I would like to get this moved over to Enron's pool.
We don't need to have the gathering and transmission contracts moved over.
Comments/questions?
| CNG Appalachian production |
I'm going through the Jan transport invoices.
I see I need to bill CES for some South Georgia activity.
How did we pay South Georgia, I don't see a matrix in Unify.
| Jan Transport |
T&F Operating has sent ENA a "breach of contract" letter and is requesting to terminate the contract effective 4/1/2000.
Colleen, I will give you a copy of the letter that was faxed to John Singer.
CES did a buy/sale behind Penn Fuel on CGAS for 1 year starting Nov 1, 1999.
T&F is the supplier and Glenn Gary was the market.
The market went away effective 4/1/2000 and ENA/EES has no other market behind this part of Penn Fuel's system.
We checked with the Penn Fuel asset management deal and according to Penn Fuel, they can't take it either.
T&F is looking for their payment for Jan, Feb, and Mar, and T&F will waive any and all "cover" cost that ENA would otherwise be liable for subsequent to April 1, 2000.
John Singer wants to make sure we address the hedges in the books - will this need to be included in the CES true-up?
Also, John wants to know if he should sign the letter?.
Colleen, I told John you would anwser that question.
| Citygate Production |
This deal has been entered a CNG South Citygate deal and it should be entered and CNG Appalachian production.
Jim Javins said he thought the deal was behind hastings.
Could you guys move it.
I would but Mr. Tengle yelled at me about messing up the risk assignments.
| Deal 218918, McIntosh Partnerships |
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