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Skip, I agree with the sentiment of your post .  Huey Long was right about Standard Oil, and a chicken in every pot.  He wasn’t without “sin,” but his assassination was no mere personal vendetta.  So, “don’t tax you, don’t tax me, tax the man behind the tree.”  Greed has gripped our state and country, and the special interests have no intention of letting go.  Assuming we’re still a market-driven economy, the LA AC may be developed in time.

There is no doubt that we are a market driven economy.  And that the AC will have to provide an acceptable rate of return to draw the capital required for full on development.  Neither of those facts are related to politics. 

No different than any other O&G play in any other state as I see it. Just different regulations and requirements - which is the norm across the USA.

I have heard horror stories about regulatory difficulties in other states - but O&G operations continue if the "rewards" are there to get!

As many company presentations and analyst reports clearly and definitively state, Louisiana has a very industry friendly regulatory agency. 

Re: EOG Well Production Update

I just looked at SONRIS and saw info posted dated 1/1/18 showing production totals of 8801 BO & 8334 MCF. A continued drop from the previous months reported volumes.

But it is interesting to see that the allowable has now been INCREASED to 2100 BOPD from the previous month's 1120 BOPD. The new number (2100) is the same as the original allowable posted granted by the state for this well.

This new allowable is approved to be in place for 6 months.

One can look at this in several ways but I believe that the operator has shown the state that they are / have installed artificial lift system (gas lift?) to increased well production to a point that will support the new increased allowable.

We addressed the production profile on this well in earlier postings. Initially the well would produce on its own without any "help" from artificial lift. High pressure gas production makes it possible to flow this well. 

But as formation pressure (and associated gas pressure and rates) dropped, production rates dropped and artificial lift was needed to "unload" the fluids (oil and water) that were in this 20,000' wellbore. This profile is very similar to other unconventional reservoirs and their performance.

Think about the amount of pressure that is exerted on the lateral by having a column of oil and water in the casing - without sufficient pressure coming from the formation to "unload" and move this fluid column to the surface, the production rate will logically decrease. Artificial lift will help unload this fluid column and subsequently increase production.

I am sure that EOG is watching this production very closely and getting info that will not be in the public record (e.g. choke sizes, pressures, down sizes, daily fluctuations, etc.). All this will go into their decision process for drilling new wells in the area..

The Eagles Ranch will be due for its semi-annual well test (DM-1R) soon, if it has not already been done and just not as yet entered in the database.  That will provide a choke setting and pressure reading along with the other standard measurements.

Craig, please edit your discussion title to include a link to the Eagles Ranch well so it is easier and quicker for us to review changes and updates to the well file.

http://sonlite.dnr.state.la.us/sundown/cart_prod/cart_con_wellinfo2...

Will do skip

Thanks.  We will all want to check the well file for updates.

I found a nearby offset well and log near the EOG well. The Dallas Production / Rabalis #1 Lahaye was drilled in 1982 (API 19-009-20282). There was a porosity log run / looking for the 5" log to see details as to porosity. Very good resistivity package from 15,370-15,500; in the Lower part the AC. Very confident that this is the correlative interval that EOG has targeted with their lateral wellbore to the south of this well.

This vertical well was completed in the AC (1182 to 15,384') / no IP or stimulation data available but well only produced 2610 BO from 3/83 to 5/84. Looks like a typical non naturally fractured AC well.

I figure that EOG looked at this well very closely in their regional evaluation as they selected this first location. Then drilled a pilot well to get more modern logs (and probably core) before drilling the lateral.

Re: Dallas Lahaye (Continued)

I found the original scout card for this well on DrillingInfo.com.

Original target here was the much deeper Tuscaloosa Sand section. Operator had a ton of problems drilling this well due to overpressure, lost circulation and various mechanical problems. After multiple unsuccessful attempts at completion in the deep Tuscaloosa sands, operator moved up hole to the AC to try to salvage the well with a completion (probably chasing a mud log show encountered while drilling).

Operator eventually completed well at 15,182 to 15,384'. No stimulation noted. IP rate was 20 BO (44 API) with 30 MCF per day on a 12/64" choke with flowing pressure of 200 to 500#.

Max monthly production rate for this well was only about 10 BOPD during a single month. No gas reported as to production - figure it was flared and not reported.

Note that I have found the 5" sonic log plus the mud log on this well - I will post more later after I have had a chance to look at this closer. 

Lahaye%20Scout%20Ticket.pdf

Hi RockMan, It was typical of the Tusc drilling in the 70's and 80's to mud up the AC on the way down to TUSC. I know of several wells drilled to Tusc in EBR  and EF that had to have pre-mix mud convoys deliver mud to for a week at a time while drilling in AC.Then they tried to get production from the AC after finding Tusc was not productive.  I scouted all of the wells on the East side of the river and that was typical of the operation in that day. 

Hi Joe,  could one of those in EBR Parish, been the Spurgeon Well.  Could it have been back then ( 1980's ) they did not know how to get results from the Austin Chalk.

John Lann   EBR

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