Question for the people in the know about my future oil and gas chances. When they drilled Monster - the drill bit stopped approximately 500 yards away from where I have property. The shale thinned and like someone said they didn’t extract enough oil to fill a sewing machine (had to laugh at that one ). To make things worse, now I’m literally in a gray area (on that map ).
In your opinion does this mean I should never expect to be re-leased after this term is over? Do you suppose in the future I would ever be part of a Plot for drilling on the East side of 77? Is it like drilling a water well where you move over a little from a dry hole and it makes all the difference?
The nearby “dry hole” is definitely a huge negative as to this specific O&G formation / play concept. But technology (e.g. frac stimulation) can change / improve over time as to this one specific issue. Without having the log / drilling information in hand, I can;t TOTALLY rule out the possibility that something may happen in the future that could resurrect this play concept in your area.
As to your inquiry about comparison to water wells, that is not the case for this Eagle Ford section.
Plus, this is only ONE O&G play. There may be other targets / concepts both deeper or shallower that companies may want to chase for leasing and development.
Mother Nature and especially geology can be very fickle and unpredictable. But there still may be some hidden treasures associated with your minerals that haven’t been figured out yet.
Swamper, my family’s place is in a very similar situation to where you are. When EOG drilled the Reimers and Monster, I knew it would be a make or break for “our area” on trend to the north/northeast-ish. Now seeing the results, I am pretty pessimistic for the future unless as Rockman pointed out, there is a different formation that pops up. However, it will take high prices for someone to drill another wildcat formation test in this area.
Driving past the gas plant on FM 340 around 10 am and at least 5 oil transports were there loading. Looked like one compressor running as well. Saw several other transports up and down the road as well.
It looks like the only wells connected to the gas plant right now are the Maddox+3 wells. Francis pad still has flare. the flare at production plant is quite large…so hoping the Maddox+3 wells are very successful.
Now does anyone know where the rig will go after the CR 306 pad wells are done…(Leakey+3) these 4 wells should be completed in just a couple of weeks, and the new staked 6 wells on CR 183 has no activity as far as any pad prep. could the rig be going back to the southwest again ? ??
Should see some new permits getting posted very soon if it is staying in our area.
I wouldn’t be surprised if there’s a market problem with the nat gas. Waha is Permian and apples/oranges but the fact remains that Waha nat gas prices are currently negative.
William 1 Think you might be right monster and reimers had the fat lady done sang now she’s just passing some gas. Today going on 4 days of course it’s a monday no trucks oil are water showing up nobody. Who would guess April had the most oil trucks since these wells started.
EOG is almost done with CR306 wells. Still…no action at all on the 6 well flagged area off of CR 183. Where will the rig go ? Lots of action on the Rawlins pad…but looks like all about the pipeline. They are adding an additional line from Rawlins to Plant..looks like a least 1 more month.
No flowback on Rawlins after 2+ weeks. Could EOG be drilling Alfaro and Kenobi next ? then frac those and flowback all 4 together ?
or is the rig leaving again since the pipelines are taking a long time to finish…they did the 7 mile long Blackshear pipeline in 2 months…this is crazy…
or does EOG have another pad marked that has not been mentioned here yet ? No major permits in Lavaca county have been posted for over 6 weeks…for EOG or Flywheel…when oil is at $100+…
Also heard that since EOG already drilled out the pilot wells(hole) for Alfaro and Kenobi when they did Rawlins and Bruhn that this “holds” the lease, and they will not have to pay the options coming due…not sure if this is correct…again, i don’t want to call attorney again $$$$$$
Depending on the way the lease(s) read, they could be perpetuating the continuous drilling provision which can be anywhere from 90-180 days, etc. Totally depends on how the lease(s) were drafted and what constitutes perpetuating the lease via drill bit, etc.
Nine energy is at the rawlins pad and i assume they are starting the frac cleanup and flow back. I thought the pipeline was finished but they laid down another string of pipe yesterday from the rawlins pad to the gas plant.
We received $1.98 for nat gas and $19.11 for LNG for march
Blackshear .9 million cubic feet/day
Parr 1.2
Reimers .2
Monster .2
Francis 1.3
Friends 6.6
Harwi 2.8
Mulinge 5.5
Note: All my EOG & Redhawk leases pays for flaring, and this was with 2 different lawyers…so I am assuming if you used a lawyer you are getting paid for the flaring…
Thanks for posting these volumes and prices. Good to see gas flaring clauses in place - O&G lawyers getting better on this.
Gas prices dismal - but at least getting paid something for NGL’s / That price will go up with oil prices / normally 40-60% of oil price depending on Btu make up (pentanes, hexanes, et al).
Interesting range of rates - are all these wells in the approximate same period of production time (i.e. # of months) or varied as to that metric?
I would take the NGL’s for each well and look at ratio of Bbls NGL per MMCF of post processing gas - could be interesting trend
Same with any oil production as to ratio of bbls to MMCF post processing
Ideally, you should look at the raw, full well stream gas volume instead of post processing volumes for these ratios.
These should be posted on Tx RRC production site for the wells.
Thinking some interesting trends and patterns pop up - and with some very rapid changes (especially in dip directions, i.e. NW to SE)
Does anyone understand what kind of separation is taking place at the Processing Plant? I’m guessing that initial gas/liquid separation is done at the wellhead and further processing takes place at the Plant. Are the Plant products crude, Y grade NGL and natural gas?
Production from wellhead goes thru separator equipment to drop out as much liquid (oil or condensate) as possible. Plus divert water to separate tanks.
Then the remaining raw gas goes to pipeline to processing plant.
Processing plant strips out as much of the NGL’s as possible - essentially taking end product natural gas (called residue) to about 1000 Btu quality
Pre Processed gas at the entry point to plant may be in the 1250 to over 1500 Btu range depending on NGL concentations.
Maybe EOG will post a gas analysis or two on Tx RRC to give us an idea of gas quality
All you smart oil guys the last info I got from royalty owners was monster payed off better not sure why.
If any body heard that the pecan pad may be getting smaller just asking. A dozer with 4 rippers and a super loader showed up this weekend. May be limestone going to make another pad are they going to rebuild CR226.
Total $747,000 to date $164,300 total given to mineral owners
Monster
Dec $2 $2
Jan 109 7
Feb 131 2
March 190 27
Total sales $470,000 to date $103,400 total given to all mineral owners
Yes, March sales did increase and will be seen on the royalty checks that should have been received last week through Tomorrow, depends if you are on check or direct deposit. April oil sales should also be higher because of oil prices…as long as the volume does not decease.
As far as CR226…they did a good job making the gavel roads asphalt around the Blackshear Cr 244, but look now at CR 195..its torn up big time, and they have not fixed it, just dropped some gravel on the sides, and it was an asphalt road. They have a bond with Lavaca county, so if there are enough complaints the county should fix it and charge EOG.
). To make things worse, now I’m literally in a gray area (on that map 
).
