Captain Pablo said:

---

TommyBrady said:

---

For all you O&G folks my wife's grandparents have somewhere over 100 active wells in Andrews and Ward Counties

How much would that bring in yearly and over the life of a well? Most were drilled in the last 10- 15 years and the last about 2-3 years ago. Just going off average royalty and production.

I know it can vary a bunch and this is crazy ballpark numbers but we were just trying to figure out what might be the situation.

---

Have y'all considered simply asking the grandparents how much money they make off the wells?

It's kind of impossible to answer that question without knowing where the wells are, what the productivity of each well is, etc

---

Thanks

TommyBrady said:

---

Captain Pablo said:

---

TommyBrady said:

---

For all you O&G folks my wife's grandparents have somewhere over 100 active wells in Andrews and Ward Counties

How much would that bring in yearly and over the life of a well? Most were drilled in the last 10- 15 years and the last about 2-3 years ago. Just going off average royalty and production.

I know it can vary a bunch and this is crazy ballpark numbers but we were just trying to figure out what might be the situation.

---

Have y'all considered simply asking the grandparents how much money they make off the wells?

It's kind of impossible to answer that question without knowing where the wells are, what the productivity of each well is, etc

---

Thanks

---

You're welcome, I guess. Why not just ask the grandparents?

TommyBrady said:

---

For all you O&G folks my wife's grandparents have somewhere over 100 active wells in Andrews and Ward Counties

How much would that bring in yearly and over the life of a well? Most were drilled in the last 10- 15 years and the last about 2-3 years ago. Just going off average royalty and production.

I know it can vary a bunch and this is crazy ballpark numbers but we were just trying to figure out what might be the situation.

---

depends on what the total production is per well and what the prices were when they came online when you normally see the highest production rates. Your grandparents will have all the production data on each well in the energylink / envirus portal for well owners, this app is used by alot of well producers in Texas, that is if gramps wants you to see it!

fullback44 said:

---

TommyBrady said:

---

For all you O&G folks my wife's grandparents have somewhere over 100 active wells in Andrews and Ward Counties

How much would that bring in yearly and over the life of a well? Most were drilled in the last 10- 15 years and the last about 2-3 years ago. Just going off average royalty and production.

I know it can vary a bunch and this is crazy ballpark numbers but we were just trying to figure out what might be the situation.

---

depends on what the total production is per well and what the prices were when they came online when you normally see the highest production rates. Your grandparents will have all the production data on each well in the energylink / envirus portal for well owners, this app is used by alot of well producers in Texas, that is if gramps wants you to see it!

---

Awesome info! Appreciate it!

It's going to be somewhere in the range of surface damages to "y'all should never have to have jobs again."

Not sure how this affects ttu. Their deep pockets guy already sold his companies has his billions in the bank doesn't he?

Also depends on what "have over 100 active wells" means as far as WI/RI.

A good starting point would be if visiting her grandparents consists of driving to a trailer park in league city vs driving to the hanger of their private jet

TommyBrady said:

---

Captain Pablo said:

---

TommyBrady said:

---

For all you O&G folks my wife's grandparents have somewhere over 100 active wells in Andrews and Ward Counties

How much would that bring in yearly and over the life of a well? Most were drilled in the last 10- 15 years and the last about 2-3 years ago. Just going off average royalty and production.

I know it can vary a bunch and this is crazy ballpark numbers but we were just trying to figure out what might be the situation.

---

Have y'all considered simply asking the grandparents how much money they make off the wells?

It's kind of impossible to answer that question without knowing where the wells are, what the productivity of each well is, etc

---

Thanks

---

Could be $2000 a year! Could be $2,000,000! Might as well Ask the Magic Eight Ball if you don't want to ask directly.

And Rule #1 if you ever inherit as was pounded into my head from Day 1 by my father. Never sell your mineral rights. Never. Selling the dirt on top is okay, but never sell out what is underneath. If grandpa and grandma are getting letters in the mail or phone calls to buy their mineral rights, that should raise even more suspicion to not sell them. Never ever never.

Yep. That's been said already several times.

Sorry, I obviously missed it- several times

Find the Colonial Pipeline hacker and have him disrupt oil distribution again to drive up the price.

(Yes, I assumed their gender, but the cybercrime industry is 70% male.)

TommyBrady said:

---

For all you O&G folks my wife's grandparents have somewhere over 100 active wells in Andrews and Ward Counties

How much would that bring in yearly and over the life of a well? Most were drilled in the last 10- 15 years and the last about 2-3 years ago. Just going off average royalty and production.

I know it can vary a bunch and this is crazy ballpark numbers but we were just trying to figure out what might be the situation.

---

Bout three fiddy

A_Gang_Ag_06 said:

---

Bird Poo said:

---

Sims said:

---

DrEvazanPhD said:

---

AJ02 said:

---

It's already affecting us O&G folks.

---

Yep.

Strangely though, we've been at this low-60/high-50 price point for a while, and I haven't seen much in the way of rigs dropping. I wonder if after q4 earnings calls we'll see some of the majors pull back

---

Permian resources noted in their Q3 disclosures an 11% reduction relative to 2024 in drilling cost per lateral foot. Which likely translates to faster drilling (feet/day)

Cevitas Q1 showed drilling times about 10% faster than plan.

Enverus emphasized batch drilling and longer laterals (13k ft)

All of that points to less rigs to accomplish the same thing. Now to what degree the producers are completing the wells at current prices, I dunno. Maybe easier to just drill ducs and wait for prices.

---

That's quite a jump in performance. New technology come on-line or something? Could also be more experienced staff retaining oil-field jobs since the job market sucks.

---

People are pushing the limits even more these days. I think downhole tool and rubber components are making a huge difference on the exploration side. Operators are spending more time on bottom as opposed to tripping for tool failures. Laterals are not only being pushed out farther on six and eight well pads, but u-turn wells are gaining steam. Think two laterals with one vertical section as opposed to two. Operators are also "wine racking" their laterals in existing fields where they might not have in the past. Basically it's becoming incredibly efficient while squeezing every bit of production out of acreage.

---

How long have they been drilling the U-turn wells? It was brought up in one of my meetings last week that they're having a ton of success with it and saving a lot of time & money. And almost every day I'm seeing posts about new records in ROP/drill depth/speed. I only know of my little niche product's impact on that, but curious to hear from others what they're seeing as the cause for most of the gains in efficiency from a drilling/well construction aspect.

I've seen them become more commonplace the last two years or so. They're often drilled in areas where there are lease constraints. They're no more complicated than an extended lateral. What I have yet to see is one penetrate two different formations. For example, they'll drill an Eagle Ford down dip then the up dip coming back. A proposal was sent to me to drill an Austin Chalk lateral then steer down and drill an Eagle Ford coming back. I recommended against it though due to the large difference in the pore pressure/frac gradient window. The project ultimately turned into a u-turn Austin Chalk well.

BigRobSA said:

---

"Who needs oil, I ride the bus!"


;-)

---

1, 2, 3

And another one rides the bus.

A_Gang_Ag_06 said:

---

I've seen them become more commonplace the last two years or so. They're often drilled in areas where there are lease constraints. They're no more complicated than an extended lateral. What I have yet to see is one penetrate two different formations. For example, they'll drill an Eagle Ford down dip then the up dip coming back. A proposal was sent to me to drill an Austin Chalk lateral then steer down and drill an Eagle Ford coming back. I recommended against it though due to the large difference in the pore pressure/frac gradient window. The project ultimately turned into a u-turn Austin Chalk well.

---

Nvm

Captain Pablo said:

---

TommyBrady said:

---

For all you O&G folks my wife's grandparents have somewhere over 100 active wells in Andrews and Ward Counties

How much would that bring in yearly and over the life of a well? Most were drilled in the last 10- 15 years and the last about 2-3 years ago. Just going off average royalty and production.

I know it can vary a bunch and this is crazy ballpark numbers but we were just trying to figure out what might be the situation.

---

Have y'all considered simply asking the grandparents how much money they make off the wells?

It's kind of impossible to answer that question without knowing where the wells are, what the productivity of each well is, etc

---

Nvm

AJ02 said:

---

A_Gang_Ag_06 said:

---

Bird Poo said:

---

Sims said:

---

DrEvazanPhD said:

---

AJ02 said:

---

It's already affecting us O&G folks.

---

Yep.

Strangely though, we've been at this low-60/high-50 price point for a while, and I haven't seen much in the way of rigs dropping. I wonder if after q4 earnings calls we'll see some of the majors pull back

---

Permian resources noted in their Q3 disclosures an 11% reduction relative to 2024 in drilling cost per lateral foot. Which likely translates to faster drilling (feet/day)

Cevitas Q1 showed drilling times about 10% faster than plan.

Enverus emphasized batch drilling and longer laterals (13k ft)

All of that points to less rigs to accomplish the same thing. Now to what degree the producers are completing the wells at current prices, I dunno. Maybe easier to just drill ducs and wait for prices.

---

That's quite a jump in performance. New technology come on-line or something? Could also be more experienced staff retaining oil-field jobs since the job market sucks.

---

People are pushing the limits even more these days. I think downhole tool and rubber components are making a huge difference on the exploration side. Operators are spending more time on bottom as opposed to tripping for tool failures. Laterals are not only being pushed out farther on six and eight well pads, but u-turn wells are gaining steam. Think two laterals with one vertical section as opposed to two. Operators are also "wine racking" their laterals in existing fields where they might not have in the past. Basically it's becoming incredibly efficient while squeezing every bit of production out of acreage.

---

How long have they been drilling the U-turn wells? It was brought up in one of my meetings last week that they're having a ton of success with it and saving a lot of time & money. And almost every day I'm seeing posts about new records in ROP/drill depth/speed. I only know of my little niche product's impact on that, but curious to hear from others what they're seeing as the cause for most of the gains in efficiency from a drilling/well construction aspect.

---

We have about 10 planned in the Bakken next year and more in 2027. Usually they are planned where there is a trapped 1280 where we are unable to extend the laterals to 3 or 4 miles.

TommyBrady said:

---

fullback44 said:

---

TommyBrady said:

---

For all you O&G folks my wife's grandparents have somewhere over 100 active wells in Andrews and Ward Counties

How much would that bring in yearly and over the life of a well? Most were drilled in the last 10- 15 years and the last about 2-3 years ago. Just going off average royalty and production.

I know it can vary a bunch and this is crazy ballpark numbers but we were just trying to figure out what might be the situation.

---

depends on what the total production is per well and what the prices were when they came online when you normally see the highest production rates. Your grandparents will have all the production data on each well in the energylink / envirus portal for well owners, this app is used by alot of well producers in Texas, that is if gramps wants you to see it!

---

Awesome info! Appreciate it!

---

Regardless, take Grandma out to lunch often and suffer thru Papa's stories with a smile on your face.

You can do this Tommy.

If any of you O&G guys work in the safety side and need some fixed wireless gas detection, let me know. If you are in the upstream, especially in the Permian, you prob already got us. But if you don't, I'll make sure to get you that TexAgs discount. Got any questions, hit me up.

Nm

If you own mineral rights in Texas, you are getting 3-4 letters a week looking to buy them

CanyonAg77 said:

---

If you own mineral rights in Texas, you are getting 3-4 letters a week looking to buy them

---

On a few occasions, I have contacted the sender to confirm my own records and swab them for information.