And so good morning everyone. Thank you. I'm
getting some feedback.
I'm going to go ahead and just mute everyone for the moment and then
I'll. Unmute um.
OK, so I'm Katie Dahlberg. I'm a Data Analyst and Team Lead
for the Economic and Demographic Analysis section
of the Water Use, Projections, and Planning division at the
Texas Water Development Board. I am also the contract manager
for this mining water use study contract between the TW
DB and the University of Texas Bureau of Economic Geology.
So just kind of quickly a few housekeeping items. I know
we've all been doing virtual meetings for awhile now. I have
muted everyone, just so it’s quiet for the speakers and there's
no feedback. But please use the chat feature or the raise hand
feature if you have questions or concerns or feedback or input.
Whatever you may have. I've also set aside dedicated time at
the end of today's meeting,
so that we can hear from anyone who would like to provide some
insight. I really appreciate everyone being here. I know we are all very
busy and with the Holidays coming up, and it's Friday. So
I really appreciate you taking the time to join us today and
we're very excited to start this mining water use study in
partnership with UTBEG and the United States Geological
Survey or USGS.
So let me now introduce the Director of Water Use,
Projections, and Planning, Temple McKinnon who will provide more
background on the purpose of
this study. Let me see Temple if I can. Are you unmuted? I
think so. Can you hear me great? Yes I can. OK great
good morning everybody and thank you, Katie.
I appreciate like Katie said everybody coming together this
morning and having some patience with us, scheduling this kickoff
meeting. It's been lots of logistics to get us to this
point. So as Katie mentioned, we applied for a grant from USGS
Water Use Data and Research program for their fiscal year 20
program. So it's been awhile, but we finally have got a
contract in place. We're looking forward to working with the
Bureau of Economic Geology and
Bridget Scanlon. We received funding just over $120,000 to
conduct an update to a similar study we did with the BEG back in
2011. Um and Katie and you and Bridget will cover all the
specifics later, but basically the study is designed to provide
a comprehensive, and quantitative assessment of mining water use
and water sources in this state.
So the industry sectors that we’ll be evaluating are going to
include oil and gas aggregates, and coal and lignite.
And then we'll utilize the results of this study and the
development of our historical and current water use
estimates and then the water demand projections for the
next state water plan. The 2027 State water plan.
That plan is going to have a planning horizon through 2080,
so we're going to be projecting some pretty volatile use way out
into the future. So I'm really looking forward to Bridget
helping us out with that.
And, as with last time, we're really going to be depending
upon stakeholder involvement for this sector of use. It's very
difficult for us to get
accurate data so you guys have the local information
that we need to improve the use of our estimates and
projections. So I will hand it back to Katie to work us
through the agenda. But thanks for working with us and
we're here to help you guys facilitate getting
information to Bridget and wrapping up the study.
Thank you, Temple. Now, I wanted to provide a short
introduction to the division that Temple and I work in. In
case anyone's not familiar, we work in the water use
projections and planning division at the TWDB, which is
tasked with developing the Regional Water plans and state
water plan, which we do on a 5 year cycle and the division is
comprised of three sections. We have the Regional Water planning
section which overseas and coordinates the development of
the Regional Water plans.
We have the water use an planning data section which
conducts the annual Water Use Survey which surveys
approximately 7000 municipal and industrial water users in Texas
every year. In addition to managing the Regional Water
planning database and the Texas Water Service Boundary Viewer
application. And Lastly, we have the economic and mammographic
analysis section, which is where I work. We develop annual non
surveyed water use estimates and annual utility population
estimates. We also develop projections for population,
municipal water demands and non municipal water demands for the
regional and state water plans.
An Additionally as part of the State water planning process, we
develop this socioeconomic
impact analysis. So now they've given just a little bit of
background about our Division I want to return to the focus of
today, which is the mining water use study and to just kind of
recap what Temple said in this study. We will develop
historical water use estimates by County, play an water source
for hydraulic fracturing, and develop historical water. Use
estimates for colon lignite mining, as well as aggregate
production. Additionally, we will develop water demand
projections by County for each of these mining types.
And so now I would like to turn the presentation over
to Bridget Scanlon with you TBG, who will discuss this
methodology and more detail.
Right, thank you so much Katie, and I'm extremely grateful. Can
you guys see my screen?
Yes, OK, great. I'm extremely grateful to you
and show and Katie and Temple and others for their
support for this study. These are very difficult
times, and so we really appreciate the support.
As Katy mentioned, I'm going to talk about water use
estimates and projections in the Texas air mining and oil
and gas industries.
And I would like to.
And represent talk about the cold work my coworkers so.
My name is Bridget scanned and I've been at the Bureau
for about 30 four years and that's a picture for about
10 years ago and I'm not going to change it, ever.
And then Bob Reedy and I've been working together for about the
past 15 years, and he's going to work on this study. And Bob is
also working with the text net Scissor Center for integrated
seismic research group, and so has a lot of background on oil
and gas industry from this work that he's doing, JP Nico did the
2011 assessment and we're building off of that. So here's
a lot of knowledge about these assessments, and Shenyang is a
data analyst. And she is going to be working on the projections
for this study. And she also is working on the Title Resource
Assessment Group in the Permian.
Um hi. Bridget and I'm going to interrupt you just for a moment.
I'm sorry I gotta comment that someone cannot see the
presentation. So just wanted to see if anyone else could chime
in if they are, I'm able to see it so I just had him make sure
that everyone else can. I'm able to see it. I'm able to. I can
see it. OK OK great, thank you. This is being recorded.
Yeah, that could be it too. Maybe adjust your window.
This is also being recorded so we can share it afterwards
and for some reason we can't see the presentation. Sorry
bout that Bridget. Thank you.
So the first task in this project is to quantify current
and historical water use for hydraulic fracturing and
produced water volumes in the state. So we will be looking at
data sources, Sir, for hydraulic fracturing water use in the
primary data sources fracfocus, but we also use the IHS database
because frac focus does not provide any information on the
well completion data and it's good to check one source against
the other, although addresses.
Using frac, focus more and more the time period that we
will be considering is 2009 through 2020.
And we will be looking at the depth and the lateral length of
these wells and also calculate the year water use intensity for
hydraulic fracturing per length of lateral. Alot of people
indicate you know the water used for hydraulic fracturing has
been increasing but also the lateral lengths have been
increasing. So I think it's important to consider the water
used per length of lateral. So for example in the Permian Basin
our most recent data suggested.
That they were using about 17.5 million gallons per, well,
that's a median volume. And but and then about 2000 gallons per
foot of lateral and the water used per foot of lateral has
been stable for the past few years, but the length of the
laterals and what is profile has been increasing. So in this
study will be looking at the Permian Eagleford Barnett and
Haynesville please. And then we will also be conducting surface
with the operators and we're hoping that Tech Saga and CJ
Treadwear will talk in a little while about interacting with
their Texas oil and gas Association. To get insights
into how much of the water is sourced from produced water for
hydraulic fracturing, the frac focus group and Groundwater
Protection Committee are
planning. On including produced water as a source for hydraulic
fracturing in the future, but they don't have that.
I mean they do have it now, but it's pretty difficult and most
people don't report it, but hopefully with the easier
reporting we'll see more of those data in the future.
Um? We'll also be looking at the produced water volumes, and Bob
Reedy has a database where he tracks at this information in
our primary source for produced water volumes is the IHS
database, and because there's about a one year lag between
the. With reporting we will be looking at the time period from
2009 through 2019, will be focusing on unconventional
reservoirs because they produce water from conventional
reservoirs. A lot of that goes back into the reservoir for
enhanced oil recovery and then we'll check these produced water
volumes against the volumes that are reported for the saltwater
disposal. Because most of the
produced water. Has been injected into the subsurface
using soft water disposal wells.
So there's a lot of interest in in produced water volumes, and
it seems that for in the past that the USGS has included the
produced water and the hydraulic fracturing in their water use
category from mining.
And so we will be collaborating with the USGS to try to clarify
some of those issues.
The second task, then it is identifying the sources of water
for hydraulic fracturing and these can be surface water or
groundwater, and they can be fresh or brackish groundwater.
We will use data from the Texas Department of Licensing and
Regulation under the categories of rig and frac supply wells and
also industrial wells and assume that these are used mostly for
hydraulic fracturing in these areas of unconventional
development and based.
On the depth of the TDLR Wells, Bob Reedy links those to the
occupiers using the groundwater availability modeling model
data, and then he also looks at the water quality data for these
upwards to provide an indication of the water quality used for
hydraulic fracturing, whether it's fresh or brackish.
Task three is developing projections of future water
demand for hydraulic fracturing. For oil and gas, and Chen if you
are available, can you talk
about this? Sure.
Yeah, for for this task we will develop projection of future
hydraulic fracturing water use demand for unconventional oil
and gas development in Texas. So I'll briefly discuss the
methodology we are going to take a first. We will project a well
inventory or the remaining number of wells that could be
drilled by estimating the remaining drillable area and the
well spacing as well as the lateral length of future wells.
And we know that the well spacing in the lateral end there
quite dynamics and they can be different from basin to basin.
So here we're going to look at the drilling pattern of the
wells that were drilled in the in the last three years and
perform a statistical analysis to estimate the expected well
spacing letra lens and also hydraulic fracturing water use
intensive are for those for the for the future wells I want to
mention that we will also
consider. The parent and child well interference issue when
project well spacing. So the recent data shows like upscaling
trend of well spacing in the last two or three years which we
build. This is largely driven by the well interference concerns
between parent and child wells and the operators. Now they
trying to avoid a dense drilling too in order to reduce the
interference between the early drilled well and.
And the later drilled wells.
And also we were when we will consider resourcing place
formation thickness and also vertical spacing when we project
the vertical stacking.
And so with the projected well eventually and water use
intensity projection, we will be able to assess the total amount
of HF water use demand for recovering all the resources at
a technical basis. In other words, assuming all potential
wells will be drilled, what is the total actual water usage
demand an we will perform this this assessment at one Square
mile resolution? For each unconventional basin in the USA,
so sorry in Texas and we will expand our previous projection
to include not just the Permian Basin Eagle Ford but also our
Burnett enhance. Well place,
yeah. Thanks so much Chen. And of course as everybody knows
these days it's very difficult to have a crystal ball about the
future of oil and gas production and chain with her work on
projections for oil and gas for the Title Resource assessment
will be able to leverage that worker to apply to developing
the water use demands in the future. And when you focus on
technically recoverable resource, assuming that you're
going to. Produce all of the resource. I think we countered
that by the fact in the Permian we only focus on a couple of
units. I think the Wolfcamp A&B units and so there are about 10
potential stacked units, so if we all were estimate by
estimating technically recoverable resource, we're
underestimating by just focusing on a couple of the very high
producing units at the moment.
But we can talk more about that later.
So the next task task for is to identify locations of operations
and quantify current projected future water use for coal and
lignite mining. So here Bob Reedy has mapped the coal mines,
the active coal mines in Texas, and you can see Eagle Pass in
the Southwest, San Miguel and Three Oaks, etc.
And.
At oh, sorry, so these are the current active minds,
and they're about.
About seven of them, six of them that are active in Texas.
Calvert, Cassie, Liberty, San Miguel, and South Hawesville,
Antheum strip, and eagle pass. Just recent is closing at the
moment and Martial mind. Just recently closed. We will survey
the coal companies Luminant and North American Coal Company, and
we are currently working with them on a DoD proposal and
looking for rare Earth elements in critical minerals in cold.
And also in ash from the power plants and we will also talk
with the Texas Mining and Reclamation Association so
that we get good data on the water, use estimates and the
we will include the dewatering data and consider that as
consumptive even if it is put into a surface water body and
then we will use the electricity projections from
our Carpenter to estimate future water use.
So here you can see the locations of these are the
aggregate facilities that Katie provided to me, and
these are from 2019 data from the TCQ permits. Aggregate
production operation permits.
We will be looking at different types of extraction material and
the total disturbed area and we will be serving the operators
and evaluate how much water is reused or recycled.
Um, so here you can see on the map on the left, the yellow is
the sand and gravel, the red is granite and the mustard is mixed
and the blue is limestone and the Gray is caliche.
So a task 66 would be collaborating with USGS
personnel on water. You Sir, for the mining category and the USGS
provides data every five years that they call it from the Texas
Water Development Board and also from discussions with the
Railroad Commission. So we will be talking with them and making
sure that our results are consistent with what they're
putting forward also.
And we've been publishing a few papers while back is so just
this was a paper we published in 2017. There's a lot of confusion
and oftentimes about water use and produced water volumes for
unconventional development. And in this study we were
emphasizing that in the Permian 40 billion barrels of water were
produced from conventional reservoirs and only a 10th of
that came from.
Unconventional reservoirs at that time, and that was 2005
through 2015 and most of the produced water from conventional
reservoirs goes back into the reservoir to maintain pressure
for enhanced oil recovery. So if you're suffering from insomnia,
I would definitely recommend this paper. This is another
study that we looked at, published this year looking at
projections of produced water on the right hand side. You can see
these different bubbles so they
produce water. Is in Gray an on the left one is for the
Delaware Basin and on the right is the Midland Basin and in the
center. Then is the projected water demand for hydraulic
fracturing. So I think this emphasizes that even if we
reused or the produce water for hydraulic fracturing, we would
have a lot of excess produced water that we would need to
manage, and I think the state is interested in looking at
potential beneficial uses of that and treating it for
different sectors.
And so this shows some of the different options. Then for
using that water in different sectors. And I think the
dominant one would possibly be irrigation use or in the Permian
Basin would be discharged at the Peakers River possibly.
So that's that's all. The material that I have, Katie,
and I guess I could stop sharing and we'd be glad to
answer any questions.
Thank you for chat. How do I stop sharing? I think
that there should be like an X at the top of your.
Your screen in the in the.
Microsoft Teams. Meeting that we're in an.
Am I still sharing? Though? Yes you are.
Yeah, I so I. I think that right? Yeah, thank you.
Great, so I definitely want to give us a lot of time for
questions and answers. I had a few other things to add just
about the contract. May check my notes real quick and so we the
contract timeline were right at the beginning of this study and
the contract will run through August of 2022.
BT WDB will provide data support for BG throughout the contract
and near the end of the study when BG is drafted. Their final
data set. I will develop an interactive dashboard to share
on the TW DB website, which will include water use estimates and
projections by County and mining type, and this is just a way to
display the data results and share our study in an
interactive format. As part of the contract, the Gianti WDB
will produce progress reports every six months and we hope to
share that those reports with stakeholders keep you up to
date. What we're doing. We also hope to continue to have
progress meetings, meaning kind of like this. Right now we're
thinking then next meeting might be May or June of 2021, but I I
will keep everyone posted about that and about our progress
reports and any other information we might.
Pulled together and I will send out more information via email
about that. So I would like to open it up for questions and
answers. You can use the chat box feature which should be at
the top of your screen. Mine says show conversation, that's
where chat boxes you can also raise your hand if you would
like to speak and come over the line and either I can unmute you
or you might be able to unmute
yourself. But please feel free to provide any pizza. So Katie,
are you going to talk about it as CJ Treadway to talk about
the? Yes, yes, so I know. So we got let me hit on that in
just a second Bridget. We did get one question from.
Dexter May, did you say the study is anticipated to be
completed in 2022? That's correct. We were thinking August
of 2022. And let me see I know CJ Treadway had
an idea for.
That she wanted to talk about at this meeting, so let me see if I
can unmute CJ and and.
And so we can hear from her.
Let's see I am not able to unmute CJ, but.
CJ, if you're able to unmute yourself, you're more than
welcome to come over the line.
Or write in the chat box.
We did get another question from John Ellis and timeframe for the
projections will be 2030 through 2080 to match the 2027 State
water plan. And how will you determine what
areas to develop first?
Anne. I think that's a good question for Bridget, but John.
Do you want to expand what what you mean?
If you want to unmute yourself, you're welcome to
join.
I just wondered about.
How you determine you know which areas say of the Permian Basin?
Will you know? EXPAND, 1st and more the timeline of development
for each of the types of.
Of mining.
Chen, do you want to die? Yes, I think that's a excellent
question because it's really difficult to to determine which
areas will be developped first because it's related to which
area is economic recoverable or have higher probability.
Um, but in our analysis we just focus on the technical
recoverable resource assess, like assuming that all the
potential volume or wells will be drilled so they're kind of
treated equally so we don't tie this projection to the to the
profitability. Or the productivity, but just
on a technical basis.
John, maybe I can add a little bit to that. I mean, so
technically recoverable resources if we assume that the
wells are drilled, you know, I think Chen we come up with the
rate of above maybe 6000 wells per year over a 50 year time
frame. So the 50 year time frame for the state water plan.
Seems to sync up with what we would be required if we had the
maximum drill rate, you know? So it seems it's in the ballpark at
that time period to develop the reservoirs and reservoirs like
the Barnett and the Haynesville would be depleted within that
time period, maybe in the 20s thirties. Or, you know, in the
20s thirties. But the Permian is such a huge reservoir with so
many stacked please that that.
Would have enough resources to last about at least 50
years if we had a high rate of development.
So does the historical data support that you know
they'll find an area that they believe is profitable,
and so they'll focus on that for awhile and then
somebody else may find another area that you know
is is more profitable? Or are you know?
Doing well, is there any kind of historical data from the past?
Wells were drilled and how
people behaved. To help you in in how what your rate of
expansion would be, you know by County or whatever when will
definitely John. I think you know Chen. I mean you know we
see which units have been developed in which, like the
Wolfcamp has been the dominant unit. And then it also depends
on infrastructure and pipelines and take away capacity and all
of these things. So I think
they. Some knowledge of dash from the Torah group and so we
can have some ideas, but it may not be very highly constrained.
Yeah, yeah, it's not an easy task at all, so.
That's why Chen's doing it.
Yeah, as I bridges said, we definitely can leverage some of
the knowledge that I gained from that or a group like what is the
most heavily target formation? What is the mostly drilled
location like the center of the basin? So those those kind of
information? So we yeah we will consider when we.
Do DD projection, yeah?
OK.
Thank you, thanks Johnny.
So we have another question from Sean Abbott. I'm says, I
know we are RC Railroad Commission permit rig supply
in some cases do wells permitted for rig supply with
RC RC still get permitted with or reported to the TDLR? The
Department of Licensing Regulation.
Well, Sean, I I would assume that they do but but that's
certainly something that we should check into when we do the
study and we will follow up on that. But thanks for that.
Excellent question. I, I believe that I'll chime in here. I do
believe that that that the TDLR does have all water wells. I
believe that's the law. I don't think it distinguishes between
what the uses. There's a large population of wells that are are
labeled as frac supply wells. Rig supply wells in the
different place and so yeah, I'm pretty sure the TDLR has every
well or they're supposed to.
Right and we are, we think the TDLR database is
fantastic. I mean there were about 1000 wells drilled
maybe in 2019 in the ogalala for rig and frac supply and
New Mexico doesn't have a similar database so it really
limits what we can understand that the Permian in New
Mexico. So it's a huge plus to have those data.
We have another question from Simon Kill or Simone Ann as you
acknowledge oil and gas projections are very volatile.
How do you plan to address this volatility in projections?
The question.
Well, you know when we have tried to publish some of our
studies in the past, people have accused us of being tone
deaf and that there won't be any oil and gas production in
the future, and so our projections were voodoo.
So we recognize that, but we try to.
Give our best estimate and we know that we're in gas is not
going away in the near future, and we leverage off of the
historical data and change, you know with machine learning and
data analytics. Then makes projections based on as she
indicated. You know well spacing, well depths and
stacking and and remaining wells to be drilled.
But where it's not clear you know if all of those wells
would be drilled, or at what time, but as I indicated, you
know we're being conservative in that we are focusing on the
main producing units in the Permian, and if we over
estimate for those units that may be balanced by not
considering some of the other units.
I hope that it tried to address your question. I think
if we could do these projections, we wouldn't be in
the jobs wherein we would be.
Doing other things so sorry.
You have another question from Tony Smith. Are you
going to have alternative scenarios of projected
growth?
Not that that's a great idea, and I think that is something
that we will discuss. I mean, I know CG treadwear has.
Having some technical
difficulties, but we hope to have.
A group with Tech Saga to help guide some of these analysis and
I think you know a low and high scenario might be a good idea
and then the water develop board may have some ideas on that also
so we will certainly consider.
A couple of maybe bounding scenarios and what we think
might be the best guess.
Maybe CJ might.
And.
Provide some input and that yes, we're having some some technical
difficulties and unmuting CJ so CJ I don't know if you're able
to unmute yourself via the phone. Oh great, but.
Press * Six time your phone.
That's a nice suggestion, thank you.
Maybe try that CJ if you can or you know, use the
chat feature which ever you would like to you hello hi.
Hello. Yeah, we can hear you CJ. OK, I'm so sorry about that. I'm
really. I have a Mac computer and really have a lot of
problems with this Microsoft Teams, so I apologize for that.
Text logos for the last actual three studies that have been
conducted. An oil and gas water use type saga has been involved.
We basically had kind of a technical work group that is
available to work with BG in the Water Development Board and I
would suggest that we do the same type of thing again.
That sounds super and CJ. How many people were on those
working groups in the past and how many different
companies were represented and will you have? Will you
also have some midstream companies possibly involved?
We have next three members of our Association, so we will
certainly ask them to engage an it it varied from study to study
how many people engaged. But we had a significant representation
of the industry.
And you're also involved with the Groundwater Protection
Committee, aren't you CJ? So that's another.
Group.
Yeah, yeah.
Yeah. Right, so the Janvier reports you know for the USI
think they're very valuable and.
I put the. Hopefully we will be going into much more detail for
Texas then, but they provide a nice background for the US. The
Groundwater Protection Committee. Water reports that
John Vale has published in the
past. Yeah, I agree.
And thank you CJ for the suggestion. I think this is a
great idea, and since you know was done on the 2011 study and
we this current study is is in update to the 2011, I think that
that would be a really great
idea and. CJ, what's the best way to kind of coordinate an you
know, for people who might want to be involved in that more
specific technical work group?
Well, what we've done in the past is Texas Tech. Soda has a.
Headset the water committing an what we've done is gone to the
members of our Water Committee an ask for participation, and
then we would invite over the BD and Mark about on board to come
meet with us and and see if you had questions or.
Other technical things that we could help you with.
Greatly appreciate that, and I think it would be extremely
helpful, especially when we are considering produced water reuse
and some of these things that there are not explicit reporting
data, so it would be great to get a feedback from industry and
some of those issues.
Right? I think it has been real valuable in the past.
Thanks. Yes, thank you.
And we had another question from Joanne I might have
missed this. How well reuse be included in the analysis.
So do I know we will be calculating the water demand to
hydraulically fractured these wells and then if we understand
that produced water is used maybe for 10% of to meet 10% of
the hydraulic fracturing demand then that would be subtracted
from the hydraulic fracturing water demand. So we would only
report then that the water used
from the. External sources like the Aqua furs or surface water
was. 20% of the total demand so, but it's a very difficult. It
seems to be a very difficult number to estimate to get an
idea of how much is being reused, but we will try to get
at that with the Tech Saga working Group and maybe with the
survey with industry or other approaches and frac focus will
be reporting that it will have a way of reporting that in the
future. That would be more readily.
Available so maybe more operators will report that
in the future.
I I don't see any other questions at this time and if
anyone has any more questions you know, please. Either you're
welcome to unmute yourself an or I'm raise your hand and I can
try to unmute you, or you can put it in the chat.
Just give it one more minute to make sure we don't miss
anyone's questions.
And people can always email us afterwards, right?
Katie? And yeah.
Yes you can, so I'm the one who sent the this meeting invite
everyone, so you're welcome to send an email to me. I'm Katie
Dahlberg and my email address is just my name
katie.dahlberg@twwdb.texas.gov, but I did send this meeting
invites in my emails included in there and then. I can help
coordinate any questions to Bridget as well.
And I hope we have another question. Um, how about
assumptions on local impediments to building infrastructure or
pipelines? These could vary significantly by County.
Yes, Sir, that will certainly be an issue in some regions, and I
think with this technical working group with the tech
circle, we might be able to get some insights into that. And
maybe we can. We can also try to map the existing infrastructure
and I know midstreams are doing a lot with expanding the
infrastructure so that water can be more readily moved around and
so too. Increase the potential for produced water being reused
for hydraulic fracturing, so we'll try to map the existing
infrastructure and talk to operators, then about issues
they might have in different regions and and try to get some
insights and sometimes at conferences and stuff. We get
feedback and some of these types of issues. Also, CJ do you want
to add anything to that?
I know I, I think you expressed that pretty well, right?
Great.
Sorry, I don't see any further questions and you know, as I
said earlier in the meeting, one more question will your study?
Attempt to quantify the extent of potential reuse of produced
water for uses other than hydraulic fracturing.
Well, this study will provide the data on the produced water
volumes, historical produced water volumes in the hydraulic
fracturing water demand. So then we'll be able to get an
estimate of how much you produce. Water might be
available then for other potential uses, but I think
there are other efforts in the state of that are trying to
maybe evaluate.
Potential beneficial uses outside of the oil and gas
sector and that would require much more detailed analysis on
produced water treatment and infrastructure and testing and
New Mexico produced water research consortium is doing a
lot of that type of work for the New Mexico portion of the
Permian Basin and there may be similar efforts that will start
in Texas in the near future. Texas Desal Association has.
I had very good webinar series this fall to address
some of those topics.
Thank you for Jenn.
Thank you everyone for the questions. These are
really great.
And I'm.
We you know, we hope to keep everyone updated on an, you
know, the progress of this study. We will be producing
progress reports every six months. The first one will be in
March of 2021.
And, um.
And then it'll be six months after that, and we hope that we
can do more meetings such as this one where we can get people
together. This group of stakeholders together and have
these discussions, hopefully more questions than answers, and
any insight these questions have been really great. We really
appreciate everyone for asking these questions and an joining
us today and listening and.
Anne. So if there are no further questions then.
I think this would be the end of the meeting and hopefully I
will be emailing everyone soon with follow-up about where we
are in the study.
Thanks so much Casey, I really appreciate it and hope
everybody has a nice holiday and can relax and Stacy.
Yes, happy Holidays everyone and Anne have a
great rest of your day.
I'm going to stop recording.