 What I'd like to talk about is a produced water from unconventional now that we solved all the legacy issue We can turn our attention to produced water and I want to talk about origin of the produced water characteristics, what are the potential impacts, what are the management options, and I'm going to close off with a few thoughts on future challenges and opportunities in addressing and produced water issue. Everybody knows this, I'm going to spend any time on this slide except to remind you that you frack the water and I do insert K in the fracking business. I'm sorry I started like that 10 years ago and so I can't change you know although the original birding was without a K, so it was fracking without K. So you inject the fracturing fluid, you tear up the rock, you shove in the propane to keep the fractures open then you have to take the fluid out and that is your produced water. Now in the frack fluid composition, there's a lot of discussions there and the EPA website contains hundreds of chemicals that have been ever used in hydraulic fracturing operation anywhere ever and so there's like hundreds of chemicals, nobody's right mind is going to put all these chemicals in the frack fluid and so you can see that the chemicals range from acids, you know, bio-sides, cross-linkers and all of these chemicals have some purpose in the frack business and there's a lot of them but you're not going to put all of these chemicals into one job and the reality is that early on we try to put this in perspective by saying okay less than a half a percent of the total volume or mass of stuff injecting the well is chemicals, but considering that you know we're injecting five million gallons of water at 2,000 tons of sand, you know, half a percent is still about 50 tons. That's a lot of chemicals so that didn't serve the right purpose, but nowadays you know in Pennsylvania at least where we exclusively do a slick water fracturing they basically introduce three chemicals. Okay, fractured reducer is not single chemical, but it's a FR 300, FR 400, mostly polyacrylamide but you know there's one chemical for fraction reduction, one antimicrobial agent and scaling Hibber and that's it. So the the the and in that case the additives are less than 0.1 percent. So that is much better than half a percent that we used to use in the past. Now after you're done fracking the well you have to release the pressure, let the water come back out to open a pathway for gas to start migrating to the surface and that is a called the flow back because and it's just operational definition. It really doesn't matter. It's the first couple of weeks when you have an active crew flowing back the water and managing that water before you put a well in production and then suddenly we call it a produced water. It's the same thing so I'm going to talk about it as a produced water in general. So we typically in Pennsylvania get anywhere between 10 and 40 percent. This is this is a vertical well so it doesn't matter 10 to 40 percent and the flow rate starts off at 6000 barrels a day and then quickly levels off to you know 10 barrels a day or 20 barrels 50 barrels a day and actually here you have to choke the well to not take the sand out. So the reality is that the 10 to 40 percent of water comes back out during the flow back period and the rest comes back out during the operation as a produced water. So the question is why only 10 to 40 percent? Well the shale formation when you frack it there is a lot of water that's being held in the shale formation by capillary forces because we're talking about hairline fractures so the capillary force are holding a lot of water there plus Marcellus is almost bone dry you know it's very under saturated and it's a lot of watering vibes into the shale and stays there and then it comes back out over time with the gas production. So the question first question that people were asking is this fracking fluid going to contaminate our groundwater? Is it going to reach the groundwater and so forth and the DOE did a fantastic job in the Green County where they were monitoring six wells that are being drilled in the Green County. They had a few conventional upper Devonian wells in the Bradford formation and they put a couple of monitoring wells and there were monitoring this site for a very long time and based conclusion that they came up with is that you know there is the fracture growth during the hydraulic fracturing stopped more than 5,000 feet below the drinking water wells and there was no evidence of any upward migration of gas or fluids from this hydraulically fractured Marcellus shale well that's going to go up and start contaminating everything above it. Now the producers here were quickly discovering that they don't know what to do with this water But so the less of it comes back out the better off we are and so then they discovered if you shot in the well Not by intention by an accident. They ran out of they didn't have the pipes ready to go So they shot in this well for about 13 days or so and they got less than 10% of the water to come back out Just because the water imbibes more and more into the shale formation and stays there And that's a good thing for them because the less water that comes back out the less they have to deal with But the reality is that for example in this case We had a two wells that were fracked with a tap water you know they used to frack with a tap water and You know the two wells nearby actually mimic each other in terms of the quantity of salts or TDS Total is all solids start off at about 20,000 it kind of increases in levels to about a hundred in this case This was the well that was shut in for 13 days But it was fracked with the produced water reused in the formation So of course the salinity comes out much higher because your frack fluid was 50,000 TDS So your produced water is going to be at least that much and it's going to grow from there and the reality is that there's a lot of Data that people have looked at of various formations how the the water that comes the produced water that comes out Initially is a signature has a signature of the frack fluid and then later on has a signature of the produced water and you basically have you know reduction in the Hydroflex in the frack fluid and increase in the formation water and this is the paper from Conduction science of total environment to show you that here are the different Formations and their best estimate as to the salinity of the water and the volume produced and you can see that the Marcellus is pretty dry It's a very little volume produced and one of the producers early on told me if if the Marcellus were anything like Permian, you know with all that water we wouldn't be developing it as fast because we wouldn't know what to do with the water So it was just luck or the draw that Marcellus doesn't have much formation water and we don't have to deal with it Now what's in the produced water? Yeah, you know, you can typically look at this Anions, you know total dissolved solids, you know up to 340,000 and then radium and uranium radioactive active components and clearly when you see the barium that can be 2000 milligrams per liter and calcium magnesium fairly high concentrations the first thought that we had was that Yeah, maybe if this industry is systematically polluting the surface water We ought to see some barium, you know coming up in the surface water analysis And so because there are spills that have been recorded and so already talked about it So I'm not gonna spend a lot of time talking about spills They do happen, but these are spills that are in a DP web PADP website And they include two gallons here 20 gallons there even the spills on the line well pad are recording on the spill database And so if you look at the one mid-sized EMP company that in 2012 moved 68 million barrels of water and the total spill they had a 66 spills that were a total number of barrel equivalents were spilled was 1500 That's 0.002 percent of water that they moved around spilled I would think that's a pretty Decent record in terms of what happens with the water that's being moved around And so we look you know Sue and I have been looking at it for three years because we wanted to become famous and Show irrefutable evidence and say aha we got you and so Unfortunately, you know our good conscious We couldn't make a determination that you know the barium and the bromide concentration all these other contaminants are Systematically on the rise in surface waters in Pennsylvania Of course, you know once we get closer to this period where we're monitoring closer and you know this industry came to town That's one of the good things about this industry in Pennsylvania because Environmental issues came to the forefront people are much more cognizant much more Aware and are monitoring and looking at these issues. So that's good for the environmental gene department And so in and they're starting to monitor discharges, you know permitted Discharges from unconventional water treatment salt water springs and so forth and that's where you have this higher levels But if you look at Barium you can go back to 1965 and and today in 2010 the differences are not observable So we can't really say there is any systematic evidence yet The other question comes a lot is the organics aha in organics not a problem. What about the organics? Well, if you look at this, this is a very nice paper came out in 2017 where they looked at the 40 Compounds dividing to semi and the volatile semi volatile and non-volatile compounds that are associated with produced waters and these Group of researchers took all these compounds and say, okay, let's see what happens if we take a Well-feeled under development. We were drilling about 60 wells per year and assuming that 70% of that water is reused for fracking and That 30% is directly discharged into a local creek, you know during low-flow conditions What's gonna happen? So they took this a Risk-based approach to say how much of a risk is that gonna pose for the ecosystem in the aqueous environment? And it turns out of out of these 40 compounds that were initially identified There is only about nine of them that exceed this risk quotient above one and this risk quotient is calculated by dividing the maximum concentration of these contaminant in the I'm sorry in the river maximum concentration predicted in the river based on the dilution ratio with a Probo or not no effect concentration meaning that these were based on the studies that anybody has ever done with these Compound and what is the lowest concentration that exerted any kind of impact on? Daphnia or that had minnow or any of these aquatic species And so you can see that there's only a couple of compounds that have a fairly high risk You know three or four compounds that have a fairly high risk and the other ones are Not on the radar the reason why I'm bringing this up is that To me we shouldn't be focusing and trying to identify Everything that's exactly in that stream because we could spend the next 20 years doing that as the Equilateral equipment gets better and we can trace level detect trace levels. We can do that. It's not a problem We should approach take this risk-based approach to see what happens if this water ends up This produce water ends up in this scenario or that scenario how much of an impact is it going to make? Before we make a decision to investigate specific compounds Now what do we do with a produced water? Of course, you know you already heard in the video the 90% of the produced water is going to disposal wells We tried the discharge to publicly owned treatment works in Pennsylvania for a short period of time And then they quickly figured out that that's not a right thing to do We have some centralized waste treatment facilities in Pennsylvania that are by and large converted There the most of them were from from the conventional wells and very small flows and so forth But now most of them are being converted to recycling plants And then the other one is this treatment for reuse or surface discharge You know is the other option. This is what I already mentioned that Is a brilliant strategy that came out of Pennsylvania in support of the oil and gas industry So disposal wells in Pennsylvania very few of those available in Pennsylvania and no commercial capacity speak of and You know, they will probably play a limited role because most of the formations that are suitable for disposal are already taken for gas storage That the gas storage makes more money than the disposal well So it's unlikely they're gonna be converting these formation into a storage of disposal wells and the other thing is that people have start looking at these conventional depleted reservoirs and I'm nervous about it I don't think it's a good idea simply because if you look at this graph, you know from a classical graph, you know That looks at how far from the horizontal formation how far the fractures Extend to prove that in most cases in the Marcellus shale We're more than 5,000 feet below the bottom of the groundwater and that was the point of the figure But the other point that I want to make is that this conventional well are sometimes at two three thousand feet The other thing is that the fractures can you know extend two thousand feet if they keep fracking Overboard and so to me using the conventional depleted wells for disposal is a very risky proposition because like you heard we have 200,000 conventional wells we don't even know where they are and so the chances of connecting with one of these well wells are pretty high So treatment for reusing fracking operation. That's a great idea reduces liability in the volume of water And so we looked at what are the roughly the cost of the treatment for variety of options when you take it to a Class to disposal well, then you do a little bit of a treatment in the field for reuse or maybe you do a little Extensive treatment for precipitation for the removal or norm or you do the offside So there are technologies that are already in play that can be used and they cost money anywhere from three bucks of $3 a barrel to maybe $7 a barrel This is that based on the technical economic analysis got no market conditions built into these costs and so this is how we switch from 97 where most of it was Basically going through a conventional treatment in 2007 we started a little bit with the POTWs But right now 90% is being reused a little bit goes to Ohio and for disposal And there is a little bit of advanced treatment processes that can mechanical vapor heat and pressure and compression To remove the water and recover clean water out of it now The problem that I see and and I sit in academic institution I can afford to think five ten years down the road and the problem that I see is that Every well field eventually becomes a net water producer your water reuse For fracking only works as long as you have another well to frack once your Product your drilling schedule is out of whack for whatever reason either the barrel the cost of gas goes down or You're done fracking your ability to reuse the water is diminished more and more and these are projections you know in Pennsylvania that it's going to keep just going into the Number their volume of produced water that needs to be handled is you're going to keep increasing and these are projections that shell made in 2011 for specific well feel that at some point The amount of water produced is going to be greater than what's being able to reuse for fracking And then somebody's going to have to pay the piper and figure out what to do with this water Of course disposal wells are a big alternative in in Texas But as we've heard they're under pressure the capacity disposal wells is getting to the limit And so they're being taken by Producers and we're going to have to figure out what to do with this water And so we said we can do the treatment and the favorite response from industry is like okay We can do advanced treatment recover the salt and Do a crystallization and get sodium chloride out get 90% removal? I said great But the question is what are you going to do with all that salt and back at the envelope calculations say that you know Let's say we have 80,000 wells in Pennsylvania and we get 80% salt recoveries for free doesn't cost anything We're gonna be producing 8 million tons of sodium chloride in Pennsylvania You can't think that all of that is going to be using for the icing the roads because the entire US of a uses Maybe 12 to 15 million tons of salt including Colorado Wyoming and so you're not going to ship salt and beside the current salt Producers are not going to play dead and you know turn over and say okay go ahead So we need to figure out what are we going to do with this water and think about it as the resource rather Than a liability the other issue that's coming back higher my radar screen is this norm in Pennsylvania because we have the most Radiogenic Formation that we're fracking into right now There is very little norm being generated Comparatively and most of that goes into the landfills and basically each landfill has the annual Limit that it can accommodate and as long as you diluted with the garbage to stay below 25 picocuries per gram You're good And so but the problem is that right now we we had a when I did this calculations It was seven and a half thousand well So total radioactivity 22 curies when I divide the all of that by the volume of Solid waste generated in Pennsylvania. I end up, you know below five picocuries But if I make a projections What is the amount of radioactivity is going to come back out once we're hit over? 35,000 wells in Pennsylvania There's gonna be so much norm coming back out that I can't possibly diluted with all the garbage that's being produced in Pennsylvania and somebody's gonna have to ship it to Michigan or Utah and pay for a box of down for disposal So to summarize We've seen a rapid development of this industry and like any other industrial activity where people are involved, you know accidents can't happen But there is no evidence for widespread groundwater contamination by the fracturing fluid. There's no widespread evidence for Sustained impact on surface water quality. We have very little disposal options in Pennsylvania Those wells in Ohio are 300 miles away from payoga County So it's pretty expensive to truck the water there And so the flow back water you reuse is a great alternative for now works perfectly in Pennsylvania But it has a limited lifetime at some point It's not gonna be feasible and at that time we need to be looking and developing industries They're gonna utilize some of the resources that are available in this produced water Whether it's a sodium chloride calcium chloride for fertilizer or whether it's a lithium and some other components that are valuable And I think maybe the time is now to think about these opportunities in the future so with that I'm gonna thank you for your attention and be happy to answer questions No question