hello good morning good afternoon and good evening for everyone who's tuning in on behalf of biopet and Military sear shop I'd like to welcome you all in our summer internship program my name is May to a senior gas and petrochemicals engineering student s SP Egypt young professionals member and I'll be your moderator for today so before we start please keep the chat box professional and ethical and don't forget to drop your questions in the Q&A section below so without further Ado let's welcome Dr Muhammad who will give us a session on artificial LIF technology Dr Muhammad has PhD in petroleum production engineering with specialty in artificial left and production engineer engineering and operation he's currently a staff member of future University and a head of petroleum technology department of new cro Technological University meanwhile Dr Muhammad is global technical director of artif IAL LIF system for United LIF technologist Dr Muhammad is a technical and business professional with over 34 years experience in oil and gas industry with with long experience of Business Development sales marketing operation teaching and applications engineering covering artificial lab design operation Tres shooting and optimization for major services companies like lkin GE Tundra process solution with a Ford United left Technologies and oil field operation for a major operator like en agba GPC Dr Muhammad field experience include the setup installation operation and optimization of different forms of artificial left systems in the Middle East North Africa Russia Rania turkey and berai over the past years Dr Muhammad also has played a major role in the Practical training for the field staff and engineers in the oil and gas production engineering and while operation for different major companies in the Mana region USA Canada Romania turkey and Far East Dr Muhammad was Society of petroleum engineering s Egyptian Egyptian section president program and membership chairperson also he the membership chair person and director of SB International artificial left gas well deification technical section Dr Muhammad published and presented over 55 technical papers he te several technical sessions for local and international conferences and workshops currently he is a Committee Member of atce 2020 and 2021 MEF s Middle East artificial left conference Dr Muhammad is 2011 and 2020 recipient of the spa Regional Technical award in production and operation thank you so much Dr Muhammad for coming today and the mic is yours thank you may thanks as usual you know thank you Alum good morning good afternoon good evening would I just to continue starting sorry for what happened yesterday about the power and so on and connected disconnected today we'll try just to continue from what we are stopping at day about one of the major form of artificial lift we said just yesterday we plan to cover most of artificial LIF system most form of artificial LIF system yesterday we covered the first 2.1 and two and today we plan to going to cover some some some bsic informations you know general information about the G left you know while if you are aware of this one or know this one you can able just to understand very well the gas LIF and so on you know gas LIF currently as I said before you know they start to be one of the major artificial LIF after that application of unconventional fields and so on especially Deep Field high gas fors and and so on you know artificial LIF start to be one of the most economical sorry guys left one of most most economic artificial left for this type of field and so on then yesterday we said that you know just G LIF what is the gas lift and how it's working the gas lift how you start to to thinking about gas LIF when you start to think about gas lift G LIF is one of the major as I said you know one of the major artificial lift Forum you know especially for a certain application certain area if the G LIF is working for the well it can be most of the economical artificial lift you know it's lift is you can consider it is a a extension of Flowing Wells if you look to the gas lift you are it's behaved like a gas well like a Flowing Wells but with some artificially you know interference from your side you know for that Wells to keep the well flowing you know yesterday we said that in order the well to be flowing you must have the bottom hole pressures capables to lift or to lift the hydrostatic head of the flow inside the tubing inside the well up to the surface plus to overcome you know the Wellhead pressure we need we need certain value of wallhead pressure for the flu to move from the wallhead to the inside facilities whatever facility you have you know is in some areas the facility is far and there is a plenty of oil in in the fields and the pressures can be reach to more than 300 400 PSI you know then you need to have that value plus all the pressure loss you know you have down holdall from bottom to uh the surface and so if you are overcome to three these three items then the will can be flow but in this case will be flow artificially by you know by using naturally gas you know use gas compressed and you are pumping the sorry you are compressed the gas you know compress the gas from the surface at the surface inside the anulus and this gas you know through a certain valves we we plan to explain what this valve you know it's jointed the the produced flowed you know inside the tubing and and help or support the wells to be flowing and just produce the desired the required production to the Serv what type of gas is used for the gas lift system in general in general and majority of the worlds is used Natural Gas natural gas either from the produced gas from this well or some other Wells or if you have a gas field near of you you can use it you can use it and even sometimes if the Wellhead pressure of the gas field near of you maybe you don't need some compressors at the Serv plus sometimes you can you can have some air for very shallow Wells you know some ws and some area you know it's not not a common but it can be the main idea here to have some sort of gas in just mix it with the fluids in order just you know to help the well to flow to the C and can be mixtures of G ear and gas but however you know let us to focus in the first one you know it's using the produced gas or natural gas what we can found this is one of the M important you know thinking about how to use a gas lift and so on in general there there is more than one type of has left yes depend on the well depend on productivity depend on the bottom hole pressures depend how you want to produce these SWS what is the bottom pressures what's the amount of fls you have in the world and so in the market you know General speaking there is what we call First Continuous Flow gas LIF you are continuously Compressed Gas continuously injected gas in the O and the other also we have what we called intermittent flow G you are injecting gas stop injecting gas stop and so on how this type of just technique or methods is is is working I will just you know talk you through this one then we have two type of system of gas LIF it's what we called Continuous Flow G Rift and intermediate flow G Rift what is a continuous flow G how the convention gas LIF Continuous Flow gas lift is is working you know how a gas lift system it work for the conventional gas lift what we call continuous gas lift and so usually and also the other type of gas lift but you know in in the first one The Continuous Flow or just the other one you are injecting gas from the casing there's some some case but is not in our you know Focus today sometimes you know some people injecting from tubing this is different subject now you know but let us to f in the principle you are injecting gas this is a Yow arrow in the anul space between the casing and the tubing and the gas is entered to the tubing through one of uh a valves I will explain you how valves through vales or a certain part you know and jointed the produced fluids and lifted the flow to the surface you know like this you know if you look to this one this just animations about if one of this usually in in in gas LIF only one vales open at time even if you have more than one Val in the W in the W but only one Val is is open at the time the Val is open is called operating Val for this one you know you're injecting gas in the anulus and the gas just through go to the tubing through this port or this Val jointed the flow of the tubing and this is you know reducing the hydrostatic hit while one of the main purpose of that reducing hydrostatic head and also there is some other techniques here I will explain later on you know for the gas lift how to lift the flow and just you know is lifted the flow and then Continuous Flow this a continuous flow as LIF how it's working again how it's working in The Continuous Flow G LIF principle we said that we injecting G through the ANS the G is enter to the tubing through the valve the bottom bulb this one and jointing the tubing to the surface how is working how you simulated this one you know how is lifted float is only by reducing the the float Gravity the density the aage gradient of the float or what what we have this jointed gas you know joint the formation gas or formation fluids the produced float to LIF float to the surface usually there is one or more than process just helping the well helping the fluids to flow from bottom to the surface what is this process first all we thinking about and this is the main also idea and and the main concept in the gas lift is reducing of flow density I have a float inside the Ws or example water oil whatever gravity of the oil if it is the oil with API for example 40 in average gradient will be how much about 3 PSI per foot if I injecting some gas and the gas mix it with the fluid then the average gradient for sure will be less than3 BSI per foot then the hydrostatic head equivalent to the world dips will be much less this one of the main process what else yes in the same oils especially if you have high gas rituals de boils and so on this gas when start to travel upward you know look to that one the bubble of gas start to be expanded when the bubble of gas has expanded you know expansion of the injecting gas so that it push the fluid push the liquid ahead up usually the gas is moving up is not moving down you know then when the the bubbles of gas start to be expanded you know it's pushing the liquid or the fluid up further to reduce the colum weights more more helping you know helping fluids to move up and so if there is some other technique or some other possible process yes not only that gas as much as going up the gas the pressure decrease and when the pressure decreases the bubble of gas or SL of gas it start to be expanded start to be Biggers and bigger and so on and when we have a slug of gas big slugging of gas inside the tubing this slug of gas making like you know displacement all the fluid above of it you know then displacement of fluid you you by the slugging in the same WS you can found one of these process or more than one of these process for sure you know the first one is okay you know you can found just this is only bubble of flow reducing the den of the flow bubble flow with expansion of gas start if the gas start to move up and up with a certain velocity and start to be uh you know slugging then we we can you can have more and more process usually start to design the gas left and start to to look to What's happen down for two- face flow because usually gas left why you say it is an extension of the wall of the flowing was because usually you are dealing with two phase vertical flow concept for these Wells you know then when we start to design with the correlations we see we know what process in the well how we can move from one process to the other if we wanted to have more than one to process then which can start you know to control amount of gas and pressure of gas going to the Wells and and injecting to the Wells and so on this is a continuous flow gas left we said that in gas left technique there is two techniques Continuous Flow and the second one is intermediate flow The Continuous Flow the is using for high production for well producing continuously for the well with a good productivity and so on what happen if I have a s with low productivity this Wells you know only producing you know very low amount of floats and this float cannot be reach to the surface but the world hies you know the fluid inside the world it is you know what you call the float gra viscosity and so on the design said yes gas lift can working in that case in this case you know you what what you have will float is your will stopped and then you allowed the will FL FL to be accumulated at the end of the tubing if you stop the well there is technique what we called is a build up the will start to be build up building up what building up a fluid at the bottom because the floid is heavy you know floid at the bottom at as a predesigned amount of fluid head of fluids we be in the well then we know okay yes when the fluid is build in in the bottom of the whe for example 100 ft 200 ft 300 ft then I have to inject it in the anash to push that fluid that fluid already accumulated in the well to the surface when the float reached to the surface this is like that you know the well is STO no gas injected and there is a flow in in the bottom of the well when you have a certain amount of Flo in the bottom of the well I start to inject the red arrow know gas inside the anulus entering to a certain valve at the B botom this gas going to below the head of the below The Columns of the floats and pushing that fluids to the surface pushing that flu to the surface until the fluid reached to the surface there bues there since the flow reach to the surface then this well I stopped again after I stopped the well again and and and the cycle start to be repeated and repeated usually this type of intermediate gas lifted use for for low production for low productivity worlds and however it's not an economics it's not an efficient you know efficient because in most cases you have a lot of fluid slipped back again when you are pushing gas it's not working like a plugging you know it's a float you know is a float then the gas can be you know move through that flow and in in in it's not you know very efficient and so sometimes it's used for shallow Wells low productivity Wells when it was you know other form of artificial Li maybe is not economical and so on sometimes it's combined with some other type of artificial LIF like plunger lift and so on plunger assist however you know this is the second technique or second process of the gas lift system and so on you know this is slide just you know explain to you you know the process how is working you know if you look from from the uh left side one you know this is at the bottom there is a fluid you know just accumulated if you look to the surface you know what happened here you know the will you know immediately just before injecting G there is a flow in the bottom at that case you know you have the surface controller valve surface control valve is closed the same after I I have a certain volume of the flow inside the Ws what happen you know the surface control valve start to be open and allow the gas to be injected inside the well the gas go below the plug after the gas glow below the pla plug is pushed the plug to the surface second one is during the injection operations when the slug is reached to the surface in this case the there is a sensors at the surface you say okay this is now all the plug or the end of the plug or the gas the plug is moved and you know to the to the from the well head and so on the surface control start to be closed because the world completely now is fed with gas why I injecting more gas you know because only the flu is reach it and at a certain depth a certain place in the W head is since there is no more Flood now or the plug or the flu start to move and this only sensing guys you know then if when this close is allow the wells just to be stopped this just after the injection when the whe is stopped you know start the flow to build up again and the cycle is repeated this what you called intermittent gas flow gas lift operation usually know how I use gas from where I use gas you know what is the source of my gas how the field working with the gas LIF is looks like you know usually in all Fields if one ring with gas LIF or any type of artificial if you have more than one Wells you know in in the field more than one well all these Wells is producing when the well is producing producing fluid with gas all the production of that Wells going to the surface facility from the surface facility is have separations of the gas and the float they are taking some the some of the required gas you know required to inject based on my previous design and this gas going to a compressors the compressors is compressed the gas and you have some you know measuring control manifolds you know to control amount of gas required for each well amount of gas and pressure required for each well and distributed and the cycle repeated this if you are using the produced gas if you are using Outsource of gas then you have something different than this you have source of gas but meanwhile going to also the manold measuring devices control station and the control amount of gas going to each ws and so on okay based on that based on the gas lift based on why I use gas lift based on what I I mention about gas lift for sure there's some Advantage some limitation and some disadvantage for gas lift as I mentioned the gas lift it is an extension for the flowing W there is no moving Parts there is no moving equipment inside is a well then the gas LIF can be handle sand handle whatever even can be used for for deviated Wells for horizontal Wells for whatever type of WS there is no restrictions you know inside the Ws for flow to move in the tubing because there is no mechanical movement not only that you know G LIF really it's it's more flexible type of artificial Li for design rates if I design the well for example for a certain rate and based on W productivity based on the amount of fluid based on water cut increase decreased and so on I can control the injecting gas injecting uh volume and pressure of gas and the place even while I when I I need to inject the gas at what deps at what bu of the deps then you can have more flexibility on gas LIF for that reason one of the main important things for the gas lift is optimization is really is one of the artificial lift required continuous optimization continuous monitoring you know what's going on down hall do I use a gas in my in in my best efficiency best economical ways and so on you know since there is no you know nothing inside the well inside the tubing only the valves the G lift Valves and so on then the tubing have full poor tubing draft then you can run whatever you have inside the tubing you can do some W line operations some downhole perforation some downhole cleaning whatever you have you have a a tubing is is you have full por from inside the tubing even the whe head if you look to the whe head of the G left is only Christmas tree it's very small similar if you go to the well if you not notice the casing and the line going to the casing you saw that is a FL world only have a Christmas tree in in in in the well at the well head and so on the equipment the gas LIF or it's using what you call gas LIF Val this gas lift is can be retrieved by wire line slick line what we call you you don't need a rig no rig for that reason one of the main reason using gas lifting of short operations you know because it's not required in case any problem happen for the gas lift Valves and and in the down hall you know you know you can use you know multi- well production from single compressor as there the previous slides what I mentioned you know we have one compressor and this compressor you know is Compressed Gas to different Wells you know maybe to I don't know depend on the amount of gas the volume of compressor then from one source of compressors you can run different well for that reason again it's using as a platform you have only one compressor and one compressor run all the wells in the plat forms and so on you know but meanwhile no no one of artificial lift have only advantage all of them have some Advantage some disadvantage some limitation limitation mean that I can use but you know with a certain limitation with a special design was we have to be monitoring closely the economics the efficiency and so onion this is type of artificial that need high pressure gas well or compressor you need you must have a compress to compress the gas you know or or if you have a high pressure gas well near of this then okay you can you can run this usually one well is non economical because the compressor running compressors you know it's really the operating cost is is high and so on you know since it's using gas and gas simulated the wells and the gas injecting to the flu and try to mix it with the flow then when the viscosity of the flow increase this is efficiency of that gas injection will not be high the flood will be slipped you know the gas slipped and the flo will be know will be a big difference in viscosity and so on this is like a Flowing Wells depend on reducing hydrostatic head then any bottom hole flowing pressure change is stive because I in this case what I have I simulated as I said like a flowing wall then flowing W depend on one bottom ho flowing pressure to lift the flow to the surf then when bottom ho flowing pressure is changed you know decreased or increased whatever then the gas lift efficiency will be changed same here you know the back pressure the will head pressures you know we said that the poal flow pressure must have must be equal the hydrostatic head plus the wellhe pressure plus the pressure loss then when wellhe pressure is increased that mean the the volume of gas I need to inject or just the place of gas I need to inject it can be you know should be you know re redesigned or just reevaluated and so on and maybe sometimes it's not economical or sometimes you not able to lift all the flow then the back pressure is so stive when you have the back pressure sudden immediately you have low production any any any any operations in the surface facility in pipeline it's it's creating some pack pressure increasing the wheet pressure you will notice that the well production of production from this well will be decreased what is the equipment used for gas lift what type of equipment usually I use to gas lift the well since I said you know I I I I run this well with artificial Li then is must be a certain equipment used to artificially lifted that Wells and all type of artificial lift when you start to say equipment used to artificially lift that walls that's mean we have a surface equipment and downhole equipment for gas LIF what equipment we have this is a just you know show you these slides you know simulate what the guys left was you what we have in the bottom of the whe what we have in the surface of the W for the G left you know component what component I have what is the downhole component down Hall that's mean all the equipment in the well below the well heads down to the Wells whatever I found in the wells we called downhole equipment what's the downhole equipment for gas lifted Wheels mainly we have gas lift valves some valve because you know I injected gas but you know I I need to have some control for the gas is injected where I need to inject the gas I need to inject the gas as a as a depth of 1,000 ft or 2,000 ft or 3,000 ft or whatever then at what depth I need to inject the gas how volume I need to inject the gas then I need to have something sort of control some something to control the amount and the place of gas to injecting down hall the Ws this what you called gas lift valve how the G left valve will be installed inside the well the G left valve like this picture you know just a pie of equipment it's it's very small and so on you know how you fix it inside the well because this must be fixed inside the well and meanwhile must be allow the fluids you know the gas to communicate it the fluid to communicate it they come some sort of communication between the flow in the anulas and the flow in the tubing then this gas left valve is installed in what we called gas lift mandrel Mandel gas lift mandrel it is a place in which the the valve is placed this is a g left valve and this is a g left valve inside the Mandarin and this is the mandrel usually the mandil is a part of the well completions when you R the Wells you run the whs and you have a Mandel with threaded in in the top and the bottom and you you are connecting to the tubing at a certain predetermined deps or predetermined places and you connect it after you run and you can run the W line using W line you run the wi line you run the valves or just after that you can retrieve the this will be you know how the valve installed inside the manderin in in the down hall these a m there's some some type some some accessories I can use sometimes in in in such type of oils and so on you know and this is a gas lift equipment you know I am not talking about completion now I'm talking about the gas lift equipment and so on in this case you know if you look to the gas lift valves with the gas lift Mandarin this is one you know the red colors this is the gas and this a gas lift Val and this is a gas lift Mandel just zooming on that one you know when at a certain Delta P pressures between the tubing and the casing the valve is open allow the gas to enter to the tubing and when enter to the tubing float and lifting was one of the process what I mentioned before at the surface remember we said I must have a control I must have something to control the will it's open or stop volume of gas pressure of gas injecting and so on then I need to have a compressors or high pressure line compressor high pressure line usually is not for one well compressor sometimes you know for in most time you know for couple of WS more than well but however I need to have a source of high pressure gas high pressure gas come from a lion from a Wells from compressors and so something you know to compress the gas and to just give me a gas at the whe head with a certain value of pressures over this gas plus the whe head in in head for G lift is very simple it's just a Christmas tree and so on plus a controls control valves or control whatever just to control flow and control pressures and so on then let us to focus a little bit more about valves gas lift valves and gas lift mandals and so on and how what we need gas lift Val someone say okay why we need gas lift valve this is a cross-section you know on the on the on the mandil and the valve installed inside the Mand then the gas lift valve we are needed gas lift valve to provide the communications some Comm communication for the fluids between the fluid in the anulus and the fluid in the tubing I have to communicate you know between the flood in the anus and the flood in the tubing you know with a control when it's open when it's closed when I need to have the communication when I need not to have a communication like isolated like stopped this one you know then the valve used to control the flow of the injected gas into the production tubing then I need to inject gas in in this case or I I need to stop I need to inject gas at that deps or not or deps deeper or just shall and so on then the valve operation in this case it's depend on a preset opening since the valve is controll then I have to preset the valve preset the valve what what that mean the valve in the workshop just to set that valve I say okay this valve with a certain techniques I will show you later on certain techniques this valve should be if the pressures in the anulus is higher than the pressure in the tubing with a certain value the valve should be open if the pressure is low the valve should be closed if the pressure higher more and more and more in a certain thing you know the valve should be open or close then the valve open or close it's built on a preset preset the Val in the workshop we say okay you if you have a Delta B across you from the casing and the tubing you need to open or you need to to close you know then in this case you know the Val operation depend on preset opening and closing pressure in either tubing or casing he s with the Delta B from casing to tubing or from tubing to casing there's different Valves and different technique of Val using for this then each one looking for the gas lift WS or gas lift completion you will found more than one valve in the well the world maybe have five valve six valve 10 15 small you know then I have more than one valves in the world why I used more than one valves inside the wells you know more than one Val inside the wells is this all the Val is working is this all the valves working at the same times or what is the reason using this valves usually all the valves in the Ws inside the Ws it's should be only at the times when I have operation only one valve should be open and the rest of the valve will be closed the same time when one valve is open the other valve immediately it should be controlled based on what based on the preset pressures uh in in for the valve in the workshop all the valve inside the W the W have some name certain names in all the valve inside the worlds above the operating valve operating valve that's mean the valve are continuously operating to inject gas and this Val is open and allow the gas to go inside the tubing all the valve Above This valve is called unloading valves then what is unloading valve the bottom one is called operating valve or orifice valve some people know it's oral Valves and so on but all the valve above that is called unloading Val what mean of unloading why I need to do this unloading or unloading valve as I mentioned before you know according to the valve LIF valve G left valve design all the valve will be closed until a certain condition of pressures across that valve between casing between anulas and the tubing is meat or riched when the valve is open it's allow the gas or permit the gas to pass from the ging to the tubing and mix it with this one and operating gas lift valve is installed as I said before you know to control your you know the injection point when you need to injection in this point or in this point or in this point or in this point you know above or below you know okay then the valve are installed above the desired valve or operating valve is used for unloading the wells let us to see what mean of unloading the wells and why I using usually when the wells is die or just the stop or after work over or have some shut down operation and so what type of fls will be inside the tubing in this case you will have inside the tubing only liquids because if the whe is stopped then the liquid accumulated have a liquid inside the tube if the will is producing and stop due to any situation any type of shutdown any type of operation then I have a liquid after work over operation what type of fluids you will have inside the tubing and the anals you have the killing fluids you have the killing float usually it's it's you know I don't know water or KCl or diesel whatever you have then the flo all the whe will be have only single face liquid phas Flo inside the whe if there is no unloading valve and I want to produce the well in this case I if I want to inject gas I need to inject the gas to a certain place this gas the gas pressure add the surf and until is reached to the operating valve these pressures you know should be you know should be roughly equal the hydrostatic head of all the fluid column inside the tub and usually the float column inside the tubing especially if it's water the hydrostatic head will be a very high in this case I need a very high pressures at the surface as the beginning very high pressure then I need a very big compressor very high pressure then I need a very high will head very high pressure rating will head equipment and so on you know then also the outside the tubing collapse or tubing something like that should be withstand all this type of pressure for that reason they are using sorry they are using the unloading valve then unloading valve what we mean I injecting gas and I will show you this is a loading technique for that w the first valve is open then they lifted the amount of FL from here to the surface and this amount of FL will be you know only about two phase flow then reducing the hydrostatic head when reducing the hydrostatic head and the second valve is open the first valve is closed and reducing this hydrostatic head after the gas is injected and so on there is some some slide later on you know will go through this in details and so is there is different type of valves in the in the market yes there is different type of Val but there is a main common technique main common vales using in the market you know there is some smart valve and some other technique of valves and so on and the most common valve the first valve of called you know injection pressure operating valve i p o injection pressure operating valve is respond to injection gas pressure that's you know this valve is open or closed based on the pressure outside the injected gas in the anulus pressure of the injecting gas of anas add the valve deps the second valve is called production pressure operating valve PP o production pressure operating valve is respond to flowing pressure based on the flowing pressure inside the tubing inside the tubing at the valve deps this is you know just schematical about how this injection IPO valve is working you know this is simulated to the flowing and this is a valve mechanism you know how the valve you know if the injecting gas comes here and this is a pill under the valve you know is preseted in the workshop with a certain volume certain pressure of nitrogen whatever you know then will be under pressure If there is no pressure from outside this is pressure is pushed this port and this port in the bottom will be closed and when the gas the pressure outside this gas outside this this gas LIF reach to a certain value is higher than the pressure inside the pillow is lifting this one this port is open this port is open and then you allow the flow to go and so on this just you know I I I I I keep this for you just to understand you know how this valve is working what the difference between this one and this one and so on I said you know the second part in downhall equipment or the gas lift equipment is the Mander Mand in which the valve I installed you know I installed this is valve and mandalin then the valve installed inside the mandin generally speaking in the market there is two type of mandarins like there is different type of valves but mainly there is two type of Mandarin one we called conventional mandarins and the other one called you know retrievable wire line mandril conventional mandrel that's mean the valve installed in the mandrel but you know it's not from inside the tubing this the valve installed in the Mandel before I run the mandril in the wells before I run the completion in the wells and usually this type of matal Ed for shallow Wells and so on you know it's it's not expensive but you know it's not economical as the operation point of view was in case I have some problem with a valve I need to change the Val for some operation and so I have to pull the completion completely to retrieve the Val and change the Val the main common one is what we called you know it is retrievable or side bucket mandal you know conventional pressure valve or or retrievable side bucket Mander in in in this sorry in this one you are connecting to the tubing and you have a certain configurations you know while the valve is installed inside the Mand inside the tubing in case if I want to just to retrieve the Mandarin with a slick line I run here catch the M the valve retrieve the valve make repair replacement whatever and rerun again and so on is one of the main common valves main common Mand used in Z mon let us to back again about you know the loading sequence how to unload the wells I think unload the wells that's mean when the well have completely full with the liquids completely full with the liquid then in this case you know we are running the gas lift different gas lift Mand in or in order to reduce the amount of float the pressure of gas need to inject it and Resto the well to production after whe is completed usually as I mentioned before you have some certain float inside the tubing and inside the casing the gas lift pressure it's have a certain availability in in in the in in in the field you maybe in most cases not generally enough not high enough to lift all the hydrostatic head inside the well if I have a well for example with a depth 6,000 ft and the float gradient point3 ising up more than 2,000 PSI like that then you have you need to inject gas with more than 2,000 PSI what if you have a o at 9,000 ft or 10,000 ft or 8,000 ft what if you have a not only not not oil I have a water with a float gradient 045 saline Waters or something like that you need 4,000 5,000 P that's usually is not available or required a very high compressor and just to do that in in this case you know a series of unloading the will to reducing you know amount of pressure or value Vol value of pressure required to unload the wells using a different valves and a different depes inside the whe and this one of the main important design steps in design when we design the gas LIF uh how to design the valve valve spacing valve place inside the whe in this okay in this case the valve is designed just to use what's available of gas based on my availability of gas and the the pressure of gas I do the design and I spacing the valve inside the Ws this just a first graph you know talking from some Slumber presentations this graphs you know showing for the left side one well well is full with the liquids kissing and tubing you know if you look to that liquids you know the pressure at the bottom against this liquid this what you call chutting bottom hole pressure in this one unit then the pressure in the casing and the pressure in the tubing almost the same the gradient in the casing is the same pressure of the gradient of the tubing the top one is the casing pressure the bottom one here you know is the gradient is the tubing the pressure of the flow inside the tub and this is you know the required will pressure to give the flow to move to the surface what's the mean of unloading how to unload how to reduce if I want just to lift all that flow then I need pressure at the surface equal to 7,000 P because this the onus will be full of gas the tubing will be full of liquids and in order for that gas to push the liquid the gas density is very very low you know then all that should be full of gas then the pressure here should be equal the hydrostatic head of the pressure inside the tubing then if I need just there is there is one valve or and and I need just to lift this if FL then I need a pressure at least 7,000 PSI to lift that one but generally 7,000 is very high then for that reason we use more than one valve to unloading the whe how that can be reduced the amount of allhe pressure when you start to inject G in the casing what happen here you yes in this case in order to reach that still the pressure at the bottom is the same you know pressure between here and there is the same but we compensate you know the equivalent pressure of this liquid inside the tubing in the anulus with the gas then thehead pressures of the gas injecting gas here reach it to more than 1,000 PSI then I have to have more than 1,000 PSI just to push this amount of fluids you know inside the tubing and so on then I still I still above the first valve there is no gas entering to the tubing when I start to increase the gas increase the pressure and when I reach reached to around 2,000 PSI I reached with the gas to the first valves when the gas reached to the first valve what happened here you know when the guys reached to the first valve the valve is open when the valve is open it allow the gas to enter inside the tubing when the gas enter inside the tubing is mixed with the flow when the gas is mixed with the flo then the average gradient of the flu from the depth of the first valve up to the top is less than the dead oil this will be low then if you look to the this blue curve you found here the gradient start to be decreased you know then the pressure here you know if you look to the pressure is moved a little bit you know because hydrostatic head here is equal only the the head of the liquid this only Liquid Plus the head of the two phe flow in this one then the equivalent pressure is less than bottom hole now than one 7,000 BS if I start to continuous continue inject gas yes I start to continue inject gas in this case you know I increase the gas pressure increase the gas pressure and in this case until I reach it to the second valve when I reach to the second valve what happen here yes the pressure reach to Second valve second valve is open then allow gas to enter inside the the tubing then the head of the fluids from the second valve up to the surface will be to face flow the gradient for sure will be less than the dead liquid then the pressure at the bottom of the Ws start to be creating some draw down some pressure less than the formation pressure this allow the formation to produce some two-phase flow because the flow in the formation is oil and gas start to produce some fluid enter inside the well where the pressure is decreased and meanwhile you know the I still continues to inject I still continues to inject and so on until you know all that downhall pressure is increased to the pressure I already decide or already designed before when I reach to a certain amount or a certain deps you know in this case you know I I consider this like an operating valve and the will start to be reduce this the ideals instead to need remember at the beginning I said you know in order to keep this well and lift the flow inside the well I need almost 6 or or 7,000 BSI now I need only 2,000 PSI see how much saving in pressure at the surface when I using more than one bu inside the W you know this just you know some some graph is not not we talking now okay in order to design the gas lift or gas lift valve or all type of artificial lift system for sure you need to have more information remember yesterday I said when you selecting artificial lift you need to consider all the aspects in the wells all the aspects on the reservoir in the in the in the Wellhead facilities in all all the criteria of the fluids and and so on you know then for design of continuous gas lift we need as much as information you put in front of you you will output design will be you know will be more efficient and more good design I need to know what size of tubing inside the well in order to know what the two- face flow pressure loss will be inside what size of material I have to leun what size of valve size of casings in the anulas between casing and tubing and so on dips to the center of perforation what the depth of perforation because in this case you know this is what you call this a flowing walls extension flowing well then I need to have to know very well what's the bottom hole flowing pressure what what is the oil API oil API and cons consequently the gravity and viscosity and so on what's the formation gas oil ratio because I will injecting gas injecting gas what volume of gas I need to inject I need to in volume of gas depend on how much even the formation assist me or help me because I assist the formation or help the gas formation I increase for example if I will produce with gas oil ratio for example, 1500 standard cubic feet per day if I start to inject gas some volume of gas and I reach to 700 standard cubic feet per day then I increase the oil gas oil ratio increase the gas o ratio I decreasing you know the hydrostatic head and and so on you know specific gra of the formation gas and so on what the required production if there is a water you know what what water I have what specific gravity of water because I will lift that water you know against how much will head pressure I will have to design my gas LIF valve since I running or just I dealing or I working with a gas then the gas is sensitive to pressure and temperatures remember the gas low you know there's two main ter gas low pressure and temperatures for the gas pressure and temperature affecting with each other on the gas you know injecting gas pressure available if there is a Wells if there is a gas field near me or there is a compressor what size of compressor if if new compressor or just a compressor already in the field I have to rerun new ws and so on you know volume of gas gas availability and so on bottom hole pressure productivity index type of reservoir and so on you know is a minimum information I have to have when I start to design some gas lift information gas LIF design there is different way way different methods use really there is a lot of uh what you call software in the markets you know software there is some commercial software General softwares and it's very efficient software and some also private software some you know in-house built-in software you know a lot of major surface company have their own software to design the the gas LIF and usually most of the different methods incorporate different design philosophy based on what philosophy you have based on what type of valve I have remember I said I have injection pressure operating valve or a pressure or or a production pressure operating valve what type of valve I have what type of will I have you know what type of correlation because you know sometimes you know due to change in flood parameters and flood concentration water and so and maybe required some correlation to correlate what is a two- fa flow inside the tubing maybe Chang it with time and so on then as I said you especially for gas lift you have to simulate what you call Nole analysis what type of of flu what restriction where is I need to to reduce the the restricted pressure and so on and sometimes you know we are used manuals manual design it's not efficient sometimes used for very shallow for a small well but you know for critical Wells no computer assist methods program like Prosper VI and so on you know there is a lot of software using in the market I will just you know since most of you just are student I give you just a very very quick hint about the manual methods and how how they are designed while the the the software depend on that you usually for the manual method design of gaslift I have you know just I need to design the gaslift like this the left side how many valve I have to run in the well at what depth each valve will be the first valve second valve third valve what's the space between first valve and second valve for each whe is a unique each will have a unique design unique system depend on a lot of value all the information I I I presented in my previous slides and so on you know you need to start with a graph like this you know you have some piece of papers in the top one you are you know representing or just have a line to represent the pressures and in the vertical one you need to have the line represent to the depths and at the bottom you need to have at what depths What depths of my perforation What depths of of the last valve I have not to run Below in this one then you have a sheet of gas LIF graph what you call this a gas LIF graph of two these two axes you know horizontal and vertical axis and so on first thing on this graph you have to you know to construct or just to determine what gas availability what gas pressures available because based on my availability I just design the system design the valve space based on availability of the gas pressure and volume but here you know let us to consider what's the pressure gas what is the injecting gas pressure and at the surface what will be the injection gas pressure at the deps you know due to change in pressure change in temperature gas gravity not big difference but you know you construct a line like this one you know this can be determined from simulations run if you want to just or just you know empirical charts there is some empirical chart depend on gas gas gravity gas proper you know uh temperatures and so on and some there's some simple equations can be used then based on the available what the maximum pressure will be at the surface and corresponding will be how much the pressure if I injecting down hole this this is represent the line injecting pressure gas you can use some very simple rule of sample like this one you know pressure at T so you know so pressure at surface and and you know multiply 2.3 for pressure at cus over 100 f depths at which you need to calculate the pressure of gas over 1,000 FTS this is a very simple you know roughly calculations you know because you know you need to have some in you know information about temperatures and some effect of temperatures and so on you know okay then I have this and construct this line second line I need to have this you know what type of fluid inside the well is the water is the oil what type of gravity of this one you know then I need to draw a line from the upper left corners from zero here upper left corner of the gas left paper representing the static flow gradient inside the whe while the static float gradient is very simple technique you know equals the float gradient multipli the dips and so on then you have second line now we have two line line represents the gas I I will injected line represent the flow in the wells what type of flow in the wells sorry in the well yes what type of did flow in the well what you call static gradient in the well then when I start do that I need to also to un know to know previously what will be the gas liquid ratio unloading gas liquid ratio I have to use available it should be equal available indicting gas plus divided by the desired production rate you know I have a gas and I have a production rate I have to lifted from this well this what we call how much amount of gas I need to inject it how much amount of gas I have to you know to design to lifted this flow you have to note that you know you are lifting a de columns from this well and no gas inside this well and then for example if I want to just you know to produce or just lift 600 Barrel a day from the ctin O and all the available of gas what we have gas rates from the compressor as the we sites in it's 1,200 mcf per day then the injected gas liquid ratio is divided by this two is equal 2,000 standard cubic feet per barrels how to do that how to help how to allow that you know it's usually you have two phase flow correlations like this is can help you or can support you and in this one you know and you need to select what is the propers what is the sbles Two Face flow correlation flow gradients curve you know I have to use this depend on what depend on a lot of information for example what tubing size and size well because each curve represent a certain tube cubing size each curve represent at how much flow I have to read this is 600 then I have to select this chart for 600 bar day W what API gradient fluids what were AI oil AI for that load I have to LIF for example this one is represent 35 API what's the gas specific graphity I injecting gas for sure each gas has a certain specific graphity what's the specific gravity of that gas what is the average flowing temperatures as I said you know temperature is have a very big effect on the gas you you start to look to what the suitable two phe flow correlations or just flow graphs the gradient that exist and you select this one these the first steps after the second after the the the the previous slides I have to do for example this one you know as I said you know each curve represents sometimes a certain correlation at a certain gas liquid ratio and so on then I represent usually I I I construct this gas lift this is gas pressure line and this is hydrostatic line based on the previous curve I select yes how much my gas liquid ratio for example if it is 600 as the previous design and this is the situation of the well flowed well completion I found in the well I produce 600 bar per day with 278 in tubing and so then I select this curve you see that curve at 600 per per day and I took this curve exactly and I put it you know in the same chart but at what you know it's not starting from zero starting from the well head pressure I stopped at the well head pressures you know and I overlay the gas papers this gas lift paper on the curve and I track the curve represent the calculated unloading gas liquid ratio then I have three lines on this curve like this you know three lines let us to say how we select the first valve second valve third valve based on this this three line if we are using triangle and constructing a line parall you know this line parall to the static gradient static gradient of that flow this D line you know and we moved that line until is reach to the well head pressures in the line from the well head pressure until you know that you know this line is construct you know or just interact with with a gas pressure line then in this case you know you have construct a line parall to static gradient starting from one starting from wellhe pressure at zero depth at the surface to the point to what point to the point where it's intersect with the casing gas pressure this line you know this solid line until is reach it here this theoretically should be the depth of the first Val but due to downhole sometimes it change it downhole we don't know exactly you know the pressure temperature what's can be effect efficiency we take some safety factors safety factors depend on the type of vales the type of gas the type of oils a lot of things but in general you know the people is sometime people you know according according to some situation is using if you don't know you are using 30 ps t Factor instead to install the valve for example at depth 4,000 ft no I left this to the top little bit until the difference between the the the pressure of the gas and the the the curve represent the two- pH flow pressure is the difference between the two is is around 30 p in this case I draw a horizontal line until reach to the the the depth line and this represent the first valve dipss of the first valve okay this is same technique used for the second V you know but I have to to remember that this valve Now is working with a pressure not at the surface temperature work sorry at with the temperatures at the temperature not with the surface temperature then I have to know what the temperatures at the will then I have to also draw the temperature gradient curve in order to know for example the first Val it's working at 100° F then when I have to preset the valve pressure at at my workshop the pressure inside the valve I have to consider these pressures should be open and close at this type of pressure this type of temperatures and so on because if I if I ignore that then the condition of the pressure will be changed because the valves will be full with the gas and so on with the same technique you are going to determine second valve third valve fourth valve until you reach to the bot however this is manual and not many people is using just this is you know we are educating the student you know just in order to understand the software and so on how to have but however you know there is as I said there is plenty of softwares and software will guide you you know through each point you have to consider you know in in in the design he will ask you about what type of valves who's manufacturing this valve you know what size of valves what you know the total deps you have in the worlds what the production required and so on and this is a screen what inside you some input data and output data from one of the measure using one of the common used uh software like viam and so on you know and at the final he generate something like what we are doing by your hand you know but is more accurate taking into consideration all the factor while are not able to taking by using a hand calculation at the end after you you design this valves and place of the valve you have to generate a table like that because each valve this valve number one valve number two three four each valve should be working what the depth of the valve what is you know the temperature of the valve what the working pressure should be as the valve open and close and so on you this just you know the valves and design of the valve I like you to remember since you are working with artificial lift for each type of artificial lift in the market there is an API and ISO standards you know can guide you and control the manufacturing the design guide you for design and so on you know this slide just show you some of the main common list of API and ISO standards used for gas lift system you know you if you are click on in in each one of that you know will open for you for example you know AI specification 11 PB it's gas LIF Val orice and dummies you know it's GI you all the spe about the gas lift Val the sides was inside and in what size of mandal you have to run and so on you know um you have you know for for example you know you have one like RP 11 PB is recommended practical for G lift system design the one before the last one you know is recommended practical for gas lift system design and performance prediction yes how to design G LIF is just guide guideline you for sure there is some assumption in these worlds and so on it's not like the software but this can guide Len you about how to design and and so there's several difference you can reference you can you know you can look for about G lift and gas lift system design operations and so on this just you know a very basic information about gas lift how the gas lift is working and you know how the G LIF design what the mean equipment is the G LIF is a big subject but you know this is just the first step in order to you know to understand and to learn about gaslift thank you and this is just you know thank you thank you so much Dr Muhammad it was really really informative thank you for time and effort uh we just have a few questions the first question can we use gas lift in high viscous fluid it's not recommended you know it's not recommended because you know for high viscous Flo you are injecting gas and the gas going to you know should be mixed with with that float if the float is very high viscous then the gas will slip from the float if you look you know when you start to you know to design or just to study two-phase vertical flow correlation there's some you know some terminology called SLI and hold up and so on and usually is not recommended this is the last choice to use gas lift for for for for high viscous [Music] floating okay and the second question if the Well's productivity is very low until a point in which the the surface line of the formation fluid gas and oil is below the the P the Packer is gas lift is sufficient in this type of cases no no because G LIF you know simulated FL ons and gas lift he have to lift the fluids inside of the world in this case you know if there is a gas enough gas in the formation and the fluid is not viscous fluids and so on maybe maybe you know and not deep well and also not deep Wells you know maybe sometimes the intermediate gas lift can but this required to look to the the the properties of the float the downhole pressures the depth of of the wells and how much pressure I need to have because you know but for sure will not be efficient you know and sometimes maybe we used by as I said with some combination if the gas liquid ratio is high enough what is a produced gas liquid ratio to a certain value there is a technique maybe in the lecture number four or later on we can present it what you call gas lift assist plunger system plunger lift system but it's not recommended you know okay the last question is it possible possible that after designing a gas lift valve depth the liquid level Falls below it yes it's possible because you know a well if if if you're running with a depletion Drive reservoir for that reason I said you know if you remember I have different valves in the wells and the gas lift system is a flexible when we design I have to consider this is Reservoir is a depletion Drive Reservoir with the time the bottom hole FL pressure or Reservoir pressure is depleted then when I design the valve I have to consider not to operate with the last valve maybe I can keep one valve or two valves you know as a spar you know to do that but it's sensitive to the bottom heart pressure for sure yes okay thank you so much Dr Muhammad K and thank you all for your attending highlighting that this session would be recorded and uploaded soon on Pat YouTube channel so make sure to subscribe on our YouTube channel thank you so much all and bye