Empower Your Business with Pipeline Integrity Management System in Affidavits

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okay hello everyone welcome to our next session uh this is uptcs and spso here our next session is about the integrity management system and our speaker the other speaker is most of all uh mr muslim soccer halls two masters degrees in controlling engineering from abu dhabi university and innovation management from cambridge university also he is engineer and the natural class analyst his mind huge years of experience in the upstream oil and gas sector mainly in production technology managing assets and other ones due to this reason i want to say that you can use just use and value this session and enjoy from this session i want to give the stage to speaker support support you can sign yeah thank you so much thank you for the for the introduction uh good evening everyone salaam alaikum and i am mustafa i will take you through brief concepts of all integrity and weather integrity management systems what is well integrity why do we know why do we need it why it's important to the business uh why oil integrity management system is useful and what are the tools and the toolkits for managing world integrity in practice why wells fail we have wells made out of steel well-designed and we have strong materials but they fail in the end they fail because of the interaction between design operation environment the rating to their equipment the pressures the operating conditions and the way we treat them putting this all together will make the steel the the very hard material that you can see on the surface make it very brittle make it very soft make it corroded and make it fail would it add value to track failures in in wells imagine if you have wells that has collapsed pipes or burst tubing or leakage in the in a a or b annulus and you don't know where is it you don't know if it was fixed or not you don't know what was bending you don't know what was the reason and this these diseases keep spreading in your wells tracking tracking failure events and tracking the reasons is one of the key steps in managing your stock to fix your wells and managing your future operations which wells are fixed to operate and which well wells are not safe to operate and you need to take actions on does failures related to specific type of wells in specific reservoirs absolutely not all wells fail but with different percentages wells that are in conventional unconventional onshore offshore reservoirs they fail wells that are drilled for water injection water production gas injection or gas production all of them fails even wells that that are drilled for carb storage they fail they fail because of that as we said because it's not just the matter of i see a solid salt steel on the surface it would be solid all the time no it depends on the material the operating conditions the pressures and temperatures and the age of the wells the erosion velocities of the fluids and all sorts of things what element failed the most from a study by richard and davis in 2015 he found out that the majority of failures more than 35 percent of failures happened because of tubing problems leakage and through tubing corrosion and tubing burst in in the tubing followed by the conductor an ir safety valve casing and wellheads and brake breakdown of the rock formation it comes it comes at the end but what is what is well integrity of the bits simple introduction well integrity is the application of technical operational organizational solutions to reduce risk of uncontrolled release of formation fluids throughout the life cycle of the well so we manage technicals operations and organizations how we design and how we operate our operational procedures and how the organization behaves how the organization deal with events we gather them all to make sure that the wells are safe and they don't release any fluids in uncontrolled manner throughout the life of the well through drilling through the through production through specific operations and down through abandonment so the goal of will integrity is to reduce risk in technical terms to as low as reasonably practical which risks we want to reduce is the risk of having uncontrolled fraud from the well we don't want the corrosive toxic flammable fluids to be released outside of the wellbore to the environment because it will harm people and it will uh it can cause severe damage fires and as we're gonna see later but which fluids we want to control as we see from the definition of well integrity it just to protect against uncontrolled release it didn't mention whether these fluids are only flammable fluids unflammable fluids it's all fluids the wells should not produce outside the environment they are producing for so an injection well should just take injected water in the designed formation not in all formation of the well acts several formations a well that's producing from reservoir x fluid should not go into reservoir y or go to the be released to the atmosphere a water source well the water should be produced to the surface surface water network not to be released or relate to the environment so the main goal is to reduce the risk of having uncontrolled slow throughout the life cycle of the well well integrity should be involved in the beginning in the end and during and during the operation phase of the well in the early in the early stage of the well if we get any kind of failure it's an indication of quality of the material we choose quality issues with the design and if we get integrity issues at the late life of the well it means it means that the degradation and the weird rate of equipment has been reached and anything in the middle it's it's a cause of uh the the frequent stresses that the wells get subjected to so if the tubing for example fails because of uh uh incompatible material and you get and you get corroded uh kuru the junctions this could happen very very early in the in the life of the well and you can have a damage a damaged sub-surface safety valve because of the passage of the wildline through it and or you can have fluid erosion that can cause problems to the flanges and valves that they pass through and the late at the late field life or the late life of the equipment what do you think about the size of well integrity market as a whole like in in the oil and gas business the majority of people they they like to work in in the upstream operations fracking perforations um drilling uh reservoir management and all of these nice things but um we all we also hear about the energy transition and the potential long-term uh decrease in oil demand and uh and all these energy rhetorics the only sector that will always keep growing is will integrity for example in the u.s the u.s they drill from 5 000 to 6 000 wells per year on annual basis so imagine this huge number of wells of the many many years you will end up with so many wells that reach their economic level or they get damaged beyond fixing or not beyond fixing or the fixing cost would be more than the economic value that we're gonna bring so with time you get more and more abandoned wells and these abandoned or failed wells their integrity should be assured for for various reasons but how many wells are abandoned or the separate integrity problems in canada there are more than 300 000 wells that are abandoned and these abandoned wells they need monitoring through integrity systems they need assurance that these wells can still don't produce any uncontrolled float flows in the u.s it's around 3.2 million wells globally the number is not known but it's estimated by reuters to be 29 million wealth bloomberg estimate 13 million wells so the market for well integrity for managing failed wells abandoned wells is is growing and will always keep growing even if the whole industry is uh is not there and this this will not happen anytime soon but even if one anteriority as we said it offers a merge between three pillars to control the wells during the life cycle it wants to control the safety of people assets and environments with technical knowledge about our wells about our reservoirs our designs and the management the management of rules and responsibilities that of people that are involved in the system asset management risk management corrective maintenance and verification and testing of equipment we put this all into into into into into a framework to end up with assessing the status of the wells the severity of risks and the priority of fixing uh failures whenever we get them one integrity management system is linked to the top to the top to the top agendas of the companies through the world integrity guiding manuals and the weather integrity guiding manuals is linked to the regulations on the country you are applying you are operating in like uh for example if uh if country x requires all flowing wells to be equipped with surface with subsurface safety valve then the company should reflect that in its well integrity management manual and this should be put into into into operations so well integrity is is not just linked to the operating unit itself but it's also governed with some guiding principles from the operating from the from the country where the company is operating in what value well integrity brings to the business first the first fundamental value is ensuring safety of people and assets some wells are drilled close to residential areas where where it could be of severe impact to have uh oil and gas leakages uh there because of the of the people living in in the nearby also it's it protects the um the the the environment um because of offshore offshore wells in case you get any issues with them the consequences could be severe for the marine life and and even for the for the quality of air reducing methane emissions as we remember that we think that we have millions and millions of wells that are abandoned globally and there are studies that estimate that these wells are emit millions of tons of methane every year for example the number estimated globally the 2.5 million ton of methamphetamine is equivalent to 144 million barrels of consumed oil or around 16 coal-fired power plants in one year so the environmental impact of mechanic missions coming from just abandoned wells is is huge it protects reputation as as we know in the deepwater horizon case in pb in the gulf of mexico that the company was punished by top authorities even the the u.s the u.s president himself he visited the location and as we see in the economist headline here it's obama versus just one problem with cement made the president of the united states to to stand against uh against the company and the company was forced to to sell assets and they lost they lost money and reputation based on one one well integrity event well integrity is one of the core fundamentals for carbon capture and storage storing carbon in the deep underground reservoirs means you take the collected carbon and you inject it in wells in underground storage reservoirs so the whole cycle should be should be assured to not to be leaking and not to allow for any uncontrolled fluid flows one integrity management system to ensure its goals it needs to have some you component to take into account well designs production data completion data preventive maintenance scheduling maintenance results rules and responsibilities and what value model and we will get through them any any question any anyone would like to to say any comments if there is any questions you can write them to the chat box or i will read them for speaker with some awesome uh or you can just interrupt and say what you would like to have because uh it's it's better if if we have some some kind of interaction okay so a while integrity management system it gathers the understanding of well-designed production data completion data preventive maintenance maintenance results facility status reporting rules and responsibilities and rules should do what and when and will fill your model for well design we need to make sure that we have barriers and we will get through what is the definition of barriers and why do we need them and what barrier policies should be in place and how we deal with it production data we need to monitor the pressures the wellhead pressures and the annulus pressures because it's it's one of the things that can make you be aware may make you detect failures um very easily monitoring the the annulus pressures a and b annulus pressures over constant intervals for example every two weeks every one month and then you compare your results to make sure that you are operating below the the allowable limits and also to detect if there is an increase of decrease in any annulus and you try to know why because it's a it could it could guide you for a potential problem communication between tubing and annulus or failure in one and one of the barriers completion data governs the calculation of the mass the maximum allowable annular surface pressure which is the pressure if you reach you would risk you would risk the weakest point in your in your completion in your barrier preventive maintenance schedule is the time through which you sit the preventive maintenance which is the wellhead integrity test and the set sub-surface integrity test you do these tests over intervals the intervals are set in the will integrity in the in the will antiquity system to alert the organization to the needs of verifying verifying the the wellhead or verifying the subsidies of wells and to keep track of results of these verification process maintenance when you investigate them you get to detect what's right and what's wrong you get to detect what failures do you have and how do you deal them and how you should prioritize them rules and responsibilities are included in the system as well to know who should do what and when split the responsibility between between the different technical departments and technical disciplines for work to be coordinated and run smoothly with failure model it it defined the urgency of the failure it defines which failure is very urgent to fix because it has high risk and which ones you can live with or give them more time to to fix and hope to fix and it also defines which failures you can you can keep the wells open while waiting to fix them and which wells will and which failures will force you to to shut down the world for example if your well integrity management manual requires you to have surface surface control safety valve in the completion for all flowing or all flowing wells naturally flowing wells and you get a failure in the well for you to comply and if the well failure model uh indicate that it's a it's a high risk you would need to to shut in the well until you replace the surface safety valve but for example if you have the um the kill wing valve failed and the will failure model define it as a low risk low risk failure and you can live with it for a year or two years until you fix it you can still keep operating your wells and the last the last item in the toolkit is facility status reporting if the wells reached to a specific specific high risk failures you would need to you would need to inform higher authorities in the organization like the operation manager or even higher higher than this that to alert them that that you have this number of high-risk wells and you to alert them with the necessary necessary actions to be taken to align the organization and fix it whenever possible yes well barriers for that one of the main the main things in in one integrity management is defining the weld barriers for the wells to know if if the wells are operating safely or not for example in the in this in this conventional conventional well case we have the blue items show the primary element the primary barrier and the red the red equipment show a secondary barrier the primary barrier is the barrier that will hold the fluids of the well in case something happens for example in our case here we have the we have the packer we have the tubing and we have the safety valve in case we get any problem these are the first to hold the fluids in the well the secondary barrier barrier which is the red one is the one that holds fluids in case the primary barrier fails if the primary barrier of the well fails which is the blue one for example you get a leakage in the and the tubing you get leakage and the packer or you get failure in the safety valve you expect that the lower muscle valve the well head the christmas tree the cement um to hold to hold the to hold the fluids in the well and prevent the fluids from going anywhere in any uncontrolled manner so a barrier is an envelope of one or several dependent physical elements it's designed to contain hydrocarbon floats and gases and other well fluids its intent to prevent flow from one formation to another in the subsurface and also flow from the well to the environment so even the cab rock here can be considered the barrier because it prevents fluids from going up to other formations or escaping behind the the formation here the cement the cement is a barrier because in case we lose the primary barrier the cement will hold to prevent the fluids from going up between the casings elements shall be verified and tested from time to time and this is where we're going to discuss the the barrier philosophy for example in case a and k is b we have in case a a well that can flow to the surface the well when we shut in the well the the complete that tubing is is full of the flows to the surface so this will scalable to flow to the surface this will is not capable to flow to the surface when we shut it down we still have a distance empty and we can have a fluid level uh somewhere below the below the christmas tree if well a do you think well a has has two barriers or well b has two barriers which one has two barriers for the case of will a we only have one barrier the barrier where you can have like your tubing and your christmas tree your packer and that's it you have nothing else if you lose your first barrier it's already the christmas reads it's combined between both the primary and the secondary barrier so you can't say that the tubing is a primary barrier because it has it it's its elements intersect with the secondary barrier elements but here in well b we can consider that the fluid column is a barrier itself because all in all the fluids will not will not go out out of the of of the reservoir by themselves so in this case the fluid column itself the oil fluid column and the reservoir and and the well is considered as a primary barrier and then we can take the backer and the com and the lower master valve and the tubing as the secondary barrier a word barrier policy uh for example for a company like shell states that it need you need to have two tested barriers throughout the life of the well you need to have two because in case you lose one of the barriers you don't just rely on the other one instead you go to restore the the barrier that fails to have the two barriers along the life cycle of the well do we need barriers for abandoned wells yes absolutely even abandoned wells should have two barriers there shall be two barriers available during the well activities and operations including suspension and abandoned wells where a pressure differential exists that may cause uncontrolled flow flow even if the well is is closed it should have the proper abandonment procedure that ensures that you have two barriers in place you can think of barrier policy is like having uh having two hats it's uh it's sometimes called the hat over hat policy if you lose one hat you still have the other one but you need to go and pick up another one here in this schematic it goes the the the same example that we went through before but in in in more illustrated manner the primary barrier is composed of the the the cab rock of the reservoir the seven inch liner cement and then the seven inch uh liner hanger and then the liner itself and then you go in the the tubing and then you go to the subsurface safety valve and the gas lift valve the secondary barrier you go to the casing show this is the first thing you will face the casing show of the of the 958 production uh production casing and then before you you will see the cement of this casing as well and then the [Music] 958 casing and then you will go to the wellhead and then you will go to the tubing hanger and then the christmas tree the christmas tree conductor is a secondary barrier well integrity management system in in practice what do we do in practice what comes and how would we deal with it first you do something called the wet the wet is the well and uh well uh well integrity uh well integrity test it's one of the preventive maintenance that we discussed in the in the well integrity toolkit you make sure that your valves and well heads and the seals are in place yeah to make sure that uh that the valves are operating the number of pens of each valve is ing to standards and the valves they hold they hold pressures they are not leaking and to make sure that the seals or the christmas tree are not leaking you record it you you perform it based on the schedule based on the um the preventive maintenance schedule for the for the webcast the step test is that sub surface integrity tests you bring the fluid pump and then you connect it to annulus a and then you test it is the ear annulus you test it for for 15 minutes or ing to the your procedure and then you see if it leaks or not if it leaks then there is a potential problem in a annulus maybe you have a problem in the line or hanger in the packer you have leakage in the in the tubing in the in the casing you need to investigate later and then you connect the pump to b annulus and if you have c annulus you do the same and you test it you you recall the volume of the fluid you you you add and to top it up and you monitor the you monitor the pressure gauge during the test to make sure it's it's safe and not not leaking in practice we do the set test every four years and the wet test every year and then annulus pressure monitoring in annuals in annual expression monitoring what we do is we record uh on on constant intervals like it depends if that if the field is monitored automatically you can recall these data every day but if the field is uh is if the data is manually collected it usually takes efforts for people to go to to well locations and and collect the gauges and usually like within two two weeks to to one month uh you record a annulus b analyst c analysts tubing head pressure over time and you keep you keep track of them if there is a change then this implies um failure in one of the items maybe you have leakage behind the casing maybe fluids are maybe you have vacuum and you lose the the fluids and the well maybe from monitoring it maybe you have communication and whenever you get an annulus excursion whenever you get pressure in the annulus higher than what you usually get from the well what you do is you can do an annulus investigation where where you um where you release the fluids from the well from from the annulus that uh that has high analyst pressure you monitor the the the flow type that's coming the the volume that you get at what time and you record the decrease in pressure to monitor it it's if it's serious or not maybe if you get the carbon from the from the annulus that could be a severe severe issue and um and if the pressure in the annulus and the tubing will respond together then you have communication between the tubing and annulus this information is just for you to to put it into the context we we can't in a few minutes cover all these items in place we just touch on them and then we put them into the right block for you to to capture the whole system and how it works after we perform our annulus pressure monitoring exercise the wet the set the annulus pressure we said we do it monthly the wet we do it every year and the stuff we do every four years then we combine the failure histories we have in the system when the mass when the mass exceeded uh it reached its uh its safe limit uh we look at the previous failure reports we look at when when operations were performed on the wells when corrective actions were where were completed if we have uh failure trends in specific wells like for example in in one of the fields what we used to get is um is loss of containment in in a annulus we lose the integrity of the of the of the of the 958 casing why because we have corrosive water behind behind the casing cello corrosive water that that that caused corrosion to the casing and cause failure and that was trending in the same fields like this this this problem happened in in three and three four wells about the same age so we expect that you have a trend you have a trend here and you try to even react to the other wells before before the situation gets worse or maybe you add your top up most event well when you set your casing you take into consideration as well the status of the well is the well is is it a high producer or low producer because if the well is high producer and you want to shut the world down for operation usually it's it's difficult to do so it depends on the company and its target look at the mass the completion data the reservoir data and you look as also what future operations should be performed on the well because the integrity status of the wealth could impact the the how things should should go in the world and risk assessment considerations when you perform your exercise and you get the data uh from the test you perform and you you study the the history and the failures and the the status of the wells you try to assess the rest of the world is this well is is a higher risk on a lower risk well and what you take in consideration you take location outflow potential well stream composition external environment and redundant systems for location you need to know if the well is onshore or offshore man the run man for example if the well is offshore and you have a failed surface safety valve and the will is capable to flow to the surface this could be an issue you need you need to make sure that people people are safe because in case you lose you lose fluids and you don't have the specific safety valve in the well could be a severe case and proximity of the well to other wells outflow potential is is the ability of the world flow to flow to the surface at uh the the outflow potential you can consider it as like if if we lose the christmas tree of the world how much fluids are gonna are gonna be coming out of the well in the worst case scenario if we lose the christmas tree and the well is producing to the atmosphere how much of the well is going to produce it's it's it's a useful piece of information because it tells you the severity of the top case the top case is that you your well is just producing to the atmosphere workstream composition do you have solar fluids do you have corrosive fluids you have poisonous components external environments you need to take into account the external corrosion to the environment you have fatigue of your components mechanical impact and possible collisions with with vehicles like for example in one of the fields in the western desert uh one one of the mitigation actions on one of the fields was to have a fence steel fence around the well to prevent cars from hitting in the well at night redundant systems it's like automatic for down systems do we have automatic shutdown systems on the wells or not because it if if if you have a case uh where you where you lose control of the well and you have an automatic shutdown system it could be better for example if the production the production valve is leaking and it's visual that the production valve is leaking and you have an automatic lower master valve you can shut down the automatic muscle valve but if you don't have it and the well is producing lowered that's high content it could be a severe case and people couldn't it was alive so we mixed the data that we collected from the annulus pressure monitoring with the wellhead integrity test with the subsurface integrity test with the technical data events failure history with our risk assessment considerations which is on art this is how you assess the risk we measured with our will failure model to assign action codes and correction plans but what is the world failure model workflow model is the risk-based matrix it defines the defined causes and effects of failure types and different types of wells and it gives them the action codes i will say model like like the template we have here we have the failures that we expect to have and we have the types of wells this is this is actually um a schematic of of a real well failure model you put the types of wells you have for example we classify them as high pressure gas low pressure gas low pressure oil high pressure oil and water inject to wells and then we put the failures that we encounter for example is it a single surface failure or multiple surface failure or single subsurface failure or multiple of both for example if you have failure in the wing valve in the swap valve and the upper master valve how critical it is for a gas well to a oil well to water injector to high pressure gas well for example if if you have a problem in the swap valve the square valve that you can you can just open and connect uh connect the pressure gauge to read the pressure on the christmas tree if you lose it in a well it's uh it's not a major it's not a major incident but if you lose the lower muscle valve it's it's a thing if you have multiple failures for example if you lose the upper and lower muscle valves and high pressure gas well it's it's high priority to be fixed for example if you lose that for a water injector well it's less priority so you give it you give it smaller number if you have tubing to a analyst communication a high pressure gas well it's it's uh it's high action codes you need to fix it you need to fix it sooner and you give it high high priority to fix whether your model action codes can be um interpreted as follows it depends on the organization each organization uh define it differently for example if if the well has zero action codes it means that the well is fine everything is tested and perfect but the well has action code of one repair it in the next planned intervention if if you have uh for example this well if you are planning to change the compute the completion in four years okay go in four years and change it and you don't need to take any urgency and simple action code of six repair at the earliest opportunity but within two months and it gives the possibility for the will to flow okay it gives you the possibility okay if you have uh if you have uh problem in the tubing to uh tubing to a analyst communication in in low pressure oil well okay you can give the taxi code six because you can fix it in in two months but if you have it in a gas well maybe you give it action ten of eight or nine eight you need to carry out formal technical review within seven days and then you can you can fix the will of the earliest opportunity 10 emergency it's uh lost you you have you have severe severe failures and mine make well save immediately and repair immediately you need to move your rigs why it's not easy to uh to do the fixing of wells and and repair them it's because you take resources of a company the regs are there to uh to these fees to upgrade pumps to repair completions of uh high producing wells but when well integrity comes and you have a failure you need to reallocate these resources from from doing operations that will bring bring production gain and make the company meets target to go to fix fix some of the wells to ensure safety i think uh that's that can be enough for today like we took so long i still have uh long material but i feel like it it will be it would be a long a long tiring session can we uh can we have questions if you if you guys would like to ask something thank you so much mr for this valuable session and excellent explanation about that integrity systems yeah thank you thank you hope it was valuable and i hope if any of you guys have any question any comment any any concern anything you didn't like about the presentation i would be very happy to to hear your response i see one question at the chat box i did for you i have a hi guys i have a question yes please hi mustafa um my name is last iphone all of you all the way from the caribbean region ah cool yeah nice to have you let me ask you a question um as it relates to topic at hand um well integrity management two words um information and data um with respect to information and a maximus central reliability engineering standpoint whereas um with information which is um generating the input um which is the process i'm talking about here uh the operational procedures resources etc as compared to the data and let's let's look at the data as being the the output and we know um again we're talking about generating or not over unorganized and unrefined facts from a particular field they say i feel probably about seven wells okay so we generate that that that that all puts um i know you have to clean that data to get to get insight on that particular field my question to you is um with respect to integrity well management which one will be more important um in making some decisions the aspect of the the information the the input which is the process or for the data which is the the the output to generate insights which is you want to ask which is more important to the company or to making integrity decisions or integrity decisions integrity you know it's um it can't be this linked like um if you need to have facts you need to have the information right right and you need to have the data through which you can gather insights like the example we gave about the field where we found that we lost the nine uh five over eight inch inch casing because we have corrosive corrosive water behind the casing right we found that in three wells three water water injected water injected wells and we have 10 other injectors in the in the field with the same design with the same access to the same formation from that from that insides from that we got from the data that trend we we managed to to secure the other worlds you can scrap the casing you can you can take your mitigation action you can try to put corrosion inhibitors in the in in the water you inject uh whatever you would do but but that gave you guidance to react uh waiting for facts alone you will wait for other wells to fail right to react to them but uh and and inside some facts together usually uh other other ones uh for you to proceed forwards and that in a good process if the process is this linked if someone is excluded for it for example that the process aligns because in well integrity so many people are should be aligned you need to have your field manager with the production manager aligned with the operation manager aligned with the well integrity team with the asset team all of them should agree on fixing a well and all of them should should agree on removing resources to do specific operation so if the process is not solid you will get into subjective assessment from each one of them that's why the concept of welfare your model and action codes has been in place because this is this is the failure the failure is saying that we need to fix it in a month all of us we need to combine our efforts to fix it in a month so it's it's a process okay honestly you can't know which but which one is uh is of higher priority or maybe i didn't understand your question correctly but right no no no no i think i think you did and i understand yeah thank you so much thank you okay thank you sure um we have some questions at chatbots can you yes uh what are the investigation techniques to identify leak source depends it depends where you get the leak from for example if if i have high high a annulus pressure what would i need to investigate here i need to make an annulus investigation what you do is you open the annulus and you monitor the fluid leakage and the pressure drop you monitor if it's going to be chopped up again or not if it does if it does and you see that your tubing pressure is constant and then you deplete the tubing pressure and the tubing pressure remains constant then you don't have communication issue you have a problem in the in the in the annulus and the annulus itself away from the tubing so maybe fluids are sneaking behind the pattern the pecker is leaking maybe you have high pressure gas well and the gas is leaking behind the packer if you get gas from the annulus but if you don't get gas from the annulus then maybe um leakage in the one of the casing shoes maybe the casing itself is leaking from one of the surface water formations that's why you need to collect this fluid and see its salinity analyze it and if it's hydrocarbon so these are the the sort of things that that make you um that make you um investigate the leakage in its source also you need to look at the mud log you need to know which formations are producing the fluid you found maybe you have a surface gas formation and you know that your um your cement is not usually good in this area or you got you got cavity while well not not covered you got a bigger hole while drilling and you don't think the cement fill it completely so this is the sort of analysis you need to know for example you go and perform your set test the well is fine you don't see any pressures on the annulus and anything and you go you do your set test and be annulus and you find yourself bumping pumping pumping pumping so you don't get anything so your your float that you are injecting is leaking so you don't have completion fluid in the tubing itself and then in the analyst itself so from these interactions with the well and your experience with the area and the data available to you you get to know these sort of things and if you get suspicious at some some point so for example i expect that the casing is leaking or the casing is corroded you need to you need to know you you need them to go to make uh to make uh corrosion logs to know to know the thickness of the case if you lost it or not ok sorry no sorry you you can continue okay yeah so you have a question you i see that you you are taking the floors number one thanks and also there is some other questions if you want like i read them for you what can i do if a annulus hold and be producing the surface behind cellular uh this one i can't tell i can't tell sorry producing what producing hydrocarbons or producing uh [Music] producing water rie i'm not sure what is that no i haven't faced this issue to be honest until using brine maybe maybe uh maybe you have an active surface uh surface formation uh water and you don't have good cement in the p annulus it depends as well where where where the b anise is connected to the deformations on the and the mud log is it cemented behind it you trust the cement you don't trust the cement any any more questions like we can be done by now or anyone if anyone would like to have one question we can go for it also if you will have any questions you can ask at group or me and we will ask these questions to the speaker and try to get the answer after session i hope it was useful and um anyone would like to this hello mr can you hear me yes yes i can hear you hello i'm oscar how's it doing zach oscar how are you have you been nice presentation good work thank you very much i have a few questions if you don't mind for the brime and secondary buyers that you showed us in the schematic these barriers is it valid for the well in short condition and producing condition the blue and red lines this one this one is schematic with envelopes yeah this one this one yeah sorry the you think it's it's you ask is it is it valid for a well in flowing condition and closing condition yep uh i didn't ask myself uh i didn't ask myself this this question but i feel like it would be the same okay right but if you are flowing so well if you are flowing the well in the production header uh your fluids will be getting inside the flue line and the header and it will not be contained under the surface 50 valve so i think in in my opinion this is well for just a certain condition and this def long condition will be other barriers like the low line itself the flow line yeah the the other barriers of the floor lines is another story we we just want to make sure that the wells flowing from the well that the fluids flowing from the well are controlled with the flow line to the facilities it's uh it's uh it's another story yes as i see it or or you you guys deal with it in different way in in gapco yeah we have different methodology we have uh some details about this issue but i think you are right about this point but this is a really good schematic to illustrate the condition and the principle of barriers which is primary and secondary barriers and envelopes that contain the fluids inside the well yeah and even if we look here i think it's the valves here are in closed mode surface safety valve is closed and here and here the lower muscle bubbles flows a second question for the upper and lower muscle wall you have the upper is actuated which is a systematic one or both of them will be actuated the upper and lower muscle travel only one uh usually in biblical we have the lower mass of the lower muscle that actuated uh so for that you are uh speaking about the lore master valve is more more important than the upper master the lower muscle is more important yeah because it is actuated not a manual yeah but in other companies they may use upper muscle valve like actuated and the lower will be a manual and will not be closed in any production situation just an emergency you should close the manual lower master valve and the other master is automatic just in case if you have a leakage in the flu line if you have some emergency situation the shorted one will be closed ah okay no we in in in in babet school we have uh the lower muscle valve is actuated so i even didn't ask myself this question so thank you for the illustration that's a very good point i i didn't get to know this before thank you mustafa i may have some points about the questions that was asked about the biannualist fluids yes please uh you may have some investigation actions like making some logs some logs that have leak detection capabilities that can use ultrasound or sound methodologies as you can hear behind the casing you can detect the the depth of the leakage just for knowledge and some messages for all intervention uh some few companies now supply tools to enterprise in the b annulus between two casings and a dumb sump cement if you know the top of cement the dips of it you can like a little hose between the two casings and make it like a tag the top of cement and bob some some some gel some sealant some sort of gel or or cement especially just as visual fluid which is more dense than water which will be present in the annulus this density fluid will get segregated under the the fluid in the annulus and make a good seal like a ring between the two casings this is for remedial work and if you want to keep the well as it is it's just a water between the two casings you just keep the pressure in the in the annulus as it is if you bleed this fluid it will enhance and induce more fluid production between the two casings and if you keep the pressure uh to build up above the mass pressure it will be a problem so the the least action to be made for this situation just two minutes of pressure in periodic intervals and bleed the pressure which get high above the upper limit or just to keep it above a lower limit not to induce more fluids just the monitoring if it's just a slight saline water we wanted to keep an eye on it and make your pressures contained and safe between the two casings not to impose high pressure to affect your facilities just some notes you can consider in your new decision about monitoring and assessing the risk for this wealth well done well done i asked i've been a very quick have you a good presentation and wish you the best in your your career and your sessions thank you so much thank you so much uh sorry guys can we can we stop here and maybe we can do another session where we can go in depth of the of the set of the well integrity management system from from the system itself into the technicals uh and how we can calculate the mass how we can look at the case study to assess what risk should we consider how we can solve it what uh what and what more investigations do we need and how we can do that thank you so much for all and your time the great explanation thank you so much thank you thank you and thank you guys for for holding on to it and for your valuable questions and interventions thank you bye-bye have a have a nice day