Volumetric well control method is an important well control method which should be used when the normal well control method cannot be done. Volumetric Method does not intend to kill the well but it aids in controlling the down hole and surface pressures
Not a very good/realistic example. First of all, a 5 bbls swab kick represents approx. 40 psi max. delta pressure in a 8-1/2" hole [the picture shows that gas is still on bottom, not across drill pipe as yet]. It is therefore impossible to have 310 psi at surface, unless the 5 bbls have migrated way up the hole and expanded about 8 times [ignoring any gas influx density as it decreases]. We also should not say " bleed off 11.28 bbls to maintain BHP", because that is NOT what we actually do. We have a 120 psi increase as a result of gas migration and we then slowly [very, very slowly] bleed off fluid while keeping casing pressure more or less constant. This is a very, very boring undertaking, believe me. And for 120 psi takes quite a bit of time [many hours in fact] as migration through mud is slow and all you do is crawling back, bit by bit, to original BHP. At some point you will need to change the capacity as well [to casing to drill pipe capacity], but that might be a guestimate as you may not know precisely where the top of gas will be. The last point is the maximum surface pressure, mentioned as 1500 psi. Why would you relate to surface pressure per se? What really matters is the weakest formation below the casing shoe and once the kick is inside the casing, then - if you do everything right - the casing pressure is not so crucial anymore. All in all, when an example like this is presented, make sure the facts are realistic and 100% correct so that the explanation makes sense to the viewer.
Volumetric Methods are important to learn for all those working at Drilling Site
Volumetric well control method is an important well control method which should be used when the normal well control method cannot be done. Volumetric Method does not intend to kill the well but it aids in controlling the down hole and surface pressures
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Very Good Explaination. Thank you Petro Proficient #petroproficient
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Not a very good/realistic example. First of all, a 5 bbls swab kick represents approx. 40 psi max. delta pressure in a 8-1/2" hole [the picture shows that gas is still on bottom, not across drill pipe as yet]. It is therefore impossible to have 310 psi at surface, unless the 5 bbls have migrated way up the hole and expanded about 8 times [ignoring any gas influx density as it decreases]. We also should not say " bleed off 11.28 bbls to maintain BHP", because that is NOT what we actually do. We have a 120 psi increase as a result of gas migration and we then slowly [very, very slowly] bleed off fluid while keeping casing pressure more or less constant. This is a very, very boring undertaking, believe me. And for 120 psi takes quite a bit of time [many hours in fact] as migration through mud is slow and all you do is crawling back, bit by bit, to original BHP. At some point you will need to change the capacity as well [to casing to drill pipe capacity], but that might be a guestimate as you may not know precisely where the top of gas will be. The last point is the maximum surface pressure, mentioned as 1500 psi. Why would you relate to surface pressure per se? What really matters is the weakest formation below the casing shoe and once the kick is inside the casing, then - if you do everything right - the casing pressure is not so crucial anymore. All in all, when an example like this is presented, make sure the facts are realistic and 100% correct so that the explanation makes sense to the viewer.
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@@PetroProficient It is truly commendable to create these well control examples and I am convinced that readers will benefit from it.
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