Thank you our beloved professor Martin blunt for making this video and sharing with everyone. I am truly blessed to have studied the same concept from you at Imperial. Stay healthy and happy. 😊
Thank you Mr Martin! Currently reading for my fundamentals of reservoir engineering final exam...and this came in handy....Bless you sir...peace and love to you and yours.
Respected sir. I thoroughly enjoyed this video and learn many new concepts. Thank you so much!!! Your every effort motivates me to dig deeper into reservoir engineering.
Can I ask a question? If we have mixed-wet core with very low Sor, it will obviously will have high displacement efficiency, which is simply function of Swi and Sor. But in reality in reservoir we don’t produce so much oil. My question is are there any guidelines for fw (fractional oil flow) cut off value to estimate true displacement efficiency in reservoir. I mean in reservoir we stop at fw 0.95 or so, isn’t it?
No, not necessarily, for the reason you say. As I emphasize in the video recovery is not determined simply by Sor. To understand local displacement efficiency, you need to perform a Buckley-Leverett analysis to quantify the recovery at the number of pore volumes injected in a field setting, as described in my other videos.
Thanks so much for amazing lecture, can you please, kindly illustrate in much more details how to perform water-oil relative permeability unsteady state at constant pressure. how to measure differential pressure between inlet pressure and outlet pressure and how to make constant during the whole test
This would be the subject of another video. You do not have a constant pressure drop, but a constant flow rate, imposed by the injection pump. The pressure difference can be measured using a differential pressure transducer linked to the fluids at the inlet and outlet. Also the fractional flow at the outlet needs to be recorded. For more details see the book: Relative Permeability of Petroleum Reservoirs by M.M. Honarpour.
@@BoffyBlunt thanks so much Dr. Martin, of course I know we can perform test at constant flow rate, also we can measure it at constant pressure. But I'm asking about how can I make differential pressure constant. Also, if I make it at constant flow rate, the used pump will fix injection flow rate and show injection pressure on its screen, I tried to make it at constant pressure, but the pressure gauge reads zero of outlet pressure due to opening flow path, so if I use transducer, it will read value of outflow pressure?
@@bocus9001 You cannot have a constant pressure and a constant flow rate. If your outlet is connected to the atmosphere, then this pressure will be zero (gauge), but the pump can measure the inlet pressure. What we do in the lab is measure the differential pressure across the core itself using a sensitive transducer.
Very wonderful explanation. I loved it :) I have a question: Is there any exception for gas reservoirs not obeying the first diagram (water-wet case)? For example, how can we assess "gas condensate" reservoirs in terms of relative permeability when pressure is below the dew point? thank you.
In almost all cases gas reservoirs are water-wet. That is water is the wetting phase. In a gas condensate below the dew point, water is again the most wetting phase, oil is intermediate-wet and gas is the most non-wetting phase.
@@BoffyBlunt In the zero dimension we have NOTHING. in the first dimension we have SOMETHING, a delta of wet water in 3d ICE, a point. In the second upper dimension, we have a line connecting the points, pull and push to flow as wet 3d liquid water, 2 points and a liquid line a short distance away. However, in a longer or infinite distance it vaporizes wet 3d gaseous water. Therefore, water H20 with 3 phases ice, liquid and air. All occur in differential heat (FIRE) and normalized to EARTH (norm), FIRE (hot and cold norms), WATER (norms at short distances) and AIR (norms at infinite and greater distances). All these phenomena allow it to happen in a 3d space-time dimension. Our next level dimension is the space-time dimension of the 3D SOUND where the SOUND comes from the cosmos the trumpet (ZOHAR) changing into another phase never seen before. Thanks for the video to illuminate further research from the EARTH, FIRE, WATER and AIR bases with neurons aided by smelling, tasting, hearing, touching and seeing reality.
In careful coreflooding experiments, typical residual saturations of less than 10% are possible. Of course, these saturations are never reached overall in the field, as thousands of pore volumes of water need to be injected.
However , in the real world: A water wet rock (clastic 30 pu) in the M east has almost no residual oil (2% by volume)when produced under natural conditions. Our major carbonate reservoir (30 pu , oil wet, its roughness !) has been under gas injection from day one. Current residual oil saturation is still at 25% Rock is only mixed wet in the lab !
I am not sure what you mean by natural conditions: if this is primary recovery the very low residual saturation you quote is remarkable. For gas injection the current remaining (it is not a residual) saturation does make sense.
what an energetic presentation!! Thank you professor
Thank you Mr.Blunt, very interesting.
Thank you our beloved professor Martin blunt for making this video and sharing with everyone. I am truly blessed to have studied the same concept from you at Imperial. Stay healthy and happy. 😊
Thank you Mr Martin! Currently reading for my fundamentals of reservoir engineering final exam...and this came in handy....Bless you sir...peace and love to you and yours.
Very wonderful explanation, Professor.
Respected sir. I thoroughly enjoyed this video and learn many new concepts. Thank you so much!!! Your every effort motivates me to dig deeper into reservoir engineering.
Great effort professor. Thaaaank you.
Thank you !
you are a legend
It is rather interesting to investigate the impact of the pore geometry on Kr for non water wet reservoirs.
Really enjoy it
Can I ask a question?
If we have mixed-wet core with very low Sor, it will obviously will have high displacement efficiency, which is simply function of Swi and Sor.
But in reality in reservoir we don’t produce so much oil. My question is are there any guidelines for fw (fractional oil flow) cut off value to estimate true displacement efficiency in reservoir. I mean in reservoir we stop at fw 0.95 or so, isn’t it?
No, not necessarily, for the reason you say. As I emphasize in the video recovery is not determined simply by Sor. To understand local displacement efficiency, you need to perform a Buckley-Leverett analysis to quantify the recovery at the number of pore volumes injected in a field setting, as described in my other videos.
Thanks so much for amazing lecture, can you please, kindly illustrate in much more details how to perform water-oil relative permeability unsteady state at constant pressure. how to measure differential pressure between inlet pressure and outlet pressure and how to make constant during the whole test
This would be the subject of another video. You do not have a constant pressure drop, but a constant flow rate, imposed by the injection pump. The pressure difference can be measured using a differential pressure transducer linked to the fluids at the inlet and outlet. Also the fractional flow at the outlet needs to be recorded. For more details see the book: Relative Permeability of Petroleum Reservoirs by M.M. Honarpour.
@@BoffyBlunt thanks so much Dr. Martin, of course I know we can perform test at constant flow rate, also we can measure it at constant pressure. But I'm asking about how can I make differential pressure constant. Also, if I make it at constant flow rate, the used pump will fix injection flow rate and show injection pressure on its screen, I tried to make it at constant pressure, but the pressure gauge reads zero of outlet pressure due to opening flow path, so if I use transducer, it will read value of outflow pressure?
@@bocus9001 You cannot have a constant pressure and a constant flow rate. If your outlet is connected to the atmosphere, then this pressure will be zero (gauge), but the pump can measure the inlet pressure. What we do in the lab is measure the differential pressure across the core itself using a sensitive transducer.
Very wonderful explanation. I loved it :)
I have a question:
Is there any exception for gas reservoirs not obeying the first diagram (water-wet case)? For example, how can we assess "gas condensate" reservoirs in terms of relative permeability when pressure is below the dew point? thank you.
In almost all cases gas reservoirs are water-wet. That is water is the wetting phase. In a gas condensate below the dew point, water is again the most wetting phase, oil is intermediate-wet and gas is the most non-wetting phase.
@@BoffyBlunt thank you so much professor.
@@BoffyBlunt In the zero dimension we have NOTHING. in the first dimension we have SOMETHING, a delta of wet water in 3d ICE, a point. In the second upper dimension, we have a line connecting the points, pull and push to flow as wet 3d liquid water, 2 points and a liquid line a short distance away. However, in a longer or infinite distance it vaporizes wet 3d gaseous water. Therefore, water H20 with 3 phases ice, liquid and air. All occur in differential heat (FIRE) and normalized to EARTH (norm), FIRE (hot and cold norms), WATER (norms at short distances) and AIR (norms at infinite and greater distances). All these phenomena allow it to happen in a 3d space-time dimension. Our next level dimension is the space-time dimension of the 3D SOUND where the SOUND comes from the cosmos the trumpet (ZOHAR) changing into another phase never seen before. Thanks for the video to illuminate further research from the EARTH, FIRE, WATER and AIR bases with neurons aided by smelling, tasting, hearing, touching and seeing reality.
How low residuel saturation of the oil is in?? the case of oil wet
In careful coreflooding experiments, typical residual saturations of less than 10% are possible. Of course, these saturations are never reached overall in the field, as thousands of pore volumes of water need to be injected.
However , in the real world:
A water wet rock (clastic 30 pu) in the M east has almost no residual oil (2% by volume)when produced under natural conditions.
Our major carbonate reservoir (30 pu , oil wet, its roughness !) has been under gas injection from day one. Current residual oil saturation is still at 25%
Rock is only mixed wet in the lab !
I am not sure what you mean by natural conditions: if this is primary recovery the very low residual saturation you quote is remarkable. For gas injection the current remaining (it is not a residual) saturation does make sense.
can we get your Instagram or fb or something like this