Mar 11 2012, 01:03 PM
QUOTE(hj.pet @ Mar 11 2012, 05:32 AM)
so u r saying dat the best way to determine the OGC n WOC is by log data rite?
actually, the field was given to us for our final sem project. other groups have been given with tonnes of log data but not us. i guess, it's impossible for us to come out with the FDP with zero log data. to make things worst, the MDT-GR data were given to us was only from 1 wildcat well while we have about 12 wildcat wells in the map. i guess there's no way for us to determine the type of formation, the type of reservoir, the formation pressure, etc since we can't correlate those 12 wildcat wells right?
owh, that's a new info for me knowing dat the footwall n the roofwall of the fault are different in pressure. i wish i can show u the complication that we are facing right now with the numbers of the fault available in our field
it seems impossible for us to drill if we are going to avoid all the fault at all. let say if we want to drill on the fault, the only thing that we can do is to change the mud weight everytime we drill along it, right?
hahahaha can i use wang pos then?
the biggest problem for us is that the MDT-GR data that we have is only from 1 well. please correct me if i'm wrong but i don't think it's possible to generate a fluid distribution map only by referring to 1 wildcat well data.
seriously, we really don't know what to do next. i think we'll ask to change the field coz it seems impossible to come out with a FDP with these type of datas
If all else fails use these methods.actually, the field was given to us for our final sem project. other groups have been given with tonnes of log data but not us. i guess, it's impossible for us to come out with the FDP with zero log data. to make things worst, the MDT-GR data were given to us was only from 1 wildcat well while we have about 12 wildcat wells in the map. i guess there's no way for us to determine the type of formation, the type of reservoir, the formation pressure, etc since we can't correlate those 12 wildcat wells right?
owh, that's a new info for me knowing dat the footwall n the roofwall of the fault are different in pressure. i wish i can show u the complication that we are facing right now with the numbers of the fault available in our field
it seems impossible for us to drill if we are going to avoid all the fault at all. let say if we want to drill on the fault, the only thing that we can do is to change the mud weight everytime we drill along it, right?hahahaha can i use wang pos then?
the biggest problem for us is that the MDT-GR data that we have is only from 1 well. please correct me if i'm wrong but i don't think it's possible to generate a fluid distribution map only by referring to 1 wildcat well data.
seriously, we really don't know what to do next. i think we'll ask to change the field coz it seems impossible to come out with a FDP with these type of datas
Since you have information from one well, then at minimum you have to assume
1. Any hydrocarbon encountered by the well (from MDT data) will only be limited to the fault blocks that it is drilled. All other blocks cannot be counted in the volume calculation. This will be your proved in place/reserve for FDP purposes.
2. I thought you should be able to come up with the OWC/GOC from the MDT datasets? You should have the oil pressure sample and if you're lucky the gas pressure sample from the MDT and using the hydrostatic pressure, you should be able to come up with the OWC/GOC (if you have the gas pressure sample) right? If you can do that, then your proved fluid limit will be based on the MDT
You can do a Proved + Probable volumes based on your assumption that some of the fault blocks are not sealing and that from the GR datasets, you should be able to tell what kind of environment you're in, channel sands, shoreface, etc and you can then assume how widely distributed the sand is ... if it is a channel system complex, use a modern analog to come up with the distribution of the channel complex. Usually based on the thickness of the channel complex, you should be able to come up with a reasonable width of the complex (i.e if the channel sand is 30 metres then, the channle complex can be 1-2km in width etc.) from there, you can estimate the proved + probable assume that the faults are not sealing for areas where there are channel sands.
If the GR indicates that it's a shoreface system, then you need to determine where you believe the source of deposition is and where the direction of the beach is, based on that you can then estimate the width of the shoreface and how long the beach is going to be, use an analog like Pantai Cinta Berahi or Desaru or whatever you like. From there, you can determine the proved + probable.
For maximum case, treat the field as a homogeneous reservoir. If the sand is 30 meters thick, assume the whole field has the same sand thickness and go from there.
That is why we never develop a field based on one well, that's just insane because the risk and uncertainty is so high ...
That is why Geologist is important as well
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the project would be totally f*#ked up if both geologist and petrophysicist couldn't do their job properly!
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