Once you shut in the well in and obtain shut in drill pipe pressure, you can estimate formation pressure by applying the hydrostatic pressure concept.
This following equation demonstrates you how to figure out formation pressure from the kick analysis.
Formation Pressure = SIDDP + (0.052 x Hole TVD x Current Mud Weight)
I just create the well control tracking sheet (well control time log) that you can use it to record what actually happen while performing well control operation. This is the updated version 2013.
Download here >>
the well control tracking sheet
Float Bumping Procedures To Get Shut In Drill Pipe Pressure VDO
If you cannot see, please follow http://www.youtube.com/watch?v=KYXnyInpXkU
Well Control Books
I got a question about how an anticline gas cap can create the abnormal pressure. The anticline with gas cap can be the potential high pressurized zone. Because of reservoir connectivity between fluid underneath gas and gas reservoir, it can generate abnormal pressure. This example below demonstrates you how this situation could happen.
In some situation, where you drill with mud weight that is very close to balance condition (near formation pressure) and you don’t have much room to weight up due to fracture gradient limitation, from the well control perspective, you may need to drill one stand, then circulate bottom up and perform flow check. If everything is static, you can go ahead and drilling. Moreover, you need to look at the peak gas after going back to drill because it indicates how well of mud weight is. If you don’t see any gas peak, it means that your mud weight at the static condition is good. However, if you see any gas peak while drilling but it does not come from formations that you are drilling, this situation indicates that you don’t have or just enough mud weight to control the well in the static condition. You can check where the gas coming from by using a lag stroke calculation.
