Reservoir Engineering [Reservoir Pressure]
1. How important for a Reservoir Engineer to have an idea
(a) About the number of sedimentary cycles associated with stratigraphy of the concerned (clastic/non-clastic) province – in the context of over-pressure generation?
(b) About the province of interest that remains formed on tectonically active margins or not?
Are they characterized by growth faults (produced by gravity)
or by folds (from compressional forces)?
Or, not?
Whether regional stress and gravity-driven deformation are to be understood by a Reservoir Engineer (towards basin evolution)?
In total, a Reservoir Engineer is also expected to have a sound knowledge on each depositional unit that remains distinguished by its specific stratigraphy, sedimentation and hydrocarbon distribution?
2. Having known the importance of predrill PP data (as it not only significantly impacts drilling safety and costs associated with petroleum exploration and production but also directly influences wellbore stability, drilling fluid selection and the overall performance of hydrocarbon extraction), and, if an inefficient prediction of pore pressure could lead to an inefficient production strategies, reduced recoverable hydrocarbon volumes and also, with possible reservoir damage, then, how frequently pore pressure (the pressure exerted by fluids within reservoir pores) gets deviated significantly from the hydrostatic pressure resulting from tectonic activities, fluid over-pressure (but still below the lithostatic pressure) and compaction?
3. If identifying over-pressure zones (disequilibrium-compaction/fluid expansion) beforehand (possibly by lithology, sedimentation rate and tectonic setting) remains to be challenging (due to the possible misinterpretation by seismic wave disruption), then, how exactly, pore pressure affects the dynamic bottom-hole pressure profiles during production?
And, how frequently oil and gas wells have encountered formation fluids when the pore pressure exceeds the mud pressure that causes wellbore instability and eventually leading to catastrophic blowouts, kicks, complete washouts, loss of drilling fluid circulation, pay formation damage and stuck pipes?
4. Why does Eaton method not provide accurate predictions towards estimating pore pressure (as a function of sonic velocity & effective stress) especially in over-pressure zones?
And, what is the advantage with Bowers method?
Whether, the assumptions (about normal compaction trends and the relationship between over-pressure indicators and pore-pressure) associated with Miller method prevent precise estimation of pore pressure?
Can any of the above three methods precisely predict the depth @ which over-pressure begins (top of over-pressure)?
How approximate will be the construction of a 3D pressure profile from a 1D pressure profile?
5. To what extent, predicting the onset and magnitude of over-pressure is going to be challenging towards hydrocarbon exploration (as it remains to be critical in wellbore design, fluid in-place volume estimation and well deliverability)?
6. Does over-pressure always result from the rapid sediment deposition during normal mechanical compaction at shallow depths; and does it always result from fluid expansion @ greater depths?
Suresh Kumar Govindarajan
Professor [HAG]
IIT Madras 26-Dec-2024