07_Formation Pressureeeeeeeeeeeeeeeee.ppt

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1. I.Pressure Concepts
Depth:
Measured
Depth (MD).
True Vertical
Depth (TVD).

2. I.Pressure Concepts
Force:
((Force = Mass X Acceleration))
DENISTY:
((= Mass (or Weight) Per Unit Volume))

3. Pressure
((Is an Expression of Force Per Unit Area))
•Hydrostatic Pressure.
•Frictional Pressure.
•Annulus Pressure.
•Well Bore Pressure.
•Differential Pressure.
•Bottom Hole Pressure.

4. Pressure Concepts
Balance:
((Refer to the Relation Between the
Formation Pressure and the
Hydrostatic Head))
Balanced.
Under Balanced.
Overbalanced.

5. Porosity.
Saturation.
Permeability.
Overburden.
Formation pore pressure.
Compaction.
Matrix stress.
II.ROCK PROPERTIES

6. 1. Porosity
Matrix
Pores
Porosity= Pore SpaceVolume
Bulk Volume.

7. Porosity Generations
Primary porosity:
•HPP 40%.
•At 10000’, shale porosity
reaches 5%.
Secondary porosity:
•Those ones created after initial
deposition.
•Either by dissolving or
fracturing.

8. 2. Saturation
•Is that fraction of pore volume that is
filled with a given fluid.
•A 20%sw= 20%of the pores are filled
w/ water & 80% w/ other fluid which may be
oil or gas.

9. 3. PERMEAPLITY
•Is a measure of the ease with which a
fluid willflowthrough a formation.
•Q= k*a* (p1 –p2)/v*l.
•K = QVL/A(P1-P2) in millidarcies.
•The larger the porosity the higher the
permeabilty.

10. 4. Overburden
•Overburden load:
Is the combined weight of the formation
matrix and the fluids overlying a
formation.
•Overburden pressure:
Is the pressure exerted by the
overburdenload upon underlying
formations.

11. Compaction
It is PRINCIPALYa process of
mechanical rearrangement

12. Factors Affecting Compaction
Rate
1.Rate of deposition.
2.Tectonic forcess.
3.Formation permeability.
4.Lithology.
5.Diagenesis.
6.Osmosis.

13. Overburden
Matrix Stress
Pore Fluid
Pressure
Overburden
pressure

14. Matrix Stress
Is the resistance of the formation
matrix to compaction expressed in
psi or psi/ft.

15. Overburden Gradient
This is an expression
of the pressure unit
per unit depth. e.g.
•psi/ft.
•ppg..

16. 5.Formation Pressure
((Is the Fluid Pressure Found Within
the Pore Spaces of the
Formation))
•Can Be Expressed As an Average
Vertical Pressure or Equivalent Mud
Weight. E.G. psi, ppg, G/cc…

17. Normal Pressure
Matrix
Pores
Expelled fluid

18. Formation pressure equalin
magnitude to the hydrostatic pressure of
a column of pore fluid that reaches from
the surface to the vertical depth of the
formation.
Normal Pressure

19. Abnormal Pressure
Matrix
Pores

20. Formation pressure greater than
the magnitude of the hydrostatic
pressure of a column of pore fluid that
reaches from the surface to the vertical
depth of the formation.
Abnormal Pressure

21. 1.Concept of Continuous
Deposition
This concept assumes that the compaction
rate of any formation is the same as for all
formations of a given type.
This mean that shales for example
deposited at different times and buried to
different depths are considered to have
compacted at the same rate as long as the
formation pore pressure remained normal.

22. 2. Pressure Seal
((A zone of low permeability acts to
trap the pore fluids within a
formation.)).
•May be either physical or chemical.
•Restrict the vertical an lateral movement of
pressure.
•e.g. evaporates, faults ..

23. 3.Equilibrium.
S = Mv + P
S= overburden.
Mv= Vertical matrix stress.
P= formation pore pressure.

24. Equilibrium
Matrix Stress
Pore Fluid
Pressure
Overburden
pressure

25. 4.Transition Zone
This is an argillaceous
sequence of gradual pore
pressure increase above a
permeable high pressure
formation.

26. Causes of Abnormal Pressure
Rapid subsidence and sediment
accumulation.
Thermal expansion.
Tectonic movement.
Reservoir altitude.
Clay digenesis.
Repress ring of shallow reservoirs.

27. Signs of Abnormal pressure
Normalized drilling rate (Drilling models).
Change in rotary torque.
Change in drag.
Shale density.
Gas analysis.
Flow line temperature.
Size and shape of cuttings.
Open hole logs.

28. Normalized Drilling Rate
1.Weight on bit.
2.Rotary speed.
3.Bit diameter.
4.Bit type.
5.Rock type.
6.Mud properties.
7.Differential pressure.
8.Hydraulics.

29. “d” Exponent
R/60N= (12W/10^6D)^d
-Log(R/60N)=d*log (12W/106D)
-d= Log(R/60N)/ log (12W/10^6D)
R=rop (ft/hr).
N= rpm.
W=wob (ib)
D= bit diameter (in).

30. Corrected “d” exponent
Dc = d*(n/mw)
N= normal pp
Mw= mud weight

31. Factors Affecting dc
1.Bit wear
2.Lithologic change
3.Drastic changes in drilling parameters.
4.Bit types.

32. Flow Line Temperature
Formation fluids tend to act as thermal
barriers or insulators which impede the
normal flow of heat from the earth’s
core to the surface.

33. Flow Line Temperature

34. Size and shape of cuttings
A cutting drilled near balanced
conditions will be larger and more
angular in shape than one which is
drilled under conditions of greater
overbalance.

35. Pore Pressure Calculations
1.Depth of seal
FP=Sf-[(Se-n)/(TVDe/TVDf)]
FP= fm pressure
Sf= overburden at wanted depth
Se= overburden at depth of seal.
N= normal pp.
TVDe= depth of seal
TVDf= fm depth

36. Pore Pressure Calculations
2. Eaton equation
FP=Sf-(Sf-n)*(DCo/DCn)^m
FP= fm pressure
Sf= overburden at wanted depth
N= normal pp.
DCo= observed dxc
DCn= normal dxc1000
1500
2000
2500
3000
3500
0.1 1 10
Dc Exponent
TVD (m)
NCT
Top
Overpressure

37. Resistivity1000
1500
2000
2500
3000
3500
0.1 1 10
RILD (ohm.m)
TVD (m)
NCT
Top
Overpressure 1000
1500
2000
2500
3000
3500
100 1000
Sonic (usec/m)
TVD (m)
Top of
Overpressure
NCT
response
in casing
Cycle
Skipping Sonic

38. III-FRACTURE PRESSURE
Is the pressure needed to
make a fracture in a
formation.
•The orientation of the produced
fracture depend on the orientation
of the principal stress of the
fracture point.

39. Principal Stresses
At any point in the
formation there
exists a stress
regime consisting of
three perpendicular
stresses
Sig1 maximum, sig2
intermediate, sig3
minimum.

40. Fracture development
The fracture is
developed
perpendicular to the
minimum stress

41. Poisson Ratio
The ratio of transverse strain to axial strain
V=change in breads/original breads
change in length/original length

42. Fracture pressure
Fr={V/(1-V)}*(S-P)+P

43. Leak off Test
Application of
pressure to a
formation to
determine its
fracture pressure,
without fracturing
the formation.
Frp= MWt + LOP
TVDt*.052

44. Thanks for your attention