stimulation 3
TRANSCRIPT
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Methods to determine insitu stress
A. Field techniques
B. Lab techniques
C. Calculate from elastic properties
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Stimulation hydraulic fracturing
Copyright, 2011
Idealized surfacepressure during hydraulic fracture treatment
(Allen & Roberts, 1982)
Net fracture pressure pressure in fracture in excess of closure pressure
Dp= Pf - Pc
Pressure
Time
Pad Volume Sand Placement in Fracture Frac
Closure Time
Breakdown
S
tartSand
Sandto
perforations
Sh
utdown
pumping
Fractureclosed
Tubing friction pressure loss
Fracture Closure Pressure-Hydrostatic
Reservoir Pressure-Hydrostatic
Constant pump rate, increasing sand concentration
Pressure rise reflecting normal frac extension
Breakdown Pressure the pressure required to initiate the fracture
Must exceed the minimum stress at the borehole and the tensilestrength of the rock.
Extension or propagation pressure the pressure required to extend the existing fracture
Closure pressure the pressure required to hold the fracture open
Equivalent and counteracts the minimum principal
insitu stress; pc shmin Approximated by PISIP Pc.
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Stimulation hydraulic fracturing
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A. Field Techniques
Summary of Pre- and post-fracturing tests for determining
extension and closure pressures SPE Monograph Vol 12(1989)
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Stimulation hydraulic fracturing
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A. Field Techniques
1. Hydraulic Fracture Stress-Test Procedure or Microhydraulic fracturing testAnalysis:
Assume one principal stress is parallel to borehole axis, i.e., sv.
Must overcome the strength of the rock and the insitu stress concentrations
upper bound due to no fluid penetration assumption.
lower bound accounts for fluid seepage prior to breakdown
xyforT
pp
yx3
upperb
p ss
ss
ss
12
21
,where
12
Tpp2yx3
lowerb
p
rockofstrength
tensile
pressure
pore
stressborehole
induced
pressure
breakdown
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Stimulation hydraulic fracturing
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A. Field Techniques
1. Hydraulic Fracture Stress-Test Procedure or Microhydraulic fracturing testAnalysis:
after pumping the pisipsx slightly greater than minimum principal stress
(assuming negligible borehole effect)
Repeat a second cycledifference is loss of tensile strength due to presence
of fracture. Resulting in 3 equation and 3 unknowns (sx, sy, T)
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Stimulation hydraulic fracturing
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A. Field Techniques
1. Hydraulic Fracture Stress-Test Procedure or Microhydraulic fracturing testExample:
Ideal stress test data with obvious ISIP
SPE Monograph Vol 12(1989)
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Stimulation hydraulic fracturing
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A. Field Techniques
1. Hydraulic Fracture Stress-Test Procedure or Microhydraulic fracturing testExample:
From the ideal stress test the breakdown pressure, pb
was observed to be 8620 psi and the minimum horizontal
stress, shmin= sxwas measured to be 8225 psi. Other
parameters are:
Pore pressure, pp = 6800 psi
Vertical stress, sv = 8465 psi
Biotsconstant, = 1
Poissons ratio, = 0.229
Tensile strength, T = 215 psi
Calculate an upper and lower bound for the maximum horizontal stress,shmax= sy
psiyy
Tppyxupperbp
94752156800)8225*3(8620
3
ss
ss
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Stimulation hydraulic fracturing
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A. Field Techniques
1. Hydraulic Fracture Stress-Test Procedure or Microhydraulic fracturing testExample:
Calculate an upper and lower bound for the maximum
horizontal stress, shmax= sy
psiyy
Tppyxupperbp
94752156800)8225*3(8620
3
ss
ss
35.012
21
,
8955)35.1(2
215)6800)(35(.28225*38620
12
23
s
s
ss
where
psiy
y
Tppyxlowerb
p
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Stimulation hydraulic fracturing
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A. Field Techniques
2. Steprate testExample:
Given a reservoir with the following properties:Bw = 1.0 RB/STB mw = 0.45 cp
h = 270 ft f = 0. 186
ct = 1.5 x 10-5 psi-1 rw = 0.25 ft
Depth = 7,260 ftInjected-fluid pressure gradient = 0.433 psi/ft
Determine the fracture gradient.
The break in the data indicates a surface
fracture pressure of about 1,000 psi. The
fracture gradient is estimated by dividing thebottom-hole fracture pressure by the depth.
The fracture gradient is:
[(0.433)(7,260) + 1,000]/7,260 = 0.57 psi/ft
Step rate injectivity test
Earlougher (1977)
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Stimulation hydraulic fracturing
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A. Field Techniques
2. Steprate/Flowback testObjective:
preferred for determining closure
pressure.measures entire interval
Procedure:
Inject fluid and create fractureflowback at constant rate
Trial and error to find appropriate
rate, 1/10 to of average injection rate
Analysis:
Pressure decline exhibits characteristic reversal in slope at closure pressure.
Caused by flow restriction introduced when the fracture closes.
Application of step-rate and pumpin/flowback testsSPE Monograph Vol 12(1989)
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Stimulation hydraulic fracturing
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B. Lab Techniques
1. Anelastic Strain Recovery (ASR)
Objective: Obtains orientation of principal
stress.
Procedure:
Sensitive strain measurements are
obtained on retrieved oriented core. Measures the volume change of core as
pulled from the surface.
Analysis:
The strain orientation is assumed the
same as the principal axes of the insitu
stresses. The time-dependent strain and total
strain are directly proportional. (Economides & Nolte, 1980)
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Stimulation hydraulic fracturing
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B. Lab Techniques
2. Differential Strain Curve Analysis
(DSCA)
Objective:
Obtains orientation of principal stresses.
Analysis:
Based on strain relaxation as an imprintof the stress history
Relies on the assumption that the
resulting microfracturing is directly
proportional to the stress reduction the
core has sustained
(Economides & Nolte, 1980)
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Stimulation hydraulic fracturing
Copyright 2011
C. Calculate from elastic properties
Objective:
Obtain minimum, insitu stress magnitude, stress profile
Procedure:
a. core triaxial tests under various confining pressures
b. combine sonic and density log measurements
Analysis: Obtain elastic properties, and E and calculate the minimum
horizontal stress from the following equation
ppppv1min,h s
s