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The evaluative methods on shale gas
productivity using the DFIT
2014. 9. 18
Dr. Sangyup Jang
T.H. Kim, G.S. Lee
C.H. Shin
This is the Eternal Flame Waterfall, on Shale Creek, in Chestnut Ridge Park, near Buffalo, New York. A pocket of natural methane gas in an alcove below the waterfall seeps out through a fracture in the rocks.
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1. Introduction
2. DFIT(diagonal fracture injection test)
3. Pre-closure analysis
4. After-closure analysis
5. Summary and future works
Contents
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Milli-darcies 1 x 10 -3 D
Micro-darcies 1 x 10 -6 D
Nano-darcies 1 x 10 -9 D
Sand stone
Formations
Tight
Formations
Shale
Formation
Introduction
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• Low permeability, Long transient time
• Build-up, Draw-down, flow test is impossible
• Needs for rapid test method for shale/tight formation.
→ Mini fracture test(DFIT)
• Effective permeability using DFIT(diagonal fracture
injection test)
The limit of conventional well test method for
shale formation.
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DFIT or Mini frac test
Ewens, 2012
Perforation Installation of pressure
gauge
Injection Shut-in
and record
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PRE CLOSURE ANALYSIS •Formation Breakdown Pressure •Fracture Closure Pressure •Instantaneous Shut in Pressure(ISIP) •Fracture Gradient = ISIP / Formation Depth •Net Fracture Pressure (Δpnet) = ISIP - Closure Pressure •Fluid efficiency = Gc/(2+Gc) : Gc is the G-function time at fracture closure •Formation Leak Off Characteristics AFTER CLOSURE ANALYSIS •Formation permeability (k) •Reservoir pressure (pi) •Net Horizontal Stress(closure – pore pressure)
Diagonal Fracture Injection Test (Mini frac test)
Fracture Closure
Pressure
Nolte, 1982
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Research Trend
Nolte (1979)
• G-function and fracture pressure decline analysis
Castillo(1987), Mukherjee(1996), Baree(1998)
• Pressure dependent leak-off vs. G-function, dP/dG, GdP/dG plot
Gu et al(1993), Nolte(1997), Benelkadi and Tiab (2004)
• After closure time function, Impulse fracture test
Soliman et al. (2005) / Craig and Blasingame (2006)
• Short term test
Meyer (2007)
• Mass and momentum equation for 2D-fracture
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• Located in north eastern British Columbia
• Horn River Group(Muskwa Fm., Otter Park Fm., Evie Fm.)
• Approximately 2,500m below surface
• Average 170m thick, Average TOC : 4.3%
• Composed of siliceous, organic rich shale (high quartz content)
Horn River
(Kiwigana)
British Columbia Alberta
General information
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Data Chart
10000
15000
20000
25000
30000
35000
40000
45000
50000
55000
60000
65000
70000
75000
80000
85000
90000
Cal
cula
ted
San
dfa
ce P
ress
ure
(kP
a(a)
)
-6000
-5500
-5000
-4500
-4000
-3500
-3000
-2500
-2000
-1500
-1000
-500
0
Liq
uid
Rate (m
3/d)
0.48 0.50 0.52 0.54 0.56 0.58 0.60 0.62 0.64 0.66 0.68 0.70 0.72 0.74 0.76 0.78 0.80 0.82
Cum Time (h)
Injection data for Well A
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• G function : dimensionless time function relating shut-in time to total pumping time
3
4
2
)(
))1((sin)1()(
)1(3
4)(
))((4
)(
5.05.01
5.15.1
o
o
p
p
D
DDDD
DDD
oDD
g
g
t
ttt
ttttg
tttg
gtgtG
(For high leak-off)
(For low leak-off)
(For high leak-off)
(For low leak-off)
Definition of G-function
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Pressure dependent leak-off -> Existence of fracture!
SHmax
G-function analysis of Well-A
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• It could be possible to find out the leak-off behavior and
fracture related reservoir properties for shale formation
by pre-closure analysis
• G-function analysis data and OBMI data were compared
to validate the existence of natural fracture near well
bore and reliable correlation is found with this methods.
Summary
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• Combing the continuity equation, the equation
of motion, and the EOS
t
p
k
c
r
pr
rr
t
1
t
p
z
p
k
c
r
p
z
pr
rr
t
1
Diffusivity eqn.
Real gas law
Gas compressibility, pseudo state (ф, μ, z constant)
'43173.7lnln
711)()(
2s
rC
kt
kh
QTPmPm
wt
aiwf
Conventional gas well test
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Nolte
Radial flow
0
000,251
000,251
000,251
1
1
1
1
Rwi
cR
t
c
tR
R
c
tiw
Fpp
tm
Qkh
kht
Qm
Fkht
Qptp
Soliman-Craig
Radial flow
)01
(
)4.1694(
)4.1694(
1)4.1694()(
2
2
ttpp
m
Vkh
kh
Vm
ttkh
Vptp
p
wi
R
inj
inj
R
p
inj
iw
Linear flow
5.0
2
105.31)(
ttkhxC
Vptp
pft
inj
iw
L
t
Liw FCk
Cptp
Linear flow
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Permeability : 11.6 d
Initial pressure for radial flow
: 5,324 psi
Leak-off coefficient
: 6.0519 10-4 ft/min1/2
Permeability : 9.98 d
Initial pressure for radial flow
: 5,317 psi
Fracture half-length : 16.6 ft
Nolte method Soliman-Craig method
Reservoir properties from 2 methods(well A)
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96.1
038.0
01.0086.0
pct
zf
ErGc
pk
f: Viscosity of injected fluid (=1 cp, assumption)
pz: Net fracture extension pressure above closure pressure(9873 psi)
Gc: G-function closure time (=32.705h)
E: Young’s modulus(=3.35Mpsi)
rp: Storage ratio(=1)
ø : porosity(=0.04)
Ct : Total compressibility(=5.09X10-5 /psi)
Calculate K = 4.4351uD
Permeability estimation
Case G-function(Baree) Nolte Soliman
Well A(μD) 4.4351 11.6 9.98
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Summary and further study DFIT results in the Kiwigana shale formation were presented.
The results have good consistency between other analytical methods and will be used for hydraulic fracturing job effectively.
The need for the prolonged shut-in time is realized to analyze the radial flow regime in DFIT.
Permeability estimation equation is useful for rough calculation.
Many production characteristics of shale gas reservoir need to be monitored to correlate reservoir properties.
Influence on adsorbed gas and stress dependent rock properties should be considered to evaluate more precisely.