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IDENTIFICATION AND EVALUATION OF FRACTURED
TIGHT-SAND OIL RESERVOIR IN DEEP ZONE OF BOHAI GULF
Shanjun Li1
, Ce Liu1
, Liang.C. Shen1
, Hanming Wang2
, Jian. Ouyang3
, and Genji. Zhang4
1ECE Department, University of Houston, 4800 Calhoun Rd., Houston, TX 77004 Email:
[email protected], [email protected], [email protected] of Houston, currently an employee of Schlumberger, Schlumberger, Houston TX,
Email:[email protected] National Petroleum Company, Email:[email protected]
4University of Petroleum, China, Email:[email protected]
Copyright 2006, held jointly by the Society of Petrophysicistsand Well Log Analysts (SPWLA) and the submitting authors.
This paper was prepared for presentation at the SPWLA 47thAnnual Logging Symposium held in Veracruz, Mexico June4-7, 2006.
______________________________________
Abstract
In this paper, three fracture models are considered. First,we study the plane fracture model that represents the
formation consisting of fractures with equal spacing
and opening. Second, the matchstick model in whichtwo sets of perpendicular plane fractures exist is
examined. Third, we also study the cubic one where
three sets of plane fractures perpendicular to each other.These models can be represented by a macro-
anisotropic medium using equivalent conductivity
theorem. Using a 3-D FEM codes, dual laterologresponses in the models may be computed.
The simulated results of plane fracture model show thattool response in the equivalent medium equals to that of
the original fracture-free medium only when the
spacing between fractures is small , and that deep
laterolog response (Rlld) is greater than shallowlaterolog response (Rlls) for large dip angles and Rlld is
smaller than Rlls for small dip angles.
The computed responses of the matchstick model show
that when the porosity of main set fractures is muchgreater than that of another set, the response of the
model has the same characteristics as the plane model;
and when the main fracture porosity decreases, Rllddecreases for large dip angles and increases for small
dip angles. Rlls decreases for large dip angles and
changes very little for small dip angles. Samecharacteristics are found in the response of cubic
situation.
An inversion code has been developed to computefracture porosity and dip angle from dual laterolog
response, and used to evaluate the fracture porosity anddip angle in tight-sand oil reservoir in Bohai Gulf.
A Well A was drilled in Dagang Oilfield in Bohai
Gulf in 1999. When drilling through a tight-sandformation with low porosity and low permeability,
more than 67 cubic meters of mud was lost. Oil testingof the reservoir with 12.2mm nozzle produced 543
cubic meters of oil and 90,500 cubic meters of gas daily.
Such high production in this kind of reservoir was
beyond expectation of all experts working on thisproject. Based on the characteristics of dual laterolog
curves and related geometrical data in this region, thislayer and two others were named as fractured reservoirs,
and their fracture porosity and dip angles were
computed by using the inversion code. Oil testing to
another reservoir obtained 220 cubic meters of oil and79,984 cubic meters of gas daily.
INTRODUCTION
Fractures provide the path for oil and gas to move inreservoirs. That is the main reason why the
permeability in the formation with fractures is much
higher than that without fractures. So the production of
oil and gas especially in low permeability formation ismainly depended on the existing of fractures. Thus the
exploration and development of fractured reservoirs isone of main goals for most oil companies. The ability to
identify fractures and to evaluate their porosity, dip and
strike angles become an important requirement for well
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logging analysts to acquire.
Interpretation of logs obtained by electrode-type tools
in fractured formations requires special attention. A
fractured formation is an electrical anisotropic medium,
which means that the conductivity is different indifferent directions. Because of this property, it is
difficult for log analysts to identify and evaluate
fractures if standard interpretation routines are used.Some features in the dual laterolog responses in
fractured reservoirs have long been one of the keyproblems that log analysts wish to resolve. To this end,
using a 3-D FEM code, Sibbit et al. (1985) computed
the dual laterolog response of a single fracture when the
fracture dip angle is 0o or 90o. Philippe et al. (1990)derived the conductivity tensor formula for a medium
containing parallel fractures with equal aperture andspacing. They also obtained approximate dual laterolog
responses in a fractured medium with an arbitraryorientation angle. By means of a 3-D FEM code, Wang
et al. (1998) computed dual laterolog responses in many3-D cases, including those in parallel fractured
formations. Using azimuthal electrical sondes,Mousatov et al. (2003) discussed the property of
azimuthally fractured formations.
In this paper, three geological fracture types areintroduced: plane model, match- stick model, and cubic
model. It is shown that formations containing thosefractures can be treated as equivalent to some
homogeneous anisotropic media. Formula for the
effective conductivity tensor for each fracture model is
presented. Then dual laterolog responses in thosefractured formations are computed and discussed.
MODEL OF PLANE FRACTURE
A formation with plane fractures is consisted of parallel
fractures of equal aperture and spacing, as shown in
Figure1. Let dbe the fracture spacing, the fractureaperture,
bthe conductivity of the rock matrix, and
f
the conductivity of the fluid in the fracture, theequivalent conductivity tensor (Philippe and Roger,
1990) of this formation containing plane fractures with
zero dipping angle is
=
0
0
0
0
00
00
00
zzp
yyp
xxp
(1)
where
ffbfxxp += )1(0
, (2a)
ffbfyyp += )1(0, (2b)
)1(10
+=
f
bf
b
zzp
, (2c)
andd
f+
=
is defined as the fracture porosity. Note
that definition of the fracture porosity used here isdifferent from that used in (Philippe and Roger, 1990).In above equationsthe z-axis coincides with the normal
to the fracture plane and the x- and the y- axes are
parallel to the fracture plane.
Figure 1 Model of the plane fractures
The relative dip angle of the fracture is defined as theangle between the normal of the plane fracture and the
reference z-axis that is also the borehole axis. Then theconductivity tensor (Philippe and Roger, 1990) of the
dipping fractured formation is
=zzzx
yy
xzxx
0
00
0 , (3)
where
+= 2000 sin)( xxpzzpxxpxx , (4a)
0yypyy =, (4b)
= 2000 sin)( xxpzzpzzpzz , (4c)
== cossin)( 00 zzpxxpzxxz . (4d)
Note that due to the symmetry of the plane fracture, the
conductivity tensor is independent of the strike or the
azimuthal angle.
MODEL OF MATCHSTICK FRACTURES
A formation containing matchstick type of fractures is
consisted of two sets of plane fractures, as shown in
Figure 2. One set of plane fractures is horizontal orparallel to the XOY plane in the chosen coordinate
system shown in Figure 2. The other set of the plane
fractures is vertical or parallel to the YOZ plane. Herepoint O represents the origin of the coordinate system.
X
Z
Y
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Let a be the ratio of the horizontal fracture porosity to
the total fracture porosity. Assume first that the dippingangle of the fracture is zero. As shown in Appendix I,
the three diagonal elements of the conductivity tensor in
(1) can be expressed as follows:
ff
f
bf
b
fxxm a
a
a
+
+=
)1()1(1)1(0
(5a)
ffbfyym += )1(0(5b)
ff
f
bf
b
fzzm a
a
a
+
+= )1(
)1(1
])1(1[0
(5c)
Figure 2 Model of the matchstick fractures
In a similar case where one set of plane fractures isparallel to the XOY plane and the other is parallel to the
XOZ plane, the three diagonal elements are also given
by (5) with:0zzm
given by (5c). Furthermore,
0xxmand
0yymexchange their positions, i.e., the former is
given by (5b) and the latter by (5a).For the dipping case, the conductivity tensor is
same as (3), with the0xxp,
0yyp, and
0zzpin (4) replaced
by0xxm,
0yymand
0zzmin (5).
MODEL OF CUBIC FRACTURES
A formation is said to have cubic fractures if it isconsisted of three sets of plane fractures. These
fractures are parallel to the XOY, YOZ, and XOZplanes, respectively, as shown in Figure 3.
Let a be the ratio of the porosity of the main fractures
(the ones parallel to the XOY plane) to the total fracture
porosity. Let b be the ratio of porosity of the fracturesparallel to the YOZ plane, to the total fracture porosity.
With similar method of treating0xxm,
0yymand
0zzm, the
three diagonal elements in the conductivity tensor given
in (1) take the following forms:
ff
f
bf
b
fxxc b
b
b
+
+= )1(
)1(1
])1(1[0
(6a)
ff
f
bf
bfyyc ba
ba
ba
+++
+= )()1()1(1
])(1[0
(6b)
ff
f
bf
b
fzzc a
a
a
+
+= )1(
)1(1
])1(1[0
(6c)
Figure 3 Model of cubic fractures
Let0xxc,
0yyc, and
0zzcin (6) replace
0xxp,
0yypand
0zzp
in (4), the conductivity tensor of the cubic fractureformation with a dipping angle is obtained. It is easily
seen by comparing formulas (2), (5), and (6) that theplane model and the matchstick model are two special
cases of the cubic model.
SUMMARY OF 3-D FEM FORMULATION
When the dual laterolog response problem isformulated in terms of the FEM, the energy functional
is defined first (Zhang, 1986):
21 = . (7)
In (7),dVJE= 2
11
and it is the half of power
consumption in the medium;=
UI2
is the power
supplied by the electrodes; Jis the current density; Eis
the electric-field strength;EI
is the current emitted by
the electrode E; andEU
is its potential.
Y
Z
X
Y
Z
X
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In this paper tetrahedral elements are adopted. The
field strength in a tetrahedral element assumes aconstant value expressed in terms of the linear
combination of the potential values at the four nodes of
the tetrahedron. As shown in Appendix II, the half
power consumption 1 in element e of a homogeneousanisotropic medium with conductivity tensor (3) is
Vzxffzffb
yffb
V
xffb
dEEE
EE
]cossin)(2))(sin(
))(())(cos[(
22
2222
11
+++
+++=
(8)
whereeV
is the volume of the element e, andxE,
yE, and
zEare the three components of the electric field
strengthE.
For an inhomogeneous element, in which both the rock
matrix and the fracture are present, the half powerconsumption functional )(1
e in that element e is
2+= fb, (9)
where )(eb
is the power consumption in the matrix, and
efb
e
b VEE )1(2
1)( = .(10a)
Also, )(ef
is the power consumption in the fracture. In
Appendix III, taking into account the continuity of the
potential and the continuity of the normal component ofthe current density at the boundary between the fracture
and the matrix, the power in the fracture can be derivedto take the following form
effnf
f
be
f VEEE
])[(
2
1 22
)( +=. (10b)
It is proved in Appendix IV that the power consumption
defined by (8) for a homogeneous anisotropic mediumis equal to that defined by (9) for the plane fractures.
The above statement is valid on the conditions that boththe aperture and the spacing approach zero, with their
ratio kept at a constant value, and that the aperture is
infinitesimal with respect to the spacing. This means
that the formation with plane fractures can be treated asa macroscopic homogeneous anisotropic medium under
those conditions. This assertion is verified by actual
numerical computation in formation with planefractures, as we shall see later.
LATEROLOGS IN PLANE FRACTURES
Figure 4a and 4b show the influence of fracture spacing
on laterologs in the plane fractures. The abscissa
represents position of tools center and the ordinaterepresents the deep laterolog response computed with
3-D FEM. Curves labeled Rlld1 and Rlls1 are deep and
shallow laterologs with the fracture spacing equal to 1
m. Similarly, Rlld2 and Rlls2 are for 0.5 m spacing;Rlld3 and Rlls3 for 0.25 m spacing; and Rlld4 and
Rlls4 for 0.125 m spacing. It is assumed that the
resistivity of the rock matrix is 140 ohm-m and thefracture is filled with 0.18 ohm-m borehole mud. The
size of the borehole is 6 inches in diameter and the
fracture porosity is 1 %. The equivalent conductivitytensor corresponding to these parameters is listed in
Table I. These parameters are used throughout this
paper unless stated otherwise.
(a) Deep laterologs
(b) Shallow laterologs
Figure 4 Laterolog responses in a formation
with plane fractures.
140=bR(ohm.m),
fm RR ==0.18(ohm.m), bore-
hole size is 6(inch),f=1%. Curve 1 is for 1 m
fracture spacing. Similarly, curve 2 is for 0.5
m, curve 3 for 0.25 m, and curve 4 for 0.125mfracture spacing, respectively.
In both Figures 4a and 4b, it is seen that laterolog
readings in the fractured formations oscillate when the
tool moves along the borehole. The amplitude of the
10
100
1000
-2 -1 0 1 2
Position(m)
Rlld(ohm.m
)Rlld1
Rlld2
Rlld3
Rlld4
10
100
1000
-2 0 2
Position(m)
Rlls(ohm.m
) Rlls1
Rlls2
Rlls3
Rlls4
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oscillation decreases with the fracture spacing. The logs
are smoothly varying with depth without observableoscillation when the fracture spacing is reduced to
0.125 m. As far as laterolog is concerned, the medium
containing plane fractures with spacing less than or
equal to this margin can be regarded as macroscopicallyhomogeneous anisotropic medium.
Figure 5 shows responses of dual laterolog in twomedia. The first is a medium containing plane fractures
and the other is a homogeneous anisotropic medium.The abscissa represents the dip angle. The ordinate
represents Rlld1 and Rlls1, which are the deep and
shallow laterologs in a homogeneous anisotropic
medium. The curves Rlld2 and Rlls2 are the deep andthe shallow laterologs in a medium with plane fractures.
It is seen in Figure 5 that the dual laterolog responses inthe medium with plane fractures and those in the
anisotropic medium are indistinguishable for all dipangles. Of course, the conductivity tensor of the
anisotropic medium is set equal to the effectiveconductivity tensor of the medium with plane fractures.
The fracture spacing is 0.125 m.
Figure 5 Comparison between the duallaterolog responses in the plane fracture
formation and in a homogeneous anisotropicmedium with various dip angles.
Rlld1 and Rlls1 are deep and shallow responses
in a homogeneous anisotropic medium
respectively. Rlld2 and Rlls2 are deep andshallow responses in the medium with plane
fractures. Both media have the same equivalentconductivity tensor. Borehole size is 6(inch).
For the plane fracture formation,
bR=140(ohm.m),
fm RR ==0.18(ohm.m),
f=1%,
and spacing =0.125(m).
Figure 5 also displays the fact that the deep laterolog
reads lower than the shallow one for nearly horizontal
fractures. For nearly vertical fractures, the opposite is
true. Also, when the fracture dip is in the range from30o to 74o, the rate of variation of dual laterologs with
respect to the dip angle is the greatest. The critical
angle at which the deep and the shallow logs read the
same value is within this range. Both the deep and theshallow readings are affected primarily by the
horizontal conductivity at zero dip. At 90-degree dip,
these readings are approximately determined by thegeometric mean of the horizontal and the vertical
conductivities. These characteristics are common tolaterolog responses in anisotropic media (Wang et al.
1998). Figures 4 and 5 also verify the equivalence
between a medium with plane fractures and a
macroscopic homogeneous anisotropic medium in asfar as dual laterolog response is concerned.
(a) Deep Laterolog
(b) Shallow laterolog
Figure 6 The relationship between fractureporosity and shallow laterolog apparent
conductivity
bR=140(ohm.m),
fm RR ==0.18(ohm.m),
Borehole size is 6(inch). Clls0, Clld0, Clls30,
Clld30, Clls60, Clld60, Clls80, Clld80, Clls90and Clld90 are shallow and deep laterolog
apparent conductivity computed when fracturedip is 0o, 30o, 60o, 80o and 90o respectively.
10
100
0 10 20 30 40 50 60 70 80 90
Fracture Dip(degree)
Ra(ohm.m
) Rlld1
Rlls1
Rlld2
Rlls2
0
0.1
0.2
0.3
0.4
0.5
0 0.05 0.1
Fracture Porosit y(%)
Clld(s/m)
Clld0
Clld30
Clld60
Clld80
Clld90
0
0.05
0.1
0.15
0.2
0.25
0.3
0.350.4
0 0.05 0.1
Fracture Porosi ty(%)
Clls(s/m)
Clls0
Clls30
Clls60
Clls80
Clls90
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Figure 6a shows the relationship between the deep
laterolog reading and the fracture porosity for the planefracture model. The abscissa represents the fracture
porosity, and the ordinate is the apparent conductivity
reading of the deep laterolog. The curves labeled as
Clld0, Clld30, Clld60, Clld80 and Clld90 are deeplaterolog readings expressed in conductivity units when
fracture dip is 0o, 30o, 60o, 80o, and 90o, respectively. It
is seen that the deep conductivity reading increasesalmost linearly as the fracture porosity is increased.
Similar relationship between the shallow laterolog andthe fracture porosity is seen in Figure 6b. This behavior
is expected because the rock is highly resistive so that
the fluid in the fracture mainly contributes the overall
conductivity of the formation. The characteristics of thematchstick fractures and the cubic fractures are similar
to that of the plane fracture case in this regard.
LATEROLOGS IN MATCH STICK FRACURES
Figure 7 shows the relationship between fracture dipangle and the dual laterolog responses in a formation
containing matchstick fractures. Figures 7a, 7b, 7c, and7d are computed when the porosity ratio a is 0.9, 0.8,
0.7, and 0.6, respectively. Recall that a is the ratio of
the horizontal fracture porosity to the total porosity. It
is seen that in general the deep laterolog reading ishigher than the shallow reading in nearly vertical
fractures and lower in nearly horizontal fractures. Butthe difference between the deep and the shallow
responses becomes smaller when the ratio a is
decreased. Note that when a = 0.5, the horizontal
fracture is equal in porosity to the vertical fracture andthe readings at zero degree dip is the same as those at
90-degree dip.
(a) a=0.9
(b) a=0.8
(c) a=0.7
(d) a=0.6
Figure 7d Dual Laterolog response in
matchstick fracture formation
bR=140(ohm.m),
fm RR ==0.18(ohm.m),
f=1%,
Borehole size is 6(inch).
(a) Deep Laterolog
(b) Shallow laterolog
Figure 8 Dual laterolog responses in matchstick
fracture formation for various a ratios.
The curves labeled as Rlls1 through Rlls4correspond to a ratio of 0.9, 0.8, 0.7, and 0.6,
respectively.fm RR =
=0.18(ohm.m),f
=1%.
bR=140(ohm.m), Borehole size is 6(inch).
10
100
0 10 20 30 40 50 60 70 80 90
Fracture Dip(degre e)
Ra(ohm.m
)Rlld1
Rlls1
10
100
0 10 20 30 40 50 60 70 80 90
Fracture Dip(degree)
Ra(ohm.m
)Rlld1
Rlls1
10
100
0 10 20 30 40 50 60 70 80 90
Fracture Dip(degree)
Ra(ohm.m
)Rlld1
Rlls1
10
100
0 10 20 30 40 50 60 70 80 90
Fracture Dip(degree)
Ra(ohm.m
)
Rlld4
Rlls4
10
100
0 10 20 30 40 50 60 70 80 90
Fracture Dip(degree)
Rlld(ohm.m
)Rlld1
Rlld2
Rlld3
Rlld4
10
100
0 10 20 30 40 50 60 70 80 90
Fracture Dip(degree)
Rlld(ohm.m
)Rlld1
Rlld2
Rlld3
Rlld4
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10
100
0 10 20 30 40 50 60 70 80 90
Fracture Dip(degree)
Ra(ohm
.m
) Rlld4
Rlls4
10
100
0 10 20 30 40 50 60 70 80 90
Fracture Dip(degree)
Ra(ohm.m
) Rlld1
Rlld2
Rlld3
Rlld4
Figure 8a summarizes the deep laterolog responses
shown in Figure 7a through Figure 7d for various aratios. The curves labeled as Rlld1 through Rlld4
correspond to a ratio of 0.9, 0.8, 0.7, and 0.6,
respectively. It is seen that the deep laterolog readings
in 90-degree dipping fractures decrease with decreasinga ratio. Deep laterolog readings increase with a ratio in
zero-degree dip fractures. Figure 8b shows similar
behavior for the shallow laterolog readings. The curveslabeled as Rlls1 through Rlls4 correspond to a ratio of
0.9, 0.8, 0.7, and 0.6, respectively. It is seen that theshallow laterolog readings in 90-degree fractures
decrease with decreasing a ratio but the shallow
laterolog readings are insensitive to the ratio in zero-
degree dip fractures.
LATEROLOGS IN CUBIC FRACTURES
Figure 9 shows the relationship between fracture dipangle and dual laterolog responses in a formation with
cubic fractures. Figure 9a is computed for ratios a and
b equal to 0.9 and 0.05, respectively. Recall that a is the
ratio of the horizontal fracture porosity to the totalporosity andb is the ratio of porosity of YOZ fractures
to the total porosity. These a andb ratios are 0.7 and
0.15, respectively in Figure 9b; 0.6 and 0.2 in Figure
9c; and 0.4 and 0.3 in Figure 9d, respectively. Thesefigures display similar characteristics as those of
matchstick fractures shown in Figure 7. That is, whenthere are mainly horizontal fractures, as in the case of
Figure 9a, the deep laterolog reads higher than the
shallow laterolog near 90-degree dip and the readings
are just the opposite near the 0-dip angle. When thefracture volumes are nearly equal in all three directions,
as in the case of Figure 9d, the deep and shallowlaterolog readings are almost the same.
(a) a=0.9, b=0.05
(b) a=0.7, b=0.15
(c ) a=0.6, b=0.2
(d ) a=0.4, b=0.3
Figure 9 Dual laterolog responses in cubic
fracture formation for various a andb ratios.
bR=140(ohm.m),
fm RR ==0.18(ohm.m),
f=1%.
Borehole size is 6(inch).
(a) Deep laterolog
(b) Shallow laterolog
Figure 10b Dual laterolog responses in cubic
fracture formations with different a andb ratios.
Figure 10a summarizes the deep laterolog curves shown
in Figure 9. It is seen that the deep laterolog reading incubic fractures with 90-degree dipping angle decreases
with decreasing ratio a and increasing ratio b. The
10
100
0 10 20 30 40 50 60 70 80 90
Fracture Dip(degree)
Ra(ohm
.m
) Rlld1
Rlls1
10
100
0 10 20 30 40 50 60 70 80 90
Fracture Dip(ohm.m)
Ra(ohm
.m
) Rlld2
Rlls2
10
100
0 10 20 30 40 50 60 70 80 90
Fracture Dip(degree)
Ra(ohm
.m
)Rlld3
Rlls3
10
100
0 10 20 30 40 50 60 70 80 90
Fracture Dip(degree)
Ra(ohm.m
) Rlls1
Rlls2
Rlls3
Rlls4
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trend is just the opposite at the other end, that is, at
zero-degree dip. Similarly the shallow laterologreadings shown in Figure 9 are summarized Figure 10b.
It is seen that the shallow reading in 90-degree cubic
fractures decreases with decreasing ratio a and
increasing ratio b, with the opposite trend seen at zero-degree dip.
Application of Laterolog Response to Fracture
Evaluation
The software has been used in oilfield, China, to
evaluate fracture porosity and dip in carbonate and tight
sand formation. As an example, in this paper we only
give an application in tight sand formation.
In late 1999, Dagang oilfield drilled a well designatedas the A well here. When drilling from *923m through
*233m, more than 67 cubic meters of mud was lost.Interpretation of well logs showed low porosity and low
permeability, and formation water saturation computedfrom logs was very low in the region. So the layers in
this region were interpreted as water layers by Dagangoilfield well logging company. However, the oil testing
from *220m through *233m with 12.2mm opening of
pipeline given 543 cubic meters oil and 90,500 cubic
meters gas one day. Such high production in the lowporosity and low permeability zone was beyond the
expectation of all experts working on this project. Butthe use of dual laterologs can explain the unusual result.
Figure 11 shows dual laterolog data of three layers of
the A well from *930m through *230m. We can see thepositive difference between the deep and the shallow
laterolog responses. Also, the deep laterolog reading isgreater than the shallows. These observations coincide
with the characteristics of dual laterolog responses
computed above when the fracture dip angle is higher.
Based on some geometry data in this oilfield, weidentified the reservoir as a fractured one, and
interpreted other three reservoirs as fractured ones from*933m through *178m. Using the simulation software
of dual laterolog response in fractured reservoir, for
which the results are shown in Table 3.2. According to
the interpretation results, Dagang oilfield tested the
reservoir from *933m through *936m, resulting in 220cubic meters of oil and 79,984 cubic meters of gas. The
test data proved the correctness of the interpretation.Later, Dagang oilfield did image logging in this region,
which also confirmed our interpretation.
In Table 2, Section, Thk, LLd, LLs, Por, pf , Def and
FR represent region of reservoir, thickness of layer,
deep laterolog, shallow laterolog, formation porosity,
fracture porosity, interpretation definition and fractured
reservoir, respectively.
Salt mud was used with salinity 40,000mg/l. The mud
resistivity under earth is 0.05 m . Rock matrix
resisitivities were computed with Archies formula.
Those parameters were used to compute the fractureporosity and dip listed in Table 2.
CONCLUSIONS
In this paper we study three fracture models: the plane
fractures, the matchstick fractures, and the cubicfractures. It is shown that formations containing these
fractures can be modeled as anisotropic media. The
equivalent conductivity tensors for these fracturemodels are presented. The equivalence between these
fracture models and the corresponding homogeneous
anisotropic media are mathematically established and
numerically verified. By means of 3-D FEM, duallaterolog responses in various fracture models are
computed and studied. The 3-D simulation can even beused in cases where those fractures are dipping with
respect to the borehole axis. The results presented in
this paper are useful for interpreting laterologs infractured reservoirs. The software has been used by
oilfield company of China to evaluate fracture porosity
and dip in carbonate and tight sand formation and goodresults have been obtained.
Acknowledgments
This research is supported by a consortium of Aramco,
Baker Hughes, BP, Chevron E & P TechnologyCompany, ConocoPhillips, ExxonMobil Upstream
Research Company, Halliburton Energy Service,
Precision Energy Service, Shell E & P Technology
Company and Statoil.
REFERENCES
A.Mousatov, E.Pervago, and E.Kazatchenko, 2003,
Feasibility of Azimuthal Electrical Sondes for the Study
of Anisotropy in Fractured Formation, Paper YY, inTransactions of 44th Annual Logging Symposium:
Society of Professional Well Log Analysts.
Sibbit, A. M., Faivre, O., 1985, The dual laterolog
response in fractured rocks, paper T, in 26th Annual
Logging Symposium Transactions: Society ofProfessional Well Log Analyst, p. T1-34.
Philippe, A. P., Roger, N. A., 1990, In situ
measurements of electrical resistivity, formation
anisotropy and tectonic context, paper M, in 31st
Annual Logging Symposium Transactions: Society ofProfessional Well Log Analyst, p. M1-24.
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Wang, H. M., Shen, L. C. and Zhang, G. J., 1998, DualLaterolog Response in 3-D Environments, paper X, in
39th Annual Logging Symposium Transactions:
Society of Professional Well Log Analyst, p. X1-13
Wang Hanming and Shen, Liang C., 2001, Dual
Laterolog Responses in Anisotropic Crossbedding
Formation: Petrophysics, v.42, n.6, November-December, p. 624-632.
Zhang Genji, 1986, Electrical Well Logging vol. 2,
Petroleum Industrial Press, Beijing, China.
About the Author
Shanjun Li received the PhD degree in ElectricalEngineering from University of Houston, USA in 2004,
Ms degree in geoscience and BS degree in applied
mathematics from University of Petroleum, China in1993 and 1986, respectively. He worked as an
instructor in the Department of Mathematics of the
University of Petroleum from 1986 to 1990, as anengineer in Exploration Research Center of Tarim
Basin during 1993-1995, and as an associate professor
in the Department of Exploration of University ofPetroleum from 1996-2001. From 2005 to present, he is
a post doctoral fellow. His research interest is in
electrical logging theory and reservoir parameterevaluation.
Ce, Liu received the BS and MS and PhD degrees inradio engineering from Xian Jiaotong University, Xian,China, in 1982, 1984 and 1988, respectively. He has
been with the Department of Electrical and ComputerEngineering, University of Houston, TX, since 1988,
where he is currently an Professor and Director of Well
Logging Laboratory and Subsurface Sensing
Laboratory. From 1997 to 1998, he was on sabbaticalleave with Compaq Computers, Houston, TX, as a
Senior RF Architect. His research areas include EMsubsurface sensing, well logging, EM tomography,
sensor development, ground penetrating radar, RF
circuit design, and wireless telecommunication systems.
Dr. Liu is a licensed Professional Engineer and amember of SPWLA, EEGS, and SCA.
Liang C. Shen received the PhD degree in applied
physics from Harvard University in 1976. He then
joined the faculty of the University of Houston and is
now a professor in the Department of Electrical andComputer Engineering. He served as the Department
Chairman from 1977 to 1981. He was a full-timeresearch consult at Gulf Oil Exploration and Production
Company during 1981-82, and ARCO oil and Gas
Company during 1990-91. Dr. Shen founded the Well
Logging Laboratory in 1979 to do research inelectromagnetic properties of reservoir rocks. He has
published a textbook and more than 90 technical
papers. He is a fellow of IEEE and a recipient of the
SPWLA Gold Medal for technical achievement. He hasserved as an associate editor for Geophysics, Radio
Science, and IEEE Transactions on Geoscience and
Remote Sensing.
Hanming Wang received PhD degree from WellLogging Laboratory of University of Houston in 1999.
He is a senior research scientist of Schlumberger Sugar
Land Product Center. He is interesting in well logging
modeling, inversion and log analysis. He is a number ofSPWLA, SPE and SEG.
Jian Ouyang is a counselor of CNPC. He was a vice
general geologist of Exploration Bureau of CNPC.
Genji Zhang received his B.S. degree in 1952 fromTsinghua University, Beijing, China. He works with the
University of Petroleum, Shandong, China. Hisresearch interest is in electromagnetic field in
inhomogeneous media and geotomography. Mr. Zhang
is a member of the Petroleum Society of China and
Geophysical Society of China.
APPENDIX I
In X direction, the formation, as shown in Figure2, canbe treated as serial conductors of the matrix with
conductivity,
)1()1(1 +f
bf
b
a
obtained from (2b)
with fracture porosityfa )1(
, and fractures with
porosityfa. With formula (2a), the conductivity in X
direction0xxmcan be computed with the following result:
ff
ff
bf
b
fxxm
a
a
a
+
+=
)1()1(1
)1(0
(A1)
Similarly, in Y direction, the conductivity0yym
can be
computed with the following result:
ffbfyym += )1(0. (A2)
In Z direction, the formation can be considered as serial
conductors of the matrix with conductivity,
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)1(1 +f
bf
b
a
obtained from (2c) with fracture
porosityfa
, and fractures with porosityfa )1(
. The
conductivity in Z direction 0zzm con be computed withthe following result:
ff
f
bf
b
fzzm a
a
a
+
+= )1(
)1(1
])1(1[0
(A3)
APPENDIX II
In a fractured reservoir, becausef
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Table 1 Diagonal conductivity tensor elements when fracture (dip angle = 0)
Off diagonal elements are equal to zero.
Fracture modelxx (s/m) yy (s/m) zz (s/m)
Plane Fracture 0.062 0.063 0.0072
a=0.9 0.057 0.063 0.013
a=0.8 0.052 0.063 0.018
a=0.7 0.046 0.063 0.024
Matchstick
Fracture
a=0.6 0.040 0.063 0.029
a=0.9, b=0.05 0.060 0.060 0.013
a=0.7, b=0.15 0.054 0.054 0.024
a=0.6, b=0.2 0.052 0.052 0.029
CubicFracture
a=0.4, b=0.3 0.046 0.046 0.040
Table 2 Interpretation results of A well in Dagang oilfield
Section Thk LLd LLs Por pf Dip Def Test Results
m m m m % % (O
) daym /3
*933-*936 4 8 4.5 15 1 85 FR 220 oil and 79,984 gas
*158-*165 7 8 4.5 13 1 85 FR*172-*178 6 9 6 13 1.05 85 FR
*220-*226 6 5 3 13 1.9 80 FR 543 oil and 90,500 gas
3 12 9 13 0.27 70 FR
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Figure 11 Dual laterolog data of A well from *930m through *230m
0 Gr/API 150
0 SP/mv 100
2 Rlld/ohm.m 20
2 Rlls/ohm.m 20
Dept
h(m)
#*28 layer
Pf=1%
Dip Angle
=85 degree
#*51 layer
Pf=1%
Dip Angle
=85 degree
#*55 layer
Pf=1%Dip Angle
=80 degree
*930
*940
*160
*220
*230