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International Journal of Scientific Research and Engineering Development-– Volume 3 Issues 2 Mar- Apr 2020
Available at www.ijsred.com
ISSN : 2581-7175 ©IJSRED:All Rights are Reserved Page 1
Lithofacies and Petrophysical Properties
Interpretation of Reservoir Rocks: A Case Study of
Shaka field, Onshore Niger Delta. Joshua O. Mene*, Kingsley O. Okengwu* and Eric U. Eche**
*Department of Geology, University of Port Harcourt, Choba Rivers State, P.M.B. 5323, Nigeria. **Center for Petroleum Geoscience, University of Port Harcourt, Choba Rivers State, P.M.B. 5323, Nigeria.
Correspondence email: [email protected]
Abstract:
This research covers lithofacies and petrophysical interpretation of reservoir rocks using well logs and core data from Well SHA-001 to
understand the reservoir quality with respect to their depositional environments. Analysis was carried out on core sample of 84.3 feet
from a depth range of 7176 ft – 7260.3 ft in well SHA-001 to identify and interpret lithofacies depositional environments. Six (6)
Lithofacies were identified; these were Planar/Parallel laminated Sandstone, Cross-bedded coarse gravely Sandstone, Cross-bedded
medium to fine grain Sandstone, Wavy-rippled Sandy-Heteroliths, Wavy-rippled Muddy-Heteroliths and Parallel-laminated mudstone.
Bioturbations in core ranges from barren to rare with observable Ophiomorpha, Skolithos and Planolites ichnofossils which depicts
mainly costal depositional settings. Three (3) Lithofacies associations were identified; these were Coastal Plain Heterolithics, Tidal
Channel Sandstones and Fluvial Channel Sandstones. Petrophysical analysis was carried out on identified lithofacies in Well SHA-001.
From petrophysical results, Lithofacies deposited with in the Fluvial Channels and Tidal Channels depositional environments (SmX,
SP, and ScX) exhibited good to excellent reservoir qualities, these includes good to excellent effective porosity (0.15 – 0.34), permeability
(877.6mD – 3353.7mD), hydrocarbon saturation (0.62 – 0.77) and poor water saturation (0.22 – 0.37). While lithofacies deposited within
the Coastal Plains depositional environment (HsW, HmW and MP) exhibited very poor to average reservoir qualities regardless
exhibiting average to excellent hydrocarbon saturation (0.54 – 0.70) as they exhibited very poor effective porosity (0.21 – <0.0) and
permeability (310.6mD – 1452.6mD) which are very important factors of reservoir quality. This research has therefore explained how
the depositional environment affects reservoir qualities, hence a fundamental component to consider during the exploration and
production of hydrocarbon.
Keywords- Lithofacies, Petrophysical Interpretation, Reservoir Rocks, Depositional Environments.
I. INTRODUCTION
A reservoir is simply a geologic subsurface feature by nature of
its porosity, permeability and thickness (both lateral and vertical) can
accumulate and transmit a commercial volume of hydrocarbon
provided all entrapment conditions are in place. Being a subsurface
geologic feature, one cannot simply understand its sedimentological
characteristics such as lithofacies (composition and textures),
biofacies (flora and fauna composition) and ichno facies (biogenic
sedimentary structures) as well as its intrinsic characteristics such as
porosity, permeability, net-gross, geometry, trapping styles, shapes or
lateral continuity at the surface level only (outcrops and exposures).
One must apply several standard techniques as well as procedures in
understanding these characteristics at subsurface level in other to
accurately interpret their various depositional environments, knowing
fully well that every depositional environment has its own unique
petroleum play significance which influences the exploration and
production of hydrocarbon.
Lithofacies identification and interpretation helps in
understanding the sedimentological characteristics of a reservoir rock
such as grain sizes, shapes, degree of sorting, colours, textures,
sedimentary structures (physical, chemical and biological structures),
etc. This will enable proper interpretation of reservoir rocks as well as
in the determination of their depositional environments [1]. These
attributes from lithofacies could also be well utilized when carrying
out petrophysical analysis on reservoir rocks, this will aid proper
interpretation of reservoir rocks intrinsic properties such as porosity
(Φ), permeability (K), net to gross (NTG), water saturation (Sw),
hydrocarbon saturation (S-Hc) etc [2]. This will also enable proper
RESEARCH ARTICLE OPEN ACCESS
International Journal of Scientific Research and Engineering Development-– Volume 3 Issues 2 Mar- Apr 2020
Available at www.ijsred.com
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analysis during hydrocarbon volumetric calculations as well as in the
production of hydrocarbon. Lithofacies and petrophysical
interpretation of reservoir rocks therefore tends to be key players
during exploration and production of hydrocarbon. This research is
centered on the lithofacies and the petrophysical properties of
reservoir rocks from well logs and core data obtained from SHA-001
well of Shaka field, Costal Swamp Depobelt, onshore eastern Niger
Delta, Nigeria.
The Study Area (Shaka Field) is located within the Central
Swamp Depobelt of Miocene age in the Niger Delta Basin, consisting
of four (4) wells designated SHA-001, SHA-002, SHA-003 and SHA-
004 which cover an area of about 10,863.02 km2 with wells having a
distance of about 0.61km, 1.27km and 4.49km apart from each other
respectively (See Fig. 1). This research is centered mainly on Well
SHA-001 being the only cored section. References [3], [4] have all
carried detailed research and publications on the Niger Delta
sedimentary basin as regards to its geology, tectonic history and
evolution. The Niger Delta is located within the Gulf of Guinea,
Equatorial West Africa at the southern end of Nigeria bordering the
Atlantic Ocean between latitude 4o and 6o N and longitude 3o and 9o
E and extends throughout the Niger Delta province [3]. Reference [4]
suggested an area of about 75,000km2 and has an average sediment
thickness of about 12,000m. The Niger Delta sedimentary basin was
formed at the site of a rift triple junction related to the opening of the
Southern Atlantic starting in the Late Jurassic and continuing into the
Cretaceous [5]. It properly began to develop during the Eocene epoch,
accumulating sediments that now are over 10 kilometers thick,
depositing first the marine shales of the Akata formation, followed by
the intercalation of sands and shales of the Agbada formation before
the deposition of the continental sands of the Benin formation [5] (See
Fig. 2).
Fig. 1: Base Map of the Study Area
Fig. 2: Stratigraphic column showing the three formations of the Niger Delta
Basin [3].
II. MATERIALS AND METHODS
A. Samples and sampling
The data set for this research was provided by Shell Petroleum
Development Company (SPDC) under the approval from the
Department of Petroleum Resources (DPR), Nigeria. The materials
used for this research were Well logs data which included; Gamma
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Ray logs, SP logs, Gamma Ray Index logs, Resistivity logs, Density
logs and Petrophysical logs (Total Porosity logs, Effective Porosity
logs, Water Saturation logs, Hydrocarbon Saturation logs,
Permeability logs). Core data set was also utilized for this research.
B. Core Description
Core description entails a close observation and interpretation of
the sedimentological properties of the cores to understand the
lithology, texture, sedimentary structures, macroscopic digenetic
features, etc. This would enable sedimentologist to identify unique
facies, group facies that are genetically related into facies associations
as well as understanding the continuous lateral / vertical changes in
facies attributes (facies succession). From these analysis and
descriptions, the depositional environments of cored sections as well
as the whole reservoir sands within that zone could be reconstructed.
Detailed core description was carried out on 84.3 feet of 1/3rd slabbed
core photos provided from well SHA-001 at depth range from 7176 ft
– 7260.3 ft. Core description was carried out using the standard SPDC
reservoir lithofacies and genetic unit scheme as published in [6] (See
Table 1) to organize lithofacies into lithofacies associations for
accurate interpretation and reconstruction of the depositional
environments of reservoir sand.
Table 1: SPDC Recognized Lithofacies and Genetic Units Scheme [6].
Lithology Dominant
Grain Size
Dominant
Sedimentary
Structure
Secondary
Sed.
Structure
Lithofacies
Codes/
Examples
> 90%
Sand
50 - 90%
Sand
50 - 90%
mud
(10 - 50%
sand)
Sandstone (S)
c-Coarse
m- Medium
f- Fine
Sandy
Heterolith
(Hs)
Massive (M)
Cross bedded
(X)
Planar, Parallel
bedded (P)
Hummocky,
Shaley cross
bedded (H)
Wave rippled
(W)
Current rippled
(C)
Bioturbated (B)
Rooted (R)
Fossiliferous
(F)
Organic-
Carbonaceous
(O)
Cement-
general
(c)
Siderite
(s)
Deformed
(d)
ScM
ScX
SmP
SmH
SfW
SC
SmB
SR
SF(c)
HsH
HsC
HsW
HmC
HmW
HmB
> 90 %
Mud
(< 10
Sand)
Mudstone (M) MPs, MP,
MF, MO
C. Concept of Facies
Facies can simply be defined as the sum characteristics of a
sedimentary unit whose physical, chemical and biological attributes
are distinct from adjacent neighboring sedimentary units [1]. The
physical sedimentary attributes such as texture (grains sizes and
shapes), physical sedimentary structures (cross bedding, lamination,
etc.) as well as the chemical sedimentary attributes such as colour,
chemical sedimentary structures (stylolites, etc.) of a sedimentary unit
make up a lithofacies unit. Also, the biological characteristics of a
sedimentary unit such as fauna and flora distributions make up a
biofacies unit while the imprints of biological activities such as
burrows, tracks, etc. make up an inchofacies unit.
These attributes enable a total description of sedimentary rocks,
depending on the area of concentration for rock descriptions (litho,
bio or ichno). However, the combination of all these characteristics
makes up sedimentary facies.
D. Facies Analysis, Facies Association and Facies
Succession
Facies analysis involves a detailed review of all sedimentological
attributes of reservoirs in order to interpret and reconstruct the manner
in which these reservoirs materials or components were transported
and deposited, hence helping in reconstruction the depositional
environment [1]. The concept of facies comes in play during facies
analysis in identifying and analyzing physical, chemical and
biological attributes of a sedimentary unit which will facilitate an
accurate interpretation and reconstruction of the sedimentary
depositional environment. It is worth mentioning that facies analysis
covers a wide range of sedimentary scale down to the smallest
laminae of a sedimentary unit, as the smallest unit of a sedimentary
laminae should possess all attribute necessary for facies analysis.
After the sedimentary attribute of a stratum has been identified, strata
with similar facies attributes that are genetically related with a
significant depositional environment can be group as beds and bedsets
[1]; likewise, beds and bedsets with similar facies attributes that are
genetically related with also a significant depositional environment
can be grouped as formations [1]. This is known as facies association
and it is utilised in interpreting and reconstructing the depositional
environments of reservoirs during facies analysis. Facies analysis also
monitors a significant trend (changes) either laterally or vertically in
facies attributes; this is known as facies succession and it is also used
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in the interpretation and reconstruction of reservoirs depositional
environments.
E. Petrophysical Evaluation of Reserviors
Petrophysical evaluation is basically the study of the physical
properties of the rocks such as grain sizes, shapes, framework that
influence reservoir attributes such as porosity, permeability, fluid
saturation, etc. It is worth mentioning that the petrophysical attributes
of reservoir sands are highly influenced by the sedimentological
attributes that is dominant in the environment of deposition. This
implies that, as the sedimentological attributes of reservoir sands
change across wells (reservoir heterogeneity), the petrophysical
attributes also change in the same manner. The identified lithofacies
in cored descriptions was integrated into the petrophysical attributes
within the core section (appendix table A1-A3) to understand how the
sedimentological attributes of these reservoirs affect its petrophysics
and reservoir quality which is associated with the depositional
environments of the reservoirs.
Some of the derivatives of these petrophysical attributes include;
1. Gamma ray index (IGR)
Equation after [7], Where;
IGR = Gamma ray index that describes a linear response to shale
content
GRlog = Log reading at depth interest
GRmin = Gamma ray value in a nearby clean sand zone
GRmax = Gamma ray value in a nearby shale.
2. Volume Shale (VSH)
Equation after [8] of non-linear relationship for Tertiary rocks, where;
VSH = Volume of shale
IGR = Gamma ray index that describes a linear response to shale
content
3. Total Porosity (POROT)
Where; ØT = Total porosity, ρma = Matrix density = 2.65, ρbulk = Bulk
density,
ρfl = Fluid density (0.74 for gas, 0.9 for oil and 1.0 for water)
4. Effective Porosity (POROE)
e =
Where; Øe = Effective porosity, Øtsh = Total shale porosity, ØT =
Total porosity,
VSH = Volume of shale
5. Water Saturation (Sw)
Equation after [9] empirical model,
Where; Sw = Water saturation, Ro = Resistivity of the oil leg, Rt =
True resistivity reading
6. Hydrocarbon Saturation (SH)
Where; SH = Hydrocarbon saturation, Sw = Water
saturation
7. Permeability (K)
Equation after [10]
where; K(mD) = Permeability in milliDarcy, Øe = Effective
porosity, Sw = Water saturation
III. RESULTS AND DISCUSSIONS
A. Cored Depth Range
Detailed core descriptions were carried out on 84.3 feet of 1/3rd
slabbed core provided from well SHA-001 at depth range from 7176
ft – 7260.3 ft which covers parts of reservoir C (See Fig. 3). Core
description was achieved using the standard SPDC reservoir
lithofacies and genetic unit scheme [6].
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Fig. 3: Cored Sections Parts of Reservoir C
B. Depth Shift
Depth shift was carried out on cored section along with wireline
logs to correct the difference between driller’s depths to which the
core was referenced from and that of the logger’s depths to which the
wireline was referenced from. The difference between these depths
creates a depth shift which might be positive or negative, increasing
the accuracy of cores when compared along with gamma ray log for
this research. Table 2 further shows the depth shift conversion
between cores and wireline logs.
Table 2: Depth Shift Correction of Core Depth with Wireline Log Depth
S/N
DEPTH (ft)
SHIFT
(ft) CORE WIRELINE
1 7176.00 – 7183.00 7178.35 – 7185.35 +2.35
2 7183.40 – 7184.30 7183.48 – 7184.38 +0.08
3 7191.00 – 7194.00 7191.97 – 7194.97 +0.97
4 7203.00 – 7206.00 7205.00 – 7208.00 +2.00
5 7209.00 – 7212.00 7211.08 – 7214.08 +2.08
6 7212.00 – 7213.00 7213.01 – 7214.01 +1.01
7 7221.00 – 7224.00 7222.10 – 7225.10 +1.10
8 7227.00 – 7230.00 7228.03 – 7231.03 +1.03
9 7230.20 – 7230.80 7230.64 – 7231.24 +0.44
10 7247.80 – 7253.80 7247.89 – 7253.89 +0.09
11 7259.15 – 7259.45 7259.16 – 7259.46 +0.01
12 7259.45 – 7260.00 7259.48 – 7260.03 +0.03
C. Lithofacies Identification
Six (6) lithofacies were identified from inspection and
description of the cored section using the standard SPDC reservoir
lithofacies and genetic unit scheme [6]. The identified lithofacies
were;
1. Planar/Parallel laminated sandstone, SP
2. Cross-bedded coarse-gravely sandstone, ScX
3. Cross-bedded medium to fine sandstone, SmX
4. Wavy-rippled sandy heteroliths, HsW
5. Wavy-rippled muddy heteroliths, HmW
6. Parallel-laminated mudstone, MP
Table 3 further summarizes the characteristics of identified lithofacies
as well as their percentage distribution. The percentage distribution of
identified lithofacies was obtained from the percentage ratio between
the lengths of individual lithofacies to the length of the whole cored
section. Fig. 4 shows a graphical percentage distribution of identified
lithofacies within the cored section.
Table 3: Lithofacies Distributions of Cores [6]
Lithology Lithofacies SPDC
Code
%
Distribution
Length
(ft)
Sandstone Planar/Parallel
laminated
sandstone
SP 10.6 8.9
Cross-bedded
coarse-gravely
grained
sandstone
ScX 14.2 12
Cross-bedded
medium to fine
grained
sandstone
SmX 55 46.4
Heteroliths Wavy-rippled
sandy
heteroliths
HsW 19 16
Wavy-rippled
muddy
heteroliths
HmW 0.4 0.3
Mudstone Parallel-
laminated
mudstone
MP 0.8 0.7
Total 100 84.3
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Fig. 4: Graphical Interpretation of Percentage Distribution of Lithofacies of
Cores [6]
D. Lithofacies Descriptions and Interpretations
Identified lithofacies of cores were described and interpreted also
using the standard SPDC reservoir lithofacies and genetic unit scheme
[6], noting observable sedimentological characteristics such as grain
sizes, grain shapes, physical sedimentary structures and biological
sedimentary structures. Lithofacies descriptions were as follows;
1) Sandstones
i. Planar/Parallel Laminated Sandstone (SP)
This lithofacies consists of about 10.6% (8.9ft in length) of the
cored section in well SHA-001 (See Plate 1). The lithofacies is
moderately to well-sorted, medium to fine-grained sandstones, with a
dominance of fine grains. Colours identified within this lithofacies
ranges from light brown - grey with good oil stains. Sedimentary
structures were unidirectional, low angle, planar to parallel-laminated
strata bases. The internal laminae were of mm-cm thickness and
displayed weak grading. Bioturbation intensity ranges from absent to
moderate with observable signatures of Ophiomorpha and Skolithos.
The observed moderately to well sorted sandstones, with sparsely
distributed marginal marine ichnofauna assemblages showed how
these sediments were possibly deposited and reworked by the
influence of waves/tidal processes in an intermediate to high energy
flow regime within the shallow marine depositional environment. The
wave/tidal influence constantly erodes and re-deposits these sediments
at different energy intervals causing the development of low angle
planar to parallel laminated surfaces (See Plate 1). The activities in
these flow regimes also discourages the visualization of ancient
biological activities as observed by the sparsely distributed
ichnofacies signatures of Ophiomorpha and Skolithos that depicts
coastal depositional settings. This lithofacies exhibits similar
characteristics with facies deposits of the tidal channels within the
coastal depositional environment settings.
Plate 1: Planar/Parallel Laminated Sandstone (SP)
ii. Cross-bedded Coarse-Gravely Grained Sandstone (ScX)
This lithofacies consists of about 14.2% (12ft in length) of the
cored section in well SHA-001 (See Plates 2 and 3). The lithofacies is
poorly sorted, fine to very coarse-grained but predominantly coarse-
grained sandstone. Colours ranges from grey to brownish-red with
good oil stains. Sedimentary structures were massive to low-angled
cross stratifications with fine-grained to very fine-grained lamina and
sharp basal contacts between bed sets. The identified pebbles and
granules commonly form lags or are aligned on the foresets but may
also be dispersed throughout the lithofacies. Bioturbation intensity
ranges from absent to moderate with observable signatures of
Ophiomorpha and Skolithos.
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The poorly sorted, cross-bedded coarse-grained sands with sharp
erosive bases often reflects a high energy flow regime characteristic of
a fluvial depositional system. The observed coarse-gravely size clasts
were transported mostly by saltation / rolling along the channel and
were gradually deposited discretely to form quartz / gravel lags as the
energy of the flow reduces, the finer sediments were also gradually
deposited as the flow energy continues to reduce along the channel
(See Plates 2 and 3). The sediments in this lithofacies continues to
deposit in this manner forming massive to low angle cross
stratifications in a downstream direction which is diagnostic of a
fluvial system [1]. The constrained marginal marine ichnofauna
assemblages observed were indicative of a coastal environmental
setting. This lithofacies is said to exhibits similar characteristics with
sands deposits of the fluvial-dominated estuarine channel.
Plate 2: Cross-bedded Coarse-Gravely Sandstone (ScX)
Plate 3: Cross-bedded Coarse-Gravely Sandstone (ScX)
iii. Cross-bedded Medium-fine Sandstones (SmX)
This lithofacies consists of about 55% (46.4ft in length) of the
cored section in well SHA-001 (See Plates 4 and 5). This lithofacies is
moderately to well sorted, fine to medium-grained but predominantly
medium-grained sandstones. Colours ranges light to moderate
yellowish-brown to grey with good oil stains. Sedimentary structures
were unidirectional, horizontal to low angled inclined cross-
stratifications bounded by sharp erosional surfaces with argillaceous
laminae /coal bands abundance. The coarse-grained sands / granules
occurred occasionally either as sparsely disseminated to locally
concentrated. There were also mud pebbles/rip mud clast distributed
discretely within the lithofacies. Bioturbation intensity ranged from
barren to low with observable signatures Ophiomorpha, and
Diplocraterion burrows.
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Plate 4: Cross-bedded Medium-fine Sandstones (SmX)
Plate 5: Cross-bedded Medium-fine Sandstones (SmX)
2) Heteroliths
i. Wavy-rippled Sandy Heteroliths (HsW)
This lithofacies consists of about 19% (16ft in length) of the
cored section in well SHA-001 (See Plates 6 and 7). The lithofacies is
a heterolithic mixture of sands, silts and muds but predominantly
sands. The Sands were very well sorted, very fine to fine grained but
predominantly very fine grained that were rounded to sub-rounded.
Colours ranges from light to medium yellowish brown to grey.
Sedimentary structures were wavy rippled to sub-parallel laminated
fine-grained sandstones interbedded with wavy shale laminations and
sharp erosive bases between individual laminae. Bioturbation is
generally rare with recognisable traces of Planolites and
Ophiomorpha ichnofossils.
The restricted marginal marine ichnofaunal assemblages and
heterolithic texture of this facies indicates deposition in a low energy,
shallow marine setting which is categorized by alternating suspension
and bedload sediments. The sedimentary structures on this lithofacies
were due to the constant erosion and re-deposition of the sediments by
low waves energy. Marine sediments were possible carried by these
low wave energies, deposited on the previous sediments that were
equally reworked at the same time as the wave energy attenuates. This
lithofacies exhibits similar characteristics with sediments deposits of
the estuarine channel margins or bays depositional environments.
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Plate 6: Wavy-rippled Sandy Heteroliths (HsW)
Plate 7: Wavy-rippled Sandy Heteroliths (HsW)
ii. Wavy-rippled Muddy Heteroliths (HmW)
This lithofacies consists of about 0.4% (0.3ft in length) of the
cored section in well SHA-001 (See plate 8). The lithofacies is a
heterolithic mixture of sands and muds but predominately muddy
sediments. Colours ranges from light to medium dark grey.
Sedimentary structures were traces of small scaled wavy, current
rippled, planar laminations with traces of organic debris and tiny
discrete shell fragments. Bioturbation is generally rare with
recognisable traces of Planolites and Ophiomorpha ichnofossils.
The restricted marginal marine ichnofaunal assemblages and
heterolithic texture of this facies indicates deposition in a low energy,
shallow marine setting which is categorized by alternating suspension
and bedload sediments, but predominantly suspension sediments. The
deposition of this lithofacies is similar with that of the Wavy-rippled
Sandy Heteroliths (HsW) in Plates 6 and 7. The difference could be
accounted by the flow energy regime of the transporting medium, this
lithofacies was deposited in a lower energy that allowed very fine
grain sediments to coagulates and deposit as mudstone within the
lithofacies (See Plate 8). This lithofacies exhibits similar
characteristics with sediments deposits of the estuarine channel
margins depositional environments.
Plate 8: Wavy-rippled Muddy Heteroliths (HmW)
3) Mudstone
i. Parallel Laminated Mudstone (MP)
This lithofacies consists of about 0.8% (0.7ft in length) of the
cored section in well SHA-001 (plate 9). The lithofacies consists of
shales with bands of silty sand lamina with varaible thickness.
Colours ranges from light brown, medium to dark grey. Sedimentary
sturctures were parallel to sub-parallel laminated with very fine
sandstones/siltstones that were planar laminated. Traces organic
debris were obsereved in the mudstone. Bioturbation intensity ranged
from rare to absent with discrete small scale borrows.
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The fine-grained textures were indicative of sediments deposited
under low hydraulic energy conditions mostly by suspensions. The
presence of silty sands lamina were indicative of a more energetic
storm wave deposits than that which initially deposited the muds. The
restricted marginal marine ichnofaunal assemblages suggested a
reduction in the amounts of oxygen associated with organic material
in a quiet water setting. This lithofacies exhibits similar characteristics
with sediments deposits of the coastal depositional settings in
particular the lagoon depositional environments.
Plate 9: Parallel Laminated Mudstone (MP)
E. Lithofacies Associations
Lithofacies associations are groups of genetically related
lithofacies having the same depositional environment significances
[1]. Lithofacies associations were carefully recognized using the
standard SPDC reservoir lithofacies and genetic unit scheme [6]. The
complete details of lithofacies association were displayed in appendix
A1 and A2, the recognized lithofacies associations were as follows;
1) Tidal Channel Sandstones
Lithofacies grouped under this association were the Cross-
bedded medium to fine grain sandstone (SmX) and the Planar/Parallel
laminated sandstone (SP) (See Fig. 5 and 6). This was categorized by
moderately to very well sorted medium to fine-grained sandstones that
exhibits an observable unidirectional horizontal to low angle cross-
stratifications as well as planar to parallel-laminations bounded by
subtle to sharp erosional surfaces. Evidence of tidal influence are
observed from the presence of argillaceous lamina / coal lamina of
mm-cm thickness as well as mud pebbles/rip mud clast at several
intervals within the lithofacies. Bioturbations level of occurrence was
from rare to moderate whose ichnofacies assemblages consists mainly
of Skolithos, Ophiomorpha with rare traces of Diplocraterion which
indicates the littorals zones along the sandy shorelines that are tidally
influenced.
Figure 5: Lithofacies Log Description of the Tidal Channel Sands – A
Figure 6: Lithofacies Log Description of the Tidal Channel Sands – B
2) Fluvial Channel Sandstones
Lithofacies grouped under this association were mainly Cross-
bedded coarse gravely sandstone (ScX) and Cross-bedded medium
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sandstone (SmX) (See Figure 7 and 8). This is categorized by poorly
sorted fine to predominantly very coarse-grained sandstones that
exhibits observable unidirectional massive to low-angled cross
stratifications with fine-grained to very fine-grained lamina of which
observed pebbles and granules form lags, or are aligned on the
foresets but may also be dispersed throughout the lithofacies with
sharp basal contact between bedsets. These are evidence of fluvial
influence in which sands deposition was in sinuous to straight crested
dunes migrated by high energy fluvial currents. Regardless of these
fluvial influences, observable traces of marginal marine depositional
settings are exhibited as indicated by the observed barren to low
bioturbation levels often cause by Ophiomorpha borrows which
indicates deposits closeness to the coastal depositional settings,
comparable depositional environments are of the fluvial-dominated
estuarine channels.
Figure 7: Lithofacies Log Description of the Fluvial Channel Sands – A
Figure 8: Lithofacies Log Description of the Fluvial Channel Sands – B
3) Coastal Plain Heteroliths
Lithofacies grouped under this association were mainly Wavy-
rippled sandy heteroliths (HsW), Wavy-rippled muddy heteroliths,
(HmW) and Parallel-laminated mudstone (MP) (See Fig. 9). This is
categorized by a heterolithic mixture of sands, silts and muds. Sands
and silts are very well sorted, very fine to fine grained that exhibits
wavy rippled to sub-parallel laminations with wavy shale laminations
with sharp erosive bases between lamina. Shales are moderately fissil
and parallel to sub-parallel laminated with very fine
sandstones/siltstones that are planar laminated. Observable organic
debries and well as tiny discrete shell fragments are exhibited on the
shales which is an indicator of an energy low and oxygen depleted
environment. Bioturbation occurrence is rare to absent with
observable ichnofossils assemblages consisting mainly of Planolites,
Skolithos and Ophiomorpha borrows which indicates the littoral to
sub-littoral zones along the sandy shorelines to the shoreface
depositional settings. Generally, this unit is erosively overlain by
channelized sandstones of the tidal channel depositional settings
(lithofacies succession). Table 4 generally shows a summary of
interpreted depositional environments of cored section from
interpreted lithofacies associations.
Figure 9: Lithofacies Log Description of the Coastal Plain Heterolithics
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F. Petrophysical Interpretation of Lithofacies
From the effective porosity-permeability graph shown in figure
10, it was observed that lithofacies of the Cross-bedded Coarse
Gravely Sandstone (ScX) showed permeability range values from
3353.7mD – 3017.5mD and effective porosity range values from 0.34
– 0.32, this is an indicative of excellent permeability and effective
porosity attributes. The lithofacies of both Cross-bedded Medium to
Fine Sandstone (SmX) and Planar/Parallel Laminated Sandstone (SP)
showed permeability range values from 2318.5mD – 877.6mD and
effective porosity range values from 0.28 – 0.15, this is an indicative
of good to moderate permeability and effective porosity attributes.
Lithofacies of the Wavy-rippled Sandy Heteroliths (HsW) showed
permeability range values from 1452.6mD – 371.5mD and effective
porosity range values from 0.21 – 0.05, this is an indicative of
moderate to poor permeability and effective porosity attributes. The
lithofacies of both Wavy-rippled Muddy Heteroliths (HmW) and
Parallel-laminated Mudstone (MP) showed permeability range values
from 312.7mD – 310.6mD and effective porosity range values from
<0.0, this is an indicative of very poor permeability and effective
porosity attributes.
Table 4: Summary of Interpreted Depositional Environments of Cored Section
Cored Depth (ft) Depositional
Environments
Lithofacies
7176.0 – 7183.5 Tidal Channel
Sandstones
SP and SmX
7183.5 – 7192.4 Fluvial Channel
Sandstone
SmX, ScX
and HsW
7192.4 – 7215.6 Tidal Channel
Sandstones
SmX, ScX
and HsW
7215.6 – 7230.0 Fluvial Channel
Sandstones
ScX and SmX
7230.0 – 7247.2 Tidal Channel
Sandstones
SmX, ScX
and HsW
7247.2 – 7260.3 Coastal Plain
Heterolithics
HsW, MP and
HmW
Figure 10: The Relationship Between Effective Porosity and Permeability as a
Function of the Reservoir Qualities of Identified Lithofacies.
From the hydrocarbon saturation-permeability graph shown in
figure 11, it was observed that lithofacies of the Cross-bedded Coarse
Gravely Sandstone (ScX) showed hydrocarbon saturation (Sat.HC)
range values from 0.77 – 0.74 (77% - 74%), this is an indicative of
excellent hydrocarbon saturation attributes. The lithofacies of both
Cross-bedded Medium to Fine Sandstone (SmX) and Planar/Parallel
Laminated Sandstones (SP) showed hydrocarbon saturation (Sat.HC)
range values from 0.72 – 0.62 (72% - 62%), this is an indicative of
good to excellent hydrocarbon saturation attributes. The lithofacies of
Wavy-rippled Sandy Heteroliths (HsW) showed hydrocarbon
saturation (Sat.HC) range values from 0.70 – 0.58 (70% - 58%), this is
also an indicative of average to excellent hydrocarbon saturation
attributes. While lithofacies of Wavy-rippled Muddy Heteroliths
(HmW) and Parallel-laminated Mudstone (MP) showed hydrocarbon
saturation (Sat.HC) range value ranges from 0.56 – 0.54 (56% - 54%),
this is indicative of average hydrocarbon saturation attributes.
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Figure 11: The Relationship Between Hydrocarbon Saturation and
Permeability as a Function of the Reservoir Qualities of Identified Lithofacies.
From the water saturation-permeability graph shown in figure 12,
it was observed generally that lithofacies of the Cross-bedded Coarse
Gravely Sandstone (ScX), Cross-bedded Medium to Fine Sandstone
(SmX) and Planar/Parallel Laminated Sandstones (SP) showed water
saturation (Sw) range values from 0.22 – 0.37 (22% - 37%) while the
lithofacies of Wavy-rippled Sandy Heteroliths (HsW), Wavy-rippled
Muddy Heteroliths (HmW) and Parallel-laminated Mudstone (MP)
showed water saturation (Sw) range values from 0.30 – 0.46 (30% -
46%).
Figure 12: The Relationship Between Water Saturation and Permeability as a
Function of the Reservoir Qualities of Identified Lithofacies.
From the above petrophysical results of lithofacies, it was
observed that lithofacies deposited with in the Fluvial Channels and
Tidal Channels depositional environments (SmX, SP, and ScX)
exhibited good to excellent reservoir qualities, these includes good to
excellent effective porosity, permeability, hydrocarbon saturation and
poor water saturation. While lithofacies deposited within the Coastal
Plains depositional environment (HsW, HmW and MP) exhibited very
poor to average reservoir qualities although they exhibited average to
excellent hydrocarbon saturation. This was due to the fact that they
exhibited very poor effective porosity and permeability which are
very important factors of reservoir quality during the exploration and
production of hydrocarbon.
IV. CONCLUSION
After a total review of the identified lithofacies attributes, it was
therefore concluded that lithofacies within this reservoir were
deposited in a coastal depositional setting that was evidently incised
by estuarine channels of both fluvial and tidal backgrounds and
possibly adjacent to a swamp land paleo-environment. The
petrophysical attributes of identified lithofacies within this reservoir
has facilitated the differentiation of highly productive zones from the
less productive zones (reservoir compartmentalization). The highly
productive zones within this reservoir were lithofacies that were
deposited within the Tidal and Fluvial Channels depositional
environment as they exhibited good to excellent reservoir quality
while the less productive zones within this reservoir were lithofacies
that were deposited within the Coastal Plains depositional
environment as they exhibited very poor to average reservoir quality.
This was compared with other fields studies within the Niger Delta
such as the D2 Sands of Greater Ughelli Depobelt [2] whose high
productive zones were in the Upper Shoreface and Channel
depositional environments, and least productive zones in the Tidal
flats and Lower Shoreface. Other reservoir studies within the Niger
Delta such as that of [11], [12] was also compared with results gotten
from the study area. This research has therefore explained how the
depositional environment affects reservoir qualities, hence a
fundamental component to consider during the exploration and
production of hydrocarbon.
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ACKNOWLEDGMENTS
The authors hereby acknowledge the assistance of Shell
Petroleum Development Company (SPDC) through the Department of
Petroleum Resources (DPR) for the provision of available dataset for
this work. Also, the Department of Geology, University of Port
Harcourt for the provision of workstations and laboratory for this
research.
REFERENCES
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Niger Delta, Nigeria”. American Journal of
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556-566, 2015.
[3] H. Doust and E. Omatsola. Niger Delta, in J. D.
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[4] T. J. A. Reijers. “Stratigraphy and sedimentology of
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[5] L. W. Michele, R. R. Charpentier and M. E.
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[6] A. H. Davies, L. S. D. Onuigbo, H. M. A. Cruts, C.
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[8] V. Larionov. Borehole Radiometry. Moscow, USSR,
Nedra, 1969.
[9] G.E. Archie. "Classification of carbonate reservoir
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[10] O. O. Owolabi, T. F. Longjohn and J. A. Ajienka. “An
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unconsolidated sands of Eastern Niger Delta”; Journal
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[11] O. W. Osayande and K. O. Okengwu. “Lithofacies
Analysis and Depositional Environments of the Waz
Fields, Niger Delta, Nigeria”. The International
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[12] R. O. Oyanyan, C. G. Soronnadi-Ononiwu and A. O.
Omoboriowo. “Depositional environments of sam-bis
oil field reservoir sands”. Pelagia Research Library
Advances in Applied Science Research. Iss. 3, vol. 3,
pp:1624-1638, 2012.
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APPENDIX
Figure A1: Sedimentary Log and Description of Cored Section-A
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Figure A2: Sedimentary Log and Description of Cored Section-B
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Table A1: Petrophysical Attributes of Reservoir C in Well SHA-001 (Cored Section)
MD (Ft) Gamma
(API)
R
(ohm.m)
K (mD) RHOB
(g/cm3)
IGR
(gAPI)
VShale
(%)
Por.Tot.
(m3/m3)
Por.Eff.
(m3/m3)
Sw Sat.HC
7175 89.51 11.9766 400.753 2.32 0.88 0.7029 0.2 0.0594 0.40997 0.59
7175.5 82.64 14.2422 541.2903 2.3011 0.8 0.5558 0.2115 0.0939 0.38775 0.6123
7176 75.69 16.8281 733.0885 2.2801 0.71 0.435 0.2242 0.1267 0.36573 0.6343
7176.5 71.3 19.4219 877.5999 2.2656 0.66 0.3707 0.2329 0.1466 0.35201 0.648
7177 70.66 22.6562 900.0878 2.2635 0.65 0.362 0.2343 0.1495 0.35002 0.65
7177.5 73.77 25.8906 793.9816 2.2739 0.69 0.4059 0.228 0.1354 0.35973 0.6403
7178 74.41 23.2969 773.3079 2.276 0.7 0.4154 0.2267 0.1325 0.36173 0.6383
7178.5 73.77 18.4531 793.9816 2.2739 0.69 0.4059 0.228 0.1354 0.35973 0.6403
7179 73.77 15.5312 793.9816 2.2739 0.69 0.4059 0.228 0.1354 0.35973 0.6403
7179.5 75.05 11.6484 753.0113 2.278 0.71 0.4251 0.2254 0.1296 0.36373 0.6363
7180 75.05 9.0625 753.0113 2.278 0.71 0.4251 0.2254 0.1296 0.36373 0.6363
7180.5 71.94 7.7656 855.4827 2.2678 0.67 0.3795 0.2316 0.1437 0.354 0.646
7181 70.66 7.4453 900.0878 2.2635 0.65 0.362 0.2343 0.1495 0.35002 0.65
7181.5 65.63 9.7109 1090.449 2.2455 0.6 0.2994 0.2452 0.1718 0.33447 0.6655
7182 58.08 15.8594 1423.487 2.2154 0.51 0.2215 0.2634 0.2051 0.31131 0.6887
7182.5 50.53 46.9375 1825.414 2.1806 0.42 0.1595 0.2845 0.2391 0.28821 0.7118
7183 43.02 91.5625 2318.533 2.1395 0.33 0.1103 0.3094 0.2752 0.26505 0.735
7183.5 34.84 107.3125 3017.545 2.0843 0.23 0.068 0.3428 0.3195 0.23919 0.7608
7184 31.09 211.625 3423.072 2.0538 0.19 0.0518 0.3613 0.3426 0.22695 0.773
7184.5 32.32 234.125 3281.781 2.0643 0.2 0.057 0.3549 0.3347 0.23102 0.769
7185 36.08 239.5 2897.448 2.0936 0.25 0.0738 0.3372 0.3123 0.24316 0.7568
7185.5 37.99 249.25 2722.754 2.1072 0.27 0.0831 0.329 0.3016 0.24926 0.7507
7186 38.59 257.5 2670.73 2.1113 0.28 0.0861 0.3265 0.2984 0.25116 0.7488
7186.5 39.87 276 2563.512 2.1198 0.29 0.0928 0.3213 0.2915 0.25519 0.7448
7187 41.11 294.25 2464.207 2.1277 0.31 0.0995 0.3165 0.285 0.25907 0.7409
7187.5 42.39 288.75 2366.054 2.1357 0.32 0.1066 0.3117 0.2785 0.26306 0.7369
7188 44.9 273.5 2184.494 2.1505 0.35 0.1216 0.3027 0.2659 0.27087 0.7291
7188.5 46.78 278.5 2058.108 2.161 0.37 0.1335 0.2964 0.2568 0.27667 0.7233
7189 50.53 303 1825.414 2.1806 0.42 0.1595 0.2845 0.2391 0.28821 0.7118
7189.5 50.53 312 1825.414 2.1806 0.42 0.1595 0.2845 0.2391 0.28821 0.7118
7190 49.93 276 1860.902 2.1775 0.41 0.1551 0.2863 0.2419 0.28638 0.7136
7190.5 50.53 243.25 1825.414 2.1806 0.42 0.1595 0.2845 0.2391 0.28821 0.7118
7191 51.81 232.375 1751.64 2.1869 0.43 0.169 0.2807 0.2333 0.29213 0.7079
7191.5 54.33 223.875 1613.568 2.1987 0.46 0.1889 0.2735 0.2218 0.29983 0.7002
7192 56.2 219.125 1516.279 2.2072 0.48 0.2047 0.2683 0.2134 0.30557 0.6944
7192.5 57.48 220.75 1452.634 2.2128 0.5 0.216 0.265 0.2077 0.30948 0.6905
7193 56.2 219.125 1516.279 2.2072 0.48 0.2047 0.2683 0.2134 0.30557 0.6944
7193.5 53.69 208.75 1647.773 2.1958 0.46 0.1837 0.2753 0.2247 0.29788 0.7021
7194 50.53 202 1825.414 2.1806 0.42 0.1595 0.2845 0.2391 0.28821 0.7118
7194.5 48.66 202 1938.627 2.171 0.4 0.1461 0.2903 0.2479 0.28245 0.7175
7195 48.06 216.125 1976.051 2.1678 0.39 0.142 0.2922 0.2507 0.28061 0.7194
7195.5 48.06 208.75 1976.051 2.1678 0.39 0.142 0.2922 0.2507 0.28061 0.7194
7196 48.06 190.75 1976.051 2.1678 0.39 0.142 0.2922 0.2507 0.28061 0.7194
7196.5 49.93 163.5 1860.902 2.1775 0.41 0.1551 0.2863 0.2419 0.28638 0.7136
7197 52.45 149.25 1715.698 2.1899 0.44 0.1739 0.2788 0.2303 0.29409 0.7059
7197.5 52.45 142.375 1715.698 2.1899 0.44 0.1739 0.2788 0.2303 0.29409 0.7059
7198 50.53 141.75 1825.414 2.1806 0.42 0.1595 0.2845 0.2391 0.28821 0.7118
7198.5 48.66 139.875 1938.627 2.171 0.4 0.1461 0.2903 0.2479 0.28245 0.7175
7199 44.26 128.75 2229.228 2.1468 0.34 0.1177 0.305 0.2691 0.26889 0.7311
7199.5 41.11 114.4375 2464.207 2.1277 0.31 0.0995 0.3165 0.285 0.25907 0.7409
7200 37.99 113.625 2722.754 2.1072 0.27 0.0831 0.329 0.3016 0.24926 0.7507
7200.5 37.99 112.75 2722.754 2.1072 0.27 0.0831 0.329 0.3016 0.24926 0.7507
7201 39.23 118.875 2616.499 2.1156 0.29 0.0894 0.3239 0.2949 0.25317 0.7468
7201.5 41.75 123.125 2414.599 2.1317 0.31 0.103 0.3141 0.2817 0.26107 0.7389
7202 44.26 128.75 2229.228 2.1468 0.34 0.1177 0.305 0.2691 0.26889 0.7311
7202.5 44.9 134.375 2184.494 2.1505 0.35 0.1216 0.3027 0.2659 0.27087 0.7291
7203 46.14 133.25 2100.328 2.1575 0.37 0.1294 0.2985 0.2599 0.2747 0.7253
7203.5 46.14 131.5 2100.328 2.1575 0.37 0.1294 0.2985 0.2599 0.2747 0.7253
7204 46.14 144.375 2100.328 2.1575 0.37 0.1294 0.2985 0.2599 0.2747 0.7253
7204.5 46.14 161 2100.328 2.1575 0.37 0.1294 0.2985 0.2599 0.2747 0.7253
7205 46.14 186.125 2100.328 2.1575 0.37 0.1294 0.2985 0.2599 0.2747 0.7253
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Table A2: Petrophysical Attributes of Reservoir C in Well SHA-001 (Cored Section)
MD (Ft) Gamma
(API)
R
(ohm.m)
K (mD) RHOB
(g/cm3)
IGR
(gAPI)
VShale
(%)
Por.Tot.
(m3/m3)
Por.Eff.
(m3/m3)
Sw Sat.HC
7206 45.54 160.125 2140.65 2.1541 0.36 0.1256 0.3005 0.2628 0.27285 0.7271
7206.5 48.06 133.75 1976.051 2.1678 0.39 0.142 0.2922 0.2507 0.28061 0.7194
7207 52.45 107.6875 1715.698 2.1899 0.44 0.1739 0.2788 0.2303 0.29409 0.7059
7207.5 54.33 87.375 1613.568 2.1987 0.46 0.1889 0.2735 0.2218 0.29983 0.7002
7208 56.84 87.375 1484.203 2.21 0.49 0.2103 0.2666 0.2106 0.30753 0.6925
7208.5 60 32.0312 1333.053 2.2234 0.53 0.2396 0.2585 0.1966 0.31718 0.6828
7209 63.75 23.625 1167.687 2.2384 0.57 0.2783 0.2495 0.18 0.32869 0.6713
7209.5 66.9 15.5312 1039.837 2.2502 0.61 0.3144 0.2423 0.1661 0.33841 0.6616
7210 70.66 11.6484 900.0878 2.2635 0.65 0.362 0.2343 0.1495 0.35002 0.65
7210.5 72.57 9.7109 833.7409 2.2699 0.68 0.3885 0.2303 0.1408 0.35599 0.644
7211 73.21 9.3828 812.3726 2.272 0.68 0.3977 0.2291 0.138 0.35798 0.642
7211.5 71.94 7.4453 855.4827 2.2678 0.67 0.3795 0.2316 0.1437 0.354 0.646
7212 68.18 6.7969 990.7844 2.2548 0.63 0.33 0.2395 0.1605 0.34235 0.6576
7212.5 63.75 8.4141 1167.687 2.2384 0.57 0.2783 0.2495 0.18 0.32869 0.6713
7213 57.48 14.2422 1452.634 2.2128 0.5 0.216 0.265 0.2077 0.30948 0.6905
7213.5 53.69 25.8906 1647.773 2.1958 0.46 0.1837 0.2753 0.2247 0.29788 0.7021
7214 47.42 43.375 2016.693 2.1644 0.38 0.1377 0.2943 0.2538 0.27864 0.7214
7214.5 41.11 78 2464.207 2.1277 0.31 0.0995 0.3165 0.285 0.25907 0.7409
7215 34.84 95.5 3017.545 2.0843 0.23 0.068 0.3428 0.3195 0.23919 0.7608
7215.5 33.6 139.875 3143.976 2.0747 0.22 0.0625 0.3487 0.3269 0.23519 0.7648
7216 34.2 157.625 3081.969 2.0794 0.23 0.0651 0.3458 0.3233 0.23713 0.7629
7216.5 36.08 134.375 2897.448 2.0936 0.25 0.0738 0.3372 0.3123 0.24316 0.7568
7217 38.59 117.9375 2670.73 2.1113 0.28 0.0861 0.3265 0.2984 0.25116 0.7488
7217.5 41.75 76.6875 2414.599 2.1317 0.31 0.103 0.3141 0.2817 0.26107 0.7389
7218 46.14 52.75 2100.328 2.1575 0.37 0.1294 0.2985 0.2599 0.2747 0.7253
7218.5 51.17 34.3125 1788.206 2.1837 0.43 0.1642 0.2826 0.2362 0.29017 0.7098
7219 56.2 18.125 1516.279 2.2072 0.48 0.2047 0.2683 0.2134 0.30557 0.6944
7219.5 61.23 14.2422 1276.854 2.2285 0.54 0.2519 0.2555 0.1911 0.32097 0.679
7220 65.63 14.2422 1090.449 2.2455 0.6 0.2994 0.2452 0.1718 0.33447 0.6655
7220.5 68.18 16.5 990.7844 2.2548 0.63 0.33 0.2395 0.1605 0.34235 0.6576
7221 62.47 20.7188 1222.31 2.2334 0.56 0.2646 0.2525 0.1857 0.32477 0.6752
7221.5 56.84 24.5938 1484.203 2.21 0.49 0.2103 0.2666 0.2106 0.30753 0.6925
7222 53.69 29.4531 1647.773 2.1958 0.46 0.1837 0.2753 0.2247 0.29788 0.7021
7222.5 51.17 36.5625 1788.206 2.1837 0.43 0.1642 0.2826 0.2362 0.29017 0.7098
7223 48.66 32.0312 1938.627 2.171 0.4 0.1461 0.2903 0.2479 0.28245 0.7175
7223.5 49.29 26.2188 1899.413 2.1743 0.4 0.1506 0.2883 0.2449 0.28441 0.7156
7224 51.81 16.5 1751.64 2.1869 0.43 0.169 0.2807 0.2333 0.29213 0.7079
7224.5 54.96 13.2656 1579.925 2.2017 0.47 0.1942 0.2717 0.219 0.30179 0.6982
7225 58.08 15.8594 1423.487 2.2154 0.51 0.2215 0.2634 0.2051 0.31131 0.6887
7225.5 62.47 14.5625 1222.31 2.2334 0.56 0.2646 0.2525 0.1857 0.32477 0.6752
7226 66.27 11 1064.947 2.2478 0.6 0.3068 0.2437 0.169 0.33644 0.6636
7226.5 64.39 11.3281 1141 2.2408 0.58 0.2853 0.248 0.1772 0.33066 0.6693
7227 61.23 14.2422 1276.854 2.2285 0.54 0.2519 0.2555 0.1911 0.32097 0.679
7227.5 57.48 21.6875 1452.634 2.2128 0.5 0.216 0.265 0.2077 0.30948 0.6905
7228 49.93 35.9375 1860.902 2.1775 0.41 0.1551 0.2863 0.2419 0.28638 0.7136
7228.5 43.02 78.3125 2318.533 2.1395 0.33 0.1103 0.3094 0.2752 0.26505 0.735
7229 34.2 94.1875 3081.969 2.0794 0.23 0.0651 0.3458 0.3233 0.23713 0.7629
7229.5 32.32 111.9375 3281.781 2.0643 0.2 0.057 0.3549 0.3347 0.23102 0.769
7230 31.68 124.625 3353.709 2.059 0.2 0.0543 0.3582 0.3387 0.22893 0.7711
7230.5 31.09 94.5 3423.072 2.0538 0.19 0.0518 0.3613 0.3426 0.22695 0.773
7231 32.32 38.8438 3281.781 2.0643 0.2 0.057 0.3549 0.3347 0.23102 0.769
7231.5 35.48 23.9531 2954.806 2.0892 0.24 0.071 0.3399 0.3158 0.24124 0.7588
7232 38.59 16.1875 2670.73 2.1113 0.28 0.0861 0.3265 0.2984 0.25116 0.7488
7232.5 43.02 15.8594 2318.533 2.1395 0.33 0.1103 0.3094 0.2752 0.26505 0.735
7233 48.66 17.1562 1938.627 2.171 0.4 0.1461 0.2903 0.2479 0.28245 0.7175
7233.5 54.33 19.7344 1613.568 2.1987 0.46 0.1889 0.2735 0.2218 0.29983 0.7002
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MD (Ft) Gamma
(API)
R
(ohm.m)
K (mD) RHOB
(g/cm3)
IGR
(gAPI)
VShale
(%)
Por.Tot.
(m3/m3)
Por.Eff.
(m3/m3)
Sw Sat.HC
7234 53.69 23.9531 1647.773 2.1958 0.46 0.1837 0.2753 0.2247 0.29788 0.7021
7234.5 51.81 29.7812 1751.64 2.1869 0.43 0.169 0.2807 0.2333 0.29213 0.7079
7235 48.06 35.9375 1976.051 2.1678 0.39 0.142 0.2922 0.2507 0.28061 0.7194
7235.5 47.42 26.8594 2016.693 2.1644 0.38 0.1377 0.2943 0.2538 0.27864 0.7214
7236 49.29 20.7188 1899.413 2.1743 0.4 0.1506 0.2883 0.2449 0.28441 0.7156
7236.5 53.69 21.3594 1647.773 2.1958 0.46 0.1837 0.2753 0.2247 0.29788 0.7021
7237 60 17.4688 1333.053 2.2234 0.53 0.2396 0.2585 0.1966 0.31718 0.6828
7237.5 66.27 13.2656 1064.947 2.2478 0.6 0.3068 0.2437 0.169 0.33644 0.6636
7238 68.74 14.8906 969.8051 2.2568 0.63 0.337 0.2383 0.158 0.34408 0.6559
7238.5 75.69 15.2109 733.0885 2.2801 0.71 0.435 0.2242 0.1267 0.36573 0.6343
7239 82 10.6797 556.962 2.2992 0.79 0.5436 0.2126 0.097 0.38571 0.6143
7239.5 85.11 7.7656 484.5798 2.3081 0.82 0.6054 0.2072 0.0818 0.3957 0.6043
7240 88.87 6.4727 411.5251 2.3183 0.87 0.6879 0.201 0.0627 0.40788 0.5921
7240.5 98.29 5.8242 310.173 2.3419 0.98 0.9414 0.1867 0.0109 0.43921 0.5608
7241 105.88 5.8242 341.6443 2.3592 1.07 1.205 0.1762 -0.0361 0.46532 0.5347
7241.5 101.49 6.1484 308.7932 2.3494 1.02 1.0451 0.1822 -0.0082 0.4501 0.5499
7242 92.62 8.4141 355.7768 2.328 0.91 0.7804 0.1951 0.0429 0.42022 0.5798
7242.5 85.75 13.2656 471.0101 2.3098 0.83 0.6188 0.2062 0.0786 0.39776 0.6022
7243 80.72 18.7656 589.5322 2.2955 0.77 0.5199 0.2149 0.1032 0.38163 0.6184
7243.5 76.97 23.2969 694.373 2.2841 0.73 0.4554 0.2218 0.1208 0.36975 0.6303
7244 67.54 26.5312 1015.117 2.2525 0.62 0.3221 0.2409 0.1633 0.34038 0.6596
7244.5 61.87 29.125 1248.5 2.231 0.55 0.2584 0.2539 0.1883 0.32293 0.6771
7245 60 30.75 1333.053 2.2234 0.53 0.2396 0.2585 0.1966 0.31718 0.6828
7245.5 61.23 30.0938 1276.854 2.2285 0.54 0.2519 0.2555 0.1911 0.32097 0.679
7246 60 28.1562 1333.053 2.2234 0.53 0.2396 0.2585 0.1966 0.31718 0.6828
7246.5 58.08 25.25 1423.487 2.2154 0.51 0.2215 0.2634 0.2051 0.31131 0.6887
7247 58.72 23.625 1392.872 2.2181 0.51 0.2274 0.2618 0.2022 0.31327 0.6867
7247.5 58.72 23.9531 1392.872 2.2181 0.51 0.2274 0.2618 0.2022 0.31327 0.6867
7248 60 23.9531 1333.053 2.2234 0.53 0.2396 0.2585 0.1966 0.31718 0.6828
7248.5 61.23 21.3594 1276.854 2.2285 0.54 0.2519 0.2555 0.1911 0.32097 0.679
7249 63.75 19.0938 1167.687 2.2384 0.57 0.2783 0.2495 0.18 0.32869 0.6713
7249.5 66.27 16.8281 1064.947 2.2478 0.6 0.3068 0.2437 0.169 0.33644 0.6636
7250 68.74 14.8906 969.8051 2.2568 0.63 0.337 0.2383 0.158 0.34408 0.6559
7250.5 71.3 13.5938 877.5999 2.2656 0.66 0.3707 0.2329 0.1466 0.35201 0.648
7251 74.41 11.6484 773.3079 2.276 0.7 0.4154 0.2267 0.1325 0.36173 0.6383
7251.5 78.8 10.3594 641.3885 2.2897 0.75 0.486 0.2183 0.1122 0.37555 0.6245
7252 85.75 9.3828 471.0101 2.3098 0.83 0.6188 0.2062 0.0786 0.39776 0.6022
7252.5 91.42 8.0938 371.5493 2.325 0.9 0.7497 0.197 0.0493 0.41627 0.5837
7253 95.81 7.1211 323.8305 2.336 0.95 0.8677 0.1903 0.0252 0.43087 0.5691
7253.5 100.21 6.7969 307.0054 2.3464 1 1.0024 0.184 -0.0004 0.44572 0.5543
7254 104.6 6.4727 327.5264 2.3564 1.05 1.1563 0.1779 -0.0278 0.46086 0.5391
7254.5 105.24 6.4727 334.09 2.3578 1.06 1.1804 0.1771 -0.0319 0.46309 0.5369
7255 103.32 6.4727 317.2562 2.3536 1.04 1.1094 0.1797 -0.0197 0.45643 0.5436
7255.5 100.21 6.7969 307.0054 2.3464 1 1.0024 0.184 -0.0004 0.44572 0.5543
7256 99.57 6.7969 307.3034 2.345 0.99 0.9817 0.1849 0.0034 0.44355 0.5565
7256.5 102.04 6.7969 310.6123 2.3507 1.02 1.0643 0.1814 -0.0117 0.45202 0.548
7257 103.32 7.1211 317.2562 2.3536 1.04 1.1094 0.1797 -0.0197 0.45643 0.5436
7257.5 101.49 7.1211 308.7932 2.3494 1.02 1.0451 0.1822 -0.0082 0.4501 0.5499
7258 100.85 7.1211 307.4944 2.3479 1.01 1.0236 0.1831 -0.0043 0.44791 0.5521
7258.5 103.32 7.1211 317.2562 2.3536 1.04 1.1094 0.1797 -0.0197 0.45643 0.5436
7259 103.96 7.1211 321.9245 2.355 1.05 1.1326 0.1788 -0.0237 0.45864 0.5414
7259.5 102.04 7.1211 310.6123 2.3507 1.02 1.0643 0.1814 -0.0117 0.45202 0.548
7260 99.57 7.4453 307.3034 2.345 0.99 0.9817 0.1849 0.0034 0.44355 0.5565
7260.5 97.65 7.4453 312.7029 2.3404 0.97 0.9219 0.1876 0.0147 0.43705 0.563
Table A3: Petrophysical Attributes of Reservoir C in Well SHA-001 (Cored Section)