A report on wireline log interpretation with emphasis on hydrocarbon of Saldanadi structure, Bangladesh

A Report on Wireline Log Interpretation
with Emphasis on hydrocarbons of the
Saldanadi Structure, Bangladesh
Course No.: GS-510
Course Title: Geophysical Field Investigation
Submitted by:
Md. Shahadat Hossain
Class Roll: 1651
Registration No.: 37524
Session: M.S. (2017-2018)
Department of Geological Sciences
Jahangirnagar University, Savar, Dhaka-1342

I
Abstract
The Saldanadi gas field located at Brahmanbaria district is one of the producing gas fields of the western
part of the Chittagong Tripura Fold Belt (CTFB). The gas field is exploited and maintained by
Bangladesh Petroleum Exploration and Production Company Limited (BAPEX) which falls under the
Rokhia anticline of the middle asymmetric thrust faulted region of the CTFB. The Rokhia anticline is
gently folded, doubly plunging, NNW-SSE trending, has no evidence of faulting at the surface and is
completely surrounded by Tripura state of India. Current study of the Saldanadi gas field includes the
well log data interpretation in order to establish lithologic succession and identifying the possible zones of
hydrocarbon accumulation. Though the Saldanadi gas field is already contributing to the national grid but
frequent scientific study of the field may find any possible development which may pay a lot in the
coming days of energy crisis of Bangladesh.

II
Table of contents
Chapter No. Chapter Title Page
Abstract I
List of Figures III
List of Tables III
Chapter-1 Introduction Location and Extent 1
Regional Geology and Tectonics 2
Chapter-2 Methodology of Well Log Interpretation 6
Chapter-3 Results of Well Log
Interpretation
Lithology delineation from Logs 10
Hydrocarbon Possibility 16
Conclusion 18
References 19

III
List of Figures
Figure No. Figure Name Page
Figure 1.1 Location of the Saldanadi gas field 2
Figure 1.2 Bangladesh PSC (Production Sharing Contract) Block Map 3
Figure 1.3 Tectonic elements in and around the Bengal Basin 5
Figure 2.1 Response of different logs in different scenarios 7
Figure 3.1 Lithology delineation from the well logs of the Saldanadi gas field 12-15
Figure 3.2 Identifying possible hydrocarbon bearing zones from the well logs of the
Saldanadi gas field
17
List of Tables
Table No. Table Name Page
Table 3.1 Observed lithology of the Saldanadi gas field interpreted from well logs 11
Table 3.2 Hydrocarbon zones of the Saldanadi gas field interpreted from well logs 16

1 A report on Wireline log interpretation with emphasis on hydrocarbons of the Saldanadi Structure, Bangladesh.
Chapter-1 (Introduction)
Bangladesh is an energy deprived country and with the increased amount of population, energy sector of
this country is at huge pressure. To meet the energy demand of the country, natural gas is one of the
prominent elements and it contributes about 75% of total energy demand of Bangladesh. Recently,
Bangladesh has been promoted to a developing country from a least developed one so, fast development
of new gas fields and re-visit of the existing fields like Saldanadi is much expected. In this manuscript the
Saldanadi gas field is examined through interpretation of well log data. Two gas sands have been
identified, from which the gas field is still producing. It is found that total GIIP from both upper and
lower gas sand is 501.186 Bcf among which 350.83 Bcf is recoverable with 70% recovery rate. In
addition total remaining reserve is 282.95 Bcf (Dey et al., 2016). After calculating the recoverable amount
of gas, Saldanadi gas field can be classified as a commercial one according to the international
classification of gas fields by size (Khan, 2007).
1.1 Location and Extent:
Saldanadi gas field is situated about 145 km east of Dhaka city, 40 km north of Comilla town, 50 km
south east of Brahmanbaria town along the India-Bangladesh border, under Kasba Thana of
Brahmanbaria district (Figure 1.1) (Dutta, 2011; Salekin, 2011; Islam et al., 2015). Titas and Bakhrabad
gas fields are about 40 km north and about 30 km west of Saldanadi respectively (Dutta, 2011). It is
almost completely surrounded by Indian Territory. The onshore area of Bangladesh has been divided into
23 blocks for hydrocarbon exploration and the Saldanadi gas field lies in Block-9 under Production
Sharing Contract (PSC) blocks (Figure 1.2) (Petrobangla-Bangladesh PSC Block Map, 2015).
At Saldanadi structure, 3 wells have been developed out of which well no 1 and 3 is vertical but well no 2
is deviated (Salekin, 2011). Well no 1 was drilled in 1966 (discovery well) which was terminated at a
depth of 2511 m (MD). Two gas zones were discovered out of three zones while conducting DST
(BAPEX-well completion report on Saldanadi, 2004; Islam et al., 2015). Based on DST result the well
was completed as dual producer at lower zone interval of 2405-2430 m and upper zone interval of 2170-
2260 m (BAPEX-Well completion report on Saldanadi, 2004; Salekin, 2011). From Saldanadi gas field
well no 1, 29.907 Bcf gas from the lower zone and 5.841 Bcf gas from the upper zone was produced from
1998 to 2010 including two shut-in periods (BAPEX-Well completion report on Saldanadi, 2004; Islam et
al., 2015). Presently the well is in production.
Well no 2 of the Saldanadi gas field was drilled in 1999 to a total depth of 2458 m (MD). Three
prospective zones were tested but only the middle zone (2300-2365 m) has produced gas. From well no 2,

26.573 Bcf gas has been produced from 2001 to 2010 and presently the well is in production (BAPEX-
well completion report on Saldanadi, 2004; Islam et al., 2015). Drilled depth of Saldanadi well no 3 is
2860 m (MD) which started its production from January, 2012 (BAPEX-well completion report on
Saldanadi, 2004; Islam et al., 2015).
Figure 1.1: Location of the Saldanadi gas field.
1.2 Regional Geology and Tectonics:
The Bengal Basin is located at the north-eastern corner of the Indian plate, sandwiched between Indian
plate to the west, Indo-Burman Ranges to the east, Eurasian plate to the north and Bay of Bengal to the
south (Alam et al., 2003) (Figure 1.3). This foreland basin (Johnson and Alam, 1991; Uddin and
Lundberg, 1999) is formed due to continent-continent collision to the north between Indian plate and
Eurasian plate and oblique subduction between Indian plate and Burmese plate to the east (Alam et al.,
2003; Wang et al., 2014). Prior to its formation, the Bengal Basin was part of the Greater Indian plate and
was separated from the ancient Gondwanaland by rifting along the edges along with the Indian plate in
the Early Cretaceous (Curray and Moore, 1974; Curray et al., 1982; Hutchison, 1989; Acharyya, 1998).
After being rifted, India made its rapid northward journey and by Early Eocene (about 44 Ma) hard
continent-continent collision commenced related to the Himalayan orogeny (Alam et al., 2003). The
Bengal Basin became a remnant ocean basin (Ingersoll et al., 1995) at the beginning of Miocene because

of the continuing oblique subduction of India beneath the southeast extrusion of Burma (Alam et al.,
2003).
Figure 1.2: Bangladesh PSC (Production Sharing Contract) Block Map (Petrobangla, 2015)

The Bengal Basin has three distinct geo-tectonic provinces: Province 1-Passive to extensional cratonic
margin to the west, the Stable Shelf Province, Province 2-The Central Deep Basin Province and Province
3-The subduction related orogen to the east, the Chittagong-Tripura Fold Belt (CTFB) Province (Figure
1.3) (Bakhtine, 1966; Reimann, 1993; Alam et al., 2003). Based on geometric shape and intensity of
folding, Bakhtine (1966) further divided the CTFB into three sub-divisions: 1) Eastern highly compressed
disturbed zone, 2) Middle asymmetric thrust faulted zone and 3) Western quite zone. Recent
investigations suggest that the fold belt has grown progressively westward and many of the folds in the
westernmost part of this province have been active only from the Late Pliocene or even later (Johnson and
Alam, 1991; Steckler et al., 2008; Maurin and Rangin, 2009; Hossain et al., 2019).
Our study area, Saldanadi gas field is located at the western part of the Chittagong-Tripura Fold Belt or
the Middle asymmetric thrust faulted zone (Figure 1.3). It is located at the central part of the Rokhia
anticline (Dutta, 2011). The Rokhia anticline is gently folded, doubly plunging and NNW-SSE trending.
Northern and southern part of the anticline lies in India while about 15 square km area of the crestal part
of the structure i.e. Shyampur Dome is in Bangladesh (Dutta, 2011; Salekin, 2011). The structure is about
40 km long and 6 km wide (Ganguly, 1997) which possesses two culminations. Structurally the northern
culmination is known as Shyampur dome, which is about 500 m higher than the southern one. The
southern culmination is known as Jalangi dome. Most of the Rokhia anticline lies within the territory of
the Indian state of Tripura.
In the Landsat map by Ganguly (1997) three lineaments were drawn within the Shyampur Dome. In the
geological map by Ganguly (1997) no faults could be observed. A subsurface fault has been identified in
the eastern flank of the time structure map of the middle gas sand and the lower gas sand by Dutta (2011).
Indication of this fault can be observed on topographic map also. Moreover, the course of the Salda river
could be an indication of an E-W fault (Figure 1.1) (Dutta, 2011; Salekin, 2011).

Figure 1.3: Tectonic elements in and around the Bengal Basin (modified after Alam et al., 2003).

Chapter-2 (Methodology of Well Log Interpretation)
It is clearly visible from the well logs that five major log types are used to determine the lithology and the
possible zones of hydrocarbon accumulation for the Saldanadi gas field. The log types used here are:
Gamma ray log, SP (Spontaneous Potential) log, Resistivity log, Neutron porosity log and Density log.
The data acquiring procedure, interpretation procedure and the advantages with their limitations are given
in the following part of this chapter.
Gamma Ray Log:
The gamma ray log is a record of the formations radioactivity which derives from three major radioactive
minerals namely: Uranium, Thorium and Potassium. In sedimentary rocks, the natural radioactivity
principally comes from potassium or shale to be very exact (Rider, 1996). Because of this measurement,
they can be used for lithology identification and for correlating zones (Asquith and Gibson, 1982). Shale
free sandstones and carbonates have low concentrations of radioactive minerals, and so they provide low
gamma ray readings. On the other hand, gamma ray readings are very high against a shale formation as
they are rich in radioactive minerals particularly in potassium (Figure 2.1) (Asquith and Gibson, 1982;
Rider, 1996). Gamma ray logs are also used to calculate shale volume quantitatively (Asquith and Gibson,
1982; Rider, 1996).
A simple gamma ray tool consisting of a scintillation counter and a photo multiplier is lowered into the
borehole that records gamma ray radiation from the formations and records the data in track 1 along with
caliper log (Rider, 1996). The accepted unit for gamma ray logging is the API (American Petroleum
Institute) and the most common scale for measurement is 0-100 or 0-150 API.
SP (Spontaneous Potential) Log:
The spontaneous potential (SP) is one of the earliest logs used in petroleum industry. It is a measurement
of the natural potential differences between an electrode in the borehole and a reference electrode located
at the surface; no artificial currents are applied (Rider, 1996). SP currents are created when two solutions
of different salinity are in contact. Primarily the SP log is used to identify impermeable zones such as
shale and permeable zones such as sand (Asquith and Gibson, 1982). Principal uses are to calculate
formation-water resistivity, indicate permeability, estimate shale volume, indicate facies and, in some
cases, for correlation (Asquith and Gibson, 1982; Rider, 1996). One major disadvantage of the SP log is
that data cannot be recorded at offshore rigs as it requires solid earth to record data (Rider, 1996). This is
a pity as SP log is very cheap to obtain and also very useful.

In order to interpret SP log, the imagination of shale baseline and SSP (static spontaneous potential) is
very important. Shale baseline is the maximum deflection of the SP curve against a thick shale bed while
the SSP line is the maximum deflection of SP curve against a shale free zone (Figure 2.1) (Asquith and
Gibson, 1982; Rider, 1996). The SP values of a formation will fluctuate between these two lines and the
desired values can be obtained. The log is usually run in track 1 with gamma ray log or caliper log and the
unit of SP current is millivolts (Rider, 1996).
Figure 2.1: Response of different logs in different scenarios (modified after Varhaug, 2016).
Resistivity Log:
Out of all the logging tools, resistivity tools are the most ancient one with which Conrad Schlumberger
started his company in 1919 (Rider, 1996). The most prominent use of the resistivity log is to identify
hydrocarbon bearing zones. Rock matrix or grains are insulators while the filled liquids determine

whether a rock is conductive or not. If the pore spaces are filled with water the rock will act like a
conductive body and the resistivity values will be very low. In contrast to this, the rock will act like an
insulator if the pore spaces are filled with hydrocarbon and the resistivity values derived from the logs
will be very high (Figure 2.1) (Asquith and Gibson, 1982; Rider, 1996). A major limitation of the
resistivity log is that it can only function in boreholes containing conductive muds mixed with salt water.
Data cannot be acquired in fresh water mud or oil based mud (Rider, 1996).
The unit of resistivity log is ohm-m2
/m, called ohm-m for short. The log is plotted on a logarithmic scale
either in track 2 alone or in tracks 2 and 3 (Rider, 1996).
Neutron Log:
Neutron log is a porosity log that measures the hydrogen ion concentration of a formation. In a shale free
formation where the porosity is filled with water or oil/gas, the neutron log measures liquid filled porosity
(Asquith and Gibson, 1982). The neutron log provides a continuous record of a formation’s reaction to
fast neutron bombardment. These neutrons collide with the nuclei of the formation material and results in
neutron losing some of its energy. As hydrogen atom has the same mass as neutron, maximum energy
loss occurs when the neutron atom collides with a hydrogen atom. Because hydrogen in a porous
formation is concentrated in the pores of a formation, so the energy loss can be related to porosity of that
formation. Whenever pores are filled with gas rather than oil or water, neutron porosity will be lowered
(Figure 2.1) (Asquith and Gibson, 1982; Rider, 1996). This occurs because there is less concentration of
hydrogen in gas compared to oil or water. A lowering of neutron porosity by gas is called gas effect
(Figure 2.1) (Asquith and Gibson, 1982). So, the major use of neutron log is to measure porosity and
discriminate between oil and gas (Rider, 1996).
Neutron log is generally plotted in tracks 2 and 3 and the unit is neutron porosity unit. The most common
scale is from 45% (to the left) to -15% (to the right) neutron porosity units. A ratio may be used instead of
a % making these figures 0.45 to 0.15 neutron porosity units (Rider, 1996).
Density Log:
The density log is a continuous record of a formation’s bulk density (Rider, 1996). This is the overall
density of the rock including the matrix and the pore filled fluids. The density log device consists of a
medium energy gamma ray source (Cobalt-60 or Cesium-137) that emits gamma rays into a formation
(Asquith and Gibson, 1982). Gamma rays collide with electrons in the formation and the collision results
in a loss of energy of the gamma particles. Scattered gamma rays which reach the detectors are counted as
an indicator of formation density. Then the density porosity of the formation can be calculated by using

particular equation. Where invasion of a formation is shallow, low density of the formation’s
hydrocarbons will increase density porosity (Figure 2.1). Oil does not significantly affect density porosity
but gas does, creating a gas effect (Asquith and Gibson, 1982). A combined neutron-density log can be
used qualitatively to identify gas zones by such neutron-density cross over (Figure 2.1). Some other uses
are: calculating acoustic impedance, lithology indicator, identifying source rocks and to identify
overpressure zone (Rider, 1996).
The density log is plotted across tracks 2 or 3 and also plotted on a linear scale of bulk density. The unit is
gm/cm3
and the most common scale is between 1.95-2.95 gm/cm3
(Rider, 1996).

Chapter-3 (Results of Well Log Interpretation)
Five major types of logs are presented here for interpreting the geological properties of the Saldanadi gas
field. Gamma ray log and SP (Spontaneous Potential) logs are used mainly for lithology construction. On
the other hand, Resistivity log (Deep induction, Medium induction and MSFL), Neutron porosity log and
Bulk density logs are used for establishing a possibility of hydrocarbon accumulation at different parts of
the tentative reservoirs. Interpretation of the Well Logs from the Saldanadi gas field is provided below:
3.1 Lithology Delineation from Logs:
As mentioned earlier, gamma ray log and SP (Spontaneous Potential) logs are handy to establish the
lithology of the Saldanadi gas field. Gamma ray log records the natural radioactivity fusing out of a
formation and deflects to the right for higher values and to the left for lower amount of radioactivity. The
radiation mainly emanates from naturally occurring Uranium, Thorium and Potassium (Rider, 1996).
While we are aware of the fact that only sedimentary rocks are encountered during drilling of the
Semutang gas field, so Potassium alone is responsible for the gamma ray deflections, shale to be more
exact.
For using the SP log to analyze lithology we had to draw Shale Baseline (green line), a line representing
the maximum amount of shale at a thick continuous shaly formation and SSP (Static Spontaneous
Potential) (yellow line) which represents the maximum deflection against a thick sandstone formation.
The shale baseline is drawn making use of the thick shale formation located approximately at 2220 to
2280 m depth (Figure 3.1). The SSP is drawn considering a thick sandstone formation located
approximately at 2160 to 2215 m depth (Figure 3.1). One major advantage of using gamma ray log and
SP log to establish lithology is both the logs coincide with each other to mark the exactly same lithology.
Bed boundaries are drawn making use of the gamma ray log over the SP log as it is more convenient
(Rider, 1996).
Now let’s focus on the attached figures at 3.1 to interpret the lithology. Starting from the top at 850 m
depth, a shaly sandstone unit/a sandy shale unit is located at least up to approximately 1000 m depth.
Underlying this, a sandstone unit from 1000 m depth gradually transforms to shaly sandstone up to
approximately 1250 m depth. From approximately 1250 to 1750 m depth a thick unit with
repetitive/alternating beds of sand-shale is encountered. From approximately 1750 to 1850 m depth the
unit remains the same (repetitive/alternating beds of sand-shale) but the amount of sand increases as both
the gamma and SP log slightly deflects to the left. The shale content again increases up to approximately
2050 m depth keeping the formation same as before. The deflection moves to the right from

approximately 2050 to 2150 m depth indicating a shale unit found here. A thick sandstone formation is
encountered from approximately 2150 to 2215 m depth using which the SSP line is drawn. Underlying
the sandstone unit, a thick shale unit is located from nearly 2215 to 2280 m depth using which unit the
shale baseline is drawn. A pocket zone of sandy shale is found from apparently 2280 m to 2325 m depth.
Another thick body of shale is located between approximately 2325 to 2400 m depth. From about 2400 to
2460 m depth a thick body of sandstone is again found which is underlain by a thick body of shale to the
bottom, nearly up to 2590 m depth. The delineated lithology from the well logs is summed below in a
table (Table 3.1):
Table 3.1: Observed lithology of the Saldanadi gas field interpreted from well logs.
Depth (m) Lithology
850-1000 Shaly sandstone/Sandy shale
1000-1250 Sandstone gradually transforming into shaly sandstone
1250-2050 Alternating beds of sandstone-shale
2050-2150 Shale
2150-2215 Sandstone
2215-2280 Shale
2280-2325 Sandy shale
2325-2400 Shale
2400-2460 Sandstone
2460-2590+ Shale

Figure 3.1: Lithology delineation from the well logs of the Saldanadi gas field.

3.2 Hydrocarbon Possibility:
As we mentioned earlier, we will be using Resistivity, Neutron porosity and Density logs for identifying
possible zones of hydrocarbon accumulation. It is convenient to mention that we are considering
conventional reservoirs, so only the sandstone bodies that show hydrocarbon promises will be focused
only. Such thick sandstone bodies are found at 1000-1050 m depth, 2150-2215 m depth and 2400-2460 m
depth deciphered from lithological interpretation (Figure 3.1 and Table 3.1).
Sandstones are always filled up with pore filling liquids, either water or oil/gas. If the voids are filled with
water, resistivity of the formation will be very low as water is a good conductor of electricity. On the
other hand, if the voids are filled with hydrocarbons then the resistivity will be very high (Rider, 1996).
Combination neutron porosity and density logs have a significant effect on hydrocarbon, particularly gas.
Gas has very low density so has a very low hydrogen index compared to water. Whenever pores are filled
with gas rather than oil or water, neutron porosity will be lowered (Asquith and Gibson, 1982). In the case
of density log, density tool investigates the flushed zone where gas is frequently encountered due to its
mobile behavior showing high density porosity (Asquith and Gibson, 1982). This overlapping behavior of
the neutron log and density log creates a cross over and a distinct gas effect is noticed.
The sandstone body located between 1000-1050 m depth has very low resistivity value and the neutron
and density logs behave as usual (Figure 3.1). Such effect can be possibly due to pore filling water. On
the other hand, the sandstone bodies located at 2150-2215 m depth and 2400-2460 m depth have very
high deep induction resistivity values. Additionally, the neutron porosity value is dramatically lowered
and the density log values are also dramatically higher in those locations (Figure 3.2). Such effect creates
a neutron-density cross over indicating to possible gas zones found at those parts of the Saldanadi gas
field.
In addition to this, the overlying shale bodies located at 2050-2150 m depth and 2325-2400 m depth of
both the possible reservoir sandstones may have acted like seal rocks. Thick shale formations are also
found below both the possible gas zones. These shale bodies may be the source rocks of these reservoir
bodies (Figure 3.2).
Table 3.2: Hydrocarbon zones of the Saldanadi gas field interpreted from well logs.
Depth (m) Lithology Thickness (m) Comments
2150-2215 Sandstone 65 High resistivity, neutron-porosity cross over (gas effect)
2400-2460 Sandstone 60 High resistivity, neutron-porosity cross over (gas effect)

Figure 3.2: Identifying possible hydrocarbon bearing zones from the well logs of the Saldanadi gas field.

Conclusion
Saldanadi gas field, a gas field operated by BAPEX is geographically located at the eastern India-
Bangladesh border of Brahmanbaria district, Bangladesh and parallelly at the onshore Block-9 of
Production Sharing Blocks (PSC) by Petrobangla. Tectonically the gas field falls under Rokhia anticline,
located at the western part of the Chittagong-Tripura Fold Belt. The Rokhia anticline is gently folded,
doubly plunging and NNW-SSE trending. No distinct fault is found at the surface but seismic data shows
a single fault at the eastern flank of the structure. Previous studies show that three production capable gas
sands have been discovered out of which two of them are still producing through two drilled wells.
Our study regarding the Saldanadi gas field using well log data is used to re-construct the litholgy and
hydrocarbon potential. Lithological re-construction is mainly based on Gamma ray log and SP log.
Interpretation shows that the upper part of the structure, at least up to 2050 m depth is composed of thin
alternate/repetitive beds of sandstone and shale or shaly sandstone with recurring sandy shale. From 2050
m depth to the bottom, thick sandstone and shale beds are encountered.
Hydrocarbon analysis from the well logs is mainly based on Resistivity, Neutron and Density log.
Combining the interpreted lithology with the response of these logs, it shows that thick sandstone bodies
located at 2150-2215 m depth and 2400-2460 m depth can be the producing reservoirs of the Saldanadi
gas field. There are thick shale bodies located above both the reservoirs which may act like seal rocks.
Moreover, thick shale bodies are also found below the reservoirs which may act like source rocks from
where hydrocarbons had migrated after being produced.

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