GENERAL GEOLOGY AND HYDROCARBON POTENTIAL OF CARBONACEOUS SHALE IN KAMPUNG IBOK, CHUKAI,
TERENGGANU
Nur Izzati Izwani Yusri*, Askury Abd Kadir Geoscience Department, Faculty of Engineering,
Universiti Teknologi PETRONAS Email: [email protected]
ABSTRACT
Various chemical analyses such as Total Organic Carbon (TOC), Source Rock Analysis (SRA), Vitrinite Reflectance (VR) and X-Ray Diffraction (XRD) have been performed to study the properties of carbonaceous shale and its hydrocarbon potential at Kampung Ibok, Cukai, Terengganu. The TOC content of carbonaceous shale in Chukai area is ranging from 1.24% to 15.3% and increases towards southern part. This may indicate that the southern part might be the deepest part of shallow marine environment. The SRA confirms that the carbonaceous shale in the study area has poor capability in generating any hydrocarbon. However, the results from VR suggested that the shale could have the possibility in producing shale gas.
Keywords; carbonaceous shale, shallow marine environment, hydrocarbon potential, shale gas
INTRODUCTION
The study area is located in Kampung (Kg.) Ibok, Chukai and also known by the name of Kemaman City.
Chukai is the biggest town in Southern Terengganu, Malaysia. As it is located between the state capitals of Kuantan and Kuala Terengganu, and it is proximity to the oil town of Kerteh, geographically has turned Chukai into a major commercial hub for the region.
Located nearby is the Kemaman Port, that serves both as a fishing port and supply base for oil platforms off the Terengganu coast.
The location of the study area, which consists of five outcrops denoted as Outcrop 1 to Outcrop 5 respectively. These five outcrops represent different lithologies for the Chukai. All of the outcrops of this study area are easily accessible as the outcrops are located along the federal main road.
PROBLEM STATEMENT
Coastal Terengganu especially south of Kuala Terengganu to Kemaman, is mainly composed of low- grade metamorphic rocks originated from the sedimentary rock. Some of the rocks are black in color, which might indicate that the rock contains high organic content becomes carbonaceous shale.
Some exposures in Chukai area have shown these characteristics. However, very limited study has been conducted to study the properties of these exposed black materials. Therefore, this research was conducted based on the limitation that have been analyzed from the previous research and to focus on analysis of hydrocarbon potential of the carbonaceous shale of the study area.
OBJECTIVE
The main objective of this research is to have a better geological understanding of the Chukai area which comprises of Sungai Perlis bed, and to evaluate the hydrocarbon potential of the carbonaceous shale which involving Total Organic Carbon (TOC) test, Source Rock Analysis and Vitrinite Reflectance test for determination of level maturation and the type of kerogen.
Figure 1 Location of study area, Chukai, Terengganu
SCOPE OF STUDY
The study includes the interpretation of the general geology of Chukai area in Terengganu as shown in Figure 1, which involves in lithology identification and structural features that requires details observation and sample collection to identify the properties of each rock. Hand specimens are collected for petrography study and geochemical analysis in the laboratory. During the outcrop survey, the study was emphasized in the description of general geological characteristics such as lithology, texture, mineralogy and primary geological structures. The primary data
consists of the geological map and cross-section of the outcrop were performed during the outcrop survey, which include identification and classification of the lithology. Rock samples have been taken from each outcrop for further geochemical analysis as for hydrocarbon potential validation of the outcrop observation. The study was emphasized on the general geology and the hydrocarbon potential of the carbonaceous shale found in Sungai Perlis bed specifically in Kg. Ibok, Terengganu.
Geology and tectonic framework on the eastern belt The Eastern Belt of Peninsular Malaysia (Figure 2) is the east part of Lebir fault including the eastern part of Johor [1]. This belt includes east of Kelantan, Terengganu and east of Johor that composed of formations aged from Paleozoic to Cenozoic. The northern part of the Eastern Belt consists of the Carboniferous meta-sediments, igneous rocks and Jurassic Cretaceous continental deposits.
It consists of the Carboniferous meta-sediments based on the fossils found in Ulu Paka, Terengganu [2], some other localities in north Pahang and Terengganu [3]
and Batu Rakit [4] and is known as the Sungai Perlis Bed [2].
The meta-sediments are the most dominant while the continental deposits occur in a number of small isolated areas. The oldest rock, which is dominant in this belt, is the meta-sediments that is Carboniferous in age and consists of mainly clastic sedimentary rocks that had undergone low-grade metamorphism [5] .
Figure 2 Study area is located in the black rectangle
Geology of Chukai, Kemaman
From the bigger perspective, the study area of this project will focus over Chukai, Kemaman area. The whole Terengganu is located at the Eastern Belt.
The most dominant rock is the sedimentary rocks formation (including the metasediment) which aged as Carboniferous and Permian together with granite formation.
The sedimentary rocks of the Kemaman area had undergone a regional metamorphism of low- grade type producing metamorphic rock unit. The oldest rocks in this area are well exposed at Tanjong Geliga, Tanjong Mat Amin and Tanjong Berhala. The
metasediments are composed of meta- quartzite, carbonaceous phyllite and slate.
Previous researchers have shown that the whole Paleozoic metasediment are known as Kuantan Group and apart from it is called the Sungai Perlis bed.
Sedimentology, stratigraphy and geochemistry of the carbonaceous shale in Kg. Ibok, Chukai, Kemaman
(Sungai Perlis bed)
The metasediments are composed of meta-quartzite, carbonaceous phyllite and slate. Goh [6] reported about the volcanic rocks and that volcanic rocks include acidic pyroclastics (lapilli tuff and ashy tuff) and rhyolitic lava flow. The intermediate and basic igneous rocks are found as marginal facies of the granite.
Chand [2] introduced the Sungai Perlis bed term to refer it to the sedimentary rocks observed in the Ulu Paka area. The name of this formation is taken from the Sungai Perlis as these kind of sedimentary rocks are exposed along the river. The Sungai Perlis bed is
defined based on the dominant rock sequences of the argillite, mostly shale, slate, phyllite, and also schist that comes together with some quartzite, meta-conglomerate and hornfels.
Pellite facies and psammite facies is observed to be present in Sg Perlis bed (pelite is and old term for a clay-rich, fine-grained clastic sediment or sedimentary while psammite is a term applied to metamorphic rocks derived from an arenaceous sedimentary protolith or sometimes used as a rock name for metamorphic rocks whose classification is unclear). Along the way to Kg. Ibok, there is sedimentary sequence which comprises of interbedded sandstones, shales and some granite. In the shale layer, there is a fine flake plant found.
This bed is correctable with the Charu Formation in Pahang that consists of interbedded sandstones, siltstones, and shale, which are believed to be deposited in the shallow marine area near shore environment by Lee [3]. The meta-sediments show at least two episodes of folding, which are north- northwest (NNW) or south-southeast (SSE) trend and north-south (NS) direction that are considered as relatively simple structures such as Bukit Bucu and Pulau Kapas area by Abdullah [7].
In certain area, such as parts of Chukai and Dungun areas, they are considered as complicated structures with three generations of folding by Abdullah [7].
METHODOLOGY
Five outcrops are identified across the 34km road of Chukai. Throughout the area of study, field observations, strike-dip reading, sample collection and sketch mapping are undertaken. The size of the samples is estimated to be in 12 cm length and 8 cm width. Rock samples are required in order to analyze the lithology of the study area. Several laboratory experiments are conducted to fully understand the properties of the rocks.
Petrography analysis
The sample that had been taken from the outcrop are further evaluated using thin sections. The purpose of this method is to examine the exact lithology and to check on the mineralogy aspect. The thin section procedure is conducted to determine the mineral composition and texture of a rock sample by analyzing them under a polarized microscope.
The characteristic of the mineral under polarized or cross-polarized light can differentiate the mineral, as well as to estimate the mineral composition of the rock.
Total organic carbon (TOC)
TOC or total organic carbon is the amount of carbon found in an organic compound. TOC may also refer to the amount of organic carbon in soil, or in a geological formation, particularly the source rock for a petroleum play. TOC analysis is measured from the total carbon present and the so-called “inorganic carbon” (IC) by subtracting the inorganic carbon from the total carbon yield.
X-ray diffraction (XRD) analysis
X-ray diffraction (XRD) is a basic tool in the mineralogical analysis of shales. It is an analytical technique used on a crystalline material to identify its phase and can provide information on unit cell dimensions. It is most widely used for the identification of unknown crystalline materials (e.g minerals and inorganic compounds). From minimal area, XRD measures the intensities of a reflected area and from the results, the atomic-level spacing of the crystal can be calculated. This helps in understanding the crystal structure for the substance. Determination of the degree of crystallization can also be calculated using XRD analysis.
Rock-eval pyrolysis
In Rock-Eval pyrolysis, a sample is placed in a vessel and is progressively heated to 550°C under an inert condition. During the analysis, the hydrocarbons
originally present in the samples are volatized at a moderate temperature. The amount of hydrocarbons is measured and recorded as a peak known, S1. Next pyrolyzed is the kerogen present in the sample, which generates hydrocarbons and hydrocarbon-like compounds (recorded as the S2 peak), CO2 and water.
The CO2 generated is recorded as the S3 peak while the residual carbon is measured as S4.
Trinite reflectance
Vitrinite reflectance is a measure of the percentage of incident light reflected from the surface of vitrinite particles in a sedimentary rock. It is referred to as % Ro. Results are often presented as a mean Ro value based on all vitrinite particles measured in an individual sample. The relationship between % Ro and hydrocarbon generation is dependent on the chemistry of the vitrinite as well as the chemistry of the kerogen.
Oil and gas zone boundaries can be established using vitrinite reflectance data. The boundaries are approximate and vary according to kerogen type.
RESULTS AND DISCUSSION
Carbonaceous shale
Based on previous studies, Chukai area is composed of meta-sediment, granite intrusion and Quaternary deposits. The rocks that are observed in the study area had undergone low-grade metamorphism, which changed shale into slate and sandstone into quartzite. Granite can also be observed on the hilly part of Kijal area.
Carbonaceous shale as shown in Figure 3 is found interbedded with shale and quartzite. The black color of the shale may indicate high content of carbon originated from the organic matter. This figure shows the carbonaceous shale outcrop that is located in Outcrop 3.
Shale usually can be recognized from other
“mudstones” because it is fissile and laminated.
Laminated is referring to the rock that is made up of many thin layers while fissile means that the rock is readily splits into thin pieces along the laminations.
Figure 3 Carbonaceous shale of Sg. Perlis bed
A strict geological definition of shale is any “laminated, indurated (consolidated) rock with > 67% clay-sized materials” (Jackson) [8]. Approximately 50% of all sedimentary rocks are classified as shale. Shales are often deposited in low-energy depositional environments where the fine-grained clay particles fall out of suspension. The red stains found on the rock indicate the presence of iron oxide, which also referring to the weathering process.
(a)
Figure 4 (a) Image of quartzite under plane-polarized and(b) (b) Image of quartzite under cross-polarized view
Other rocks with petrography analysis Quartzite
Quartzite that is found in Chukai area is interbedded with slate. Quartzite is formed by the metamorphism of sandstone. It is hard and non-foliated metamorphic rock, which was originally pure quartz sandstone.
Sandstone is converted into quartzite through heating and pressure that are usually related to tectonic compression within orogenic belts.
Quartzite is dominantly made up of quartz and minor feldspar. This quartz-rich metamorphic rocks are usually white to grey when pure. Based on the image shown by Figure 4.0, it can be concluded that this kind of quartzite is a metamorphic quartzite due to its feature that consists of interlocking crystals of quartz. It is also observed to be having a crystalline mineral with the size of grains approximately in the range of 2 to 5mm.
Phyllite
Phyllite is a fine-grained metamorphic rock formed by the reconstitution of fine grained, parent sedimentary rocks, such as mudstones or shales. A phyllite also has a marked fissility; a tendency to split into sheets or slabs due to the parallel alignment of platy minerals. It may have a sheen on the surface due to tiny plates of mica.
An obvious foliation can be seen from the image taken under microscope. Phyllite has fine-grained mica flakes in a preferred orientation. Among foliated metamorphic rocks, it represents a gradation in the degree of metamorphism between slate and schist.
Phyllite are said to have a texture called ‘phyllitic sheen’, and are usually classified as having formed through low-grade metamorphic conditions through regional metamorphism, metamorphic facies.
Fracture analysis
In order to identify the principal stresses, the fracture data is used to be analyzed using Rose Diagram. All the strike data of the joints and fractures readings obtained from the outcrop was plotted to create the Rose Diagram. The rose diagram might be a little rendered from the actual fracture system of the study area. Sigma 1 is the maximum stress that is 70°
from most prominent strike, whereas sigma 3 is the minimum stress, which is 200° from Sigma 1.
Figure 4.1 Rose diagram Outcrop 1
Figure 4.2 Rose diagram Outcrop 2
Figure 4.3 Rose diagram Outcrop 3
Figure 4.4 Rose diagram Outcrop 4
Figure 4.5 Rose diagram Outcrop 5
Based on the five rose diagrams from Outcrop 1 to Outcrop 5, Figure 4.1 to 4.5, the principal stress Sigma 1 is most likely to be in the range of 270° and Sigma 3 is at 70°. The majority of the fractures has
the strike reading in the range of 160° to 230°.
From the rose diagram, it can be indicated that the compressional stress that causes the formation of the fractures are coming from SW- NE direction.
Hydrocarbon potential of Carbonaceous shale Geochemical analyses
X-ray diffraction (XRD) analysis
Figures 4.6 to 4.10 shows the XRD phase spectrum analysis of the carbonaceous shale. This analysis indicated quartz and muscovite in the major constituents of carbonaceous shale. From this test, it can be seen that the dominant phase analyzed is the silicon dioxide (SiO2) or known as quartz and alumio- silicate (KAl2) bearing minerals.
Figure 4.6 XRD result of Sample 1
Figure 4.7 XRD result of Sample 2
Figure 4.8 XRD result of Sample 3
Figure 4.9 XRD result of Sample 4
Figure 4.10 XRD result of Sample 5
The concentration of SiO2 on the northern part is higher compared to the shale in the southern part.
The dominant concentration of quartz-bearing minerals in the carbonaceous shale samples are controlled by silicate minerals, particularly quartz that is the main constituent of most shale. A high percentage of this particular mineral explains the features of the carbonaceous shale in the study area.
There is also quite high percentage of muscovite (KAl2 (Si Al)4 O10 (OH)2) based on the results for all 5 samples. This muscovite or also called white mica has a weak chemical bond and mica minerals can be easily separated into very thin and flexible pieces. It is recognized as clay minerals and can be used to predict the quality of source rock and generation mechanism of the shales.
Based on the results, high content of SiO2 from quartz or other silicate minerals, for example, muscovite shows that the samples are very brittle. Different from the others, sample 5 is having the highest percentage of Al2 Si4 O10 (pyrophyllite). This proves that there is a difference in the content of the carbonaceous shale in the northern part and southern part of the study area. Overall, the samples tested showed crystallinity percentage ranging between 61.3% to 80.4% from the southern part to northern part.
Total organic carbon (TOC) Analysis
Black shales in general are organic-rich shales, which organic carbon contents usually exceed 1% and mostly vary between 2% and 10% [9]. Based on Table 1, the TOC content of the carbonaceous shale in the terrestrial area, which are S1, S2 and S3 located on the northern part of Chukai range from 2.12% to 5.44% that can be interpreted as very good to excellent potential of the source rock. Meanwhile, the samples on the southern part, which are S4 and S5, ranging from 1.24% to 15.3%, which can be considered as good to excellent potential of source rock.
The organic content of the carbonaceous shale increases towards the southern part. Carbonaceous
shale, which is a part of the Sungai Perlis bed are deposited in shallow marine area [3]. The southern part is interpreted to be the deepest part of the shallow marine that causes high accumulation and preservation of organic matter that contributed to high organic content in the southern part compared to the northern part.
Table 1 Results of TOC Analysis
Sample
ID Location TOC
(%) Quality S1 N 4° 22’ 41.16” 5.44 Excellent
E 103° 25’ 47.64”
S2 N 4° 22’ 41.16” 2.62 Very Good E 103° 25’ 47.64”
S3 N 4° 22’ 41.16” 2.12 Good E 103° 25’ 47.64”
S4 N 4° 19’ 34.68” 1.24 Good E 103° 26’ 53.16”
S5 N 4° 19’ 34.68” 15.3 Excellent E 103° 26’ 53.16”
Rock-eval pyrolysis (source rock analysis)
Pyrolysis is the decomposition of organic matter by heating in the absence of oxygen. The Rock-Eval instrument provides a fast determination of the type and evolution stage of kerogen, together with a direct evaluation of hydrocarbon source potential. The type and quality of kerogen are usually interpreted on a graph derived from the traditional Van Krevelen Diagram, by replacing the H/C and O/C ratios with the hydrogen index (HI) and the oxygen index (OI).
Table 2 Results of Pyrolysis with calculated parameters of the analyzed rock samples
No. Sample ID S1 (mg/g) S2 (mg/g) Tmax (°C) PI HI,%
1 CGMS 1 0.07 0.12 340 0.37 2.21
2 CGMS 2 0.04 0.06 322 0.4 2.29
3 CGMS 3 0.06 0.07 322 0.46 3.3
4 CGMS 4 0.1 0.06 305 0.63 4.84
5 CGMS 5 0.05 0.09 326 0.36 0.59
Table 2 shows that S2 values for all samples are lower than 2mg HC/g, indicated the poor capability in hydrocarbon generation [10]. Broad S2 pyrolytic peaks resulted from a very weak signal and high noise subsequently affect the Tmax values, thus produce anomalously low Tmax. This contrary with the vitrinite reflectance measurement where most of the samples shows very high reflectance values. The analyzed samples range in rank from semi-anthracite to meta-anthracite (2.12 – 4.84% Ro), which suggest the samples have undergone a certain metamorphic event based on Peters and Cassa [10].
Table 3 Showing class of kerogen based on HI and GOC value [13]
Kerogen Type HI GOC
I >700 >60% (Oil)
II 350 - 700 30% - 60%
(Oil + Gas) II/III 200 - 349 17% - 29%
(Gas + Oil)
III 50 - 199 4% - 28%
(Gas)
IV <50 <4% (None)
Hydrogen Index (HI) is actually defined as a measure of the hydrogen richness of the source rock, and
when the kerogen type is known, it can be used to estimate the thermal maturity of the rock according to Table 3. Based on the hydrogen index (HI) from the samples tested, they are having a Mixed Type of kerogen (Type II/III) which HI value ranges from 0.59%
- 4.84 %.
Vitrinite reflectance
Vitrinite reflectance measurement was performed using Leica CTR6000M microscope and Diskus Fossil software. Standard sapphire (0.589% Ro) was used for calibration. Between 10 to 40 measurements were obtained. The measurements were carried out under white light using an oil immersion X50 objective. Smallest aperture size of 3 µm was used in all measurements to minimize error.
Vitrinite reflectance is a measure of the percentage of incident light that reflected from the surface of vitrinite particles in a sedimentary rock. It is referred to as Ro (%). Results are often presented as a mean Ro
value based on all vitrinite particles measured in an individual sample. Based on the Table 4, it is clearly stated that the mean Ro value ranges from 2.12- 4.84
%. The relationship between Ro (%) and hydrocarbon potential is dependent on the chemistry of the vitrinite as well as the chemistry of the kerogen itself.
Table 4 Vitrinite Reflectance Data of Sg. Perlis bed
No Sample Name Lithology Min
%
Max,
% Mean,% No. of
reading Std. Dev
1 CGMS 1 Black Shale 3.9 6.08 4.84 40 0.621
2 CGMS 2 Black Shale 2.48 5.2 3.71 35 0.883
3 CGMS 3 Black Shale 3.28 4 3.59 25 0.207
4 CGMS 4 Black Shale 1.96 2.36 2.12 10 0.102
5 CGMS 5 Black Shale 4.04 4.78 4.39 30 0.222
Figure 4.11 A color chart for organic thermal maturity
Oil and gas zone boundaries can be established using vitrinite reflectance data. These boundaries are approximate and vary according to kerogen type.
Determination of Pearson’s (1984) [11] correlated with the thermal alteration index (TAI) & Correlation of spore color index (SCI) of Fisher et al., (1980) [12] with thermal alteration index (TAI) of Staplin (1969) [13]
for organic thermal maturity determination is shown as in Figure 4.11. In accordance of the chart above and the data obtained, all the samples fall on the over matured region in Figure 4.11. Therefore, it can be concluded that the samples tested for this test have been identified as over matured rock, and the high maturity has exhausted all oil potential.
Correlation of geochemical analyses
Gas shale potential and comparison to US gas shale As discussed [14] controls on the potential of a gas shale system include thickness and lateral extent, organic richness, porosity and mineralogical composition, which greatly influences fraccability.
All Carboniferous shales examined in this study are clearly within the gas window. However, Table 5 will focus on the study of the results of well-known gas shales Star Diagram model from the USA, Barnett Shale as it is of similar age and lithology.
Figure 4.12 Graph of Hydrogen Index (HI) against Tmax (°C)
Figure 4.13 Theoretical indicators for the identification of HI [15]
Table 5 Data of Tmax and HI obtained for shales in Chukai
Tmax (°C) HI (mg OIL/g TOC)
340 221
322 229
322 330
305 484
326 59
A graph of Hydrogen Index (HI) versus Tmax (°C) in Figure 4.12 is plotted and mapped onto the theoretical graph of it in Figure 4.13. The blue color dots showing the results in the study area are indicating the Wet Gas Generation maturity which can also be interpreted as a Mixed Type II/III of kerogen type.
Table 6 Data of Star Diagram
TOC (%) VR (%) TR (%) Silica (%) Thickness (m)
5.44 4.84 36.84 0.6 5
2.62 3.71 40 0.58 5
2.12 3.59 46.15 0.64 5
1.24 2.12 62.5 0.58 8
15.3 4.39 35.7 0.65 8
TOC (Total Organic Content) ; VR (Vitrinite Reflectance); TR (Transfromation Ratio)
Figure 4.14 Star Diagram shows the geochemical assessment and corresponding data
The gray area represents the latest oil window-wet gas window where commercial gas production can be achieved depending on hydrocarbon composition and depth (modified after Jarvie [14]). The blue area of the Star Diagram in Figure 4.14 obtained from the results of this study; Table 6 falls in the gray area of the theoretical Star Diagram; Figure 4.15 which
is using the Barnett Shale as the parameter, it can be interpreted that the samples of Chukai area are actually having the potential of producing shale gas.
However, since this study only involving limited amount of representative samples, further studies and research need to be done in order to confirm the gas shale production in Chukai area.
TOC % (10)
VR % (5)
TR % (100) Silica % (100)
Thickness m (100)
Barnett Woodford Area 1 Area 4
Figure 4.15 Theoretical Star Diagram - Geochemical assessment and corresponding data of black shales for well-known gas shale systems
CONCLUSION
Chukai area is made up of Sungai Perlis bed, which consists of interbedded shale, carbonaceous shale, phyllite, quartzite and granite. The presence of folding and thrusting in rock formation suggests that Chukai area had undergone regional compression.
The carbonaceous shales found in Chukai area are gray to black in color. This geological condition phenomenon proved that the rocks found in the
The supportive elements of the low metamorphism process are provided with the general geological analysis, which involved structural part discussed in the report. The fracture analysis indicated that the area has undergone compressional stress from SW- NE direction.
The carbonaceous shale found in Chukai area is identified as grayish to black in color. The XRD results have indicated the characteristics of the carbonaceous shale where it has brittleness properties and high crystallinity range. The TOC content of carbonaceous shale has an average of 5.34%, which indicates an excellent range of having high organic content. Based on the S2 value of Source Rock Analysis (SRA) test, it has shown that all these samples have poor capability in hydrocarbon generation [10]. This shows that the
since the value of the hydrogen index (HI) from the Vitrinite Reflectance, test shows a mixed type of kerogen class, Type II/III can be interpreted that the study area could have the potential in producing shale gas.
FURTHER STUDY
In order to ensure more accurate and precise properties, it is recommended to check on the hydraulic properties of the shale as well. Hydraulic properties are the characteristics of a rock such as permeability and porosity that reflect its ability to hold and transmit fluids such as water, oil or natural gas. This can also support the shale gas production system. Apart from that, a more detail provenance study also is suggested to be done in this project to determine the origin of the black shale in Chukai, Terengganu.
ACKNOWLEDGMENT
I would like to thank my supervisor, AP Askury Abd Kadir and coordinators, Mrs. Norsyazwani Zaini and Mr Abdul Halim Andul Latiff for the opportunity to conduct this study and their guidance, supports that they provided throughout the course of my final year project. My sincere appreciation also goes to Dr. Azlan from Universiti Malaya who has helped me a lot in conducting the lab analyses. And also my appreciation goes to Dr Abd Hadi Abd Rahman for his positive advices and helpful comments on my works. Nevertheless, my gratitude goes to all the lab technologists in assisting me with the lab works. Last but not least, I would like to thank all my family and friends for their endless moral support.
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AUTHORS' INFORMATION
Nur Izzati Izwani Yusri obtained her bachelor’s degree from Universiti Teknologi PETRONAS in Petroleum Geoscience course. She has completed her internship at PETRONAS Research Sdn Bhd as a geoscience intern and managed to express her research interest in geochemistry analysis through her final year project entitled “General Geology and Hydrocarbon Potential of Carbonaceous Shale in Kg Ibok, Chukai, Terangganu
AP Askury Abd Kadir completed his BSc (Hons) in Geology major in Economic Geology from UKM and obtained MSc in Engineering Geology from Leeds University. His MSc research topic was “The determination of shrinkage limit for clay soils using a travelling microscope with a comparison to the established definitive method (TRRL)”. After 24.5 years served as a Government Servant in the Minerals and Geoscience Department, he decided to join UTP for sharing his vast experience with students as a field geologist. Associate Professor in Geoscience Department, he involved with teaching and research on geomechanical properties of rocks, structural geology and engineering geology. He is also actively involves in AAPG-UTP-Student Chapter as Advisor on students’ activities and Council Member of Geological Society of Malaysia.
