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1991
Coals source rocks and hydrocarbons in the SouthPalembang sub-basin south Sumatra IndonesiaRubianto Indrayudha AmierUniversity of Wollongong
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Recommended CitationAmier Rubianto Indrayudha Coals source rocks and hydrocarbons in the South Palembang sub-basin south Sumatra IndonesiaMaster of Science (Hons) thesis Department of Geology University of Wollongong 1991 httprouoweduautheses2828
COALS SOURCE ROCKS AND HYDROCARBONS
IN THE SOUTH PALEMBANG SUB-BASIN SOUTH SUMATRA
INDONESIA
A thesis submitted in (partial) fulfilment of the
requirements for the award of the degree of
MASTER OF SCIENCE
(HONS)
from
THE UNIVERSITY OF
WOLLONGONG
by
RUBIANTO INDRAYUDHA AMIER
(BSc AGP BANDUNG)
Department of Geology 1991
013657
I certify that the substance of this thesis is
original and has not already been submitted for any
degree and is not being currently submitted for any
other degree
Rubianto Indrayudha Amier
TABLE OF CONTENTS
ABSTRACT
ACKNOWLEDGEMENTS
LIST OF FIGURES
LIST OF TABLES
LIST OF PLATES
PAGE
CHAPTER ONE - INTRODUCTION
11 AIM OF THE STUDY
12 PREVIOUS STUDIES
13 HISTORICAL BACKGROUND OF SOUTH SUMATRA BASIN
14 LOCATION AND ACCESS
15 MORPHOLOGY
CHAPTER TWO - TERMINOLOGY AND ANALYTICAL METHODS
21 TERMINOLOGY
22 ANALYTICAL METHODS
221 Sampling
222 Sample Preparation
223 Microscopy
2231 Reflected white light microscopy
and determination of vitrinite
reflectance
2232 Fluorescence-mode microscopy
2233 Maceral analysis
1
2
3
4
7
8
10
10
14
14
15
15
15
17
18
CHAPTER THREE - REGIONAL GEOLOGY AND TECTONIC 19
SETTING
31 REGIONAL GEOLOGY 19
32 STRATIGRAPHY 21
321 The pre-Tertiary rocks 22
322 Lahat Formation (LAF) 23
323 Talang Akar Formation (TAF) 24
324 Baturaja Formation (BRF) 26
325 Gumai Formation (GUF) 28
326 Air Benakat Formation (ABF) 29
327 Muara Enim Formation (MEF) 30
328 Kasai Formation (KAF) 32
33 DEPOSITIONAL HISTORY OF THE TERTIARY SEDIMENTS 33
CHAPTER FOUR - ORGANIC MATTER TYPE OF TERTIARY 38
SEQUENCES
41 INTRODUCTION 38
42 TYPE AND ABUNDANCE 39
421 Lahat Formation 39
422 Talang Akar Formation 41
4221 DOM 41
4222 Coal and shaly coal 42
423 Baturaja Formation 43
424 Gumai Formation 44
425 Air Benakat Formation 45
426 Muara Enim Formation 46
43 RELATIONSHIP BETWEEN RANK AND MACERAL TEXTURES 5 0
AND FLUORESCENCE INTENSITY
CHAPTER FIVE - ORGANIC MATURATION AND THERMAL HISTORY 54
51 INTRODUCTION 54
52 RANK VARIATION AND DISTRIBUTION 55
53 THERMAL HISTORY 61
54 SOURCE ROCKS AND GENERATION HYDROCARBONS 66
541 Source rocks for hydrocarbons 66
542 Hydrocarbon generation 74
5421 Timing of hydrocarbon generation 77
using Lopatin Method
55 POTENTIAL RESERVOIRS 82
CHAPTER SIX - CRUDE OIL AND SOURCE ROCKS GEOCHEMISTRY 85
61 INTRODUCTION 85
62 OIL GEOCHEMISTRY 86
621 Experimental Methods 86
622 Sample fractionation 86
623 Gas chromatography analysis 86
624 Preparation of bc fraction 87
625 Gas chromatography-mass spectrometry 88
analysis
626 Results 88
6261 Gas chromatography 89
6261 Gas chromatography-mass 92
spectrometry
63 SOURCE ROCK GEOCHEMISTRY
631 Experimental Section 9 5
6311 Sample extraction 96
632 Results 96
CHAPTER SEVEN - COAL POTENTIAL OF SOUTH PALEMBANG 100
SUB-BASIN
71 INTRODUCTION 100
72 COAL DIVISIONS IN THE MUARA ENIM FORMATION 101
73 DISTRIBUTION OF MUARA ENIM COALS 103
731 Enim Prospect Areas 104
732 Pendopo Areas 105
74 COAL QUALITY 106
75 ASH COMPOSITION 108
76 STRUCTURES 109
77 COAL RESERVES HI
78 BUKIT ASAM COAL MINES 112
781 Stratigraphy 113
7811 Quarternary succession 113
7812 Tertiary succession 113
78121- Coal seams 113
78122 Overburden and 114
Intercalations
782 Coal Quality 115
783 Coal Reserves 116
79 BUKIT KENDI COALS 117
710 BUKIT BUNIAN COALS
CHAPTER EIGHT - COAL UTILIZATION 120
81 INTRODUCTION 120
82 COMBUSTION 121
83 GASIFICATION 124
84 CARBONISATION 125
CHAPTER NINE - SUMMARY AND CONCLUSIONS 128
91 SUMMARY 128
911 Type 128
912 Rank 131
913 Thermal History 132
914 Source rock and hydrocarbon generation 133
potential
915 Coal potential and utilization 136
92 CONCLUSIONS 137
REFERENCES 143
APPENDIX 1 Short descriptions of lithologies and
organic matter type abundance and
maceral composition from wells studied
APPENDIX 2 Summary of the composition of maceral groups
in the Tertiary sequences from wells studied
ABSTRACT
The South Palembang Sub-basin in the southern part of
the South Sumatra Basin is an important area for coal and
oil production In order to develop the economy of this
region an understanding of the coal and source rock
potential of the Tertiary sequences within the South
Palembang Sub-basin is essential
Collisions between the Indo-Australian and the Eurasian
Plates formed the South Sumatra Basin and particularly
influenced the development of the South Palembang Sub-basin
since the Middle Mesozoic to Plio-Pleistocene
The Tertiary sequences comprise from oldest to youngest
unit the Lahat Talang Akar Baturaja Gumai Air Benakat
Muara Enim and Kasai Formations These sequences were
developed on the pre-Tertiary rocks which consist of a
complex of Mesozoic igneous rocks and of Palaeozoic and
Mesozoic metamorphics and carbonates
Coals occur in the Muara Enim Talang Akar and Lahat
Formations The main workable coal measures are
concentrated in the Muara Enim Formation The Muara Enim
coals are brown coal to sub-bituminous coal in rank while
the Lahat and Talang Akar coals are sub-bituminous to high
volatile bituminous coals in rank From the viewpoint of
economically mineable coal reserves the M2 Subdivision is
locally the most important coal unit Thicknesses of the M2
coals range from 2 to 20 metres The coals can be utilized
for electric power generation gasification but are
generally unsuitable as blends for coke manufacture They
have some potential for the manufacture of activated
carbons
In general coals and DOM of the Tertiary sequences are
dominated by vitrinite with detrovitrinite and telovitrinite
as the main macerals Liptinite is the second most abundant
maceral group of the coals and DOM and comprises mainly
liptodetrinite sporinite and cutinite
The Lahat Talang Akar Air Benakat and Muara Enim
Formations have good to very good hydrocarbon generation
potential The Baturaja and Gumai Formations have less
significant source potential as this unit contains little
organic matter but in some places these formations are
considered to have good potential to generate gas
The vitrinite reflectance data and studies using the
Lopatin model indicate that the onset of oil generation in
the South Palembang Sub-basin occurs below 1500 metres In
general the Gumai Formation lies within the onset of oil
generation zone but in some places the lower part of Air
Benakat and Muara Enim Formations occur within this zone
Crude oil geochemistry shows that the oils are
characterized by high ratios of pristane to phytane
indicating a source from land-derived organic matter The
presence of bicadinane-type resin and oleanane in the oils
is further evidence of a terrestrial source The biomarker
and thermal maturity of the source rocks and coals from the
Talang Akar Formation are similar to those of the oils
studied
ACKNOWLEDGEMENTS
This study was carried out at the Department of
Geology University of Wollongong under the tenure of a
Colombo Plan funded by the Australian International
Development Assistance Bureau (AIDAB) I am thankful to
Associate Professor AJ Wright the Chairman of the
Department for his support and for allowing me to use the
Department facilities during my study This study was
carried out under the supervision of Professor AC Cook and
Associate Professor BG Jones I would like to thank to
Associate Professor BG Jones for his suggestion and
guidance during the finishing of this thesis I am also
grateful especially to Professor AC Cook for introducing
me to the field of organic petrology and also for his
assistance patience guidance and suggestions throughout
this study I wish to record my deep appreciation to Dr
AC Hutton for his suggestion encouragement help and
general assistance during the finishing of this thesis I
also wish to thank all members of the staff of the Geology
Department University of Wollongong for their help
including Mrs R Varga Mr Aivars Depers and Mrs BR
McGoldrick who gave general assistance and helped in
numerous ways
I thank the Government of Indonesia particularly the
Ministry of Mines and Energy for selecting me to accept the
Colombo Plan Award The author also wishes to specially
thank the management and staff of PERTAMINA particularly Ir
M Anwar Ir L Samuel Ir L Gultom Ir HHatuwe and Ir A
Pribadi for allowing me to collect and to use the samples
and technical data from various wells of the South Palembang
Sub-basin I am also grateful to Ir Busono SE Director of
Directorate of Coal and to his predecessor Drs Johannas for
permitting me to study in the Geology Department University
of Wollongong I would like also to thank the staff of the
Directorate of Coal who helped and supported me in this
study
Special appreciation is given to Dr RE Summons Mrs
JM Hope and P Fletcher from the Bureau of Mineral
Resources in Canberra for carrying out oil analyses and
Rock-Eval pyrolysis of the source rocks samples The
assistance and guidance of Dr RE Summons particularly is
gratefully acknowledged
The author wishes to express his gratitude to the
AIDAB staff particularly to the Training Liaison
Officers such as Mr B Rush Mrs G Ward Dr D Engel and Mr
B OBrien and I would like also to thank Mr K Passmore
Ms N Lim and Ms Lisa Huff for the assistances given
during this study
I am thankful to all my colleagues particularly H
Panggabean SM Tobing N Ningrum T Ratkolo B Daulay
Susilohadi Y Kusumabrata K Sutisna R Heryanto B
Hartoyo Herudiyanto A Sutrisman and A Perwira K for
their help support and suggestions during this study
These contributions of all these people are gratefully
appreciated
Finally I am forever grateful to my wife Ida and
daughters Indri and Emil who gave me endless support love
and encouragement during this study
LIST OF FIGURES
Figure 11
Figure 12
Figure 13
Figure 14
Figure 15
Figure 21
Figure 22
Figure 23
Figure 24
Figure 31
Figure 32
Figure 33
Figure 41
Figure 42
Figure 43
South Sumatra coal province and its demonstrated coal resources (after Kendarsi 1984)
Location map of Suraatran back-arc basins
Tectonic elements of South Sumatra Basin (after Purnomo 1984)
Oil well locations and their relationship with major tectonic elements of the South Palembang Sub-basin (after Pulunggono 1983)
Geological features of the Bukit Asam and -surrounding areas and locations of boreholes studied (after Kendarsi 1984)
Flow diagram showing the method for polishing and mounting samples (after Hutton 1984)
Alteration of the macerals during coalification stage (after Smith and Cook 1980)
Diagram showing optical configuration for reflected white light and fluorescence-mode observation used in this study (from AS 2856 1986) Visual aid to assist in the assessment of volumeteric abundance of dispersed organic matter in sediments
Lineaments of subduction zones in western Indonesia (after Katili 1984)
Pre-Tertiary rocks underlying the Tertiary in the South Sumatra Basin (after De Coster 1974)
Distribution of Talang Akar Formation within the South Palembang Sub-basin (after Pulunggono 1983)
Abundance range and average abundance by volume and maceral group composition of DOM shaly coal and coal in the Lahat Formation at five well locations in the South Palembang Sub-basin Abundance range and average abundance by volume and maceral group composition of DON shaly coal and coal in the Talang Akar Formation at ten well locations in the South Palembang Sub-basin Abundance range and average abundance by volume and maceral group composition of DOM in the Baturaja Formation at six well locations in the South Palembang Sub-basin
Figure 44 Abundance range and average abundance by volume and maceral group composition of DOM in the Gumai Formation at ten well locations in the South Palembang Sub-basin
Figure 45 Abundance range and average abundance by volume and maceral group composition of DOM in the Air Benakat Formation at ten well locations in the South Palembang Sub-basin
Figure 46 Abundance range and average abundance by volume and maceral group composition of DOM and coal in the Muara Enim Formation at ten well locations in the South Palembang Sub-basin
Figure 51 Plot of reflectance against depth for samples from the MBU-2 well
Figure 52 Plot of reflectance against depth for samples from the PMN-2 well
Figure 53 Plot of reflectance against depth for samples from the GM-14 well
Figure 54 Plot of reflectance against depth for samples from the KG-10 well
Figure 55 Plot of reflectance against depth for samples from the KD-01 well
Figure 56 Plot of reflectance against depth for samples from the BRG-3 well
Figure 57 Plot of reflectance against depth for samples from the TMT-3 well
Figure 58 Plot of reflectance against depth for samples from the L5A-22 well
Figure 59 Plot of reflectance against depth for samples from the BL-2 well
Figure 510 Plot of reflectance against depth for samples from the BN-10 well
Figure 511 Schematic cross-section A-B through the Muara Enim area showing isoreflectance surfaces
Figure 512 Schematic cross-section C-D through Limau-Pendopo area showing isoreflectance surfaces
Figure 513 Plot of reflectance against depth for samples from South Palembang Sub-basin
Figure 514 Pre-tectonic coalification
Figure 515 Syn-tectonic coalification
Figure 516 Post-tectonic coalification
Figure 517
Figure 518
Figure 519
Figure 520
Figure 521
Figure 522
Figure 523
Figure 524
The relationship between coalification and tectonicsm as proposed by Teichrauller and Teichrauller (1967)
Karweil Diagram showing relationship of time (Ma) temperature ( C) and rank scales (after Bostick 1973) Scale H is used for calculating thermal history of Table 511 and 512 Hydrocarbon generation model for oil and condensate from source rocks containing terrestrial organic matter (after Snowdon and Powell 1982) Pyrolisis data S2OrgC Index which is indicative of the amounts of already generated hydrocarbons show the contribution of inertinites to generation of hydrocarbons The Tmax data showing the maximum decomposition of inertinite-rich kerogens occurs at higher activation energies compared to inertinite-poor kerogens (after Khorasani 1989) The relationship between S1+S2 values and the Score A for samples studied from the Muara Enim Formation and the Talang Akar Formation (after Struckroeyer (1988) Generalized zones of petroleum generation and approximate correlation with maxi mum palaeotemperatures and reflectance of vitrinite exinite and inertinite (from Smith and Cook 1984) Maturation model for the main organic matter groups and sub-groups (from Smith and Cook 1984) Lopatin-type model for the coalification history of the Muara Enim area Assumptions no compaction effect present geothermal gradient assumed to have operated since the Eocene erosion approximately 250 metres Lopatin-type reconstruction of coalification for the Pendopo area Assumptions no compaction effect present geothermal gradient assuramed to have operated since the Eocene erosion approximately 623 metres
Figure 611 N-alkane distribution profile in the saturated fractions in the extracts from the Muara Enim Formation (sample 5383)
Figure 612 N-alkane distribution profile in the saturated fractions in the extracts from the Muara Enim Formation (sample 5384)
Figure 613 N-alkane distribution profile in the saturated fractions in the extracts from the Talang Akar Formation (sample 5385)
Figure 614 N-alkane distribution profile in the saturated fractions in the extracts from the Talang Akar Formation (sample 5386)
Figure 615 The determination of petroleum formation zones by using Tmax (after Espitalie et al 1985)
Figure 616 Modified Van Krevelen diagram using conventional whole-rock pyrolisis data (after Katz et al 1990)
Figure 71 General stratigraphy of the Bukit Asam mining area (after Von Schwartzenberg 1986)
Figure 81 The transportation net of the Bukit Asam coal South Sumatra (after Kendarsi 1984)
Figure 82 Generalized relationship of coke strength and coal rank indicated by vitrinite reflectance and carbon content of vitrinite at constant type (after Edwards and Cook 1972)
LIST OF TABLES
Table 11
Table 21
Table 22
Table 23
Table 24
Table 25
Table 31
Table 32
Table 33
Table 51
Table 52
Table 53
Table 54
Table 55
Table 56
Table 57
Table 58
Oil fields in South Sumatra and their cummulative production until 1966 (after Koesoeraadinata 1978)
Generalized classification of coal rank (from Cook 1982)
Summary of the macerals of hard coals (from ICCP Handbook 1963)
Maceral Groups (Stopes-Heerlen system of nomenclature)
Summary of the macerals of brown coals (from ICCP Handbook 1971)
Proposed coal maceral classification system for coals (Smith 1981)
Stratigraphy of South Sumatra Basin according to some authors
Stratigraphy of South Sumatra Basin used in the present study based on Spruyts Nomenclature (1956)
Stratigraphic column of Muara Enim Formation according to Shell Mijnbouw 1978
Reflectance values and temperature data against depth in the MBU-2 well
Reflectance values and temperature data against depth in the PMN-2 well
Reflectance values and temperature data against depth in the GM-14 well
Reflectance values and temperature data against depth in the KG-10 well
Reflectance values and temperature data against depth in the KD-01 well
Reflectance values and temperature data against depth in the BRG-3 well
Reflectance values and temperature data against depth in the TMT-3 well
Reflectance values and temperature data against depth in the L5A-22 well
Table 59 Reflectance values and temperature data against depth in the BL-2 well
Table 510 Reflectance values and temperature data against depth in the BN-10 well
Table 510A Vitrinite reflectance values of Muara Enim coals measured from core samples
Table 511 Thermal history data from selected wells in the Muara Enim area
Table 512 Thermal history data from selected wells in the Pendopo-Limau area
Table 513 Summary of petrographic features and their significance in relation to oil generation and migration (from Cook and Struckmeyer 1986)
Table 61 Locations of crude oil and cutting samples
Table 62 The composition of the oils in terras of the polarity classes of saturated aromatic hydrocarbons and combined NSO-asphaltene fraction
Table 62A Peak assignments for triterpanes present in Figure 66
Table 63 The composition of saturated normal hydrocarbons determined by GC analysis The data is presented quantitatively and this is related to the peak of the internal standard 3-raethylheneicosane (anteiso C22) giving quantities in ugmg
Table 64 The composition of isoprenoid and bicadinane hydrocarbons determined by GC analysis The data is also presented quantitatively in relation to the peak of the internal standard 3-methylheneicosane (anteiso C22) giving quantities in ugmg(ppt)
Table 65 The composition of the triterpenoid hydrocarbons determined by GCMS
Table 66 The composition of the steroid hydrocarbons and four of the bicadinanes determined by GCMS
Table 67 The composition of the steroid and triterpenoid hydrocarbons and four of the bicadinanes of whole oil determined by GCMS
Table 68 The total organic carbon (TOO rock eval data and the bulk composition of the South Sumatran shalescoals extract
Table 59
Table 610
Table 611
Table 71
Table 72
Table 73
Table 74
Table 75
Table 76
Table 77
Table 78
Table 79
Table 81
Table 82
The composition of saturated hydrocarbons of South Sumatran shalescoals determined by gas chromatography analysis
South Sumatran coalsshales GC results isoprenoids
South Sumatran coalsshales GC results Isoprenoids ugmg Saturates
Coal qualities of the Enim Area (after KOG 1987)
Coal qualities of the Muara Lakitan Area (after Shell 1978)
Coal qualities of the Langaran Area (after Shell 1978)
Coal qualities of the Sigoyang Benuang Area (after Shell 1978)
Coal qualities of the Air Benakat Area (after Shell 1978)
Coal qualities of the Prabumulih Area (after Shell 1978)
Sodium oxide in Ash from the Muara Enim coals (after KOG 1987)
Summary of coal resources in the Enim area (maximum overburden thickness 100 metres to top of the uppermost mineable seam after KOG 1987) Coal qualities of the Kabau Seam from the Bukit Kendi Area after Shell 1978)
The differences in calorific value among the three main maceral groups for four German coals determined by Kroger et al 1957 (after Bustin et al 1983) Comparison of the chemical composition between Lurgi semi cokes and Bukit Asam semi-anthracite coals (after Tobing 1980)
CHAPTER ONE
INTRODUCTION
In the South Sumatra Basin coal occurs in the Muara
Enim Formation Talang Akar Formation and Lahat Formation
The main workable coal measures are concentrated at two
horizons within the Muara Enim Formation Ziegler (1918)
recognized that the lower horizon comprised (from top to
bottom) the Mangus Suban Petai Merapi and Keladi seams
and the upper horizon comprized a composite set of coal
seams called the Hanging seam The seams are in the range
of some metres to more than 10 metres in thickness
The South Sumatra Basin also plays a role as an
important oil producing area Recently there has been
considerable discussion on the oil generation potential of
coals The Talang Akar Formation has been postulated as a
source rock for oil because of the close association of coal
measures and many of the oil pools in areas such as South
Palembang Sub-basin
Oil production in South Sumatra was established in the
late 19th century from the Air Benakat Formation In 1922
bullhe petroleum company Stanvac established production from
the Talang Akar Formation The South Palembang Sub-basin is
one of the oil and gas producing areas in South Sumatra
In the present study organic petrography was used to
determine the coal type and rank and to define the potenshy
tial of source rocks and maturation level of the organic
2
matter in the Tertiary sequences of the South Palembang
Sub-basin
11 AIM OF THE STUDY
In general the aim of the present study is to assess
the rank and abundance of coal and dispersed organic matter
in the Tertiary sequences of the South Palembang Sub-basin
The study is based on petrological research both on macerals
in the coals and the relatively abundant dispersed organic
matter in the clastic sedimentary sequences The scope of
this study is to
1 describe and interpret coal type and rank trends in
the South Palembang Sub-basin
2 assess the abundance and composition of organic
matter contained in the stratigraphic sequences
3 determine the maturity of the organic matter and to
evaluate the lateral and vertical rank variations
within the South Palembang Sub-basin
4 relate coal rank variation to coalification
histories
5 define hydrocarbon source potential of the various
stratigraphic units and lithologies
6 attempt correlations of potential source rocks with
reservoired hydrocarbons and
7 draw inferences concerning the future economic
potential of coal and hydrocarbons in the South
^alembang 5ub-basin
12 PREVIOUS STUDIES
The geology of the South Sumatra Basin is relatively
well known from numerous publications (Wenneckers 1958
Jackson 1960 Pulunggono 1969 Todd and Pulunggono 1971
De Coster 1974 Harsa 1975 Pulunggono 1983) especially
the general geology of this area primarily in connection
with the search for oil and gas
Many authors have also described the potential of the
coal measures of South Sumatra including Ziegler (1918)
Koesoemadinata (1978) and Kendarsi (1984) Furthermore a
large exploration campaign was run from 1973 to 1979 by
Shell Mijnbouw NV covering an area of 71450 sq km in South
Sumatra (Fig11)
In general the earliest attempts to examine the
organic matter in sedimentary rocks were made by oil
companies to define the maturation level of the source
rocks (Shell 1978a Total Indonesie 1988 Sarjono and
Sardjito 1989 Daulay (1985) in his Masters thesis
studied the petrology of South Sumatra coals especially the
Muara Enim coals from the Bukit Asam coal mines and from
other places surrounding the mine area
In the framework of the execution of REPELITA III (Five
Year Development Plan) 1979-1984 the Lahat Geological
Quadrangle (1012) was mapped by the Geological Research and
Development Center in co-operation with PERTAMINA an
Indonesian state-owned oil company The geological map is
at a scale of 1250000 and covers an area of about 18700
sq km
13 HISTORICAL BACKGROUND OF SOUTH SUMATRA BASIN
South Sumatra Basin is one of the most important oil
and coal producing areas on the island of Sumatra South
Sumatras oil production started as early as 1898 from the
regressive sands of the Air Benakat Formation The first
fields were small and shallow and close to surface seeps on
exposed anticlines Surface structure has for many years
guided most of the exploration
In 1922 Stanvac established production from the
transgressive sands of the Talang Akar Formation which have
subsequently been the main exploration objective in South
Sumatra Between 1938-1941 Kuang-1 Ogan-3 and Musi-1
wells were drilled by BPM In these wells gas had been
encountered in the Baturaja Formation Moreover in 1959
BPM completed well Limau-5A144 as the first oil producer
from the Baturaja Limestone reservoir in South Sumatra
In the South Sumatra Basin many oil companies are
operating at the present time under production sharing
agreements with PERTAMINA They include Jarobi Oil Jambi
Shell Trend Sumatra Ltd Caltex British Petroleum Asamera
and Stanvac PERTAMINA also operates in its own right
In general the oil fields are clustered into three
structural sub-basins the Jambi Sub-basin the Central
Palembang Sub-basin and the South Palembang Sub-basin
(Fig13) According to PERTAMINA (1986) there are 57 oil
fields within the South Sumatra Basin
The maximum oil production capacity from the basin was
62200 BOPD and the cumulative production was 1680 MMBO on
1-1-1985 The occurrences of oil and gas in the South
Sumatra Basin largely occur in the Talang Akar Formation
(93) with 3 in the Air Benakat Formation and a few
occurrences in reefs of the Baturaja Formation the Gumai
Formation and from sandstones in the Muara Enim Formation
(Anwar Suseno 1988)
The Talang Akar Formation generally produces a paraffin
based oil ranging from 35 to 37deg API (Koesoemadinata 1978)
but the gravity ranges between 21 and 51deg API The Baturaja
Formation typically produces oil which has an API gravity of
373 Oil is also produced from the Air Benakat Formation
and this is a low to medium paraffin-based oil 45-54 API
However from the same producing formation an
asphaltic-based oil 22-25deg API is produced in Jambi and
these low gravity oils are biodegraded Table 1 shows some
of oil fields in South Sumatra and their cumulative
production until 1966 (Koesoemadinata 1978)
About 6 billion tons of coal reserves have been
demonstrated in the South Sumatra Basin These consist
6
mainly of hard brown coal and are clustered into several
areas Figure 11 also shows the coal potential of South
Sumatra Basin
In Tanjung Enim area coal has been mined since 1919 in
underground as well as open pit mines the underground
workings were abandoned in 1942 These coal mines are
situated in Muaraenim Regency about 180 kilometres west of
Palembang and production comes mainly from the Mangus Suban
and Petai seams of the Muara Enim Formation These coals
are mainly hard brown coals but in the immediate vicinity
of some andesite intrusions the coals reach anthracitic
rank According to Schwartzenberg (1986) the Bukit Asam
Coal Mine has potential reserves of about 112 million tons
which comprise about 1 million tons of anthracite 45
million tons of bituminous coals and 66 million tons of
subbituminous coal
The open pit was restricted to small areas with very
favorable stripping ratios and draglines were used to remove
part of the overburden until the late fifties From 1940 to
1982 the open pit mine was operated by means of power
shovels and trucks and a small belt conveyor system for coal
haulage Development of the Bukit Asam Coal Mine began in
1985 when a modern system of bucket wheel excavator
operations with belt conveyors and spreaders was installed
The mine is operated by the state-owned Indonesian company
PT Persero Batubara Bukit Asam
7
14 LOCATION AND ACCESS
Geologically the study area is located in the South
Palembang Sub-basin which lies in the southern part of the
South Sumatra Basin (Figure 12) This sub-basin is bounded
to the south by the Lampung High and to the north by the
Pendopo High Eastward the South Palembang Sub-basin is
bounded by the Iliran High and to the west by the Barisan
Mountains (Figure 13) The Palembang Sub-basin covers
approximately 125 x 150 kilometres (Pulunggono 1983)
The samples studied were collected from oil exploration
wells and coal exploration boreholes which are situated in
various oil and coal fields within the South Palembang
Sub-basin The oil fields are as follows Prabumenang
Meraksa Kuang Kedatoh Beringin Tanjung Miring
Limau and Belimbing (Figure 14) Mostly the oil
exploration wells were drilled by PERTAMINA but some old
exploration wells were drilled by StanvacBPM
In general the oil exploration wells used in this
study penetrated a high proportion of the Tertiary sequences
and some reached basement The initials depth and year of
drilling of exploration wells drilled by PERTAMINA are as
follows GM-14 1398 m 1969 KG-10 15758 m 1970 PMN-2
19596 m 1972 KD-1 18585 m 1976 BN-10 2565 m 1977
BRG-3 2300 m 1987 MBU-2 2200 m 1988 The three wells
drilled by StanvacBPM are L-5A22 2287 m 1954 ETM-3
1633 m 1959 and BL-2 1675 m 1965
8
Coal core samples were collected from seven
exploration boreholes drilled between 1986-1988 by the
Directorate of Coal in several coal fields such as Suban
Jerigi Banko Tanjung Enim Muara Tiga Arahan and
Kungkilan (Figure 15) The maximum depths reached by these
coal exploration boreholes range from 100 to 200 metres and
all were drilled within the Muara Enim Formation section
These boreholes are annotated as KLB-03 AU-04 AS-12
BT-01 KL-03 MTS-0 6 and SN-04
Administratively the study area falls under Lematang
Ilir Ogan Tengah Regency and Lahat Regency which are
situated in the western part of the South Sumatra Province
The study area includes the Lahat Quadrangle which is
bounded by the longitudes 103deg 30-105deg 00E and latitudes
03deg 00-04deg 00S (Gafoer et al 1986)
The population of this area is sparse with 404
inhabitants per square kilometres (Central Bureau of
Statistics 1978) Principally the population is
concentrated in various towns such as Prabumulih Muaraenim
and Lahat
In general the area is covered by dense vegetation
particularly the hills and swamps Irregular clearings are
also found in some places for agriculture and cash-crop
cultivation such as rubber coffee and pineapples
Wildlife such as tigers bears crocodiles elephants and
monkey roam the jungle in this area but their numbers are
dwindling In order to save these species they are now
9
protected by law
Transport to other areas is by car rail and boat
Pendopo especially can be also reached by air transport
with regular services run by PT Stanvac Indonesia A
railroad connects Palembang with Prabumulih Baturaja
Muaraenim Lahat and Tanjung Enim The roads in this area
are partly unsurfaced and therefore are muddy when wet at
which time they are passable only by four-wheel drive
vehicles
15 MORPHOLOGY
Morphologically this area can be divided into three
units the mountainous area the rolling country and the
plain The mountainous area occupies the western corner of
the Quadrangle with summits such as Bukit Besar (735 m) and
Bukit Serelo (670 m) The slopes in this area are generally
steep the valleys narrow and locally cascades occur in the
rivers Braided streams develop in the foothill areas
The rolling country occupies half of the western
portion of the quadrangle with summits reaching heights of
some 250 metres The slopes are generally gentle The
rivers have wide valleys are meandering and have deeps on
many bends The drainage pattern is dendritic
The low-lying plain area occupies the eastern portion
of the quadrangle and is characterized by meandering streams
and dendritic drainage patterns Elevations on the plain
range from 0 to about 50 meters
10
CHAPTER TWO
TERMINOLOGY AND ANALYTICAL METHODS
21 TERMINOLOGY
According to the International Committee for Coal
Petrology (1963) coal can be defined as a combustible
sedimentary rock formed from plant remains in various stages
of preservation by processes which involved the compaction
of the material buried in the basins initially at moderate
depth These basins are broadly divided into limnic (or
intra-continental) basins and paralic basins which were
open to marine incursions As the underlying strata
subsided progressively and more or less regularly but
sometimes to great depths the vegetable debris was
subjected to the classical factors of general metamorphism
in particular those of temperature and pressure
Based on this definition generally it can be concluded
that there are two basic factors involved in the formation
of coal firstly the type of peat-forming flora and
depositional environment and secondly the degree of
alteration which is a function of time temperature and
pressure In coal petrology these factors determine the
variables termed type and rank
According to Cook (1982) these variables can
essentially be considered as independent because the type of
a coal has no influence upon its rank and the reverse is
11
also true Cook (1982) also considered that in coal
petrography or more broadly in organic petrography the term
type is related to the nature of the organic matter found in
a coal or sedimentary rock
In addition Hutton (1984) stated that type is a
function of both the type of precursor organic matter that
was deposited as peat and the nature and degree of
alteration that peat components underwent during the early
stages of diagenesis which is a response to the first
(biochemical) stage of coalification (Stach 1968 Cook
1982)
Rank generally refers to the stage of coalification
that has been reached by organic matter In coal
particularly rank can be defined as the relative position
of a coal in the coalification series of peat through the
stages of the different brown coals (lignite)
sub-bituminous and bituminous coals to anthracites and
finally meta-anthracites semi-graphite and graphite
The term rank has been accepted as an international
scientific term The International Committee for Coal
Petrology (ICCP) in the second edition of the International
Handbook of Coal Petrography (1963) suggested degree of
coalification as a synonym for rank In coal petrology
the rank of coal is measured by the reflectance of
vitrinite The reflectance of vitrinite increases as the
rank of coal increases (Table 21)
Petrographic variation of coal can be assessed in tei jrms
12
ypound maceral groups (Stopes 1935) microlithotypes (Seyler
1954) or lithotypes (Stopes 1919 Seyler 1954) Macerals
are the microscopically recognizable components of coal and
are predominantly defined by morphology color and
reflectance in reflected light Macerals are analogous with
the minerals of rocks The ICCP (1963) concepts for
macerals are most closely applicable to Carboniferous black
coals because they were based on these coals (Table 22)
However Smith (1981) showed that the basic concepts of
macerals can be also applied to coals of Tertiary age
The term microlithotype was proposed by Seyler (1954)
to describe typical maceral associations as seen under the
microscope (minimum band width 005 mm) Lithotypes are
macroscopically recognizable bands visible within a coal
seam
On the basis of morphology optical properties and
origin macerals can be divided into three main maceral
groups vitrinite inertinite and liptinite The origin
properties and subdivision of these three groups are shown
in Table 23
Brown et al (1964) divided vitrinite into two groups
vitrinite A and vitrinite B Furthermore Hutton (1981) and
Cook et al (1981) proposed additional terms for alginite
within the liptinite group
The International Committee for Coal Petrology in the
International Handbook of Coal Petrography (1971 1975) has
classified macerals of brown coal as shown in Table 24
^3
This classification has been modified by Smith (1981) as
shown in Table 25 He recognized that the huminite maceral
group of the ICCP classification represents the same
material as the vitrinite maceral group but at an earlier
stage of maturation The system proposed by Smith (1981)
has been adapted in its basic form as the system used in the
Australian Standard for Coal-Maceral Analysis (AS
2856-1986)
In addition Cook (1982) also discussed the term
bitumen which was termed eubitumen by Potonie (1950) In
the International Handbook of Coal Petrography (1963 1971)
bitumen is still described as resinite which has a very low
melting point Bitumen can be mainly recognized at the
sub-bituminousbituminous coal boundary (Teichmuller 1982)
Teichmuller (1982) also noted that bitumen develops from
lipid constituents of liptinites and huminites and generally
occurs in vein-form or as fillings of bedding plane joints
but sometimes it fills in empty cell lumens Furthermore
Cook (1982) stated that bitumen is the term applied to all
natural substances of variable color hardness and
volatility which are composed of a mixture of hydrocarbons
substantially free from oxygenated bodies He added that
bitumens are generally formed from the degradation of
natural crudes by processes such as microbial attack
inspissation or water-washing Asphalts natural mineral
waxes asphaltines and petroleum are all considered to be
bitumens Cook (1990 perscoram) also
14
considered that some bitumens (including the maceral
exsudatinite) represent primary generation products
Impsonitic bitumens generally result from the alteration of
reservoired oil probably dominantly but not exclusively
during the process of deasphalting
The coal petrographic terms used in the present study
follow those described by the Australian Standard for Coal
Maceral Analysis (1986)
22 ANALYTICAL METHODS
221 SAMPLING
As mentioned in the previous chapter the core and
cuttings samples studied were cbllected from various coal
fields and oil fields in the South Palembang Subbasin area
(Table 25) Sampling has mainly focused on the Muara Enim
Formation the Talang Akar Formation and the Lahat
Formation
Samples were taken to give as wide a lateral and
vertical coverage of the sequences which are rich in organic
matter (coal-rich or coal) as possible However samples i
were also collected from other formations to examine the
degree of coalification and the origin of organic matter
occurring in these sequences Composite samples which were
taken through the entire thickness of a coal seam have been
obtained from cores from shallow boreholes Cuttings
samples were collected from oil exploration wells over
intervals ranging between 20 to 50 metres for coal-bearing
sequences and 50 to 200 metres for non coal-bearing
sequences Sampling was based on the procedure of the
Standards Association of Australia (1975) In addition
four oil samples were also collected from BRG-3 well (2
samples) and MBU-2 well (2 samples) These samples were
recovered from the Baturaja Formation ( both MBU-2 samples)
Talang Akar Formation and Lahat Formation (BRG-3 samples)
222 SAMPLE PREPARATION
The method of preparation of polished particulate coal
mounts for microscopic analysis is shown in Figure 21 All
samples examined are listed in the University of Wollongong
grain mount catalogue and where blocks are cited in this
study the catalogue numbers are used
223 MICROSCOPY
2231 Reflected white light microscopy and determination
of vitrinite reflectance
Vitrinite reflectance measurements on the samples were
made under normal incident white light using a Leitz
Ortholux microscope fitted with a Leitz MPV-1
microphotometer All measurements were taken using
monochromatic light of 546 nm wavelength in immersion oil
16
(DIN 58884) having a refractive index of 1518 at 23 - ldegc
In order to calibrate the microphotometer synthetic
garnet standards of 0917 and 1726 reflectance and a
synthetic spinel standard of reflectance 0413 were used
The maximum vitrinite reflectance was obtained by rotating
the stage of the microscope to yield a maximum reading and
then the stage was rotated again through approximately 180deg
for the second maximum reading The results of these
measurements were averaged and the mean calculated to give
the mean maximum vitrinite reflectance in oil immersion
(Rvmax)
ICCP (1971 1975) and Stach et al (1982) recommended
that one hundred measurements should be taken to obtain a
precise mean value Determination of R max standard
deviations for a number coals showed that the standard error
of the mean approaches the precision of the measurement
standards where twenty readings have been taken
Therefore in the present study thirty to forty readings
were taken on the coal
Brown et al (1964) also recommended that the most
accurate method of reflectance measurement is achieved by
measuring vitrinite A (Telinite + Telocollinite) However
selective measurement of one vitrinite type is generally not
possible with dispersed organic matter In general
vitrinite macerals give the best measurements in relation to-
rank assessment because they undergo changes
consistenly with rank (Smith and Cook 1980) and show less
17
inherent variability in reflectance according to type (Brown
et al 1964) (Figure 22) compared to liptinite and
inertinite
2232 Fluorescence-mode Microscopy
In order to provide information on organic matter type
liptinite abundance and maturity fluorescence-mode
examination was carried out on all samples by using a Leitz
Orthoplan microscope with a TK40 0 dichroic beam splitting
mirror fitted in an Opak vertical illuminator The
fluorescence-mode filter system comprised BG3 and BG38
excitation filters and a K490 suppression filter Figure
23 shows the optical system for reflected and fluorescence
microscopy used in this study (modified from AS2856 1986)
A Leitz Vario-Orthomat automatic camera system which is
fitted to the Leitz Orthoplan microscope was used to take
photographs of the samples The camera system has a 5 to
125X zoom which provided a wide range of magnification
Kodak Ektachrome 400ASA21DIN reversal film was used for all
color photographs Fluorescence-mode photographs were taken
in oil immersion using the BG3BG38TK400K490 filter
system Photographs were also taken in normal incident
white light with the same type of film used for fluorescence
mode
18
2233 Maceral Analysis
Conventional point count techniques for maceral
analysis in coal and coal-rich block samples were carried
out using an automatic point counter and stage The traverses
were made on the surface of the samples The total surface
area of the block sample traversed was 2 cm x 2 cm and the
yrain density was about 50 Approximately 300 points were
counted for each maceral analysis under reflected white
light and fluorescence mode The volumetric abundance of
various maceral groups was expressed as a percentage of the
total points recorded
Visual approximations of the abundance of dispersed
organic matter in each grain mount sample were also made by
assessing volumetric abundances as illustrated in Figure
24 The total dispersed organic matter (DOM) abundance was
visually estimated in approximately 50 grains from several
traverses across each block This method was first
described by Padmasiri (1984) and later modified by
Struckmeyer (1988) The method used in this study is based
on the Struckmeyer modification (1988) The total dispersed
organic matter abundance is calculated using the equation
2 (y x a)
V = where V = volume of a specific maceral
n occurring as dispersed organic matter
y = number of grains containing the maceral in a given
abundance category n = number of grains counted
bullgtbull n
CHAPTER THREE
REGIONAL GEOLOGY AND TECTONIC SETTING
31 REGIONAL GEOLOGY
South Sumatra Basin is one of the Sumatran back-arc
basins located along the island of Sumatra These basins
came into existence as a consequence of the interaction
between the Sunda Shield as part of the Eurasian plate and
the Indo-Australian plate (Katili 1973 1980 De Coster
1974 Koesoemadinata and Pulunggono 1975 Pulunggono 1976
Hamilton 1979 Pulunggono 1983) Oblique collision and
subduction has occurred along this margin since the Late
Cretaceous (Figure 31)
The South Sumatra Basin is an asymmetric basin bounded
to the west and south by faults and uplifted exposures of
pre-Tertiary rocks along the Barisan Mountains to the north
east by the sedimentary or depositional boundaries of the
Sunda Shelf The south-east boundary is represented by the
Lampung High the northern boundary however is poorly
defined as the South Sumatra Basin is connected to the
Central Sumatra Basin by a series of Tertiary grabens
although the Tiga Puluh Mountains are generally taken to be
the boundary between the two basins (Figure 12) The South
Sumatra Basin occupies an area of roughly 250 by 400 km (De
Coster 1974)
The tectonic features present in the South Sumatra
20
Basin are the result of Middle Mesozoic to Plio-Pleistocene
orogenic activity (Katili 1973 1980 De Coster 1974
Koesoemadinata and Pulunggono 1975 Pulunggono 1976
Hamilton 1979 Pulunggono 1983) These orogenic
activities were primarily related to the collision and
subduction of the Indo-Australian plate underneath the
Sumatra portion of the Eurasian plate
The Middle Mesozoic orogeny was the main cause of the
metamorphism affecting Palaeozoic and Mesozoic strata
These strata were faulted and folded into large structural
blocks and subsequently intruded by granite batholiths with
postulated extensions in the subsurface parts of the basins
Pre-Tertiary features combine to form the basic northwest to
southeast structural grain of Sumatra
In Late Cretaceous to Early Tertiary time the second
significant tectonic event occurred when major tensional
structures including grabens and fault blocks were formed
in Sumatra and the adjoining Sunda Basin The general trend
of these faults and grabens is north to south and
north-northwest to south-southeast
The last tectonic phase was the Plio-Pleistocene
orogeny which caused the uplift of the Barisan Mountains and
the development of major right lateral wrenching through the
length of these mountains The most prominent structural
features within this Tertiary sedimentary basin are
northwest trending folds and faults
Structurally the South Sumatra Basin is subdivided
21
into four sub-basins as seen in Fig12
- Jambi Sub-basin
- North Palembang Sub-basin
- Central Palembang Sub-basin and
- South Palembang Sub-basin
32 STRATIGRAPHY
Regional stratigraphic terminologies for the South
Sumatra Basin have been proposed by several authors such as
Musper (1937) Marks (1956) Spruyt (1956) De Coster
(1974) Pulunggono (1983) and Gafoer et al (1986) as shown
in Table 31 The stratigraphic nomenclature used in this
thesis is based primarily on that of Spruyt (1956) because
Spruyts nomenclature has been widely accepted as the basis
for rock stratigraphic subdivisions but alternative
nomenclature has also been developed (Table 32)
All these authors considered that two phases of
sedimentation took place in the South Sumatra Basin they
were the Paleogene and Neogene cycles With the onset of
clastic deposition in the Paleogene basement depressions
and fault grabens became filled Harsa (1975) pointed out
that the whole sequence of basin fill represents one major
transgressive-regressive sedimentary cycle which was
accompanied by periodic volcanic activity and periodic
movement along lines of basement faults
The Tertiary sequences were developed on the
22
pre-Tertiary surface of eroded igneous and metamorphic
rocks The pre-Tertiary rocks are generally considered as
economic basement for the basin in terms of oil exploration
321 THE PRE-TERTIARY ROCKS
Pre-Tertiary rocks crop out extensively both on the
Sunda Shield and in the Barisan Range Minor outcrops also
occur in uplifts within the Tertiary retro-arc basins
These rocks generally consist of a complex of Mesozoic
igneous rocks and of Paleozoic and Mesozoic metamorphic
rocks and carbonates (Adiwidjaja and De Coster 197 3)
Adiwidjaya and De Coster (197 3) have also distinguished
the basement rocks in the South Sumatra Basin as shown in
Figure 32 They mapped the subcrop of the pre-Tertiary
rocks in broad zones termed Zone A B C D and E
Zone A consists of Permo-Carboniferous metamorphic
rocks including phyllites slates argillites quartzites
and gneisses and occasional limestones These rocks were
intruded by diorite and granite batholiths
Zone B consists of Mesozoic metamorphic rocks including
phyllites quartzite slates These rocks are locally
intruded by granite In Bangka Island and other islands
northeast of Sumatra Triassic metamorphic rocks crop out
extensively and they are intruded by granite batholiths of
possible Jurassic age
Zone C consists of Mesozoic metasedimentary rocks and
23
limestones associated with mafic igneous rocks such as
diabase serpentine andesite and tuffs The limestones
have been dated as Early Cretaceous or possibly Late
Jurassic age
Zone D consists of micritic limestone which is
interpreted as possibly Cretaceous age
Zone E consists of a band of irregular width of
granite syenite and diorite
The main structural trends shown in the basement rocks
are NW-SE and NE-SW According to Adiwidjaja and De Coster
(1973) the structural features of the pre-Tertiary roctes
probably formed during the folding of the Palaeozoic and
Mesozoic strata by the Mesozoic orogeny
322 LAHAT FORMATION (LAF)
The name Lahat Series was proposed firstly by Musper
(1937) for a sequence of andesitic tuffs and andesitic
breccias which crop out upstream of Air Kikim The type
locality is situated in the western part of the town of
Lahat about 150 kilometres southwest of Palembang City At
this location the Lahat Formation lies unconformably upon
the pre-Tertiary basement rocks which are indicated as
Cretaceous
Sediments of the Lahat Formation show angular grains of
coarse sand to pebble size mainly comprising volcanic
fragments and unstable minerals In the central part of the
24
basin the Lahat Formation comprises grey-brown to dark grey
shales interbedded with light green-grey to light blue-grey
tuffaceous shales siltstones and some tuffaceous sandstones
and coals Thin limestone and dolomite stringers and
glauconite are occasionally present (De Coster 1974)
Based on the lithology of this formation it is thought
to represent a continental phase of deposition in fresh
water to brackish limnic environments This interpretation
has also been supported by the discovery of fish remains
fresh water molluscs and pyrite from the Kepayang-1 well
(Pulunggono 1983)
The thickness of the Lahat Formation is strongly
controlled by the palaeotopography and fault blocks In the
south part of the basin the thickness of the Lahat
Formation is typically more than 765 metres whereas about
1070 metres was found in the central part of the basin
(Adiwijaya and De Coster 1973) At the type locality the
formation reaches about 800 metres in thickness (Pulunggono
1983)
The age of the Lahat Formation is interpreted to be
Eocene to Early Oligocene based on the spore-pollen analysis
and KAr radiometric dating methods (De Coster 1974)
323 TALANG AKAR FORMATION (TAF)
The Talang Akar Formation represents the second phase
of Tertiary deposition in the South Sumatra Basin and
25
contains a continental fluviatile sequence composed of
thickly bedded very coarse to coarse sandstones
alternating with thin shales and some coals The grit-sand
facies was firstly recognized by Martin (19 52) from the
borehole data of the Limau 5A-3 well and was also named the
Talang Akar Stage
The lower part of the sequence generally consists of
coarse to very coarse-grained sandstone alternating with
thin layers of brown to dark grey shale and coal Fossils
are not found in this lower sequence The upper part is
dominated by alternations of sandstone and non-marine shale
with some coal seams The shales are grey to dark grey in
colour and the sequence becomes more marine upwards as
indicated by the presence of glauconite and carbonate and
the absence of coal layers
Some fossils of molluscs crustaceans fish remains and
Foraminifera are found in the upper part of the sequence
unfortunately they are not diagnostic fossils in terms of
stratigraphic age
Based on these features the Talang Akar Stage was
further divided by Spruyt (1956) into two members the
Gritsand Member (the lower part) and the Transition Member
(the upper part) Jackson (1960) reported that the
Gritsand Member varies considerably in thickness from zero
to at least 610 metres whereas the Transition Member
ranges between 61 to 360 metres Figure 33 shows the
distribution of the Talang Akar Formation in the South
2fi
Palembang Sub-basin in terms of thickness
Lithologys and fauna of the Talang Akar Formation
indicate a fluvio-deltaic environments passing upwards into
paralic then into a marine environments (De Coster 1974
Pulunggono 1983)
On the basis of some palaeontological and palynological
studies and also by stratigraphic position the Talang Akar
Formation has been dated as Late Oligocene to Early Miocene
(De Coster 1974) Pulunggono (1983) reported that the age
of the Talang Akar Formation can be dated using the
Planktonic Foraminiferal Zones of Blow (1969) as N3 to lower
N5 (Late Oligocene to lower part of Early Miocene)
324 BATURAJA FORMATION (BRF)
The Baturaja Formation was formerly known as Baturaja
Stage This term was introduced by Van Bemmelen (1932) to
distinguish the carbonate facies of the lower part of Telisa
Layer as proposed by Tobler (1912) He recognized firstly
the Baturaja sequence at Air Ogan near Baturaja town about
180 kilometres south of Palembang City
In most areas of the basin the Baturaja Formation lies
conformably upon the Talang Akar Formation In general the
Baturaja Formation is a platform carbonate including some
coral reefs which were developed on palaeo-highs especially
at the edge of the basin Towards the basin margins the
limestones grade into calcareous clays and fine to medium
sands
According to Simbolon (1974) in Air Ogan the Baturaja
Formation can be subdivided into two divisions a lower
bedded and an upper massive unit separated by calcareous
shales The bedded unit consists of lime mudstones and lime
wackestones intercalated with marls while the massive unit
consists of mudstones wackestonespackstones and
boundstones with abundant large Foraminifera in the upper
part
The Baturaja Formation occurs only on the broad shelf
and platform areas of the basin In some areas this
formation was not deposited In structural high areas the
Baturaja Formation was deposited directly upon the
pre-Tertiary basement rocks
The thickness of the Baturaja Formation is strongly
variable depending on the palaeotopography from about 60
to as much as 200 metres thick In the Limau Anticlinorium
area the Baturaja Formation reaches 60 to 75 metres in
thickness while well data from Benuang Raja Pagardewa and
Prabumenang show the maximum thickness reached is about 200
metres (Pulunggono 1983)
Based on the presence of Spiroclypeus especially
Spiroclypeus orbitoideus and Spiroclypeus tidoenganensis
the lower part of the Baturaja Formation is dated as
Aquitanian (lower part of Early Miocene) while the upper
part is dated as Burdigalian (middle to upper part of the
Early Miocene) to Lower Langhian (lower part of Middle
Miocene) on the basis of the presence of Eulepidina and the
28
absence of Spiroclypeus fauna (Adiwidjaya and De Coster
1973) Pulunggono (1983) inferred that on the basis of the
Planktonic Foraminiferal Zonation (Blow 1969) the age of
the Baturaja Formation is probably N5-N8 (lower part of
Early Miocene-lower part of Middle Miocene)
325 GUMAI FORMATION (GUF)
The most widespread rock sequence occurring in the
Tertiary is the Gumai Formation which was deposited during
the maximum phase of the marine transgression Formerly
this formation was named by Tobler (1906) as Gumai Schiefer
for the shale sequence which crops out at Gumai Mountain
near Lahat town During the fifties oil companies termed
this sequence the Upper Telisa but then the name was
changed to Gumai Formation
In general the Gumai Formation is characterized by
fossiliferous typically globigerinal marine shale
including minor intercalations of limestones and sandstones
(De Coster 1974) At the type locality it comprises
tuffaceous marl layers alternating with some marly limestone
layers (Pulunggono 1983) In Limau area a dark grey
shale bituminous and containing thin layers of marl and
marly sandstone from the Gumai Formation was penetrated by
some boreholes
Faunas such Bolivina and Uvigerina are common in the
Gumai Formation De Coster (1974) believed the Gumai
29
Formation was deposited in warm neritic conditions which
were indicated by the presence of these faunas combined
with the widespread occurrence of glauconitic foraminiferal
limestone
The thickness of the Gumai Formation varies greatly
with basin position In the Palembang Sub-basin the
thickness of the Gumai Formation varies from about 15 0 to
500 metres but in the Lematang Depression it reaches about
2500 metres (Pulunggono 1983)
The age of the Gumai Formation can be dated by using
the Planktonic Foraminiferal Zonation from Blow (1969) as -N9
to N12 ( lower part of Middle Miocene to middle part of
Middle Miocene Pulunggono 1983)
326 AIR BENAKAT FORMATION (ABF)
The Air Benakat Formation corresponds with the onset of
the regional regressive phase In general this formation
comprises- shale with glauconitic sandstones and some
limestones deposited in a neritic to shallow marine
environment
Formerly the Air Benakat Formation was named by Tobler
(1906) as the Onder Palembang but this name was changed by
Spruyt (1956) to the Air Benakat Formation The upper part
of this formation is dominated by tuffaceous sandstones
alternating with marl or glauconitic sandstones Tuffaceous
claystones and sandstones are dominant in the middle part
3n
while the lower part consists mostly of claystone
According to Pulunggono (1983) the thickness of Air
Benakat Formation ranges from 100 to 1100 metres In the
Limau area about 600 metres of Air Benakat Formation was
penetrated by Limau 5A-156 well (Pulunggono 1983)
The age of the Air Benakat Formation can be interpreted
using the Planktonic Foraminiferal Zonation from Blow as
Nll12 to N16 (middle part of Middle Miocene to lower part
of Late Miocene Pulunggono 1983) In most reports it has
been interpreted to be mostly Late Miocene in age (De
Coster 1974)
327 MUARA ENIM FORMATION (MEF)
The Muara Enim Formation was first described as the
Midden Palembang Series by Tobler in 1906 at the type
locality Kampung Minyak near Muara Enim town At this type
locality the formation comprises three lithological
sequences coal units claystone units and sandstone units
This formation lies conformably upon the Air Benakat
Formation Haan (1976) further divided the Muara Enim
Formation into two members Member A and Member B During
the Shell Mijnbouw Coal exploration program in 1978 the
stratigraphic column of the Muara Enim Formation was further
modified and the members have been divided into four
divisions
- M4 comprises an upper coal division corresponding to
31
the Hanging Coals
- M3 comprises the middle clay sand and coal division
- M2 comprises the middle coal division corresponding
to the MangusPangadang coals
- Ml comprises the lower clastic and coal division
Table 33 shows the stratigraphic column of the Muara
Enim Formation These divisions can be recognized
throughout most of the South Sumatra Basin with apparent
wedging out of the upper and middle coal divisions on the
basin margins Shell Mijnbouw (197 8) reported that the coal
seams of the middle and lower divisions are more widespread
and thinner than the seams of the upper division due to a
shallow marine influence during sedimentation
The lower boundary of the Muara Enim Formation was
first defined by Tobler(1906) at the base of the lowest coal
band in the South Palembang area (the Kladi coal) but this
definition could not be applied to the North Palembang and
Jambi areas where the coals are less well developed
Another criterion used by oil industry geologists to define
the boundary is the top of the continuous marine beds or the
base of the first non-marine beds the base of the
non-marine beds can be recognized by the presence of
arenaceous units displaying coal lenses and a lack of
glauconite
The Mangus seams of the M2 division have good marker
features especially a clay marker horizon which can be
recognized over a wide area This clay marker contains
32
discoloured biotite which was deposited over a wide area
during a short interval of volcanic activity and it can be
used to correlate the coal seams over most of the South
Sumatra Basin
Fossils are rare in the Muara Enim Formation
Therefore the determination of the Muara Enim Formation age
is mainly based on its regional stratigraphic position
rather than palaeontological data Baumann et al (197 3)
determined the age of the formation as Late Miocene to
Pliocene on the evidence of its regional stratigraphic
position and the palaeontological data admittedly rather
poor of lamellibranchs and arenaceous Foraminifera On the
basis of Planktonic Foraminiferal Zonation from Blow
Pulunggono (1983) determined the age of the formation as
N16-N17 (lower part of Late Miocene - upper part of Late
Miocene)
The thickness of this formation is about 45 0 to 750
metres (De Coster 1974)
328 KASAI FORMATION (KAF)
Conformably overlying the Muara Enim Formation is the
Kasai Formation This formation is often marked by a
distinct pumice or lapilli horizon containing rounded pumice
fragments of about 1 cm diameter Light coloured poorly
bedded tuffaceous sands and gravels often containing clear
grains of crystalline quartz are interlayered with light
33
bullolo-red or bluish-green clays (Shell Mijnbouw 1978)
Rare thin coal seams are also present
The Kasai Formation is interpreted to be
Plio-Pleistocene in age based on its association with the
orogeny and associated vulcanicity of that age
33 DEPOSITIONAL HISTORY OF THE TERTIARY SEDIMENTS
In general deposition of the Tertiary sediments in the
South Sumatra Basin occurred during a period of relative
tectonic quiescence which happened between the periods of
tectonic upheaval in the Late Cretaceous-Early Tertiary and
the Plio-Pleistocene (De Coster 1974) De Coster (1974)
stated that the tectonic quiescence probably resulted from a
reduction in the rate of sea-floor spreading activity during
that time Consequently sedimentation of the Tertiary
sequences was mainly controlled by basin subsidence
differential erosion of the source areas and eustatic
sea-level changes
The initial deposition of Tertiary sediments in the
basin occurred in the Late Eocene and Early Oligocene in a
continental environment These deposits are represented by
the Lahat Formation filling a terrain of substantial
topographic relief which developed as a result of the
orogenic activity during the mid-Mesozoic the faulting of
the Late Cretaceous and Early Tertiary and differential
erosion of the exposed pre-Tertiary basement rocks The
3 4
Lahat Formation formed as a set of alluvial fan braided
stream valley fill and piedmont deposits and is
characterized by a feldspathic basal unit Probably this
unit is an erosional product of nearby granitic hills
The tuffs occurring in the Lahat Formation were derived
from the intermittent vulcanism and probably from erosion of
earlier-deposited tuffs Indications of local swamp
conditions can be recognized from the presence of thin coal
layers In the Late Eocene-Early Oligocene a fresh water to
brackish lacustrine environment developed in parts of the
South Sumatra Basin and a shale sequence was deposited in
this environment During this time the lakes may have had
intermittent connections with the adjacent seas giving rise
to some limestone dolomite and glauconite-rich beds
According to De Coster (1974) probably in the Middle
Oligocene sedimentation of the Lahat Formation was
interrupted by regional uplift which occurred in the late
Early and Middle Oligocene This interruption is
represented by the unconformable contact between the Lahat
Formation and the Talang Akar Formation
Deposition of the Talang Akar Formation began in the
Late Oligocene in the form of alluvial fan and braided
stream environments filling topographic lows and
depressions Therefore the Talang Akar Formation locally
occurs overlying the pre-Tertiary rocks This sedimentation
continued in Early Miocene in a fluviatile deltaic and
marginal-shallow marine environment During this time the
connection to open
3 5
marine conditions became more significant and the sea
gradually encroached into the basin Topographic relief
became less pronounced as sedimentation continued
Subsequently delta plain sediments developed over broad
areas consisting primarily of point bar and braided stream
deposits These graded into delta front and marginal marine
sands which in turn graded into prodelta shales laid down in
the more distal parts of the basin As the progradation
continued delta plain facies such as channel
crevasse-splay flood-plain or marsh deposits were formed
The Talang Akar Formation has its type area in the
South Sumatra Basin but the term is also used for similar
sequences in the Sunda Basin and Northwest Java Basin as far
east as Cirebon in Java The Talang Akar sequence is also
recognized in the Bengkulu Trough a fore-arc basin to the
southwest of the South Sumatra Basin
As the sea level rose in the Early Miocene the sea
started to encroach upon the basement highs and the sediment
input declined leading to deposition of the Baturaja
platform carbonates in reef back-reef and intertidal
environments In the early stages the Baturaja Formation
was deposited on shelfal and platform portions of the basin
as platform or bank limestone deposits In the later
stages further buildups of detrital reefal and bank
36
limestones were formed on top of these banks in restricted
localities In the central part of the basin the Baturaja
Formation grades laterally into argillaceous limestones or
marl and vertically into shales of the Gumai Formation
Deep marine conditions became more widespread in the
early part of the Middle Miocene as basin subsidence
exceeded sedimentation and the deposition of Gumai shale
continued In some areas the deposition of Gumai Formation
was directly after the Talang Akar Formation During this
time the basin experienced the maximum marine incursion and
the most widespread phase of deposition According to De
Coster (1974) the South Sumatra Basin was probably
connected with the Sunda Basin when sea covered most of the
remaining topographic highs in the basin
In the Middle Miocene the sea became shallower and
environments of deposition gradually changed from neritic to
continental This event may be related to the regional
uplift accompanied by vulcanism and by intrusion of diapiric
masses and batholiths (De Coster 1974) The Air Benakat
and Muara Enim Formations were deposited during this time in
shallow-inner neritic to paludal-delta plain environments
During the deposition of the Muara Enim Formation
widespread areas of swampland and marsh were present
throughout the basin and extensive thick coals were formed
at this time
The last of the major tectonic events in the South
17
Sumatra Basin was the Plio-Pleistocene orogeny This
orogeny was probably the direct result of renewed collision
betwween the Indo-Australian Plate against the Sumatra
part of the Eurasian plate Sedimentation occurred in the
basin during that time resulting in deposition of the Kasai
Formation The Kasai Formation consists mostly of erosional
products derived from the uplifted Barisan and Tigapuluh
Mountains and from the uplifted folds being formed in the
basin during the orogeny
33
CHAPTER FOUR
ORGANIC MATTER IN THE TERTIARY SEQUENCES
41 INTRODUCTION
Cuttings samples from ten oil exploration wells drilled
in the South Palembang Sub-basin were studied with an
emphasis on the organic petrology and maturation level of
the organic material Selection of well sections to be
examined was determined by availability of sample material
and drilling data as well as preferences given by
PERTAMINA The samples were taken from the PERTAMINA core
shed at Plaju Palembang and were examined for maceral
content at the University of Wollongong The results of the
analyses are expressed on a 100 maceral basis Cuttings
samples were selected by the author for study on the basis
of their content of coal and carbonaceous or dark shale
particles All samples are from Tertiary sedimentary
sequences
Because of poor initial sample collection methods at
the well site some of the cuttings samples from the older
oil exploration wells (L5A-22 TMT-3 BL-2 BN-10) contain
vitrinite having oxidation rims (frypanned rims)
The well locations are given in Figure 14 Some coal
samples from the Muara Enim Formation were also collected
from shallow boreholes located around the Bukit Asam coal
mine as shown in Figure 15 Table 41 shows wells sampled
39
and the total number of samples from each formation Bar
diagrams and pie diagrams of organic matter type abundance
and maceral composition are shown in Figures 41 to 46
Short descriptions of lithologies and organic matter type
abundance and maceral composition from each well are
presented in Appendix 1
42 TYPE
421 LAHAT FORMATION
The Lahat Formation is largely confined to the deeper
parts of oil well sections studied such as in the BRG-3
GM-14 BN-10 MBU-2 L5A-22 and PMN-2 wells The Lahat
Formation consists mainly of sandstone shale siltstone and
thin coal but in the MBU-2 well it consists of volcanic
breccia
Organic matter is predominantly terrestrial in origin
DOM content in the samples ranges from 009-1699 (average
= 85) by volume DOM on mineral matter free basis
comprises 21 to 99 (average = 84) vitrinite trace to 9
(average = 2) inertinite and trace to 55 (average = 14)
liptinite
Several thin coal seams occur in the Lahat Formation
The coal content of the samples from this formation ranges
from 2 to 34 (average = 18) by volume The coal
comprises (mmf basis) 73-99 (average = 86) vitrinite
40
014-7 (average = 4) inertinite and 03-20 (average =
10) liptinite (Figure 41)
Vitrinite is the dominant maceral present in this
formation both in DOM and coal It occurs as well
preserved stringers laminae lenses and disseminated
particles Detrovitrinite and telovitrinite occur in
approximately equal amounts Vitrinite is commonly
associated with sporinite cutinite resinite and
liptodetrinite
Sporinite and liptodetrinite are common in this
formation In general the macerals of the liptinite group
have a weak to very weak fluorescence intensity and
fluorescence colours are dark orange to brown In some
samples it is very difficult to detect liptinite occurrences
in fluorescence mode
Inertinite is rare in the samples and occurs mainly as
inertodetrinite Semifusinite and sclerotinite occur in the
samples from GM-14 and BRG-3 but are present only in minor
amounts Fusinite occurs as thin layers and rarely as
isolated lenses in a detrovitrinite matrix Inertodetrinite
is present in most of the samples but as a minor component
Bitumens occur associated with quartz or clay grains
and they are characterized by yellowish green fluorescence
Oil cuts and haze are also present in the samples from the
L5A-22 well typically where oil is seen to be expelled
during examination in fluorescence-mode from fractures in
telovitrinite Some oil stains were also found in
41
detrovitrinite and telovitrinite as shown in Plate 1
Pyrite commonly occurs throughout the samples and is
typically framboidal in form
422 TALANG AKAR FORMATION
The Talang Akar Formation was penetrated by all of the
petroleum exploration wells used in the present study
Samples collected from this formation are mainly cuttings
samples but some core samples were also obtained Organic
matter abundance of the Talang Akar Formation was determined
from forty eight cutting samples Sandstone siltstone and
shale are the dominant lithologies of the Talang Akar
Formation Coal layers are commonly present in this
formation varying in thickness from thin stringers to 2
metre seams
4221 DOM
DOM content of siltstones sandstones and shales by
volume of the samples taken from the formation varies
between 182 to 3791 (average = 1363) The highest
proportion of DOM occurs in coaly shales Vitrinite is the
dominant maceral in DOM (mmf basis) ranging from 41-99
of the DOM (average = 90) Liptinite ranges (mmf basis)
from sparse to 55 (average = 7) Inertinite occurs only
in minor amounts ranging (mmf basis) from rare to 19
(average = 3) Vitrinite occurs in all lithologies as
12
fragments laminae lenses and thin stringers (Plate 2)
Vitrinite layers commonly contain inclusions of liptinite
macerals such as sporinite resinite and liptodetrinite
Sporinite is the most common liptinite maceral in this
formation In general liptinite has a weak to very weak
fluorescence intensity and is dark orange to brown in
colour Sporinite occurs mostly as miospores and pollen
grains and is disseminated throughout the coals and shales
Oil drops also occur in the samples and have yellow
fluorescence Framboidal pyrite is commonly present in this
formation (Plate 3) 4 1
4222 Coal and Shaly Coal
In general Talang Akar coals are well developed in the
Pendopo-Limau area The samples from the Talang Akar
Formation comprise 24-82 (average = 3947) coal and
12-30 (average = 2314) shaly coal by volume (Figure
42) The coals (mmf basis) comprise 48-99 (average =
87) vitrinite 01-19 (average = 3) inertinite and
053-49 (average = 10) liptinite These coals vary from
sub-bituminous to high-volatile bituminous in rank and are
characterized by a high vitrinite and a moderate liptinite
content Shaly coals comprise (mmf basis) 48-97
(average = 84) vitrinite trace to 22 (average = 4)
inertinite and 2-30 (average = 12) liptinite
The microlithotypes present in these coals are vitrite
with lesser amounts of clarite Vitrite layers consist of
i
43
celovitrinite and detrovitrinite and are associated with
sporinite and minor resinite Oil staining of polished
surfaces of vitrinite is commonly present Sporinite is the
dominant liptinite maceral It is dark orange in
fluorescence mode
Bitumens are common in the Talang Akar Formation and
show yellow to orange fluorescence as shown in Plates 4 to
9 and 12 to 13 They occur mainly in coals and are
associated with oil cuts Some exsudatinite occurs in the
coals and is yellow to dark orange in fluorescence mode
(Plates 8 to 11) Sclerotinite is also present and occurs
as teleutospores In some samples sclerotinite was filled
by bitumen as shown in Plates 10 and 11 During examination
using fluorescence mode oil was expelled from sclerotinite
(Plates 14 and 15) and telovitrinite (Plates 16 and 17) in
some samples
423 BATURAJA FORMATION
The Baturaja Formation consists of platform carbonate
deposits which comprise limestones grading to calcareous
clays and fine to medium grained sandstones A thick
section of this formation was intersected by KD-01 well from
1363 metres to 1572 metres In general DOM in the samples
from the Baturaja Formation is rare to abundant (lt01 to
295 with average = 087 by volume) DOM (mmf basis)
in this formation comprises rare to 99 (average = 97)
vitrinite barren to 1 (average = 02) inertinite and 0
44
to 8 (average = 28) liptinite (Figure 44)
Vitrinite is mainly present as detrovitrinite
Inertinite is rare and occurs as inertodetrinite Minor
sporinite also occur in the samples and has orange
fluorescence Fluorinite is present in the samples from
BN-10 well and has a yellow flourescence Pyrite is
commonly present throughout the lithologies
424 GUMAI FORMATION
The Gumai Formation consists of deep water marine
shales and limestones DOM content of the samples from this
unit ranges from 005-733 (average = 187) by volume and
comprises (mmf basis) 24-92 (average = 63) vitrinite
2-37 (average = 22) inertinite and 0-57 (average = 15)
liptinite
Vitrinite is common in the lithologies and occurs as
detrovitrinite Inertinite is commonly present and occurs
as inertodetrinite and micrinite but sclerotinite and
semifusinite are commonly present in the samples from the
KG-10 well Liptinite is represented by cutinite
sporinite liptodetrinite fluorinite and resinite
Sporinite is common and has orange to dark orange
fluorescence Cutinite is orange to dark orange in
fluorescence mode and is thin-walled
Bitumens are sparse in the samples from the Gumai
Formation except those from the KG-10 well where they are
45
common to abundant with greenish yellow fluorescence Oil
drops are also present and show a yellow colour in
fluorescence mode Some phytoplankton are also present in
the samples and occur as very small tests which in some
cases are very difficult to recognize from the matrix They
have a green fluorescence colour Euhedral pyrite is
commonly present in the lithologies
425 AIR BENAKAT FORMATION
The Air Benakat Formation consists of neritic to
shallow marine deposits in which DOM ranges from 015 to
154 (average = 366) by volume High proportions occur
in carbonaceous shale or claystone whereas low proportions
occur in limestone and marine sandstone
On a mineral matter free basis DOM comprises 54 to
91 (average = 78) vitrinite rare to 7 (average = 3)
inertinite and 7 to 39 (average = 19) liptinite Figure
45 shows the abundance of DOM in the Air Benakat Formation
Vitrinite is the most common organic matter in all
lithologies with detrovitrinite the main maceral This
maceral is assocciated with the liptinite macerals
suberinite cutinite resinite sporinite and
liptodetrinite
Liptodetrinite sporinite and cutinite are commonly
present in the Air Benakat Formation They are orange in
fluorescence mode Minor greenish yellow fluorescing
46
fluorinite and orange fluorescing resinite are also present
Inertinite is rare and occurs as sclerotinite and
inertodetrinite
In general bitumens are abundant in the samples and
they occur commonly in sandstone siltstone and claystone
They have a yellowish-green to green colour in fluorescence
mode Desiccation cracks in the bitumens are commonly
present and some of bitumens have a cauliflower shape Oil
drops are common in the samples from KG-10 well and show a
yellowish-green colour in fluorescence mode Framboidal
pyrite is more common than euhedral pyrite
426 MUARA ENIM FORMATION
The Muara Enim Formation includes the main workable
coal measures of the South Sumatra Basin and contains the
large brown coal (lignite) resources of the South Sumatra
region The Muara Enim Formation comprises three
lithological sequences they are coal units claystone units
and sandstone units as shown in Table 33 The coal beds in
the basin range from a few centimetres to about 40 metres in
thickness The coals vary from brown coal to sub-bituminous
in rank but locally reach anthracitic rank in zones of
contact alteration
Organic matter in this coal-bearing sequence occurs as
dispersed organic matter and as discrete coal seams
According to Cook and Struckmeyer (1986) DOM associated
47
with coals is generally similar in its origin maceral
composition and chemical properties to the organic matter in
the coals but can also show some systematic differences
The Muara Enim Formation occurs in nine oil wells
studied and fifty seven cutting samples were taken from this
formation Twenty eight coal samples were also collected
from seven cored coal exploration boreholes In addition
maceral analysis data of the Muara Enim coals are also
available from Daulay (1985) who studied the petrology of
the Muara Enim coals
In the cuttings samples studied coal occurs as layers
lenses or streaks and contributes between 356 to 100
(average = 66) by volume Based on the results of maceral
analyses of these samples on a mineral matter free basis
the Muara Enim coals comprise 74 to 88 (average = 81)
vitrinite 3 to 12 (average = 6) inertinite and 8 to
17 (average = 13) liptinite (Fig46)
The core samples (mmf basis) have 75 to 97
(average = 86) vitrinite 175 to 8 (average = 5)
inertinite and 225 to 16 (average = 9) liptinite
(Fig46) Within the limits of sampling precision the
results for coals from cores and from cuttings are very
similar
DOM contents of the Muara Enim Formation range from
187 to 798 (average = 437) by volume High
proportions of DOM occur in coaly claystone or carbonaceous
mudstone but in sandstone and siltstone the DOM content is
48
low In the samples studied DOM (mmf basis) comprises
39 to 96 (average = 65 ) vitrinite 02 to 7 (average =
3) inertinite and 12 to 57 (average = 32) liptinite
Telovitrinite is the main vitrinite maceral and occurs
both in DOM and coal Telovitrinite is commonly present in
the coal as thin layers or small lenses which occur in the
detrovitrinite matrix Some of the telovitrinite cell
lumens are infilled by fluorinite or resinite (Plates 18 to
21) In some cases they are filled by clay Corpovitrinite
and porigelinite (gelovitrinite) are scattered throughout
the coals f
In general inertinite is rarely present in the Muara
Enim coals Semifusinite fusinite and sclerotinite are the
main types of inertinite Semifusinite and fusinite occur
as layers or lenses as shown in Plates 22 and 23 Cell
walls of the fusinite and semifusinite vary in thickness and
degree of preservation Scelerotinite includes
teleutospores and scelerotia (Plate 24) Some cell lumens
in sclerotinite are filled by resinite and mineral matter
In some samples well preserved of mycorrhyzomes can also be
found (Plates 25 to 27)
The liptinite in the coal mainly comprises resinite
cutinite liptodetrinite sporinite suberinite with minor
fluorinite and exsudatinite Liptodetrinite is a
significant component of Muara Enim coals and comprises fine
degradation products of other liptinite macerals It has
bright yellow to orange fluorescence Resinite has yellow
49
to orange fluorescence (Plates 21 and 28 to 31) Cutinite
is commonly present as tenuicutinite and has yellowish
orange fluorescence but some crassicutinites can be also
found as shown in Plates 32 and 33 Sporinite is also
commonly present in the coals and is yellow to dark orange
in fluorescence-mode (Plates 34 to 37) It occurs mostly as
miospores and pollen grains and is disseminated throughout
the coals Suberinite shows orange to dark orange
fluorescence and it is also commonly present in the coals
(Plates 38 to 41) Exsudatinite occurs in few samples and
has a very bright yellow to orange fluorescence (Plates 40
to 43)
In general the Muara Enim coals are rich in bitumens
hence an attempt has been made to estimate the abundance of
bitumen by using the point counting method Bitumen content
of the coals (mmf basis) varies from 075 to 55
(average = 31) Bitumens occur mostly as medium to
large discrete bodies which are commonly globular in shape
(Plates 44 to 47) Flow structures occur and oil cuts are
common from bitumens and indicate that the bitumens have
been soft and mobile when entering the open spaces or during
the development of fracture porosity (Cook 1987)
Teichmuller (1982) noted that this stage represents the very
beginning of bituminization and can be related to the
genesis of fluid petroleum During this stage bitumen
fills the cavities bedding planes and joints Cook (1985)
added that the abundance of bitumen may be related more to
50
the migration characteristics of fluids from the organic
matter system than to any sharp threshold in the rate of
generation of soluble bitumens The occurrence of bitumens
in veins may be due to fissuring caused by hydrocarbon
generation pressures rather than to passive emplacement
into pre-existing cavities (Cook 19 87) An interesting
feature of the bitumen under microscope is the presence of
desiccation cracks (Plates 48 to 51) In some samples
bitumens also appear as cauliflower-shaped aggregates The
bitumens have bright green to greenish yellow fluorescence
but commonly they show dark yellow fluorescence in their
centre and gradually change to bright yellow fluorescence
toward the outer margins
Mineral matter is commonly present in the Muara Enim
coals and is represented by clay occurring as pods and
infilling cell lumens Framboidal pyrite is also commonly
found infilling cell lumens Quartz and siderite occur
sparsely in the coals
The main microlithotypes of the Muara Enim coals are
vitrite and clarite
43 RELATIONSHIP BETWEEN RANK AND MACERAL TEXTURES AND
FLUORESCENCE INTENSITY
Parallel with the increasing level of coalification
some physical and chemical properties of coal will be
gradually or progressively changed Peat and soft brown
51
coals have high bulk porosities and high water contents
With progressive coalification moisture content decreases
and calorific value and carbon content increase
Furthermore the pore volume of vitrinite also decreases
during the coalification process Stach et al (1982)
reported that the pore volume of vitrinite varies with rank
from 005 cm3g for vitrinite with 71 carbon content to
003 cm3g for vitrinite with 94 carbon content apparently 3
passing through a minimum of 0025 cm g at a carbon content
of about 89 Because of increasing carbon content and
aromacity the three maceral groups liptinite inertinite
and vitrinite become more highly reflecting and
increasingly opaque
Cell structures and plant tissues readily discernible
in low rank coals become increasingly difficult to
recognize at higher rank Texture becomes more compact with
coalification In comparison with other macerals vitrinite
textures are sensitive to increasing temperature and
pressure but they alter in a uniform manner during
coalification Telovitrinite textures are more sensitive to
increasing rank than those of detrovitrinite (Smith 1981)
Smith (1981) further reported that in the Gippsland Basin
telovitrinite shows remnants of open cell lumens and cell
walls and cell contents aligned parallel to bedding to about
1250 metres depth where Fornax is 030 He also indicated
that with bull increased depth the major process of
telovitrinite metamorphism appears to be conversion of
52
textinite and well preserved texto-ulminite into
eu-ulminite At 1742 metres (R max 050) almost all cell
lumens of telovitrinite are completely closed
In the samples studied Muara Enim coals occur at
present depths between 40 metres to 1200 metres Vitrinite
textures of the coals from the BT-01 well taken at depths of
46 to 54 metres R max 036 still show cellular structures
derived from vegetable material (Plates 52 and 53) Some of
the telovitrinite cell lumens are infilled with fluorinite
or resinite but in some samples they are filled by clay At
this rank the vitrinite is texturally immature retaining
well preserved botanical structures and voids as shown in
Plate 54 In other wells telovitrinite becomes dense and
compact and all cell lumens become closed with increasing
depth The telovitrinite is texturally mature (ie it has
been through a gelification state which has largely obscured
botanical features) These features can be seen in samples
from BRG-3 which were taken from a depth of 1200 metres with
R max of 050 (Plates 16 17 and 55) The cell lumens are
completely closed in samples with a vitrinite reflectance of
080 or greater This occurs at depths of more than 2000
metres in the Talang Akar Formation in the MBU-2 well
Under ultra-violet light excitation liptinite shows a
progressive increase in the maximum of spectral fluorescence
wavelengths with increasing maturation and the total
fluorescence intensity progressively decreases At low
rank the liptinite macerals typically yield up to 80
53
volatile matter and contain more than 9 hydrogen (Cook
1982) With increased rank the liptinite group macerals
suffer a major loss of volatile matter and of hydrogen
content Associated with these chemical changes the
fluorescence colours of liptinite change from
greenish-yellow in the peat stage to orange-brown in high
volatile A bituminous coals (Bustin et al 1983) The
fluorescence intensities and fluorescence colours are
related to presence of hydrogen in unsaturated bonds (Cook
1980)
Most liptinite macerals from the Muara Enim coals
(Fornax 030 to 050) have fluorescence colours ranging
from yellow to orange and greenish yellow in the bitumens
(Plates 46 to 50) The fluorescence colours of the
liptinite parallel increasing rank and become dark orange or
brown which are shown in the Talang Akar coals Bitumens
also become orange in this latter formation (Plates 56 to
61)
54
CHAPTER FIVE
ORGANIC MATURATION AND THERMAL HISTORY
51 INTRODUCTION
The maturity of organic matter is an expression of the
level of coalification reached The level of coalification
of organic matter can be also defined as the transformation
of organic matter from peat through the stages of different
brown coals sub-bituminous and bituminous coals to
anthracites and meta-anthracites (Stach 1982)
The metamorphism of organic matter is a product of two
variables time and temperature (Teichmuller and
Teichmuller 1982 Murchison et al 1985 Waples 1980
1985) Cook (1982) and Kantsler (1985) added a third
suggesting that at least three variables (pressure heat due
to burial of sedimentary sequences and the geological age of
the sequences) are involved in the coalification process
The role of pressure is only involved in the early stage of
biochemical coalification resulting in compaction and
expulsion of water (Bustin et al 1983) Pressure is
thought to have only a minor negative effect upon rank
increase (Teichmuller and Teichmuller 1968 Lopatin and
Bostick 1973) Huck and Patteisky (1964) claimed that high
static pressure can have retarding effects on coalification
However Bustin et al (1983) pointed out that high tectonic
pressure can lead to abnormal increases in vitrinite
55
reflectance
In most stratigraphic sequences increased temperatures
accompany burial and thus more deeply buried coals are
exposed to higher temperatures for longer time and are
generally of higher rank This relationship was first
documented by Hilt (1873) who observed a progressive
decrease in volatile matter in coals with depth (Hilts
Law) The level of coalification or rank of organic matter
can be assessed by using a variety of chemical and physical
methods Some of the more commonly used of these indices
are volatile matter yield carbon content moisture content
and calorific value Unfortunately these properties do not
change uniformly with rank and consequently are not always
suitable indicators Vitrinite reflectance is one of the
most commonly used methods for evaluation of the organic
maturation The optical properties of vitrinite macerals
alter more uniformly during metamorphism than those of other
macerals (Smith and Cook 1980) Additionally vitrinite is
present in many types of sedimentary rocks
In the present study measurements of maximum
reflectance of vitrinite were made to determine the rank of
coals from the South Palembang Sub-basin and also to assess
the maturation level of the dispersed organic matter in the
associated non-coal rock types The assessment of organic
maturation is an important parameter for evaluation of the
coal quality and the hydrocarbon source potential of the
sedimentary sequence Measurements of maximum reflectance
56
of vitrinite were made on coal and DOM from cuttings
samples The results for cuttings samples may include some
values for caved materials from overlying sequences but
these can generally be recognized from their lithological
characteristics In addition unpublished reflectance data
particularly of the Muara Enim coals are available from
Daulay (1985)
The maturation profile for a sedimentary sequence at a
given location is obtained by plotting vitrinite reflectance
against depth for each sample from a well section By
comparing these maturation data with those at other
locations in the basin the pattern of maturity distribution
within the basin can be used for locating hydrocarbon source
rocks lying within the zone of oil generation
Vitrinite reflectance values from ten oil wells are
given in Tables 51 to 510 The reflectance gradients of
these wells range from Rvmax 020 to 035 per kilometre
The vitrinite reflectance profiles with depth are presented
in Figures 51 to 510 Isoreflectance surfaces have been
constructed along section lines A-B and C-D (Figure 14) and
these are presented in Figure 511 and Figure 512 The six
oil wells illustrated in Figure 511 are located in the
Muara Enim area whereas the four oil wells in Figure 512
are situated in the Limau-Pendopo area In addition
vitrinite reflectance values from seven coal exploration
boreholes are given in Table 510A
57
52 RANK VARIATION AND DISTRIBUTION
The mean maximum vitrinite reflectances obtained from
samples examined for this study are plotted against depth in
Figure 513 The most obvious trend shown in this figure is
the increase in vitrinite reflectances with depth and this
is more marked from a depth of below about 1500 metres
(Rvmax generally about 05) to 2500 metres (Rmax generally
about 09) Some reflectance values plot below the trend
These values may relate to the presence of cavings but
generally values from the Baturaja Formation plot below the
trend whereas those from the Lahat Formation plot on or
above trend
Several reasons have been given for suppressed
vitrinite reflectance Hutton and Cook (1980) found lower
reflectance values where Botryococcus-derived alginite is
present Titheridge (1989) found lowered reflectance where
sulphur content is high and it has been reported that
reflectance is lower in some specific lithologies
The Baturaja Formation is a marine unit (containing
limestone) Many marine oil shales have lower than expected
reflectance values (Hutton pers comm 1991) and the
lowered reflectance for the Baturaja Formation is possibly
attributable to its marine origin
In the Muara Enim area the increase in vitrinite
reflectance with depth is associated with a high temperature
gradient as well as being due to depth of burial (Figure
58
511) High temperature gradients in the Muara Enim area
may relate to the effects of thermal metamorphism or
volcanic intrusions adjacent to the Bukit Barisan Mountains
KG-10 well is an exception in that samples from it show low
reflectance values (R max 044 and 048) at depths of 1524
metres and 1546 metres However these low reflectance
values probably correlate with the presence of cavings
(Figure 511) Figure 512 suggests that the increases in
vitrinite reflectance are probably related primarily to
depth of burial in the Limau-Pendopo area In this area
the thickness of the Tertiary particularly of Talang Akar
and Lahat Formations is greater than in the Muara Enim
area The highest vitrinite reflectance values (R max
095) occur in the Lahat Formation in the BN-10 well at a
depth of 2542 metres BN-10 is the deepest well used in
this study and is situated in the Limau-Pendopo area
Relationship between coalification and tectonism has
long been known (Patteisky and Teichmuller I9 60
Teichmuller 1962 Teichmuller and Teichmuller 1966
Hacquebard and Donaldson 1970 Diessel 1975) Most
authors suggest that the relationship between timing of
coalification and that of tectonic deformation in a
particular area may be investigated in two ways based on
coal rank data Firstly by comparison of the shape of the
iso-rank surfaces and structural contours and secondly by
comparison of the rate of rank increase with depth in a
particular seam compared with the rate within a vertical
59
profile such as a borehole
Teichmuller and Teichmuller (1966) divided the
relationships between coalification and tectonism into three
types pre-tectonic coalification post-tectonic
coalification and syn-tectonic coalification In
pre-tectonic coalification coalification is completed
before tectonic deformation Iso-rank surfaces would
parallel structural surfaces (Figure 514) Complete
post-tectonic coalification applies to an area in which
little or no coalification took place during initial
subsidence or during tectonic movements Early and rapid
deposition and folding under low geothermal gradients are
commonly associated with post-tectonic coalification
Teichmuller and Teichmuller (1966) suggested that
exclusively post-tectonic coalification is probably never
realized in real systems With post-tectonic coalification
iso-rank contours are horizontal regardless of the degree of
deformation (Figure 515) Syn-tectonic coalification
patterns are produced in areas where coalification and
tectonic movements occur contemporaneously In areas where
syn-tectonic coalification occurs the iso-rank surfaces are
oblique to the structural contours (Figure 516)
In the area studied the iso-reflectance line of Rvmax
03 is generally semi-parallel with the orientation of the
Muara Enim Formation This pattern is consistent with major
pre-tectonic coalification but minor syn-tectonic
coalification also may be present (Teichmuller and
60
Teichmuller 1966) In the Muara Enim area (Figure 511)
the iso-reflectance lines R max 04 to 09 generally
intersect the formation boundaries at low angles However
the iso-reflectance lines are more regular and parallel with
the orientation of the formation boundaries in the
Limau-Pendopo area where partial syn-tectonic coalification
patterns are evident (Figure 512) According to
Teichmuller and Teichmuller (19 66) this situation may
arise in younger strata of a coal basin where folding
movements are active during or very shortly after deposition
and prior to maximum burial
The Talang Akar and Lahat Formations are intersected by
the 05 to 09 R max surfaces In terms of coal rank the
coals from these formations can be classified as high
volatile bituminous coals
In general vitrinite reflectances in the Muara Enim
coals range from 030 to 050 R max with an average of
037 The coals therefore range from brown coal to
almost sub-bituminous coal in rank The M2 coals
particularly the Mangus Suban and Petai seams are mined at
the Bukit Asam coal mines Vitrinite reflectance of
dispersed organic matter of the Muara Enim Formation shows
similar patterns to those of coals not affected by
intrusions In general it ranges from 03 to 04 R max
Daulay (1985) divided the M2 coals in the Bukit Asam
area into two categories related to the effects of thermal
alteration by an andesite intrusion coal not affected by
61
contact thermal alteration and thermally altered coals
Vitrinite reflectance of coal not affected by thermal
alteration ranges from 030 to 059 Rvmax and from 069
to 260 for thermally altered coals Furthermore Daulay
noted that reflectances between 040 to 050 are dominant
at Bukit Asam By contrast vitrinite reflectance decreases
gradually from 035 to 040 towards the north (Banko
Area) and west of Bukit Asam
Coals from the boreholes BT-01 (South of Banko) and
SN-04 (West Suban Jerigi) have vitrinite reflectances
ranging from 031 to 041 In the Kl-03 and KLB boreholes
(Kungkilan area southwest of Bukit Asam) vitrinite
reflectance is relatively constant being in the range 041
to 044 Vitrinite reflectance decreases again at the
AU-04 and AS-12 boreholes (North Arahan and South Arahan
farther west of the Kungkilan area) ranging from 035 to
037 The differences in vitrinite reflectance between
coals from the Bukit Asam area and other areas are probably
due to heating effects from igneous intrusions beneath the
Bukit Asam and adjacent areas Thus it appears that even
the coals referred by Daulay to the not affected by thermal
alteration category show some evidence of localized
heating
53 THERMAL HISTORY
Thermal history of the basin can be estimated by
62
comparing data on sediment age and the level of
coalification (Kantsler et al 1978) The current thermal
regime can be ascertained by reference to present downhole
temperature data estimated from borehole logs The
relationship between maximum palaeotemperature and vitrinite
reflectance has long been studied and documented by authors
(such as Teichmuller 1971 Dow 1977 Bostick 1973 1979
Kantsler et al 1978 Kantsler and Cook 1979 Cook and
Kantsler 1980 Smith and Cook 1980 1984) Models for the
prediction of palaeotemperatures organic maturity and the
timing of hydrocarbon generation have been developed by a
number of authors
The first attempt to define mathematically the relation
of time temperature and rank was introduced by Huck and
Karweil (1955) Later Karweil (1956) developed a nomogram
for the three variables and it is known as the Karweil
nomogram The Karweil model is based on first-order
reaction rates and appears to assume that a formation has
been exposed to present downhole temperatures for all its
subsidence history Some modifications have been made by
Bostick (1973) with the addition of an empirically derived
reflectance relationship The Bostick version of the
Karweil nomogram is shown in Figure 517 Further
developments on the prediction of palaeotemperature and
thermal history from the Karweil nomogram were made by
Kantsler et al (1978)
j 3
In the present study estimations of palaeotemperature
and thermal history in the South Palembang Sub-basin were
made using the Karweil diagram as suggested by Kantsler et
al (1978) The palaeothermal history of the basin has been
assessed using the age data for the sedimentary units the
corresponding Rvmax data and the time (t) temperature (T)
and vitrinite reflectance (RQmax) nomogram of Karweil as
modified by Bostick (1973) In the modification used
temperatures derived directly from the Karweil nomogram were
named Isothermal Model Temperatures (Tiso) The isothermal
model (Tiso) assumes that temperatures have remained
constant since burial whilst the gradthermal model (Tgrad)
assumes a history of constantly rising temperatures
(Kantsler et al 1978a Smith 1981 Smith and Cook 1984)
From these comparisons an assessment can be made of whether
present day temperature (Tpres) is higher the same or lower
than the maximum palaeotemperature
The present geothermal gradient was obtained by using
the formula
T = To + TX (Smith 1981)
where T is borehole temperature To the surface temperature
X is depth and T = dTdX the geothermal gradient
The surface temperature of the Muara Enim-PendopoLimau
area (onshore) used in the calculations is assumed to be
26 C The borehole temperature data were obtained from the
geophysical well logs of the oil wells studied The results
of the calculations show that the present geothermal
64
gradient in these areas varies from 37degCkm to 40degCkm
(average = 39 Ckm) in the Muara Enim area and 36degCkm to
40degCkm (average = 38degCkm) in the Pendopo-Limau area
These geothermal gradients are lower than those reported by
Thamrin et al (1979) According to those authors the
average gradient geothermal gradient and heat flow in South
Palembang Sub-basin are 525degCkm and 255 HFU (Heat Flow
Units) Furthermore Thamrin et al (1979) reported that in
the Beringin field (Muara Enim area) the geothermal
gradient and the heat flow are 565degCkm and 266 HFU while
the values from the Tanjung Miring Timur field (Pendopo
area) are 55 km and 266 HFU respectively The Benuang
field (Pendopo area) also has a high reported geothermal
gradient having a value of 55 Ckm Based on these data the
top of the oil window can be expected to be encountered at
shallow depths of approximately 1300 metres This position
for the top the oil window is also suggested by the
reflectance data which show that the 05 reflectance values
lie at approximately 1300 metres depth
Thamrin et al (1980 1982 1984) stated that the high
geothermal gradients occurring in the Sumatran basinal areas
are influenced by high palaeoheat flows which accompanied
Tertiary tectonism Further they concluded that the high
geothermal gradients in these areas reflect rapid burial
followed by uplift and erosion The high heat flow in the
basin results from magmatic intrusions and associated mantle
waters penetrating the shallow pre-Tertiary basement to
65
within a few kilometres of the surface exposing the
Tertiary sedimentary cover to high temperatures (Eubank and
Makki 1981)
Tectonically the Sumatran basinal areas are situated
between an inner (volcanic) arc and the stable Sunda Shelf
The volcanic inner arc is represented in Sumatra by the
Bukit Barisan Range which is mainly composed of folded
pre-Tertiary rocks Eubank and Makki (1981) suggested that
in a continental back-arc basin where the sialic crust is
thinned but rifting is not complete the crust is not an
effective thermal blanket Where the crust is thin and
highly fractured simatic heat will be rapidly conducted
upward by magmatic diapirism and convective circulation of
water in the fractures In a continental setting sediments
quickly fill the incipient rifts and are subjected to high
heat flow
Scale H of Karweils diagram was used in the present
study to calculate isothermal model temperatures Cook
(1982a) suggested that Tgrad can be obtained from Tiso
values by multiplying with a conversion factor of 16
Smith and Cook (1984) suggested testing isothermal and
gradthermal models against present temperatures to establish
the relative palaeothermal history of a formation
According to Smith (1981) and Smith and Cook (1984) a
quantitative estimate can be obtained by defining the
following ratio
Grad Iso = (Tpres - Tiso) (Tgrad - Tiso)
ee
If the ratio is lower than 1 the present geothermal
gradients are probably lower than in the past and the
formation history approaches the isothermal model If the
ratio is close to one the formation history approaches the
gradthermal model If the ratio is greater than one
present temperatures are greater than the effective
coalification temperature
Thermal history data from selected wells in the South
Palembang Sub-basin are listed in Table 511 and Table 512
From data given in these tables it can be seen that in
general the present temperatures are lower than isothermal
temperatures These indicate that the palaeotemperatures
were higher than the present temperature Probably the
sediments of the South Palembang Sub-basin underwent a
period of rapid burial prior to a period of uplift and
erosion Pulunggono (1983) stated that a tensional movement
during PaleoceneEocene to Early Miocene times enhanced
block faulting with consequent subsidence of faulted block
areas along existing faults (NE-SW and NW-SE) Maximum
rates of subsidence of the faulted blocks were indicated
inferred in uppermost Oligocene to earliest Miocene times
During this phase the rate of sedimentation began to exceed
the rate of subsidence and the faulted blocks were rapidly
infilled
67
54 SOURCE ROCKS AND GENERATION HYDROCARBONS
541 SOURCE ROCKS FOR HYDROCARBONS
Potential hydrocarbon source rocks are rocks containing
preserved organic matter which includes the remains of
marine and fresh water animals and plants and terrestrial
plants For many years marine rocks were regarded as the
only prolific source for oil (eg Tissot and Welte 1978)
but over the past 30 years it has become clear that
terrestrial and fresh water organic matter can also generate
commercial quantities of petroleum A number of authors
have recently suggested that coal has played a significant
role in sourcing hydrocarbons in important oilfields such as
in Australia (Gippsland Basin) and in Indonesia (Mahakam
Delta) Oils derived from terrestrial organic matter are
generaly waxy in character as identified by Hedberg (1968)
and Powell and McKirdy (1975) and are believed to be
associated with coals or terrestrial organic material which
is particularly rich in liptinite
Authors (such as Smith and Cook (1980) Smyth (1983)
Tissot and Welte (1984) Cook (1987) have agreed that the
liptinite group is considered to be most significant
producer of hydrocarbons per unit volume organic matter
Vitrinite-rich source rocks are thought to be producers of
both gas and some oil (Cook 1982 Smyth 1983) Cook
(1987) pointed out that the difference in specific
generation capacity between liptinite and inertinite are
68
for most coals balanced by the much greater abundance of
vitrinite The generative potential of vitrinite is put at
one tenth of that of liptinite (Smyth et al 1984 Cook et
al 1985) Moreover Tissot (1984) concluded that the
source potential of Type III kerogen is three or four times
less than that of Type I or II kerogen According to
Snowdon and Powell (1982) the maceral vitrinite is
generally associated with the generation of methane during
catagenesis In addition Khorasani (1987) demonstrated
that vitrinites formed under dysaerobic conditions can
become perhydrous and partially oil prone These vitrinites
are considerably more hydrogen rich than the classical
orthohydrous vitrinites
Inertinite may have some generative potential (Smith
and Cook 1980 Smyth 1983) According to Struckmeyer
(1988) the generating potential of inertinite is considered
to be approximately one twentieth that of liptinite
Khorasani (1989) however stated that inertinite has
virtually no genetic potential for generating liquid
hydrocarbons Her statement has been supported by pyrolysis
the data index (S2OrgC) which is indicative of the
amounts of hydrocarbon already generated (Figure 518)
These data show that the contribution of inertinite to
generation of hydrocarbons prior and within the oil window
as defined by Khorasani (1989) is negligible Moreover
the Tmax data (Figure 518) suggest that maximum
decomposition of inertinite-rich kerogens occurs at higher
69
activation energies compared to inertinite-poor kerogen
However Smith and Cook (1980) suggested that inertinite
maturation may occur at much lower levels of rank than
assumed by Khorasani
According to Rigby et al (1986) and Kim and Cook
(1986) extracts from liptinite-rich coals are dominated by
branched and cyclic alkanes In comparison vitrinite yields
a high proportion of long chain n-alknes At a vitrinite
reflectance of 03-04 vitrinite-rich coals can yield
significant amounts of n-alkanes (Rigby et al 1986)
Marked n-alkane generation occurs over the range 04 to 08
vitrinite reflectance
A model for the generation of oil and condensate from
terrestrial organic matter has been made by Snowdon and
Powell (1982) as shown in Figure 519 They recognized that
the proportions of organic matter type in terrestrial source
rocks strongly controls both the level of thermal alteration
necessary for the section to function as an effective
source rock and the ultimate product (gas oil or
condensate) which will be generated
In the South Palembang Sub-basin coal measures
sequences occur within the Muara Enim Talang Akar and the
Lahat Formations As described in Chapter Four in general
these coals are rich in vitrinite contain significant
amounts of liptinite and generally contain sparse
inertinite Detrovitrinite and telovitrinite mainly occur
in approximately equal amounts in these coal measures
70
Detrovitrinite generally has a higher specific generation
capacity which may be significant in relation to oil
generation (Cook 1987) Gore (1983) suggested that
detrovitrinite may be markedly perhydrous and incorporate
sub-microscopic or finely comminuted liptinite algae
resins and the remains of a prolific animal and microbial
life including bacteria rotifers rhizopods nematodes
worms insects molluscs copepods larvae sponges fish
vertebrates zooplankton and phytoplankton Telovitrinite
however tends to be orthohydrous and may incorporate lipids
including fatty acids and proteins derived from the cell
contents secondary cell walls suberinized cell walls
bacteria resin ducts cuticles and spores (Shortland 1963
Benson 1966)
Liptinite macerals occurring in the Lahat and Talang
Akar Formations are mainly represented by sporinite and
liptodetrinite while the liptinite macerals in the Muara
Enim coals occur mainly as resinite sporinite cutinite and
liptodetrinite with significant amounts of suberinite also
present Cook (1987) suggested that the high percentage of
resinite and suberinite in some coals may be a significant
factor in relation to the timing of oil generation He also
added that most Indonesian crude oils appear to have a low
naphthenic content suggesting that the contribution from
resinite is typically low
A study of liquid hydrocarbon potential of resinite
taken from M2 coals of the Muara Enim Formation was
71
undertaken by Teerman et al (1987) using hydrous pyrolysis
methods From this study Teerman et al (1987) indicated
that a large percentage of resinite can be converted into
hydrocarbons Oil-pyrolysates are light non-paraffinic
products consisting predominantly of cyclic isoprenoids and
their aromatic derivatives The composition of these
hydrocarbons however are very distinct and different from
the composition of naturally occuring oils Teerman et al
(1987) concluded that resinite is probably not a significant
source for liquid hydrocarbons due to the lack of similarity
between these light non-paraffinic pyrolysates and naturally
occuring oils Lewan and Williams (1987) also suggested
that resinites have not been a significant source for
petroleum
In the Muara Enim Formation bitumens and oil cuts
generally are more abundant than in other Tertiary rock
sequences from the South Palembang Sub-basin The secondary
liptinite maceral exsudatinite is present in all of the coal
measures sequences and commonly occurs within vitrinites
having a reflectance between 04 and 08 It is directly
related to the formation of hydrocarbons (Cook and
Struckmeyer 1986) Fluorinite is abundant in the Muara
Enim coals which have vitrinite reflectances between 035
and 050 Teichmuller (1974) regarded fluorinite to be
primarily derived from essential plant oils but some
fluorinite may be high pour-point crude oil trapped within
the coals Small amounts of fluorinite have also been found
71
within the Talang Akar coals Oil droplets and oil hazes
occur mainly in the Talang Akar Formation and some in the
Lahat Formation Oil hazes are mainly associated with
telovitrinite where the oil comes from cracks or veins in
the telovitrinite and flows out during fluorescence
examination mode Most of the features described above are
related to oil generation Cook and Struckmeyer (1986)
summarized the occurrence of petrographic features related
to oil generation as shown in Table 513
Assessment of the hydrocarbon generating potential of
source rocks in the South Palembang Sub-basin was made by
calculating the volume of liptinite to vitrinite in DOM and
coal This calculation was introduced by Smyth et al
(1984) and later modified by Struckmeyer (1988)
Score A = Liptinite +03 Vitrinite +005 Inertinite
(all values in volume of sample)
Score A is based on the volume and composition of organic
matter in a sample An example for this calculation is
shown below
Sample A contains approximately 6 (by volume)
organic matter consisting of 3 vitrinite 2
inertinite and 1 liptinite Based on the
calculation above sample A has a score of 2
For quantification of Score A the data set is compared
to values of S1+S2 from Rock-Eval pyrolysis (Struckmeyer
73
1988) According to Cook and Ranasinghe (1989) SI is
considered to represent free bitumen-like compounds within
the rock and is taken as a measure of the amount of oil
generated whereas S2 represents the main phase of loss of
hydrocarbons due to destructive distillation S1+S2 is
measured in kilograms of hydrocarbons per tonne of rock A
classification for source rock quality based on values of
S1+S2 was introduced by Tissot and Welte (1984) as shown
below
lt 2kgtonne poor oil source potential
2 to 6kgtonne moderate source potential
gt 6kgtonne good source potential
gt lOOkgtonne excellent source potential
Figure 520 shows a plot of S1+S2 values and Score A
for four samples from the Muara Enim and Talang Akar
Formations of the South Palembang Sub-basin SI and S2
values have been produced by Rock-Eval analysis (Chapter
Six) Scores of hydrocarbon generation potential of 59 and
192 have been calculated from two Muara Enim samples (5383
and 5384) and correspond to values of 52 and 1269 for
S1+S2 The highest score and S1+S2 value occur in a coal
sample (5384) These figures indicate that the samples have
good to very good source potential Also score A values for
the Muara Enim Formation have been calculated from thirty
samples collected from wells studied The results of these
calculations indicate that the Muara Enim Formation has very
good source rock potential with an average value about 232
1
[see Table 515)
Similar values were also obtained for the Talang Akar
samples (5385 and 5386) Hydrocarbon generation scores for
the samples range from 82 to 165 and correspond to S1+S2
values of 55 and 786 The data indicate that the samples
can be classified as good to very good source rocks Again
these figures are supported by data calculated for forty
five samples collected from the Talang Akar Formation
showing very good hydrocarbon generation potential
Score A values for samples from other formations have
also been calculated The Lahat Formation is categorized as
having a good source rock potential with a score of 896
Reports from several sources such as Shell (1978) Purnomo
(1984) Suseno (1988) and Total Indonesie (1988) also
suggested that the Lahat can be considered as potential
source rocks in the South Palembang Sub-basin Lacustrine
shale deposits of the Lahat Formation are expected to be
good quality source rocks and equivalent sequences are known
as a good source in the Central Sumatra Basin having high
TOC values Good source rocks are also present in the Air
Benakat Formation which has a score of 696 The highest
scores for the Air Benakat samples occur within the upper
part of the Air Benakat Formation although results may be
slightly affected by cavings from the Muara Enim Formation
Poor score values were found for the samples from the
Baturaja and Gumai Formations The scores range from 02 to
07
75
542 HYDROCARBON GENERATION
The principal zone of significant oil generation is
generally considered to occur between vitrinite reflectances
of 050 and 135 (Heroux et al 1979 Cook 1982 Smith
and Cook 1984 Cook 1986) Initial napthenic oil
generation from some resinite-rich source rocks may occur
however at maturation levels as low as a vitrinite
reflectance of 04 (Snowdon and Powell 1982)
Cook (1982 1987) considered that oil generation from
coals occurs at a much lower level of coal rank and is
largely complete by 075 R max Gordon (1985) suggested a
threshold for oil generation from coals from the Ardjuna
Sub-basin of about 045 vitrinite reflectance
Humic organic matter becomes post-mature for oil
generation between vitrinite reflectances of 12 and 14
at which time the source rocks become mature for gas
generation (Kantsler et al 1983) Oil is generated from
organic matter at temperatures ranging from 60degC to 140 C
At higher temperatures the humic organic matter becomes
post-mature for oil generation but mature for gas generation
as shown in Figure 521 and 522 (Kantsler and Cook 1979)
Organic matter type strongly influences the range of
maturity over which organic matter generates oil (Tissot and
7 6
Welte 1978 Hunt 1979 and Cook 1982) Smith and Cook
(1980) suggested that the effect of organic matter type
variation on oil generation is complex because different
types of organic matter undergo breakdown over different
temperature ranges and yield a variety of hydrocarbon
compositions According to Leythauser et al (1980) oil
generation occurs firstly from Type I Kerogen (alginite)
then from Type II Kerogen and finally from Type III Kerogen
(vitrinite) In contrast Smith and Cook (1980 1984)
reported that this order is reversed and the inertinite is
the first to generate hydrocarbons during burial
metamorphism then vitrinite with liptinite being the least
responsive maceral group at low temperature
Based on the isoreflectance surfaces (shown in Figure
511) in the Muara Enim area the lower parts of Muara Enim
and Air Benakat Formations are early mature in the BRG-3 and
KD-01 wells while the middle part of the Gumai Formation is
mature in the KG-10 and MBU-2 wells The upper part and
lower part of the Talang Akar Formation are also mature in
the PMN-2 and GM-14 wells
In the Pendopo area the Gumai Formation is generally
mature in almost all wells studied except in BN-10 where the
lower part of the Air Benakat Formation entered the mature
stage as shown in Figure 512
It can be concluded that the Gumai Formation is in the
mature stage throughout the well sections studied
Furthermore with an exception for the BRG-3 well the Muara
77
Enim Formation is immature for oil generation throughout the
well sections in the South Palembang Sub-basin However
some indications of oil generation are present within this
formation
The Talang Akar and Lahat Formations are relatively
mature to late mature for oil generation Locally these
formations occur within the peak zone of oil generation
(R max 075) If coal is accepted as a source for oil
(Durand and Paratte 1983 Kim and Cook 1986 Cook and
Struckmeyer 1986) thermal maturation has probably already
generated hydrocarbons from the organic matter of these
formations This conclusion is supported by the presence of
abundant oil drops oil cuts exudatinites and bitumens in
the samples from the Talang Akar and Lahat Formations
5421 Timing of Hydrocarbon Generation using Lopatin
Method
In order to asses the timing of hydrocarbon generation
the method of Lopatin (1971) as modified by Waples (1980
1985) has been used in the present study Lopatin (1971)
assumed that the rate of organic maturation increases by a
factor r for every 10degC increase in reaction temperature
The factor r was taken to be close to a value of 2 For any
given 10 C temperature interval the temperature factor (x)
is given by
x = 2 where n is an index value Lopatin
73
assigned to each temperature interval
The Lopatin model is based on an assumption that the
dependence of coalification on time is linear (ie doubling
the reaction time at a constant temperature doubles the
rank) The sum of the time factors (dtn) which describe
the length of time (in Ma) spent by each layer in each
temperature interval and the appropriate x-factors was
defined by Lopatin as the Time-Temperature-Index (TTI)
nmax
TTI = s (dtn) (x)
nmin
where n bdquo and n are the values for n of the highest and max m m 3
lowest temperature intervals encountered
Lopatin (1971) suggested that specific TTI values
correspond to various values of vitrinite reflectance
Waples (1980) has modified Lopatins (1971) original
calibration but Katz et al (1982) showed that Waples
correlations are likely to be incorrect for reflectance
values higher than approximately 13 Furthermore Waples
(1985) reported that the threshold for oil generation at an
R max value of 065 which was proposed in his previous
work was almost certainly too high He further stated that
different kerogen types have different oil-generation
thresholds Therefore a new correlation between TTI and
oil generation was proposed by Waples (1985) In this
79
correlation the onset of oil generation is shown to vary
from about TTI = 1 for resinite to TTI = 3 for high-sulphur
kerogens to TTI = 10 for other Type II kerogens to TTI = 15
for Type III kerogens
In the present study subsidence curves for selected
well sequences were constructed employing simple
backstripping methods and assuming no compaction effects
and the TTIs were calculated assuming constant geothermal
gradients The subsidence plots are based on
time-stratigraphic data in well completion reports and by
correlating between wells in the studied area
The amount of sediment cover removed from the sequence
was estimated using the method suggested by Dow (1977) The
loss of cover was estimated from linear extrapolation of the
reflectance profile plotted on a semilog scale to the
020 reflectance intercept The result indicates that the
average thickness of cover lost in the Muara Enim area was
about 250 metres whereas in the Pendopo area approximately
625 metres of cover lost was lost
The maturation modelling and burial history for these
areas are given in Figure 523 and Figure 524 Top of the
oil window has been plotted at TTI=3 while bottom of the oil
window has been plotted at TTI=180
For the Muara Enim area the subsidence curve shows
that burial during Early-Middle Eocene was probably slow to
moderate and mostly continuous During the Early Oligocene
the rate of sedimentation began to exceed the rate of
sn
subsidence and the palaeotopography was rapidly filled in
During this period the sea level began to rise as the major
Tertiary transgressive-regressive cycle commenced
The peak of the transgressive phase occurred in about
the Early Miocene when the Gumai Formation was
accummulating In the Middle Miocene the rate of
subsidence progressively increased resulting in the
deposition of the Air Benakat and Muara Enim Formations
During this phase of subsidence oil source rocks of the
Lahat and Talang Akar Formations entered the generative
window at about 7-8 Ma BP Probably during Late Miocene
these formations would have been generating oil and some
gas The sediments were uplifted by a Plio-Pleistocene
orogeny probably in Late Pliocene
Total Indonesie (1988) also reported that the onset of
oil generation in the Muara Enim area probably occurred 5 to
8 Ma BP which corresponds to the end of the Miocene
or beginning of the Pliocene Based on the Lopatin model
in the Muara Enim area the oil window zone can be expected
at about 1300 metres depth Average reflectance values of
054 occurred at this depth
In general sedimentation history of the Pendopo-Limau
area is similar to that in the Muara Enim area The
thickness of section suggests that the Pendopo area was the
depocentre of the basin An exception is the Baturaja
Formation which is thickest along margins of the basin and
- 1
Ji
on palaeotopographic highs Therefore the Baturaja
Formation is relatively thinner in the Muara Enim area
The significant accumulation of sediments has played an
important role in the maturation of the oil source rocks
(the Lahat and Talang Akar Formationss) In the Pendopo
area oil generation from the Talang Akar and Lahat
Formations probably started earlier (11-9 Ma BP) than in the
Muara Enim area Shell (1978) suggested that Middle Miocene
can be considered as the timing for generation of oil in the
Pendopo area
The initiation of the oil window is at 1200 metres
depth corresponding with a vitrinite reflectance value of
053 However Shell (1978) reported that the South Sumatra
crudes indicate that their generation and expulsion
commenced at an equivalent vitrinite reflectance value of
068 and a vitrinite reflectance value of 120 is
considered to be the onset of the gas expulsion
Following the Plio-Pleistocene orogeny the structural
features of the South Palembang Sub-basin were affected
The Tertiary sediments were folded and the faults were also
rejuveneted by this orogeny As discussed above in the
Pendopo area the onset of oil generation probably started
in the Middle Miocene while in the Muara Enim area the
generation of oil may have started at the end of the
Miocene-beginning of Pliocene and prior to the final pulse
of the Barisan orogeny
32
Tn relation to this event trapping can be expected in
older structures in the Pendopo area In the Muara Enim
area however the picture become more chaotic In this
areas the zones which are modelled in the oil window would
be faulted down into the gas window or they would be
faulted up above the oil window Another possibility is the
zones which are modelled above the oil window would be
pulled down into the oil window or the gas window
55 POTENTIAL RESERVOIRS
In the South Palembang Sub-basin a number of potential-
reservoir rocks occur within two main parts of the
stratigraphic sequence firstly within the regressive and
secondly within the transgressive sequence The regressive
sequence is represented by the Muara Enim and Air Benakat
Formations whereas the transgressive sequence is
represented by Baturaja and Talang Akar Formations
The Muara Enim Formation is a major reservoir in the
Muara Enim Anticlinorium It has been reported that minor
oil production was obtained from the Muara Enim Formation in
the Muara Enim field The sandstones of this formation are
medium- to coarse-grained moderately rounded and have fair
to medium porosity (37 to 395 porosity Pertamina 1988)
The sandstones of the Air Benakat Formation are fine-
to medium-grained and have a fair to medium porosity
33
Hydrocarbon accumulations in the Air Benakat Formation have
been found in the Muara Enim Anticlinorium According to
Purnomo (1984) about 20 m3 oil per day have been produced
in this area and after twenty eight years the production
rate declined to about 5 m3 The oil is of paraffinic type
with 35 to 45deg API
In 1959 oil was produced by the L5A-144 well for the
first time from the Baturaja Formation of the transgressive
sequence In general the contribution of the Baturaja
Formation as a reservoir for oil in the studied area is
minor Kalan et al (1984) reported that three major
depositional facies have been recognized in the Baturaja
Formation basal argillaceous bank carbonates main reefal
build-up carbonate and transgressive marine clastic rocks
Within these facies good porosity is restricted to the main
reefal build-up carbonate facies This porosity is
secondary and developed as a result of fresh water influx
leaching the reefal carbonate and producing chalky moldic
and vugular porosity According to the drill completion
reports of the KG-10 and MBU-2 wells porosity of Baturaja
reefal facies varies between 76 and 254 in the MBU-2 well
to 59 to 89 in the KG-10 well
The most important reservoir rocks within the South
Palembang Sub-basin are sands from the Gritsand Member of
the transgressive Talang Akar sequence The reservoirs are
multiple and the seals intraformational Sandstones of the
Talang Akar Formation are commonly coarse-grained to
34
conglomeratic and fairly clean as the result of high energy
during their deposition The porosity ranges from 15 to 25
(Hutapea 1981 Purnomo 1984) API gravity of the oil
ranges from 15 to 402
In the South Palembang Sub-basin the majority of the
oil is trapped in anticlinal traps but some oils are found
in traps related to basement features such as drapes and
stratigraphic traps The most common setting for an oil
trap is a faulted basement high with onlappingwedging-out
Talang Akar sandstones on the flanks and Baturaja Formation
on the crest as the reservoirs
35
CHAPTER SIX
CRUDE OIL AND SOURCE ROCK GEOCHEMISTRY
61 INTRODUCTION
In the present study four crude oils and four rock
samples recovered from Tertiary sequences in the study area
were analysed The details of the sample locations are given
in Table 61 The analyses included Gas Chromatography (GC)
analysis and Gas Chromatography-Mass Spectometry (GC-MS)
analysis In addition four rock samples were crushed and
analysed for TOC content and also for their pyrolysis yield
The analyses were carried out by RE Summons and JM Hope
at the Bureau of Mineral Resources Canberra
The results of the oil analyses show that the oils have
hydrocarbon distributions derived from proportionally
different contributions from plant waxes plant resins and
bacterial biomass The oils were characterized by high
concentrations of cadinane and bicadinane hydrocarbons In
general the oils are mature
The four rock samples contained 37 to 512 wt TOC
(Table 68) thus the samples can be classified as ranging
from shale to coal Based on the Rock-Eval Tmax values
three samples were categorized as immature and one sample
recovered from the deepest part of the BRG-3 well was
approaching the mature stage The GC traces show bimodal
distributions of n-alkanes and PrPh ratios in the
86
intermediate range of 4 to 5 Two samples contained high
concentrations of bicadinanes and oleanane
62 OIL GEOCHEMISTRY
621 EXPERIMENTAL METHODS
622 SAMPLE FRACTIONATION
From four oil samples approximately 100 mg of each
whole oil was placed on a 12 g silica gel column Three
fractions (ie saturates aromatics and polars) were
collected (in 100 ml round bottom flask) by eluting the
column with 40 ml petroleum spirit 50 ml petroleum
spiritdichloromethane (11) and 40 ml chloroformmethanol
(11) Each fraction was reduced in volume on a rotary
evaporator to approximately 1 ml and then transferred to a
preweighed vial with dichloromethane (05 ml) The solvent
was carefully removed by gentle exposure to a stream of dry
nitrogen Each fraction was weighed and labelled Percent
compositions were calculated on the basis of the original
weights
623 GAS CHROMATOGRAPHY ANALYSIS
A Varian 3400 GC equipped with a fused silica capillary
87
column (25m x 02mm) coated with cross-linked
methylsilicone (HP Ultra-1) was used for GC analysis The
GC analysis was carried out on the saturated hydrocarbon
fractions The samples in hexane were injected on column
at 60degC and held isothermal for 2 minutes The oven was
programmed to 300 C at 4 Cmin with a hold period of 30
minutes The carrier gas was hydrogen at a linear flow of
30 cmsec Data were collected integrated and manipulated
using DAPA GC software An internal standard
3-methylheneicosane (anteiso-C22) was added at the rate of
25ug per mg of saturates to enable absolute quantitation of
the major peaks
624 PREPARATION OF BC FRACTION
The full saturated hydrocarbon fraction proved to be
unsuitable for GC-MS owing to generally high proportions of
waxy n-alkanes An aliquot of each of the saturated
fractions was converted to a BC fraction by filtration
through a column of silicate The sample (lOmg) in pentane
(2ml) was filtered through the silicate and the column
washed with a further 5ml pentane The non-adduct (BC
fraction) was recovered by evaporation of the solvent and
the n-alkanes by dissolution of the silicate in 20 HF and
extraction of the residue with hexane This method has the
advantage of being rapid and clean but a small proportion of
the low MW n-alkanes remains in the BC fraction
88
625 GAS CHROMATOGRAPHY-MASS SPECTOMETRY ANALYSIS
GC-MS analysis was carried out using a VG 70E
instrument fitted with an HP 5790 GC and controlled by a VG
11-25 0 data system The GC was equipped with an HP Ultra-1
capillary column (50m x 02mm) and a retention gap of
uncoated fused silica (10m x 03 3mm) The samples in
hexane were injected on-column (SGE OCI-3 injector) at 50 C
and the oven programmed to 150degC at 10degCminute then to
300degC at 3degCminute with a hold period of 30 minutes The
carrier gas was hydrogen at a linear flow of 30cmsec The
mass spectrometer was operated with a source temperature of
240 C ionisation energy of 7 0eV and interface line and
re-entrant at 310degC In the full scan mode the mass
spectrometer was scanned from mz 650 to mz 50 at 18
secdecade and interscan delay of 02 sec In the multiple
reaction monitoring (MRM) mode the magnet current and ESA
voltage were switched to sequentially sample 26 selected
parent-daughter pairs including one pair (mz 404mdashgt 221)
for the deuterated sterane internal standard The sampling
time was 40ms per reaction with 10ms delay giving a total
cycle time of 13s Peaks were integrated manually and
annotated to the chromatograms
626 RESULTS
The general nature of the crude oils from reservoirs in
^q
the MBU-2 and BRG-3 wells is summarized in Table 62 in
terms of the polarity classes of saturated hydrocarbons
aromatic hydrocarbons and combined NSO-asphalthene fraction
The oils are generally dominated by saturated hydrocarbons
ranging from 637 to 774 Therefore the oils can be
classified as paraffinic (naphthenic) oils
Aromatic hydrocarbon content of the oils ranges from
207 to 27 The 540 and 541 oils are relatively higher in
aromatic hydrocarbon content (256 and 27) respectively
than those from the 542 and 543 oils (24 and 207) The
saturated and aromatic ratios from the oil samples range
from 21 to 33
The amount of polar compounds of the oils is below 10
(18 to 93) The highest amount of this compound (93)
occurs in the oil 541 while the lowest (18) occurs in the
oil 543 Figure 61 shows the bulk composition of the crude
oils
6261 GAS CHROMATOGRAPHY
The GC profiles shown in Figures 62 to 65 have been
annotated to provide peak identification The carbon number
of the n-alkanes are identified by numbers Isoprenoids are
denoted i whereas the cyclohexanes are denoted C with
the carbon number The alkane distribution profiles of the
total saturated fration of the crude oils examined are given
in Figures 62 to 65 The abundances of n-alkane
isoprenoids and bicadinanes are listed in Tables 63 and
90
54
The GC analysis of saturated hydrocarbon fractions
(C12+) of the oils revealed bimodal patterns of n-alkane
distributions in all oil samples These compounds are
probably derived from contributions of bacteria (low MW) and
terrestrial vascular plant waxes (high MW) The waxy
n-alkanes with a slight odd over even predominance were
present in all oil samples and were most abundant in oil
sample 540 from the BRG-3 well Low molecular weight
alkanes predominated in oil samples 541 542 and 543
Snowdon and Powell (1982) pointed out that the waxy oils are
believed to be associated with coals or terrestrial organic
material which is particularly rich in dispersed liptinite
such as spores and cuticles
Isoprenoid alkanes were generally abundant relative to
the n-alkanes Oil samples 540 and 541 have higher Prn-C17
ratios (208 and 277) respectively than those of the oil
samples 542 and 543 which have ratios of 07 and 09 (see
Table 64) Phn-C18 ratios of the whole oil samples range
from 025 to 047 The highest Phn-C18 ratio (047) and
Prn-Cl7 ratio (277) occur in the oil 541 which also
contains relatively high waxes The highest wax content
occurs in oil 540 and this sample also has a relatively high
Prn-C17 ratio (2=08) but the lowest Phn-C18 ratio (025)
According to Palacas et al (1984) and Waples (1985)
oils which are derived from land plant sources have a
relatively high ratio of pristane to n-C17 (gt1) and a low
91
ratio of phytane to n-C18 (lt1) These two properties are
characteristics of predominantly land-derived source organic
matter deposited under moderately oxidizing conditions
On the basis of the Prn-C17 and PrPh ratios two
groups of oil can be distinguished Group 1 and Group 2
Group 1 includes oils from the BRG-3 well (540 and 541)
whereas Group 2 contains oils 542 and 543 from the MBU-2
well High Prn-C17 and PrPh ratios present in the oils of
Group 1 clearly show that these oils were derived from
terrestrial plant matter The Group 2 however shows lower
Prn-C17 and PrPh ratios This suggests the Group 2 oils
may have originated from a different non-marine source
compared with the Group 1 oils or may have an additional
contribution from a marine source
Pristane to phytane ratios of the oils are relatively
high ranging from 211 to 80 The highest ratios are for
the oils 540 and 541 (with 65 and 80) whereas the oils
542 and 543 have a lower ratio (with 211 and 342)
High pristane to phytane ratios (greater than 30)
characterize high wax crude oils which primarily originated
in fluviatile and deltaic environment containing a
significant amount of terrestrial organic matter (Brook et
al 1969 Powel and Mc Kirdy 1975 Connan 1974 Didyk et
al 1978 Connan and Cassou 1980) Padmasiri (1984)
pointed out that a high pristane to phytane ratio is
probably due to the presence of less reducing conditions
during early diagenesis where phytanic acid was mainly
92
converted into pristane through decarboxylation rather than
direct reduction to phytane
Pristane and phytane were accompanied by high
abundances of 1-14 1-15 1-16 1-18 and 1-21 Higher
isoprenoids such as 1-25 and 1-30 (squalane) were in very
low abundance or undetected (Figures 62 to 65)
The other series of compounds evident in the GC traces
were a series of triterpenoids This series occurs as extra
peaks in the low molecular weight end of the GC traces (see
Figures 62 to 65) According to Summons and Janet Hope
(pers comm 1990) these are monomeric (sesquiterpene)
analogues of the bicadinanes and constitute the building
blocks for the polycadinane resin compounds These
bicadinanes were assigned as W T and R1 with the addition
of another compound eluting after T and denoted T
6262 GAS CHROMATOGRAPHY MASS SPECTROMETRY
Metastable reaction monitoring (MRM) chromatograms for
mz 191 reaction of the oils studied (Figure 66) show the
series of C27 C29+ pentacyclic triterpanes Tissot and
Welte (1984) noted that these series are considered to have
originated from the membranes of bacteria and cyanobacteria
The stereoisometric ratios of 22S22S+22R for C32 and C31
r hopanes (Ja[3a+a(3 for C30 hopane and 20S20S+20R for C29
norhopane can be used as maturity parameters The
22S22S+22R ratios of the oil studied are considered to be
high ranging from 51 to 61 (Table 65) They are
93
close to the end-point value of 60 which occurs once oils
are generated from mid-mature source rocks (Seifert and
Moldowan 1978 Mckenzie et al 1980) The maturity of the
oils is also indicated by a high ratio for 20S20S+20R with
C29 norhopane ranging from 40 to 56 Furthermore the
BaBa+afl ratios for C30 hopane are generally lt 01 evidence
of a mature signature of the oils
From Figure 66 it can be seen that the most abundant
class of compounds detected were the bicadinanes They were
present in high concentration in many traces The strongest
response of the bicadinanes are shown in the mz 191
reaction trace (Figure 67) In other oils they also
co-eluted with or eluted very close to the trisnohopanes (Ts
and Tm) as shown in the mz 217 responses (Figure 68)
The occurrence of bicadinanes has been reported in
oils from Indonesia Brunei Sabah and Bangladesh by
authors such as Grantham et al (1983) Van Aarsen and de
Leeuw (1989) Alam and Pearson (1990) and Van Aarsen et
al (1990) Van Aarsen et al (1990) pointed out that
bicadinanes are cyclisation products of dimeric cadinanes
released during maturation of polycadinane a component of
damar tropical tree resin of the Dipterocarpaceae family
Many species of Dipterocarpaceae grow at the present
time in most of the South Sumatra forest areas The present
and previously reported occurrences of bicadinanes show
strong links to terrigenous organic input Table 66 shows
the composition of four of the bicadinanes and the steroid
94
hydrocarbons determined by GC MS
All samples contain C27-C29 steranes In some cases
the relative abundance of C27-C29 steranes can be used as
indicators of the nature of the photosynthetic biota both
terrestrial and aquatic while triterpanes are usually
indicators of depositional and diagenetic conditions (Huang
and Meinschein 1979) Land plant inputs are usually
inferred from a dominance of the C29 steranes However
algae also possess a wide range of desmethyl sterols
(C26-C29) and may produce an oil with a major C29 component
The distribution of steranes and methyl steranes from the
samples is shown in Figure 68 and listed in Table 65 and
Table 66
In the present study organic facies of the oil samples
were identified using a triangular diagram which shows
C27-C29 sterane distribution (Figure 69) This triangular
diagram was adapted from Waples and Machihara (1990) This
diagram shows that the origin of most of oil samples may be
higher plants which have a strong predominance of the C29
sterane The distribution of hopanes steranes and
bicadinanes from all the samples is shown in Table 67
Biodegradation of a crude oil can be indicated by the
removal of n-alkanes isoprenoids and other branched
alkanes and even some cyclic alkanes (Bailey et al 1973
Goodwin et al 1983 Cook and Ranasinghe 1989) In the
early stages of biodegradation low molecular weight
n-alkanes are removed whereas the isoprenoids are
95
residualized Therefore degraded oils contain fewer normal
paraffins or waxes than non-degraded ones In extensively
biodegraded oils all C14-C16 bicyclic alkanes are removed
followed by steranes In very heavily biodegraded oils up
to 50 of the 50a(H)14a(H)17a(H)20R isomers from the
C27-C29 steranes are removed and finally regular steranes
are also removed and changed into diasterane (Cook and
Ranasinghe 1989) Therefore in severely biodegraded oils
a high concentration of diasteranes is present
Figures 62 to 65 show that for the oils studied
abundant n-alkanes (C9 to C34) are present Volkman et al
(1983) noted that non-degraded oils show low values for the
pristanen-C17 and phytanen-C18 ratios
63 SOURCE ROCK GEOCHEMISTRY
631 EXPERIMENTAL SECTION
Four rock samples comprising shales and coals were
collected from different rock formations that is the Muara
Enim and Talang Akar Formations In general the samples
were treated by similar methods using GC analysis
preparation of BC fractions and GC-MS analysis Because
the samples were rock sample extraction was carried out as
described below
96
6311 SAMPLE EXTRACTION
The samples were crushed and analysed for TOC content
using a Leco carbon analyser The samples were also
analysed for their pyrolysis yield using a Girdel Rock-Eval
II instrument The crushed sediments were extracted using
pre-washed soxhlets and thimbles using 8713 CHCL3MeOH as
solvent and continuing the process for 48 hours The
extracts were filtered using micrometre filters and then
evaporated to near dryness These extracts were then
treated as oil and separated into the different polarity
fractions by column chromatography
632 RESULTS
The results of the total organic carbon (TOC)
Rock-Eval data and the composition of the extracts in terms
of the polarity classes of saturated hydrocarbons aromatic
hydrocarbons and combined SO-asphaltene fraction are shown
in Table 68 and Figure 610 Linear alkane distribution
profiles of the saturated fractions of the extracts are
given in Figures 611 to 614 Table 69 shows the
composition of saturated hydrocarbons determined by GC
analysis of this fraction Pristane and phytane ratios are
given in Table 611
Table 68 shows that all the samples exceed the minimum
critical limit accepted for hydrocarbon generation from
37
clastic rocks (05 wt TOC) as mentioned by Welte (1965) and
Phillipi (1969) The two shale samples contained a lower
percentage TOC (37 and 41 wt) than the two coal samples
which contained 269 and 512 wt TOC although only one
sample can be classified as true coal The two coal samples
also had relatively high HI values of 230 and both could
possibly represent source rock intervals although only the
deepest sample which has Rymax 083 is considered to be
mature
A source rock potential study of the Tertiary sequences
from the South Palembang Sub-basin has also been carried out
by Sarjono and Sardjito (1989) as summarized below
Formation Total Organic Carbon Tmax
Lahat
Talang Akar
Baturaja
Gumai
Air Benakat
Muara Enim
17
03
02
05
05
05
to
to
to
to
to
to
85
80
15
115
17
527
436-441
425-450
425-450
400-440
gt430
gt430
In the present study the Rock-Eval Tmax data show that
the samples from Talang Akar Formation were approaching the
appropriate maturity of 433 to 446degC Espitalie et al
(1985) suggested that the beginning of the oil-formation
zone is at Tmax of 430 to 435degC whereas the beginning of
the gas zone starts with Tmax of 465 to 470degC for Type III
98
and 450 to 455degC for Type II kerogen (Figure 615) However
Tmax is infuenced by organic matter type with liptinites
generally giving higher Tmax values compared with vitrinite
(Cook and Ranasinghe 1990)
The production index (PI) of the samples varies from
006 to 020 Espitalie et al (1985) also noted that the
PI can be used as another criterion of maturity They
suggested the oil-formation zone begins at PI values between
005 and 010 The maximum oil formation is reached at Pis
of 030 to 040 Beyond this the PI values tend to remain
stationary or even decrease (gas formed)
A plot of the hydrogen index (HI) and oxygen index (01)
is given in Figure 616 It is clearly seen that the samples
are categorized as Type III kerogen which would be largely
derived from the woody portions of higher plants
The GC traces of the four samples all show bimodal
distribution of n-alkanes and PrPh ratios in the
intermediate range of 4 to 5 The coal sample from the
Muara Enim Formation (5384) shows a predominance of odd
carbon number waxy n-alkanes which implies a high
terrestrial plant input (Figure 612) Shale sample (5385)
which was taken from the Talang Akar Formation shows a
predominance of low carbon number n-alkanes without
significant oddeven predominance (Figure 613) The
shallow (5383) and deep (5386) samples both show about equal
abundances of short and long-chain n-alkanes but
additionally sample 5386 has only a weak oddeven
99
predominance (Figures 611 and 614)
Based on the distribution of C31 aB hopanes (22Rgtgt22S)
it is clearly shown that the shallow samples (5383 and 5384)
are very immature (Rvmax 041 and 047) The Talang Akar
samples (5385 and 5386) having reflectance values of 071
and 083 however show some mixed characteristics with an
immature distribution of C31 aB hopanes (22Rgtgt22S) an
immature C29 sterane 20S20R pattern a mature aB
(hopane)Ba (moretane) ratio and a mature C27 sterane
distribution The 20S20R ratio of C28 sterane is
intermediate Based on these characteristics it may be
concluded that the deepest sample (5386) is only just
approaching oil generation maturity but the sterane 20R20S
ratio of the oil sample 541 was similar to the sample 5386
A high concentration of bicadinanes and oleanane was
also shown in the Talang Akar samples (5385 and 5386)
These characteristics are also found in the two oil samples
which were taken from the same well However due to the
limitations of the data these similarities could not be
used to determine whether the Talang Akar samples represent
a source rock for the oils The biomarker signature and
thermal maturity of the deepest sample (5386) shows similar
patterns with those from the oil sample (541)
100
CHAPTER SEVEN
COAL POTENTIAL OF SOUTH PALEMBANG SUBBASIN
71 INTRODUCTION
The regional stratigraphy of the South Sumatra Basin
shows that coal seams occur more or less continuously over a
number of the Tertiary formations such as the Lahat Talang
Akar and Muara Enim Formations The coals with economic
potential are largely within the Muara Enim Formation
An assessment of coal potential in the South Sumatra
Basin was made by Shell Mijnbouw during a major coal
exploration program from 1974 to 1978 The area for coal
exploration included the South Palembang Sub-basin In the
South Palembang Sub-basin several government institutions
such as the Directorate of Mineral Resources (DMR) the
Mineral Technology Development Centre (MTDC) and the
Directorate of Coal (DOC) have also been involved in
exploration for and development of the Muara Enim coals
The volume of coal available in the South Palembang
Sub-basin was assessed by Shell Mijnbouw (1978) at
approximately 2590 million cubic metres to a depth of 100
metres below the ground surface These reserves are
clustered into two areas the Enim and Pendopo areas
Two thirds of the volume of the coal is found in the seams
of the M4 unit but the coals are low in rank
101
72 COAL DIVISIONS IN THE MUARA ENIM FORMATION
As mentioned in Chapter Three the Muara Enim Formation
can be divided into four subdivisions (from top to bottom)
M4 M3 M2 Ml subdivisions (See Table 33)
The oldest unit the Ml subdivision consists of two
coal seams the irregularly developed Merapi seam and the
5-10 metres thick Kladi seam at the base of the unit
Neither of these seams generally offer a resource potential
within the range of economic surface mining The interseam
sequence between the Kladi and Merapi seams is characterized
by brown and grey sandstone siltstone and claystone with
minor glauconitic sandstone
The M2 subdivision comprises three coal units (from top
to bottom) Mangus Suban and Petai Haan (1976) recognized
that most of these units locally split into two seams which
are designated as follows
Mangus unit Al and A2 seams
Suban unit BI and B2 seams
Petai Unit CI and C2 seams
These seams can be found in the area around Bukit Asam
From the viewpoint of economically mineable coal reserves
the M2 subdivision is locally the most important coal unit
particularly in the Enim area The coals are mainly hard
brown coal in rank but high rank anthracitic coals can be
also found in the immediate vicinity of some andesite
intrusions
102
The interseam rocks in the M2 subdivision are limnic
(perhaps in places lagoonalbrackish) and mainly consist of
brown to grey claystone and brown-grey fine-grained to
medium-grained sandstone and some green-grey sandstones
The coal seams of the M2 subdivision have several good
marker features which can be used to identify the seams
convincingly A clay marker horizon within the Mangus seam
is used to correlate the interval over most of the area A
well known tuffaceous horizon that separates the Al and A2
seams of the Mangus unit also can be used as a marker bed
This horizon was probably deposited over a wide area during
a short interval of volcanic activity
The M3 subdivision contains two main coal layers the
Burung in the lower part and the Benuang in the upper part
both of which are only of minor economic significance
These coal layers have several characteristic sandstone
horizons and they can be recognized in most areas The
thickness of the M3 division varies from 40 to 120 metres
The uppermost and stratigraphically youngest part of
the Muara Enim Formation is the M4 subdivision (120-200
metres thick) The M4 subdivision contains the Kebon Enim
Jelawatan and Niru seams The coals of this subdivision
were formerly called the Hanging layers in the Bukit Asam
area Jelawatan and Enim seams contain coal of a lower
rank with a lower calorific value and higher moisture
content than those of the M2 Subdivision In some areas the
M4 seams offer an interesting resource potential
103
The predominant rocks of the M4 Subdivision are
blue-green tuffaceous claystone and sandy claystone some
dark brown coaly claystone some white and grey fine-grained
to coarse-grained sandstone with sparse glauconite
indicating marine-deltaic to fluvial conditions
73 DISTRIBUTION OF MUARA ENIM COALS
In the South Palembang Sub-basin the Muara Enim coals
are clustered in two areas Enim and Pendopo area During
the major coal exploration program from 1974-1978 Shell
Mijnbouw divided the Enim area into two prospect areas West
Enim area (includes Arahan-Air Serelo-Air Lawai area) and
East Enim area (includes Banko-Suban Jerigi area) In these
areas a detailed coal exploration program was also
undertaken by DMR (1983-1985) and DOC (1985-1988) Data
from these institutions and from Shell Mijnbouw (197 8) have
been used in the present study The Pendopo area is divided
into three prospect areas Muara Lakitan-Talang Langaran
Talang Akar-Sigoyang Benuang and Prabumulih areas In
addition one particular aspect of the Muara Enim coals is
the presence of anthracitic quality coals caused by thermal
effects of andesitic intrusions These coals can be found
near the intrusive bodies of Bukit Asam Bukit Bunian and
Bukit Kendi They will be discussed separately
104
731 ENIM PROSPECT AREAS
The Enim Prospect areas can be divided into two areas
West Enim areas including Arahan Muara Tiga Banjarsari and
Kungkilan area and East Enim areas including Banko and
Suban Jerigi area The Bukit Asam coal mines actually are
included in the West Enim area but because it has already
been mined since 1919 its coal resources will be discussed
in a separate section (Section 78)
The oldest coal seam of M2 subdivision Kladi seam has
been reported to occur in the Air Serelo area The Kladi
seam offers a good prospect in terms of quality and is up to
9 metres in thickness The coal is relatively clean and
high in rank
In the Enim area the Petai seam (C) of the M2
subdivision is developed throughout the areas as a 5-9
metres seam Locally this seam splits into two layers (CI
and C2) which have been recognized at the southern part of
West Banko and also at Central Banko (Kinhill Otto Gold
1987) The combined thickness of these seams commonly
exceeds 12 metres
In general the most uniformly developed seam in these
areas is the Suban seam (B) of the M2 Subdivision This
seam has a thickness varying from 15 to 20 metres and is
characterized by up to six claystone bands It has been
reported that the Suban seam splits into a thicker (10-15
metres) upper (BI) and a thinner (2-5 metres) lower (B2)
105
seam in East Banjarsari West Banko and Central Banko
(Kinhill Otto Gold 1987)
The Mangus seam (A) of the M2 Subdivision occurs as two
leaves Al and A2 in most areas except in Arahan South
Muara Tiga and West Banko In these latter areas the
Mangus seam is split into numerous thin streaks and
interbeds by thick fluvial intersections The A2 seam is
fairly uniformly thick (8-12 metres) in most areas except
Central Banko where it tends to split The Al seam is
generally 8-10 metres thick but it splits into numerous
thin seams in the areas mentioned above
A 9 to 12 metres thick development of the Enim seam
occurs over large areas and it is generally free from dirt
bands The thickness of this seam reaches approximately 27
metres at Banjarsari and North Suban Jerigi area
Another interesting seam is the Jelawatan seam which
has a thickness between 6 to 15 metres at Banjarsari and
Suban Jerigi area
7312 PENDOPO AREA
During the Shell Mijnbouw Coal Exploration Program the
studied areas near Pendopo included Muara Lakitan and Talang
Langaran Talang Akar and Sigoyang Benuang West Benakat and
Prabumulih areas Coals from the M2 M3 and M4 subdivisions
are found in these areas
Seams present in the M2 subdivision include the Petai
106
Suban and Mangus seams The Petai seam occurs in the
Sigoyang Benuang Prabumulih and West Benakat area The
thickness of this seam varies from 5 to 8 metres The Suban
seam is found at Sigoyang Benuang and West Benakat The
Suban seam has a thickness between 9 to 13 metres The most
widely distributed seam in the M2 subdivision is the Mangus
seam It occurs over all of the Pendopo areas The
thickness of the seam varies from 6 to 13 metres The
thickest development of the Mangus seam is found in the West
Benakat area but unfortunately the dips of the seam are
relatively steep around 15
The M3 subdivision is represented by the occurrence of
the Benuang (Burung) seam which has a thickness of about 5
to 9 metres This seam can be found in the Talang Langaran
Sigoyang Benuang and West Benakat areas
Coals of the M4 subdivision are found in the whole
Pendopo area These coals are the Niru Jelawatan Kebon
Enim and Niru seams The Enim seam offers an attractive
mining target in terms of thickness as it ranges from 9 to
24 metres The thickness of the Niru seam varies from 6 to
11 metres The Jelawatan seam reaches 15 metres in
thickness in the Talang Akar area while a 5 metre thick
development of the Kebon seam is found in the Muara Lakitan
area
107
74 COAL QUALITY
On the basis of the potential use for brown coal as a
thermal energy source (calorific value and moisture content
being the main determinants of suitability) the quality of
South Sumatra coals was summarized by Shell Mijnbouw (197 8)
According to Shell Mijnbouw (197 8) the older coals of the
Ml and M2 subdivisions contain about 30-50 moisture while
the moisture content of coals of M3 and M4 subdivisions
ranges between 40-65 The dry ash-free gross calorific
value of Ml and M2 coals ranges between 6500 and 7500
kcalkg and it varies between 6100 and 7000 kcalkg for the
M3 and M4 coals The inherent ash content of coals is
usually less than 6 (dry basis) Sulphur content of the
coals is generally less than 1 (dry basis) but locally it
increases to 4 (dry basis) in some areas
Kinhill Otto Gold (19 87) has also determined the
quality of coals from specific areas such as the Enim area
According to the Kinhill Otto Gold results the rank of
coals in the Enim areas varies between sub-bituminous A
(ASTM)brown coals Class 1 (ISO)Glanzbraunkohle (German
classification) and Lignite Bbrown coals Class
5Weichbraunkohle (Kinhill Otto Gold 1987) Quality values
for the coals typically range between
Total Moisture 23-54
Ash (dry basis) 3-12
Sulphur (dry basis) 02-17
10 8
CV net (in-situ) 10-20 MJkg
Sodium in ash 18-8
Grindability 37-56 HGI
Further details of the coal qualities of the Pendopo
and Enim areas are given in Table 71-76 where the
parameters of thickness total moisture (TM) ash sulphur
volatiles and calorific values are listed Values are
averages for each seam and for each area or sub-area
75 ASH COMPOSITION
The ash composition data were obtained from Kinhill
Otto Gold (1987) According to this report the major
mineral components in Sumatran coals are quartz (detrital)
and kaolinite Small amounts of pyrite (marcasite)
volcanic feldspar Ca and Ca-Mg-Fe carbonates and sulphates
and phosphates are also present Volcanic tuff bands which
are commonly present in the coals contain mainly kaolinized
volcanic glass
A study of sodium content in the coal ash was also done
by Kinhill-Otto Gold (1987) particularly for coals in the
Enim area This study is important in relation to use of
these coals in thermal power station The Na~0 values above
3-4 are indicative of undesirable fouling and slagging
characteristics in industrial boilers and strongly lower the
ash fusion temperatures Substantial impact on boiler
operation is expected above 6-8 Na~0 The results
109
of sodium-in-ash analyses are listed in Table 77 The
analyses were performed on coal samples following the
procedures of ISO
According to Kinhill-Otto Gold (1987) the upper seam
group (M4) with the Enim and Jelawatan seams has moderate
sodium content (below 25) and peak values rarely reach
50 The lower group of seams (M2) including the Al A2
BBl and CC1-C2 seams has a moderately high to high Na20
content
76 STRUCTURES
In general the tectonic style of the area under study
is characterized by fold and fault structures Pulunggono
(1986) recognized that these structures run parallel with a
WNW-ESE trend He also concluded that the Plio-Pleistocene
orogeny was responsible for these WNW-ESE trending folded
structures with accompanying faults
Within the Pendopo areas the general trends of folds
is NW-SE This trend can be observed at Muara Lakitan area
and Talang Langaran area The NW-SE folds at Muara Lakitan
have gently to moderately dipping flanks less than 20deg
The average inclination of coal seams in the Muara Lakitan
area is about 8deg while that in the Talang Langaran area is
steeper (15 ) than that in the Muara Lakitan Low seam dips
(about 6 ) are found in the areas of Talang Akar and
Sigoyang Benuang but they become steeper (20deg) in the
110
vicinity of N-S and NE-SW faults Numerous small faults
trending N-S and NE-SW occur in the West Benakat area
Steep dips of the coal seam (around 15deg) cause difficulties
from the mining point of view In the Prabumulih area dips
of coal seams are generally low (6-10deg)
In general the strike direction of the fold axes in
the Enim area occurs at approximately E-W (80-100deg see
Figure 15) This direction turns towards WNW-ESE
(100-130deg) in the northwestern part of the Bukit Asam area
In the Northwest Banko area directions of 130-160deg are
predominant The structural features of the Banko-Suban
Jerigi area are more complicated than those in other areas
Numerous folds and faults are present in these areas A
NW-SE anticlinal axis is closely related to numerous
displacements along NNE-SSW NNW-SSE NE-SW and WNW-ESE
directions Dip angles range from 5 to 2
In the Arahan area particularly in the northern part
of this area dips of coal seams are relatively low (around
7deg) but they become higher (9-10 ) in the southern area
Relatively steep (around 14-19 ) dips of coal seams are
present in the Air Lawai areas Although the coal seams of
this area offer good prospects in term of thickness (9-20
metres) the dips of the seams are too steep for surface
mining As discussed above the geological structures of
the Banko-Suban Jerigi area are complicated due to intensive
faulting Therefore the mineable areas are restricted to
some of the relatively larger blocks bounded by fault
Ill
planes Dip angles of coal seams vary between 5 to 20
77 COAL RESERVES
As mentioned previously Shell Mijnbouw (1978) divided
the Pendopo area into four subareas the Muara Lakitan and
Talang Langaran area Talang Akar and Sigoyang Benuang area
West Benakat area and Prabumulih area Coal reserves for
each of these areas were also estimated
An in-situ coal volume of approximately 300 million
cubic metres can be expected in the Muara Lakitan and Talang
Langaran areas combined with a maximum overburden thickness
of 50 metres a minimum coal seam thickness of 5 metres and
a maximum 15 dip of the seam (Shell Mijnbouw 1978) The
Talang Akar and Sigoyang Benuang areas have about 1330
million cubic metres in-situ coal volume The coal
resources of the West Benakat area however were not
calculated because the coal seams are either too steep or
too thin In the Prabumulih area surface-mineable coal
reserves for seams of more than 5 metres in thickness and
less than 15 dip amount to 400 million cubic metres down to
50 metres depth
Although coal reserves in the Enim area had already
been estimated by Shell Mijnbouw the reserve estimates were
also made by Kinhill otto Gold (1987) and the latter are
used in the present study The classification of the
geological reserves used by Kinhill Otto Gold follows the US
112
Geological Survey system A summary of coal resources of
the Enim area is given in Table 78
78 THE BUKIT ASAM COAL MINES
Coals occurring in the Bukit Asam Mines area are known
as the Air Laya Coal Deposit because one of the mines
operating is in the Air Laya area These coals have been
mined since 1919 in underground workings but the mines were
abandoned in 1942 Since then coal mines have been
operated by surface mining systems Another coal mine is
located in the Suban area where anthracitic coals are mined
The mines are operated by the state-owned Indonesian
company PT Tambang Batubara Bukit Asam (Persero)
The geology of the Air Laya Coal Deposit was studied in
detail by Mannhardt (1921) Haan (1976) Frank (1978)
Matasak and Kendarsi (1980) and Schwartzenberg (1986)
The Air Laya Coal Deposit is characterized by the close
proximity of sedimentary and plutonic petrofacies The
thermal and kinematic impacts of the plutonic intrusions
have decisively influenced the structure and the coal
quality Mannhardt (1921) assummed that the plutonic
intrusions are probably laccoliths
The coal seams exposed in the Bukit Asam Mines belong
to the M2 Subdivision of the Muara Enim Formation (Figure
71)
113
781 STRATIGRAPHY
7811 QUATERNARY SUCCESSION
This unit consists mainly of river gravel and sands
from the ancient Enim River and overlies soft clay deposits
which are interbedded with bentonite layers of former ash
tuffs and occasional large volcanic bombs (Schwartzenberg
1986) The thickness of this unit is about 20 metres
7812 TERTIARY SUCCESSION
In the Bukit Asam Coal Mines the Tertiary succession
can be divided into two subunits coal seams overburden and
intercalations
78121 Coal seams
Three coal units of the M2 Subdivision occur in the
Bukit Asam area they are the Mangus Suban and Petai
seams The Mangus seam is split into two layers (Al and A2
seam) by a 4 to 5 metres thick unit of tuffaceous claystones
and sandstones The thickness of the Al seam is about 25
to 98 metres whereas that of the A2 seam is around 42 to
129 metres thick
The Suban seam also splits into two layers (BI and B2
seam) The BI seam is usually the best developed of the
114
sequence with an average thickness of 11 metres The B2
seam is about 2 to 5 metres in thickness
The lowest coal seam in the Bukit Asam area is the
Petai seam It varies in thickness between 42 to 108
metres
78122 Overburden and Intercalations
The overlying strata consist of claystones and
siltstones which are interbedded with up to three bentonitic
clay layers (each only a few metres in thickness) The
claystones are blue-green to grey in colour and are usually
massive but sometimes they are finely banded Clay
ironstone nodules are abundant in this unit They vary in
size from small pebbles to large cobbles
Tuffaceous claystone and sandstone occur as the
intercalation layers between the A (Mangus) seams This
unit is continuously graded from the base where quartz and
lithic fragments are enclosed in a clay matrix to the top
where the rock is fine-grained and clayey The thickness of
this unit is about 4 to 5 metres
The interseam strata between Al-Bl and B1-B2 coal seams
are characterized by similar rock types to those of the
overlying strata but plant remains occur more frequently in
the interseam strata A thin coal intercalation of 02-04
metres in thickness occurs within the A2-B1 interval This
coal is known as the Suban Coal Marker The thickness of
115
the A2-B1 interval is around 18 to 23 metres whereas that
of B1-B2 interval is up to 5 metres In the western part of
the Bukit Asam area the intercalation between B1-B2
disappears and the B1-B2 seams merge together
A sequence of some 33-40 metres of siltstone and silty
sandstone occurs between the B2 seam and C (Petai) seam
This sequence consists of glauconitic sandstone alternating
with thin lenticular and ripple-bedded siltstone layers
These sedimentary structures suggest sedimentation within
tidal zones (Schwartzenberg 1986) In the Suban mine an
andesite sill is intruded into the B2-C intercalation and
increased its thickness from about 35 to 60 metres
782 COAL QUALITY
The Bukit Asam coals are characterized by a wide range
of quality due to the intrusion of a number of andesitic
plutons during the Early Quarternary The heating has
increased the extent of coalification and advanced the rank
of coals In terms of coal rank three classes of coals are
found in the Bukit Asam area They are semianthracite to
anthracite bituminous and sub-bituminous coals Kendarsi
(1984) and Schwartzenberg (1986) described the quality of
the Air Laya coal deposit According to them the total
moisture of the Air Laya coals varies between 4 and 26
The ash content of the coals ranges between 6-7 and reaches
maximum values of around 10 in the areas of greater
116
coalification (Schwartzenberg 1986) Volatile matter of
the coals is about 321 (as received) while fixed carbon
content is around 403 (as received) Heat value of the
coals ranges between 5425 to above 6000 kcalkg (as
received) The sulphur content of the coals varies between
each seam The Al seam contains 05 A2 and BI seams
contain 03 B2 seam contains 09 and C seam contains
11 From these figures it can be concluded that the
lower part of the M2 Subdivision was more influenced by
marine conditions
Kendarsi (1984) reported the quality of coals from the
Suban mine on an air dried basis as described below
Gross CV 7900-8200 Kcalkg
Inherent moisture 17-23
Total Moisture 37-62
Volatile matter 82-168
Fixed Carbon 750-844
Ash 16-58
Total sulphur 07-12
783 COAL RESERVES
Schwartzenberg (1986) estimated and described the
reserves of the Muara Enim coals in the Air Laya mine based
on the ASTM-Standards (D 388-77) as described below
117
Class Group Approximate Tonnages
Anthracite 3Semianthracite 1000000
Bituminous
Sub-bituminous
lLow Volatile
2Medium Volatile
3High Volatile A 4High Volatile B 5High Volatile C
lSub-bituminous A
2Sub-bituminous B
15000000
30000000
66000000
T o t a l 112000000 tones
The reserves of anthracitic coals at the Suban mine
have been reported by Kendarsi (19 84) to be approximately
54 million tonnes
79 BUKIT KENDI COALS
Bukit Kendi is located about 10 kilometres southwest of
Bukit Asam Ziegler (1921) described the coals of this area
and identified the coal sequences as (from young to old)
the Hanging seams the Gambir seams the Kendi seam and the
Kabau seam The Hanging seam comprises 2 to 8 seams which
total 15 metres in thickness This seam probably belongs to
M3-M4 subdivision (Shell 1978) The Gambir seams consists
118
of 1 to 3 layers having a thickness between 2 and 10 metres
This seam probably belongs to the M3 subdivision The Kendi
seam is 8-30 metres in total thickness in the Bukit Kendi
area The Kendi seam comprises 2 to 3 layers and can be
correlated with the Mangus-Suban-Petai sequence of the M2
subdivision The Kabau seam is split into two layers with 2
to 6 metres total thickness This seam is believed to be
equivalent with the Kladi seam of the Ml subdivision
The rank of Kendi coals has been upgraded by an
andesitic intrusion from brown coal to high volatile
bituminous coal Unfortunately this coal is distributed
only in limited small areas due to the structural
complications in this region Naturally coked coals have
also been found in this area and they probably belong to
the Kabau seam The quality of the Kabau seam is described
in Table 79
Shell Mijnbouw (197 8) estimated the in-situ resources
of the Kabau seam about 05 million tonnes down to 100
metres depth
710 BUKIT BUNIAN COALS
Bukit Bunian is located 10 kilometres south of Bukit
Kendi In this area two coal groups occur which were
designated by Hartmann (1921) as the Tahis and Bilau seams
The Tahis seam can be correlated with the Kladi seam of the
Ml subdivision (Shell Mijnbouw 1978) whereas the Bilau
119
seams are believed to be equivalent with the Mangus Suban
and Petai seams The Tahis seam is split into two layers
and has a total thickness up to 4 metres The Bilau seams
can be divided into three Bilau 1 2 and 3 The Bilau 1
is a poorly developed seam consisting of 2 or 3 thin layers
and often contains carbonaceous clay The thickness of this
seam varies from 05 to 15 metres The best developed coal
seam is Bilau 2 about 10-15 metres in thickness whereas
the thickness of Bilau 3 seam varies from 15 to 8 metres
The quality of the Bunian coals was reported by Shell
Mijbouw (197 8) According to this report the reflectance
values of the Bukit Bunian coals are about 06 to 08 and
the coals have gross calorific values of about 7100-7900
kcalkg (dried air free) Inherent moisture of the coals
varies between 10 to 18 Volatile matter contents of the
coals range from 40 to 55 (dry) The coals contain less
than 5 ash and contain less than 1 to 26 sulphur on a
dry basis In the area closer to the intrusive body gross
calorific values of the coals increase to about 8300-8500
kcalkg (dried air free) and volatile matter content
decreases to about 4 Inherent moisture content of the
thermally upgraded coals drops to 1
The resources of coal have been reported to be more
than 35 million tonnes but these resources would be
difficult to mine by either open-pit or subsurface methods
due to very steep dips (20-55deg) and the complicated
structural setting
120
CHAPTER EIGHT
COAL UTILIZATION
81 INTRODUCTION
In Indonesia the utilization of coal for domestic
purposes can be divided into two categories firstly as
direct fuel for example in power plants lime brick tile
burning and cement plants and secondly as an indirect fuel
or as a feedstock for chemical industries In this last
case a major use is coke as a reductant in ore smelting and
foundries
The utilization of coal cannot be separated from the
application of coal petrographic studies because the
behavior of coal properties such as type and rank will
influence the utilization of coal Petrographic methods are
generally the most suited for determining the genetic
characteristics of coal the rank of coal and can be also
used to predict the behavior of coal in any technological
process of interest
At the present time the South Sumatra coals
particularly from the M2 subdivision of the Muara Enim are
mainly used for steam generation This energy is used
directly and indirectly in industrial processes and by
utilities for electric power generation Semi-anthracite
coals from the Suban mine are used mainly as reductant in
the Bangka tin smelter
121
The coals are transported by train from the Bukit Asam
mines to supply the cement manufacturing plant at Baturaja
town the electric power plants at Bukit Asam itself or at
Suralaya (West Java) and to supply the Bangka tin smelter
on Bangka Island (see Figure 81)
82 COMBUSTION
Mackowsky (1982) and Bustin et al (1983) noted that
the generation of energy or heat from coal by combustion is
the result of reactions between the combustible matter of
the coal and oxygen Four coal characteristics related to
rank and petrographic composition influence combustion
(Neavel 1981 Mackowsky 1982) calorific value
grindability swelling and ignition behavior and ash
properties
The relationship between calorific value and maceral
groups has been discussed by Kroger (1957) as shown in Table
81 From these data it can be concluded that macerals
which have a high hydrogen content would have markedly
higher calorific value Liptinite macerals of low rank
coals contain relatively high hydrogen Therefore the
calorific value of this maceral is also high In contrast
the inertinite macerals have low calorific values which are
partially caused by their low hydrogen content Mackowsky
(1982) recognized that the calorific value of the three
maceral groups are almost the same for coals of low volatile
bituminous rank
122
The use of coal for combustion at present is dominated
by its use as pulverized fuel for electric power generation
Baker (1979) considered that moisture content of coal is the
most important factor to be considered in fuel pulverized
plant design because variable and excessive moisture can
cause serious problems in the operation of pulverizers
Therefore coal must be dry before entering the pulverized
fuel plant
In most power station boilers coal must be pulverized
to a particle size mainly below 7 5 microns (Ward 1984)
Therefore grindability of a coal is an important
characteristic because of the additional energy required to
grind a hard tough coal Based on the ASTM Standard D-409
this property of coal is known as the Hardgrove Grindability
Index (HGI) the higher the HGI values the easier coals are
to pulverize In terms of energy required the higher HGI
values mean less energy is required for grinding than for
lower HGI values The grindability of the Muara Enim coals
ranges between 37-56 HGI
The HGI is related to rank and type of a coal This
relationship has been studied by Neavel (1981) He noted
that the HGI increases with increases in rank to about 140
vitrinite reflectance (about 23 volatile matter and 90 C)
and decreases at ranks greater than 140 vitrinite
reflectance Low-volatile bituminous coals are generally
much easier to pulverize than high-volatile coals Coals
rich in liptinite and inertinite are much more difficult to
123
grind than vitrinite-rich coal The Muara Enim coals are
rich in vitrinite but are easy to grind and commonly
accumulate in the finer fractions being enriched in the
small size range In addition mineral content of coal is
also related to the HGI values In low rank coals the HGI
values increase with increases in mineral matter content
Neavel (1981) reported that increases in the amounts of
liptinite vitrinite and pyrite can be correlated with an
increase in the explosive tendencies of dust Furthermore
he added that the tendency for spontaneous combustion in
stockpiles is mainly related to the presence of coals rich
in fusinite or pyrite The Muara Enim coals have a low
content of fusinite (less than 1) but the tendency for
spontaneous combustion is still high due to their low rank
and in some cases high pyrite content
The behavior of the individual coal macerals during the
combustion process has been observed by Ramsden and Shibaoka
(1979) using optical microscopy They indicated that
vitrinite-rich particles from bituminous and sub-bituminous
coals expand forming cellular structures However
fusinite-rich particles show little or no expansion
Expansion is greatest for medium volatile coals where it is
mainly influenced by the rate of heating They also noted
that the burn-off rate is influenced by the maceral content
Vitrinite-rich particles have a higher burn-off rate than
fusinite-rich particles
Reid (1981) noted that the ash properties are related
124
to mineral composition in the coals Mineral matter affects
the development of deposits and corrosion Variations in
type of mineral matter also can affect ash fusion
properties Coals that have low ash fusion temperatures are
likely to cause slag deposits to form on the boiler
surfaces Boilers can become coated or corroded by slag
deposits
The major elements of the ash in the Muara Enim
coals that is Fe Mn Ca Mg Na and K are bonded to the
coal These elements are present in minerals such as
quartz kaolinite pyrite detrital volcanic feldsphar Ca
and Ca-Mg-Fe carbonates sulphates and phosphates Sulphur
is a major contributor to corrosion by flue gases Sulphur
content of Muara Enim coals varies between 02 to 17
83 GASIFICATION
Gasification of coal is another possibility for using
Muara Enim coals Through gasification the coal is
converted into gas by using oxygen andor steam as the
gasification agent The gas yielded can be used as an
alternative to natural gas Gasification testing of the
coals from the Bukit Asam mines has been done by using the
Koppers-Totzek process (Gapp 1980) According to tests
the coals produced good results for gasification
In South Sumatra a large nitrogen fertilizer industry
is based on natural gas This industry is located near
125
Palembang City Continued future operation of this facility
depends on an assured supply of natural gas as its
feedstock Reserves of mineral oil and natural gas are
limited whereas abundant coal is available By using coal
gasification technology synthetic gas can be produced
economically for ammonia and methanol production Hartarto
and Hidayat (1980) estimated that one coal gasification
plant would consume about 700000 tonnes of coal per year to
produce 1000 tonnes ammonia per day He added that from
these figures about 7000-8000 tones of sulphur can be
produced a year as a useful by product Most of Indonesias
sulphur requirement is still imported because there are no
large sulphur deposits within the country Therefore
sulphur from coals could replace this import
84 CARBONISATION
In the area of coal carbonization or coke making the
application of coal petrology plays an important role
Maceral and reflectance analysis can be used to predict the
behavior of coals used for coke In general coals in the
bituminous rank range (from about 075 to 17 vitrinite
reflectance) will produce cokes when heated but the best
quality cokes are produced from coals in the range vitrinite
reflectances from 11 to 16 (Cook pers coram 1991)
However not all bituminous coals can produce coke
Carbonisation or coke making is a process of destructive
126
distillation of organic substances in the absence of air
(Crelling 1980 Neavel 1981 Cook 1982 Makowsky 1982)
In this process coal is heated in the absence of air and
turns into a hard sponge-like mass of nearly pure carbon
Coke is mainly used in iron making blast furnaces In the
furnace the coke has three functions to burn and to
produce heat to act as a reductant and to support
physically the weight of ore coke and fluxing agents in
the upper part of the shaft (Cook 1982)
In order to improve coking properties of Muara Enim
coals a Lurgi low temperature carbonization pilot plant was
built in the Bukit Asam area (Tobing 1980) The result of
the tests indicated that metallurgical coke of sufficient
strength and porosity could not be made on an economical
basis Tobing (1980) described the chemical characteristic
of the semi cokes which were produced from the Lurgi plant
and they were similar to the Bukit Asam semi-anthracitic
coals as shown in Table 82 The Bukit Asam
semi-anthracitic coal is used by the tin ore smelting in
Bangka and ferro-nickel smelting at Pomalaa (Sulawesi)
Edwards and Cook (1972) studied the relationship between
coke strength and coal rank which is indicated by vitrinite
reflectance and carbon content of vitrinite (Figure 82)
They suggested that coal containing between 86 and 89
total carbon in vitrinite can form cokes without blending
with other coals Coal which has a vitrinite content
between 45 to 55 and an inertinite content of close to
127
40 is very suitable for coking coal These target
specifications are not met by the coals from the South
Sumatra Basin
128
CHAPTER NINE
SUMMARY AND CONCLUSIONS
91 SUMMARY
911 TYPE
The composition of maceral groups in the Tertiary
sequences are summarized in Table 91 and Appendix 2 The
results of the present petrographic study show that the
Muara Enim Talang Akar and Lahat Formations contain
lithologies rich in DOM and a number of coal seams In
general vitrinite is the dominant maceral group within the
Tertiary sequences The second most abundant maceral group
is liptinite In the Gumai Formation however inertinite
appears to be the second most abundant maceral to vitrinite
Table 91
No Formation Range R max ()V
C o a l V I L
()
(mm f )
D O M V I L
()
(mm f)
1 Lahat 054-092 2 Talang Akar 050-087 3 Baturaja 053-072 4 Gumai 036-067 5 Air Benakat 031-058 6 Muara Enim 030-050
86 87
81
4 3
10 10
13
84 2 90 3 97 tr 63 22 78 3 65 3
14 7 3 15 19 32
In the South Palembang Sub-basin on a mineral matter
free basis the vitrinite content of the DOM from Tertiary
sequences ranges from 65 to 97 (average = 81) whereas in
the coals it ranges from 81 to 87 (average = 84) Both
129
in the coals and DOM detrovitrinite is the main vitrinite
maceral group and predominantly occurs as a detrital
groundmass interbedded with thin bands of telovitrinite In
some cases where the coals are affected by thermal effects
from intrusions telovitrinite is the main type of vitrinite
as reported by Daulay (1985)
Vitrinite from the youngest coal seams (Muara Enim
coals) still shows cellular structures derived from plant
material Some of the telovitrinite cell lumens are
infilled by fluorinite or resinite Gelovitrinite mainly
corpovitrinite and porigelinite are scattered throughout the
coals With increasing depth and age telovitrinite becomes
dense and compact and the cell lumens are completely
closed This occurs in the coals from the Lahat and Talang
Akar Formations For the thermally affected coals
vitrinite is mostly structureless massive and contains few
pores (Daulay 1985) The dominance of vitrinite in these
coals is indicative of forest type vegetation in the humid
tropical zone without significant dry events throughout the
period of accumulation Cook (197 5) noted that coals which
have a high vitrinite content were probably deposited in
areas of rapid subsidence In some cases vitrinite-rich
coals have a high mineral matter content
Inertinite is generally rare in the South Palembang
Sub-basin On a mineral matter free basis it ranges from
sparse to 22 (average = 5) in the DOM while in the coals
it ranges from 3 to 6 (average = 5) The highest
130
inertinite content occurs in the Gumai Formation In the
Tertiary sequences inertinite mainly occurs as
inertodetrinite but semifusinite fusinite and sclerotinite
can also be found in the coals from the Muara Enim and
Talang Akar Formations Some well-preserved mycorrhyzomes
occur in the Muara Enim coals Micrinite also occurs in
some coals and DOM and it is present generally as small
irregularly-shaped grains
Liptinite content of DOM ranges on a mineral matter
free basis from 3 to 32 (average = 15) whereas it
ranges from 10 to 13 (average = 11) in the coals
Cutinite sporinite and liptodetrinite are the dominant
liptinite macerals in the Tertiary sequences
In general the liptinite macerals from the youngest
sequences can be easily recognized by their strong
fluorescence colours compared with liptinite in the oldest
sequences Suberinite has strong green to yellow
fluorescence and mostly occurs in the Muara Enim coals
Fluorinite is also common in the Muara Enim coals It has
green fluorescence and commonly infills cell lumens or
occurs as discrete small bodies In some cases fluorinite
also occurs in the Air Benakat and Gumai Formations but in
minor amounts In the Muara Enim coals cutinite and
sporinite have a yellow to yellowish orange fluorescence
However they give weak fluorescence colours ranging from
orange to brown in the Talang Akar and Lahat coals
Exsudatinite occurs mostly in the Muara Enim and Talang Akar
131
coals but it also occurs in some of the Lahat coals It
has bright yellow fluorescence in the Muara Enim coals and
yellow to orange fluorescence in the Talang Akar coals
Bitumens and other oil related substances such as oil
drops oil cuts and dead oils occur either associated with
DOM or coal throughout the Tertiary sequences In general
bitumen and oil cuts are mostly present in the Muara Enim
coals and have a greenish yellow to bright yellow
fluorescence In the Talang Akar coals bitumen has yellow
to orange fluorescence Bitumen occurs mostly within
vitrinite largely in cleat fractures of telovitrinite but
also some in detrovitrinite Based on the petrographical
observations bitumen is probably derived from the liptinite
macerals where these macerals have a higher HC ratios
vitrinite macerals also provide some contribution
912 RANK
Mean maximum vitrinite reflectance of coal samples from
shallow drilling and oil well samples from the South
Palembang Sub-basin was plotted against depth as shown in
Figure 521 The vitrinite reflectance gradients of the
basin range from 020 to 035 per kilometre A marked
increase in vitrinite reflectance with depth is shown from a
depth of below about 1500 metres (R max 05) to 2500 metres
(R max 09) The Talang Akar and Lahat Formations are
intersected by the 05 to 09 R max surfaces and are
-oo
thermally mature for oil generation Therefore coals from
these formations can be classified as high volatile
bituminous coal The Muara Enim Formation has vitrinite
reflectance values ranging from 03 to 05 and is
thermally immature to marginally mature for oil generation
Consequently the coals from this formation are brown coal
to sub-bituminous in rank Chemical parameters such as
carbon content calorific value and moisture content from
the Muara Enim coals (see Table 71 in Chapter 7) also
support that classification In some places the Muara Enim
coals affected by intrusions have high vitrinite
reflectances ranging from 069 up to 260 and they can be
classified as semi-anthracitic to anthracitic coals The
Baturaja and Gumai Formations are thermally mature while the
Air Benakat Formation is immature to marginally mature for
oil generation
Relationships between coalification and tectonism can
be defined by comparing the shape of the iso-rank surfaces
and structural contours In general the iso-reflectance
lines in the South Palembang Sub-basin are semi-parallel
with the orientation of the formation boundaries
Therefore a major pre-tectonic coalification event is
present in this area but partial syn-tectonic coalification
patterns are also evident in the Limau-Pendopo area
913 THERMAL HISTORY
The present geothermal gradient in the South Palembang
133
Sub-basin ranges from 36degC to 40degCkilometre with an
average of 38degCkilometre However Thamrin et al (1979)
reported that the average geothermal gradient in the South
Palembang Sub-basin is 525degC per kilometre The high
geothermal gradient may result from rapid burial during
sedimentation which followed Tertiary tectonisra At least
three major tectonic events occurred in the South Sumatra
Basin that is the mid-Mesozoic Late Cretaceous to Early
Tertiary and the Pio-Pleistocene orogenic activities These
orogenic activities were mainly related to the collision and
subduction of the Indo-Australian plate against the Eurasian
plate
The gradthermal model and palaeothermal calculations
suggest that the present temperatures are lower than in the
past These also indicate that the sediments of the South
Palembang Sub-basin underwent a period of rapid burial prior
to a period of uplift and erosion
914 SOURCE ROCK AND HYDROCARBON GENERATION POTENTIAL
Organic petrology data show that the Lahat Talang
Akar Air Benakat and Muara Enim Formations have better
source potential for liquid hydrocarbons than the Baturaja
and Gumai Formations According to Sarjono and Sardjito
(1989) however the Baturaja and Gumai Formations have good
to excellent source potential based on the TOC and Rock-Eval
pyrolysis data The differing results are probably caused
134
by the limitation of samples from these formations used in
the present study
From petrographic studies the Lahat Talang Akar and
Muara Enim Formations are considered to have good source
potential for gas and liquid hydrocarbons but based on the
Tmax data only the Lahat and Talang Akar Formations are
considered to be early mature to mature with Tmax values
ranging from 430degC to 441degC This is supported
microscopically by the presence of bitumens and other oil
related substances within the coal and shaly coal samples
The Muara Enim Formation is immature to early mature with
Tmax values of less than 420degC although coals from this
formation contain significant amounts of bitumen and oil
related substances The Muara Enim and Air Benakat
Formations are considered to be gas prone but in some places
they may also generate oil The organic matter in the Gumai
and Baturaja Formations comprises mainly vitrinite and they
probably generate dominantly gas
Vitrinite reflectance data show that the oil generation
zone is generally reached below 1500 metres depth in the
Muara Enim area but it is reached below 1200 metres depth
in the Pendopo area In the Muara Enim area the top of the
oil window generally occurs in the top of the Gumai
Formation but in some wells it occurs in the lower part of
the Muara Enim Air Benakat or Talang Akar Formations In
the Pendopo-Limau area the upper and middle parts of the
Gumai Formation occur within the top of the oil generation
135
zone
The Lopatin model indicates that the onset of oil
generation occurs at 1300 metres depth in the Muara Enim
area while in the Pendopo-Limau area it occurs at 1200
metres depth In the Muara Enim area oil may have been
generated since the Late Miocene (8-7 Ma BP) while it
occurred in the Middle Miocene (11-9 Ma BP) in the Pendopo
area
Gas chromatography and gas chromatography-mass
spectrometry analyses indicate that the oils in the South
Palembang Sub-basin were derived from terrestrial higher
plant material These oils are characterized by high ratios
of pristane to phytane and by the high concentrations of
bicadinanes and oleanane
In the present study geochemical data from the source
rocks and coals particularly from the Talang Akar
Formation reveal that these samples are just approaching
oil generation maturity and their biomarker signatures are
almost similar with those in the oil sample studied
A number of potential reservoir rocks in the South
Palembang Sub-basin occur within the regressive and
transgressive sequences The Muara Enim and Air Benakat
Formations from the regressive sequences have good potential
as reservoirs The transgressive sequences are represented
by the Talang Akar and Baturaja Formations The most
important reservoir rocks in the South Palembang Sub-basin
are sandstones from the Gritsand Member of the Talang Akar
136
Formation
In the South Palembang Sub-basin oil is mainly trapped
in anticlinal traps but some oils are also found in traps
related to basement features such as drapes and stratigrapic
traps
915 COAL POTENTIAL AND UTILIZATION
In the South Palembang Sub-basin coal seams occur
within a number of the Tertiary formations such as the
Lahat Talang Akar and Muara Enim Formations The coals
with economic potential are largely within the Muara Enim
Formation In the Muara Enim Formation the most important
coals in terms of quality and thickness occur in the M2
Subdivision The M2 coals are sub-bituminous in rank and
locally increase to semi-anthracitic in the area influenced
by andesitic intrusion Although the coals from the M4
Subdivision comprise two thirds of the volume of the coal in
the South Palembang Sub-basin they are low in rank (brown
coals) The thickness of the coal seams varies from 2 to 20
metres
The moisture content of the M2 coals is about 30 to
60 calorific value of the coals is about 6500 to 7 500
kcalkg (dried air free) The inherent ash content of the
coals is less than 6 (dry basis) and sulphur content is
generally less than 1
The volumes of coal available in the South Palembang
137
Sub-basin are approximately 2590 million cubic metres to a
depth of 100 metres below the ground surface These
reserves are clustered in the Muara Enim and Pendopo areas
The coals from the South Palembang Sub-basin are mainly
used for steam power generation Semi-anthracitic coals are
used as reductants in the tin smelter Another possibility
for using the South Palembang coals is gasification where
the gas yielded can be used as an alternative to natural
gas The South Palembang coals do not have coking
properties and even where blended with other coals which
have vitrinite contents between 45 to 5 5 and inertinite
contents of close to 40 they are unlikely to give
satisfactory blends The Lurgi low temperature
carbonization pilot plant may allow more diversified coal
use
92 CONCLUSIONS
The Tertiary South Palembang Sub-basin is the southern
part of the back-arc South Sumatra Basin which was formed as
a result of the collision between the Indo-Australian and
Eurasian plates Tectonic activity in the region continued
to influence the development of the basin during the Middle
Mesozoic to the Plio-Pleistocene
The Tertiary sequence comprises seven formations
deposited in marine deltaic and fluvial environments which
are underlain by a complex of pre-Tertiary igneous
138
metamorphic and carbonate rocks
Economically the South Sumatra Basin is an important
region in Indonesia because it is a major petroleum
producing area and the coals are suitable for exploitation
as a steaming coal One large mine is presently operated by
the Indonesian government through the Bukit Asam Company
with the coal available for both internal and export
markets With regard to petroleum few petrographic studies
have been carried out to characterise the organic matter in
the source rocks or to elucidate the geothermal history of
the basin
This study was undertaken to further knowledge of the
coal and source rocks in the South Palembang Sub-basin a
sub-basin in which many studies have been carried out on the
petroleum but few on the coal and its resources Evaluation
of the organic matter in representative coal carbonaceous
shale and clastic rock samples from the seven formations was
based on maceral type and abundance studies using reflected
white light and fluorescence mode microscopy The maturity
of the rocks was assessed using vitrinite reflectance data
which was then used to determine the geothermal history as
described in the Lopatin model In addition Rock Eval
geochemistry of selected samples1 was undertaken
Four oils from the Talang Akar Lahat and Baturaja i
Formations were characterised using gas chromatography and
gas chromatograph-mass spectroscopy techniques
In general petroleum potential of the seven formations
139
in the South Palembang Sub-basin ranges from poor to good to
very good Specific conclusions arrived at during this
study are listed below
In the South Palembang Sub-basin coals occur in the
Lahat Talang Akar and Muara Enim Formations but the main
workable coal measures are concentrated in the Muara Enim
Formation The coals occur as stringers ranging from
centimetres in thickness to seams up to 20 metres thick
The Muara Enim coals are widely distributed over the entire
South Sumatra Basin Coal in the Talang Akar and Lahat
Formation is similar in occurrence to the coal in the Muara
Enim Formation
From the viewpoint of economically mineable coal
reserves coals from the M2 Subdivision are the most
important coal units in South Sumatra The coals can be
utilized for electric power generation and gasification but
are unlikely to be satisfactory as blend coals in
carbonisation processes
The clastic units contain dispersed organic matter (DOM)
which constitutes up to 16 of the bulk rock with some
carbonaceous shales associated with the coals containing up
to 40 organic matter
Many of the samples examined contain bitumens oil
drops oil cuts and oil haze when examined in fluorescence
mode These components together with the presence of
exsudatinite are accepted as evidence for oil generation in
140
some of the units especially the Muara Enim and Talang Akar
Formations
Based on the reflectance data the Muara Enim coals are
classified as brown to sub-bituminous coals in rank Some
anthracitic coals are also found in the area near andesitic
intrusions The Talang Akar and Lahat coals can be
classified as sub-bituminous to high volatile bituminous
coals in rank
The Gumai Baturaja Talang Akar and Lahat Formations
are typically oil mature but in some places the lower part
of the Muara Enim and Air Benakat Formations are also
mature The reflectance profiles of the Palembang Sub-basin
increase at 020 to 035 per kilometre and based on the
reflectance data the oil generation zone is generally
reached below 1500 metres depth
The average geothermal gradient in the South Palembang
Sub-basin is relatively high at more than 40 Ckm
therefore oil may be found at shallow depths Based on the
gradthermal model and palaeothermal calculations the
present temperatures are lower than in the past
Using the Lopatin model and taking the top of oil window
at TTI = 3 oil generation can be expected to commence at
depths of 1200 to 1300 metres which fits well with the top
of the oil window as predicted from reflectance data Oil
generation in the Talang Akar and Lahat Formations is
predicted to have started approximately 9-11 Ma BP
Coals and DOM in the Tertiary sequences are dominated by
141
vitrinite with detrovitrinite and telovitrinite as the main
macerals Liptinite occurs in significant amounts and
comprises mainly liptodetrinite sporinite and cutinite In
general inertinite is rarely present in the sequences
Bitumens are mainly found in the Muara Enim coals but they
are also found in the Talang Akar and Lahat coals The
coals and DOM are mostly derived from terrestrial higher
plants
Coals and DOM from the Lahat Talang Akar Air Benakat
and Muara Enim Formations can be considered as having good
to very good source potential for gas and liquid
hydrocarbons In some places the DOM from the Baturaja and
Gumai Formations may also generate gas Assessment of the
source rock potential of the various units was carried out
using the Score A method which is based on the volume and
composition of macerals Score A values of up to 16-19 were
obtained for some samples from the Muara Enim and Talang
Akar Formations indicating very good source rock potential
The same samples gave high SI + S2 Rock Eval values also
indicating very good source potential
The crude oil geochemistry indicates that the oils are
derived from terrestrial land plant sources a factor that
is supported by the petrographic data The oils are
dominated by saturated hydrocarbons (up to 77 of the total
oil) and can be classed as paraffinic oils Aromatic
hydrocarbons constitute up to 27 and polar compounds
comprise up to 9 of the oil
142
The saturated fraction is characterized by a bimodal
n-alkane pattern with isoprenoid alkanes relatively
abundant Prn-17 Phn-18 ratios and pristanephytane
ratios indicate that the oils were derived from terrestrial
organic matter
Gas chromatography-mass spectrometry showed that the
oils contained a series of C27 C29+ pentacyclic
triterpanes bicadinanes hopanes and C27-C29 steranes
The Gritsand Member of the Talang Akar Formation is the
most important reservoir in the South Palembang Sub-basin
but sandstones from the Muara Enim and Air Benakat
Formations also have good reservoir potential
A review of the data shows that within the South
Palembang Sub-basin the Pendopo-Limau area in the northeast
part of the sub-basin has the greatest potential for
hydrocarbon generation and therefore is the most
prospective region
142(a)
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FIGURES TO CHAPTER ONE
AREAS
NORTHERN PROSPECTS
BN BENTAYAN TG TAMIANG BA BABAT
KLKLUANG PENDOPO PROSPECT
ML MUARA LAKITAN TL TALANG LANGARAN--
TK TALANG AKAR
SB SIGOYANG BENUANG--WE WEST BENAKAT
PR PRABUMULIH ENIM AREA
ARARAHAN AL AIRLAWAI-- --
SJ SUBAN JERIGI --BO BANKO
SOUTH EAST PROSPECTS GM GUNUNG MERAKSA KE KEPAYANG MU MUNCAKABAU--VJ AIR MESUJI
TOTAL
I | 330 jgt BROWN COAL MOISTURE CONTENT i 6 0
400
I 120 mdash (WEST-ENIM J
~Jgt 450mdash (EAST- ENIM) MOISTURE CONTENT 28-36
I 10
I 50
250
5135 EQUIVALENT OF 6162 x IC6 TON (50 METER DEPTH)
Figure 11 South Sumatra coal province and its demonstrated coal resources (after Kendarsi 1984)
mdash 10degN
GULF OF THAILAND
SOUTH CHINA SEA
SINGAPORE
KALIMANTAN
INDIAN OCEAN
DIRECTION OF MOVEMENT
STUDY AREA
LOCATION MAP SCALE
200 10Oraquoi
10degS
Figure 12 Location map of Sumatran back-arc basins
Figure 13 Tectonic elements of South Sumatra Basin (after Purnomo 1984)
400
3 30
M euro)
c c o
2 = laquo = S
55SS - O OOQ if O
4laquo00
a
fl Di 4J fl bullH n
1 ftl bullH H d id CO 04
sect43 bullH -M laquo +raquo 3 mdash rt O n H CO 00 0) cn M CD H fl
M 4J -bullH 0 0)laquoH fl fi 0 0 +gt 0raquo
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i
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FIGURES TO CHAPTER TWO
IMPREGNATION
I c o tS
mdash I
u 03
gt LU
05
lt
bullJi
cr
ACUATION
a F a c lto ltB
c a i
O pound zz 3 O
C3 ltgt laquo bull gt
bullraquo SETTING
a cn
t
GRINDING
120 220 400 600 200 GRIT LAP bullbullGRIT LAP mdashbullbullWET ANO ORY mdashHWET ANO ORY mdash^WET ANO ORY
PAPER PAPER PAPER
npregnation with Astic Resin mdash
lt
POLISHING Water
Prooat
CHROMIUM SESQUIOXIOE
SELVYT CLOTH
CHROMIUM SESQUIOXIOE
SELVYT CLOTH
JtUM I
MAGNESIUM OXIDE SELVYT CLOTH
MAGNESIUM OXIDE SELVYT CLOTH
I i Washed in
Distilled Water Washed in Propan-2-oI
I I Air Dried Air Dried
Figure 21
MOUNTING ON PLASTICSNE
EXAMINATION
Flow diagram showing the method for polishing and mounting samples (after Hutton 1984)
A
c o
a o
c a cr
co
E cr
o s lt r-LU
2
X CO CO LU
z LU
c lt
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gt ra o w
o ~ re
= sect E 0 = 0
dC
pound
c o _
2 a raquo o 0 s x
o a _ 01 c
mdash ta ff ta Bgt 01 mdash o
c a a -
bullD
w C w laquo
OJ u I mdash laquo ~ laquoJ
St deg 3
E =
c _o re u o
raquo raquoj =laquo 3 C laquo mdash laquo
dego- ~ =
K
tgt
0 19
u 0 C m
gtlaquo O
0 c
0 ~
2 =bull
bulllaquo
e
o 2 0 u -
c pound ~ D gt
M
0
laquo 3 0
i^^7___
~ ~
K lt ^ gt
o 0 d u lt lt J do
laquobull bullgt 5 c ~ laquo 3
= r deg 0 u lt- 5-
(1 p - ^^
S|f 0
E deg raquo deg 0 1 - w
lt
0 5^ _l
mdash ^ z ^
bull 2 eJ o a c a bull 5pound 3 U
01
c 0 V
(0 bull ~
fc -gt ^ bullpound y
1 gt
S
_
_re a OJ 01
ro ~
UJ
0 lt r-V)
CJ
ro CJ
mdash u
m 5 ltu 0
-c S 01 Ol
a = 0 _ a bullO _z 5 T3 c S mdash flj
= c E c cu mdash mdash 0 in m pound-laquobull 10
H a C w O mdash i) m w ro
0 2 mdash 2 ta -a 5 mdash 0 0 c c E 2 -2 ro cu 0 _= _o - 0 0 0 lt (J CO
D un 0 CO
O M Li 0 0 g bull W 1 W
0 lt c u 0 c s bullH Q) 0 XJ U Li IS CI3N Li 0 mdash 3 Li 0 0 gt bullH 3 0 W H S C gtw JJ 0 CQ 0 T3
C CO H (0 -H (0 rC U XJ u bullH J3 XJ 0) C Q J H H
0 H
amp 0 0 C m-i W bullH H S l-S 0 s c X 0 10 laquo0 H
0 XJ E u in
r3 u gt bull r l U M ^ 0raquoH 0 VO ro gtM co co bullH 0i3 W Q Ll 0 rH
bull D C
0 U
3 W a lt o
E n
C c E _ B 13
s laquo
B rs
Ll 3 CT bullH LU
01
a
u 0 in
ro gt gt ro cu
gt irt
a 0
c 0 ai ~
gt
J2 0
Si
0
ta C ta
r - t - laquo gtlt c u
- J w -raquo_ = mdash i ~ ~ mdash f o c - ai U - - a - U O -- ~ 3 - - - O i bull 3
Q
6
I
0- 5
SPARSE
20
ABUNDANT
10
COMMON
10
MAJOR
Figure 24 Visual aid to assist in the assessment of volumeteric abundance of dispersed organic matter in sediments
FIGURES TO CHAPTER THREE
ta O O mm) OOmmmm O
i Agt _
bull m m amp A Cl
A A J L _
LATE CARBONIFEROUS-EARLY PERMIAN 3UB00CTION
PERWIAH-EARLY TRIASSX SUBOUCTrON
LATE TRtASSJC - JORASSC 3UBOUCTION
CRETACEOUS EAlaquoLY TERTIARY 3UB0UCT10H
TERTIARY SUBOUCTrON
PRESENT SUBOUCTrON
PATERWOSTER FAULT
DIRECTION OF SPREADING
Figure 31 Lineaments of subduction zones in western Indonesia (after Katili 1984)
fTTfflzon A
[777 lt bull I Z o n a C mZZtX
Zoo 0
Zona pound
gratilt
Kl L0METRE3
KRAKATAU
Figure 32 Pre-Tertiary rocks underlying the Tertiary in the South Sumatra Basin (after De Coster 1974)
FIGURES TO CHAPTER FOUR
LAHAT FORMATION
N = 15
DOM 009-1699(Av= 850) by vol
COAL 2 - 34 (AV = 18 ) by vol
Vol bull40
COAL
-30
20
COAL
10
DOM
Total Abundance
Average Abundance
Figure 41 Abundance range and average abundance by volume and maceral group composition of DOM shaly coal and coal in the Lahat Formation at five well locations in the South Palembang Sub-basin
TALANG AKAR FORMATION
N = 48
DOM 182^3791 (Av= 1363) by vol
ShCOAL 12-30 (Av= 23) by vol
COAL 24-97(Av= 3947) by vol
Vol
J lt ^r r r
yy bull
y | [ llK XIK bull bull j Ltrade~^J
V
^^ta^ ^ v
V 1
SHALY COAL
Total Abundance
Average Abundance
Inartinite
| bullbullbull LipTinite
Figure 42 Abundance range and average abundance by volume and maceral group composition of DOM shaly coal and coal in the Talang Akar Formation at ten well locations in the South Palembang Sub-basin
BATURAJA FORMATION N = 6
DOM 01-293 (Ava087)by vol
VoL
-a
2
_l
0
OOM
Total Abundance
Average Abundance
i Vltrfntte
Inertinite
Liptinite
Figure 43 Abundance range and average abundance by volume and maceral group composition of DOM in the Baturaja Formation at six well locations in the South Palembang Sub-basin
GUMAI FORMATION
N = 24
DOM 005- 733 (Av=l8 7)by vol
VOl
mdash4
-3
_2
1
0
DOM
DOM
Vitrinite 3 Total Abundance
aftC) HUH j Inertinite
l--y--l Liptinite
Average Atmcullt
Figure 44 Abundance range and average abundance by volume and maceral group composition of DOM in the Gumai Formation at ten well locations in the South Palembang Sub-basin
AIR BENAKAT FORMATION
N = 24
DOM 015-1544 (Av = 366 ) by vol
voi
15
10
DOM-
-5
3 =3
DOM
[ j Totol Abundance
Average Abundance
j Vi trin ita
Inertini te
Liptinite
Figure 45 Abundance range and average abundance by volume and maceral group composition of DOM in the Air Benakat Formation at ten well locations in the South Palembang Sub-basin
MUARA ENIM FORMATION IM = 57
DOM 18 7-798 fAv= 437) by vol
COAL 356-100 (Av = 66) by vol
voi rrA I0O C 0 A L
_ 30
DOM
Total Abundance
Average Abundance
COAL
Figure 46 Abundance range and average abundance by volume and maceral group composition of DOM and coal in the Muara Enim Formation at ten well locations in the South Palembang Sub-basin
FIGURES TO CHAPTER FIVE
MBU- 2 TD s 2200 m
01 02 03 04 OJ 06 07 08 09
Vttrfnite Reflectance
Figure 51 Plot of reflectance against depth for samples from the MBU-2 well
PMN-2 TD = 1959 6m
01 02 03 04 03 06 07
Vitrinite Reflectance
Figure 52 Plot of reflectance against depth for samples from the PMN-2 well
r
mdash 500
fi
E
a Q
mdash 1000
GM- 14 TD= 1398 m
N bullmdashi raquo i
u u 2
318
bull84
lt
li
3 O
I0raquo4
nee
iteo
llaquo4laquo_
BRF
TAF
LAF
6M
01 02 03 04 a3 OJS 07
Vitrinite Reflectance oa
Figure 53 Plot of reflectance against depth for samples from the GM-14 well
KG-10 TD-I575 8 m
167
U lt it
rao
u UJ
2
12TB
1447
1817
U
ltB
lt
6UF
BRF
TAF
i u iii u4 iii iii ii -uy Vo Vitrinite Reflectance
Figure 54 Plot of reflectance against depth for samples from the KG-10 well
KD- 0|
TD raquo 18585 m
Sloo
pound c
a copy
a
mdash 1000
mdash 1500
LL
468
946
i sea-
1872
ielaquo7
n
u UJ
2
LL 3
BRF
TAF
B M
01 02 05 04 OJ 06 OJ 06
Vftrfnlte Reflectance
Figure 55 Plot of reflectance against depth for samples from the KD-01 well
BRG-3 TD 2300 m - o
900
1mdash
o E
Q
a
1000
1900
mdash 20O0
Sraquo4
lt
1221
18 81
U
Ik
a lt
2 0 64 20 64
|0 280
u
3
O
JPOE-
TAF
LAF
Vitrinite Reflectance
Figure 56 Plot of reflectance against depth for samples from the BRG-3 well
TMT-3 TD-1633 m
300
c r pound
a o
a 1000
t 1500
310
U UJ
2
laquow-
u
as
lt
Urn 3 laquo9
1164
issA bull i i i i i i i
Oi 3 3 0-5 tt4 UJ 06 CL7 Qd
Vitrinite Reflectance
bull3W
Figure 57 Plot of reflectance against depth for samples from the TMT-3 well
L-5A 22 TD 2237 m
a
rmdash 500
1000
mdash 1500
2000
828
u LU
2
964
U
a
lt
LL
3 (3
1290 1312 3RF_
LL
lt
1900
U lt -I
SM
01 02 03 04 03 06 OJ 03 09
Vitrinite Reflectance
Figure 58 Plot of reflectance against depth for samples from the L5A-22 well
BL-2 TD= 1675 m
500
mdash 1000
bullpound -a o _
a mdash 1300
8(2 bull
03
1323
LSraquo6
U
3
8RF
u lt
01 as as o^ as o6 07 oa 09
Vitrinite Reflectance
Figure 59 Plot of reflectance against depth for samples from the BL-2 well
L_
E
a a)
a
BN G-IO TD 2565 m -O
MEF tlaquo4
1207
i ess 1667
aa
lt
2 427
I
3
9
DOC
LAF
01 02 03 04 03 06 07 08 09 10 II
Vitrinite Reflectance
Figure 510 Plot of reflectance against depth for samples from the BN-10 well
I UJ
u (_gt()
0
a id JJ
o pound 0) DlH ^gtM 0 Qgt
M
5 I
o o JJ ta
o flJ rd
m o
Ll 0 DO bullH
Ol
c bullH
sect
M (d
I CQ 10 0 2 O O
lt0 U C bull bullH ltU W JJ P4 QJ rd i o sect 3 ltd
rdM-l bull 3 b O-H 3 xn L3 to
CN
LO
OJ
bullH bull4
S 3 M 1 3 W N Hid3Q
Depth (in metres)
U~
1000-
2000
i rs _
3000 i
bull
0 MEF
0 ABF
+ GUF
bull BRF
bull TAF
bull LAF
00 02
ScQ bull 5e o+ JL
OOOB _
m o+ o +
0 amp + gt o
o o + e+ bull 61 D bullbull bull
bull v bull bull bull
a a
a
i | i |
04 06 08 1
Rvmax ()
0
Figure 513 Plot of reflectance against depth for samples from South Palembang Sub-basin
I
0 c bull m o
c mdash 0 ~ mdash laquo 0 0 0) -H mdash CM 1 -m bullU --I 09 S3 0 0 mm 0
U3 r-t
U5
0) U 3 rao rm
c 0 0 C - 0 lt3 bullu 0
Syn-tec
coalifj
in r-l bull
in
u 3 M Ex
c 0 0 bullH bull laquo-C 4J 0 cS jj 0 0 mdash OJ c-jj bull-
1 mdash C fl U 0 c_ 0
CO rd
fi w 0 bullH
a 0 JJ
o
cu JJ bull
T3 ^3 C cn 03 r-l
a o u bullH ltU JJ H fO H U 3 bullH S
H-H rO 05 0 E- U
0
ltu u 5 ltu JJ H ltU H
JP g
a u bullrraquo -H J3 0 CO EH
a O gti bullH A JJ (0 T3 H ltU O CO M 0 a 0 0
J3 H H 0
in
a
200-
100
0-001
(051 06 06 L5 3 4 5 (6) (7JVRmdash
40
1051 oe
35 30 IS 20 IS 10
i 5 i VVM
07 OJBJ OJ I US i h
(asi 06 071 a s
CL5) 171
10 ts
i n i i n i
25 3 I i S (S) (7| I i i
R--vfli
20 (6HgtVR
IS 06 071 08 UO US i 20 i2S 3 J JO 35 30 2S 20 15 10 S 4
1 I i 1 I I
49
I (Sb-R
(2- VVM
JS JO 35 30 75 20 15 10 5 I V V M
lime in million years 10 12 20 30 40 50 100
001 002
Z-SCALE
figure 517 Karweil Diagram showing relationship of time (Ma) temperature C) and rank scales (after
Bostick 1973) Scale H is used for calculating thermal history of Table 511 and 512
s I bull e e -
degg
m__Z
v
bullI
r e
it
a E laquo
e _
D X
bull o
e o
fl c v
8
I
o o o M o E
o
o o o 10
o (0
m (D
8 o
o o
o o
8 2 deg 8 8 8 N 10 (Ut) H plusmnltJ 3 a
o o o o
T3 CD J-gt (0
CD
a CD
co 0) bullH
gti
JS-O o (0 bullH CD
CD X EH
ca C 0
0 H
OJ
c H
u
CD gt bullH 4J (0
u bullH
gti fl
CU -H
CO
bull LD
CD to
bullH
0) M ro O v CD CN X W JJ (0 W JJ 0 (0 CO bullH W bullH H O
jJ T3 3 gt O J3 bullH JJ 0 c o u
fl
o bullH
CD JJ
MmdashI 0
c o bullH H JJ CD bullH J3 CO 01 0-H QjJ3
S O JJ U rd CD fQ CO
U S fl
raquo8 bullH 0
s J5 JJ
8 J3 CO
CO
c 0
fO U CD
c CD 0) 0 JJ
CO fl CD
CD 01
O JJ
0 JJ Ll
CD O l C
5 o 0-H CO I
CD (0 JJ
u 0 0
a i CD JJ bullH fl bullH JJ U CD C bullH 0 JJ CD M rO
I CJ CO CD bullH Ol M CD C CD W
(0
CTi 00 lt7l H
CD JJ
0 JJ U U T3 CD gti fl
X-ri
JJ rO d
s
fl 0 bullH JJ rd gt bullH JJ U to
CO C CD Ol O
u CD M
o
10
N
Ho s 1 raquo o c o laquo-0gt So p
c DTK
6 copy L6
gt ID
6
6
A
mdash
-
o
c copy -copy
c o o o c copy
mdash fm JmZ
CX D
c 1
i
o =
1 copy
t mdash 1 J=
1 oraquo
o
lt o
c deg o copy CVO
1 sect
X
CO o
V
c
o amdash
sz ogt
mdash o gtgt X
bull
to
a gts
to
o 9
V
copy
copy
a O
oraquo c
c o 3
3 cn
4
V 5 = -r V X0 deg mdash (E 01 u s a
IlNI
T
TINI
SINI
RINI
or J K gt
u o
d fl rO
bullH
0
M 0 J-i
d
c d
fl 0
a-d fl 2 0
c bullH CO rO JJ fl 0
u CD JJ
CD d
8 fl 0 bullH JJ rO U CD fl CD Ol fl
o JQ
U rO CJ 0 M d
cn i-H
bull raquo
LD
CD H
bullH
CJ iw ro
co bullgtmdash
u 0
M CD JJ JJ
CD fO
KB fl U 0-H Wsect 6 Oi 0 U
U 0 ~ 4-1 CN
H CO CD (0 cn
bullH rH JJ -
CO H O O H T3 VJ CD fl M 3 0 0 0 U JJ 0H
JJ rO co C
VERY GOOD
GOOD
FAIR
POOR
Q O
0 Muara Enim Fat
bull Tata fig Akar RB
I i I I l I 5 0 K gt
| i I l i l l
50 KXgt ISO i
02 i - i i i i
OS 10
A Liptinite bullbullbull 03 Vitrinite +005 Inertinite (Vel of sample)
Figure 520 The relationship between S1+S2 values and the Score A for samples studied from the Muara Enim Formation and the Talang Akar Formation (after Struckmeyer (1988)
Figure 521 Generalized zones of petroleum generation and approximate correlation with maximum palaeotemperatures and reflectance of vitrinite exinite and inertinite (from Smith and Cook 1984)
Figure 522 Maturation model for the main organic matter groups and sub-groups (from Smith and Cook 1984)
tfl fl 0 bullH
0 A JJ
C+JH 0 ftlaquo a) bullH
JJ (0
| CO
o ta bullH rlt m bullH H rd 0 0
CD X 4J M 0 m H 0
s E
bull rd
bull
ta CD
R O M M fl JJ Q)H
5W 0 e
OtjO CD CD LT) amp J J CN cd
ltD -P U M rd
sect a
gt C O H CD ft CD to 0 JJ Q) M a) ftgt
rd
rd
raquoJfl 0 rd JJ M rd 0 0 CD JJ
fl iH Smgtd
0 0 CD A OJ
S JJ I c -H 4J
pound 0
P fl fl 0 tfl bullH ta
JJ JJ rd 0
amp 0 JJ tfl H
JJ=
0 rd JJ ft c g o 0-H Ond
rd 0 u
M ft ft rd
fl 0 bullH
ta 0 M Q)
laquo 0 fl 0 0 0
fl CnM
ro CN
m CD U
g bullH 04
(IW Hidaa
CD 0 JJ U
LU 2 t-
LU 7 LU
O o o -1
o 1
bullH CJ JJ CD
ro w U 4J
fl bullH CO
bullH 4-1 bullH H (0 0 U
4-1 0
fl 0 bullH JJ CJ fl M JJ CO fl
CD T3 CD
fl JJ 0 bullH JJ U rfl ft S 0 u 0
ro IM CD ft 0
9 gt ro
bull CO CD M
X JJ
0 C J
gt bull CO fl 0 bullH
0 JJ
o CD H
CD
S JJ 1 fl bullH JJ rd ft 0 a
i
CN 1
LT)
22 S rn gt0 CN
CD 10 poundj sect 3 CO
gti H CD
ft CO JJ gs 3
rd
CO JJ to lt
$ rO CD U
C CD bullH -d ro u 0)
ro H 0 ft 0
rfl s jtaj CD
bullbullox a JJ 0 Pm
0 CD
rfl poundbull bullH X 0 S-i ft ft (0
c 0 bullH CO 0 M CD
CD
01 C
CD JJ CD A M JJ
S bullH
M 0
CU 4-1
fl
CD U 0
CD W to CD CD U X ft JJ
FIGURES TO CHAPTER SIX
54 0 5 41
N-ALKANES
AROMATIC
POLARS
542 54 3
Figure 61 Bulk composition of the crude oils from South Palembang Sub-basin
g d 0 ltu u JJ 4-1
CO C 0
a
rd
S
bull CD fl
CD gt bullH
rd JJ JJ rd gtiH
bullH Jfl CD CO Cu OS CD
M d rO 0 0 u V
CO CD fl
gti ro
X M d CD JJ laquod u fl JJ rd CO
4-1
H ro i c
CD M
bull bull
X bull bull
1
CO CD C rO fl bullH
CU H T3
bull bull
0) fl rO JJ CO bullH
cd
bull laquofc CO CD fl
rd U bullH CQ
bull laquo
-rO laquo
M Jjd Cw H
bull bull
M
N
rO EH
bullraquo (0 CU T3 3
CO OM
CO poundj (3
id CD ft
M d a CD 0 JJ rd g 0
U
bull U CD o f3 3 fl fl 0
0 pound
M
3 M pound X CJ
gt
M
bullH 0 bull C O CD M u rd ftT-0 CO
fl rd
bullH JJ
w VJ H CD
rO X U JJ
M bullH CD
0
rd fl u CD JJ fl
0 H to o J3 JJ rO raquo JJ CJ if)
CN bull
ltD
o u
s bullH L
CD H
0 JJ
VJ CD 4-1
0) CD ft C g (0 CO
H H 0
bullH -d M
H
bull laquo 0 in
u u fd rH 1
bull bull W H
bull
Sh JJ bullH CO fl CD JJ fl
bullH H
6 T3 bull CD O CD CD gt
C JJ rfl bull CO O) gt i H to C -H X CD CD
o co cu os c O CD rd
to v bullbull c ro xJ bullbull H
u cu H d 0 to DS rfl to CD bulllaquo U
d a CD -H gti rfl fl bull CQ xi rfl w
H JJ CD bullbull TJ rfl co fl -CD I -H rfl PS JJ C to ^ rfl CU H to rfl EH fl CD bullbull JJ to to rfl rfl CU T3 IS co - H
bull o bullraquo 4-1 CQ to C d 0 J CD CD to
rfl JO to rfl w CD E ftd
e ft 3 o c ro fl co ra tod -H JJ Ol CD C H 0 to 0 JJ CD X) to H rfl J5 to CD rd
6 1 fd -fl fl 0 fl U JJ to to 2 O CD X to JJ CJ -H fl
bull CD 0 H CO rH XJ JJ rfl JJ O Ln co
0 to H JJ CD
ro O 4-1 bull bull H Ol CD gti
vo ft fl to JJ 6 -H -H
CD 13 T3 CO to CO to bullbull fl fl O in CD O l H U r-l JJ bullH -H U I fl PL O rfl -H H
o
o LO
o
51 LU
o ro
to d Ol CD 0 to JJ CD
rd
ftd 0 fl
D ri
o rgt
o bullto
CD LO
6-0 bulllaquo cp 0 CD CD gt to JJ fl -H 4-i rd ro JJ fl JJ ra bull to 0) gt i H to fl -H X) CD CD 0 to CU PS C A CD (0 to XJ bullbull fl rd xJ bullbull H U CU H d 0 to PS rd too- V d fl CD -H gti td fl bull- CQ X X rfl w H JJ CD bullbull d ro co c -CD 1 -H rfl PS JJ C M X
^ rd CM H -to fO H fl CD bullbull JJ to to Id ro CM TD S
W -H r_z bull 0
4H to to C 0 pound 0 X 0) 0 to rd JQ to id pound 10 CD g ftTJ 2 | ft 3 o fl _ id fl CQ ro
n m
i mdash i
ri
i mdash i
tod H JJ 0) CD fl CO 0 to 0 JJ O JO to H rd J5 to o id 6 I rox fl 0 fl 0 JJ to tog 0 CD XJ to JJ CJ -H fl
bull CD 0 H to m X JJ rd laquo JJ O in w
0 to H JJ CD
in o laquoH bull bull H 0) CD gti
ltpoundgt ft fl to JJ 6 -H -H
CD (0 T3 CO to to to bullbull fl p o m CD
amp H U rH JJ bullH -H U 1 fl PLI 0 (0 laquoH H
RI
RI
IK
es
cc
48
a
i
IK
68
U
lte
8
C27
370mdashgtI9I
w
Ca i ~ bull J_ - VraquoY- mdashbullbull
C28
384-HraquoI9I
B JAJAJW- JWlU-^Ji V 1 mdash 1 mdash
K
a
raquo
a
i
186
88
C8
lte
laquo
8
C32 440mdashraquoI9I
C33 454mdash7191
IS 16
1314
bull^^JA-Jta^AiU ta^^tataW^taJ^A-^ J^JhAm-r~
17 ie
ltS Tr ltf lte lt R lt laquo
TIME (HOUR)
v^^^K^^^J^^Ji^i^
20
w 5 laquo lti I ft K i C 28 1 Ec ltc I 8lt li
Figure 66 Metastable reaction chromatograms of a typical South Palembang oil showing the distribution of hopane Refer to Table 62A for peak identification Each chromatogram is identified by carbon number (eg C27) and specific transition measured (eg 370-gt191) Ri Relative Intensity
o o z LU CL cc UJ p-
cc r-Z o z X
z II
X
-raquo X eS_ CO
-t-
X
GO
LU Z lt z lt LU -1
o (1
_l o
UJ
z lt T
Q lt O
m o w o gt c ta bullgt o m
lt3 II
iS
LU 7 lt 7
O lt o CD
O IO O
ltn c D ta ta-bullgt c o -bull) c c ta r-n
r-
LU Z lt
z 5 u m o to
o II
i-
o
ID
z lt
z o lt
()
m u 2 o X II
cc
LU
z lt
z lt n CD
o o
II
K
bull
LU Z lt 0 o X
cC
II
laquo--laquo
to 0) 0 JJ
rfl
I to XJ
u c 0
to 0) 0
bullH JJ JJ U
ro CD
rfl
to to x )
U rH CTl 0gt rH C -H I 0
to 0 CJ CD to
N
c 0 bullH
d CD JJ CJ fl to d JJ CD CO JJ C CJ 0 CD U H CD CD PS tfl
mD
CD to
bullH
CC
ltS8 45 lt8 lt8 88 45 26 58 48 5 88 53 8 54 48 55 88 5) K
TIME (HOUR)
58 48 188 88 1 8 1 I 6 46 184 18
Figure 68 Metastable reaction chromatograms of a typical South Palembang oil showing the distribution of steranes and methylsteranes Each chromatogram is identified by carbon number (eg C27) and specific transition measured (eg 372-gt217) RI Relative Intensity
Notes for the peak assignments for steranes
present in the chroiatograis
1 2
4
6 lt
8 9 10
20S-5c(H)
20R-5o(B)
2QS-5a(B|
20K-5aB)
20S-5a(B) 20S-5a(B)
20R-5a(B)
20S-5a(B)
20R-5a(Bj 20R-5afflj
13B(B
136(1
13B(B
136(B
136(B 14B(B
MB(B
146(6
14B(B 146(B
17a(B|
17a(B)
lTa(H) la(B)
17a(B)
iHolB) 17a(B)
17o(B)
lTa(B) 17a(B)
-diasterampne(C27)
-diasterane(C27| -diiethylsterane(C28) -dnethylsterane|C28)
-diaethylsterane(C29|
-sterane(C27) -sterane(C27)
-sterane(C27)
-sterane(C27)
-diaethylsterane(C29)
11 12 13 14 15 16 17 18
T= T =
raquo=
E =
20S-5a(B)146(B)lla(B)-iethylsterane(C29)
20R-5a(B)148(B)17a(Bj-iethylsterane(C28]
20S-5a(B)146(B)11a(B)-iethylsterane(C28)
20R-5a(B)146(B)17o(B)-iethylsterane(C28)
20S-5o(B|146(B)no(B)-ethylsterane(C29)
20R-5Q(B))146(B)17a(B)-ethylsterane(C29)
20S-5a(B)148(B)17a(B)-ethylsterane(C29) 20R-5o(B)146(B)17n(B)-ethylsterane(C29)
Cis cis trans C30 bicadinane
Trans trans trans C3D bicadinane
Trans trans trans C30 bicadinane Boiobicadinane C31 C30 bicadinane
C27
Figure 69 Facies interpretation using triangular diagram displaying C27-C29 steranes distribution (after Waples and Tsutomu Machihara 1990)
5383 5384
N-ALKANES
AROMATIC
POLARS
5385 5386
Figure 610 Bulk composition of the extracts from South Palembang Sub-basin in terms of the polarity classes of saturated hydrocarbons aromatics and combined NSO-asphaltene fraction
ro cr cr
E o a CD c CO
CD (0
O
o CD
CO
CD gt LO
Z
o mdash
o CM
ta-r
poundZ LL
^-
^
^ ta mdash2 o- r-
LU
CD
o ro
o CJ
d CD JJ
rd to fl JJ
rfl co CD XJ JJ fl bullH CD H bullH M-l
o to
6 bullH fl W rfl to
ro fl
pound CD XJ JJ to
CO JJ bull
amp u - rfl n to JJ
X CD
fl 0 bullH JJ fl
O bullH to JJ CO bullH
d CD fl rfl M H rfl
CD to fl 0i bullH
co on LO
CD X JJ
c bullH CO
G 0 bullH JJ
CJ ro to UJ
CD H amp
CO
fl 0 bullH JJ
rfl O
-o
ro i (3 cc
o 0) 1
o o
o
CD CD
o Ln
o
LU
i
CD
r cxi
-0 CD JJ rfl to fl JJ rfl co CD
xi JJ
c bullH CD H bullH 4-i 0 to
c o bullH JJ fl mQ bullH to JJ co bullH d CD C rfl M H rfl
g bullH
fl W rfl to rfl fl
pound CD X JJ
I to CO JJ
u bull rfl to JJ
X CD CD XJ JJ
c bullH CO C O bullH JJ CJ rfl to
co ro in CD H
CO
fl 0 bullH JJ rfl 0 Cn
I
CN
CD to fl Ol bullH
Cn CD
E o
ro i
C5
rx CD CM
CM I CD O
j co
i C D
i o C3 _S
__3 r CD LO
CM CM
CM
CO -
CD CM 1
^
1
3
CD
CD
o CM
0
^
^
_ ^ mdash gt ~
_deg mdash
LU
CD m
3 CD Oj
d CD JJ rfl to fl JJ rO co
CD X JJ fl bullH CD H bullH 4-1 0 to
a c 0 bullH JJ O bullH to JJ co bullH CD C rfl M H (fl
to ro
0)
c ro H ro EH
CD X JJ
I to H-l CO JJ bull CJ --rfl m
CO ro Lf)
to JJ
X CD CD XJ JJ fl bullH
CD
CO
C 0 bullH JJ rfl
CO fl 0 bullH JJ CJ rfl to 0 MJ Cn
ro
10
CD to fl Oi bullH Cn
cc
~v L _ a
CM ~
w
CO CM
CM CM
CO
CO mm
E
_w ro CM
cpound CD CM
raquo Sc
o CM
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m
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gtbullbull T
-gt-gt
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raquo raquo bull
J 3 - ^ ^ ^
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^
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=
4 ^ - ^
^
M j -a i
CD
pr -
i
pCD
i
1 i CD
pin
1
i
J s
LL
i 5
1 ^ i CD pro i i prj
__o
n the saturated
the Talang Akar
bullrte CD 0 H to bullH gtW IN 0 CO to JJ bull f Q 0-
rfl vo C to co 0 JJ ro bullH X m JJ CD fl CD -5 8 bullH X a
alkane distr
actions in t
rmation (sam
l to 0 fcM-i Cn
- H
1
VO
CD to
g bullH Cn
-CD
1
mCX
410
420
450
460
470 gt K 480 o E 490 -
1
BOO
940-
920
930
940
990
990
60O
TYPE III
Immature
PI Wilt InWilli ml Mmmsllilllll
Condensate wet gas
dry gas
TYPE II
Immature
1 pi Willi Gas
TYPE
Immature
ffiQiuiiiiii JSasZZZ
Non existence of Tmax
-
-410
420
-430
-bull440
-450
460
_470
Figure 615 The determination of petroleum formation zones by using Tmax (after Espitalie et al 1985)
DOO
TYPE II
200-TYPE ni
T 1 I I
50 100 150 OXYGEN INDEX
raquo
200 250
Figure 616 Modified Van Krevelen diagram using conventional whole-rock pyrolisis data (after Katz et al 1990)
FIGURE TO CHAPTER SEVEN
E a laquo CO
cn e a o i a m)
-3
V
CO bullco
CO
2 ltpound ^ltg c 3
coco M to
3 = c c e deg -o
sect_l =cn w
i ^ to i_ ta ta ta mdash
(i raquo laquo D a
deg- deg s- deg
lto a
to a
a v
2
to
bullD
3
1 I I I 2
I X
ro 2
llll 1 2
1 2
CO VO lt CO c JJ laquoH
bullH ^ fl CQ
CD X JJ
4-1 0
Oi to CD
euro CD N JJ to 10
gtS Xi X
a o ro co to 0) c bullH 0 JJ gt (0 to JJ
to CD
CO JJ
H rfl to CD fl CD O
ltH rfl bullmdashlt
rfl CD to (0
JVX
UOjJDLUJCy IDSDgt|
(ltJ d W ) q jaqiua^
(D dW) D jaqoiaj
UOIJDOIJOJ IDOQ LUIU3 OJDn^J
j v a
UOI| DILI JO J IDHOuag jv
d n o j g 6uDqLue|oct
auaoojicj auaaoiid-oiVN
AWVIia3l
auaoojj
CD to fl Ol bullH Cn
FIGURES TO CHAPTER EIGHT
N
PAUEMBANS I
w KlaquorTOpoti
BUKH^ASAM MINE ( SOURCcNF COAL )
^jM
atang $Vmdashrrrrn ProbumuUh
Muaraenim - Km 9 Ton junge nim raquo
S 0U T H
S U M AT E R A
5 pound ^
SURALAYA STEAM (POWER PLANT
(POINT OF DELIVERY)
LEGEND
System Location mdash
imdash Raiiwoy
Waterway
Lmdash Nsw Trade
if bull bullbullbullbullbulllaquo
lOOKm
Figure 81 The transportation net of the Bukit Asam coal South Sumatra (after Kendarsi 1984)
LU
u in
4-
h-(3 Z LU C 3 to-LU id
o gt-
cr lt LT toshyrn 1-
r
I 15 07 09 11 13 15 17
MEAN MAXIMUM VITRINITE REFLECTANCE
i
80 i
82 i
88 84 86
CARBON IN THE VITRINITE (dmmf)
dmmf sdry mineral matter free
90
Figure 82 Generalized relationship of coke strength and coal rank indicated by vitrinite reflectance and carbon content of vitrinite at constant type (after Edwards and Cook 1972)