Unconventional Oil and Gas Potential

8/18/2019 Unconventional Oil and Gas Potential

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Unconventional Oil and Gas Potentialin Indonesia with Special Attention to Shale Gas and

Coal-bed Methane


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Outline

1. Introduction2. Geological Setting3. Shale Hydrocarbon (Shale Gas & Oil

Shale)4. Coal-bed Methane (CBM)5. Closing Remarks


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Introduction

Goverment of Indonesia (GOI) has identified 128 Sedimentary Basins.Basin assessments will reveal the conventional and unconventionalhydrocarbon potential.

The National oil production declines up to 12% per year, therefore the GOIexpects to re-evaluate geosciences concept and prepare moredata and information in order to attract many investors to involve for non-conventional oil and gas exploration.

Distribution and occurrence of Pre-Tertiary to Tertiary shale hydrocarbonand coal bearing formation in Indonesia sedimentary basins are

remarkably abundant. Most of them indicate to contain shale oil and gasand coal-bed methane (CBM).


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Resources Triangle (Holditch)Conventional reservoirs : smaller volume,easily developed economically at currenttechnological conditions.Unconventional oil and gas reservoirs arevery abundant, but it is more difficult to

develop.This requires to be able to be accessedeasily, technological improvements,appropriate price and motivation todevelop economically

Current estimated of potential unconventional gas reserves (tight sand,CBM and shale) ranging from 1,500 TCF to 2,500 TCF are likely tounderestimate the true resources base (Source: Wood Machenzie“Unconventional Hydrocarbon – The Hidden Opportunity)


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The role of Geological Agency in

Unconventional Gas Development

• Shale Gas and CBM Survey

• Data and Information services of Shale Gasand CBM


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GEOLOGICAL SETTING


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Geological Map of Indonesia

Geological Agency, 1996


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Sedimentary Basin Map of Indonesia


Tertiary Basins Pre-Tertiary - Tertiary Basins Pre-Tertiary Basins


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SHALE GAS RESOURCES OF MAIN SEDIMENTARY BASINS OFINDONESIA

Total Speculative Resources of Shalegas in Indonesia = 574.07 Tcf



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Map of Distribution and Potential of Shale Oil and Gas Bearing Formation of Indonesia

Quaternary

Neogene

Paleogene


Oil and Gas Potency


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Oil Shale Speculative Resources in Indonesia

Indonesia oil shale resources up to 2007 amountsto 11.24 million tons, 10.09 million tons with the

details of the speculative resources and 1.15 milliontones inferred resource.



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SHALE DISTRIBUTION


14/85Barber et al, 2005 ; Geological Agency, 2010

Sungai Namaran, Tebingtinggi

Bukitsusah, Riau

Kota Buluh, North Sumatra

Barber et al, 2005 ; Geological Agency, 2010

Sumatra Backarc Basins Tectono-Stratigraphic Scheme


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Barber et al, 2005 ; Geological Agency, 2010

Intramontane Basins in Sumatra

Ombilin

Microphotographof organic matter


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Pre-Tertiary Shale Hydrocarbon in SumatraShale of Mengkarang Formation (Jambi) Shale of Rawas Formation (Jambi)

Shale of Menanga Fm(Lampung)

Shale of Peneta Fm(Jambi)

Geo lo ic al A en c , 2000


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Stratigraphy of North West and East Java Basin

Indonesia Basins Summaries, 2006


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Stratigraphy of Melawi, Barito, Kutei and Tarakan Basins, East Kalimantan

Geological Agency, 1993; Indonesia basins Summaries, 2006


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Stratigraphic Correlation of Eastern Indonesia

Piniya Mudstone

Aiduna Fm (Permian)

PAPUA



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Im po rtant elements in s hale gas play


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SHALE HYDROCARBON ASSESMENT WORK FLOW

P F l l b l i


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Pematang Fm. samples lab analysis

22

Pekanbaru

Padang

Sawahlunto

Payakumbuh

Bangkinang

Teluk Kuantan

Rengat

Pulaupunjung

Lokasi Penelitian

Bukittinggi

Batusangkar

a

b c


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Lithofacies

1 1

2 2

3 3

4 4

5 5

6 6

7 78 8

9 9

A B C D E F G H I J K L M1 mm

CLASSIFICATION: SILTY CLAYSTONE

Petrography view shows a textural of shale, mostly composed of detritalclays such as quartz, siderite and feldspar mixed with clay mineral. Shale ischaracterized by laminated clay. Framework grain components include ofquartz, sedimentary rock fragment, and the grains are commonly floating

on detrital clays.Diagenetic event consist of replacement of the unstable grain and organicmaterial mostly to siderite, and calcite. Visual porosity is moderately asdissolution and fracture.

1 1

2 2

3 3

4 4

5 5

6 6

7 7

8 8

9 9

A B C D E F G H I J K L M

CLASSIFICATION: CALCAREOUS CLAYSTONE

Petrography view shows a textural of shale, mostly composed of detritalclays such as quartz, calcite (pink color), siderite, dolomite and pyrite mixedwith clay mineral. Shale is characterized by massif clay. Framework graincomponents include of quartz, sedimentary rock fragment, and the grainsare commonly floating on detrital clays.Diagenetic event consist of replacement of the unstable grain and organicmaterial mostly to siderite, and calcite. Visual porosity is very low.


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Determinasi komposisi batuanX-RAY DIFFRACTION ANALYSIS

No Sample ID CLAY MINERALS (%)

CARBONATEMINERALS (%)

OTHER MINERALS (%) TOTAL (%)BI

(%)

S M E C T I T E

I L L I T E

K A O L I N

I T E

C H L O R I T E

C A L C I T E

D O L O M

I T E

S I D E R I T E

Q U A R T Z

K -

F E L D S F A R

P L A G I O C L A S E

P Y R I T E

C L A Y

C A R B O N

A T E

O T H E R

1 A - 11 23 - 6 - 25 35 - - - 34 31 35 452

B - 5 22 - 40 - 8 21 - - 4 27 48 25 223

C - 5 16 - 40 - 4 30 - - 5 21 44 35 314

D - 5 15 - 52 - 4 20 - - 4 20 56 24 215

E - 8 26 - 20 - 10 36 - - - 34 30 36 386

F - 4 10 - 48 - 4 30 - - 4 14 52 34 317

G - 3 6 - 66 - 4 18 - - 3 9 70 21 188

H - 6 12 - 41 - 5 30 2 - 4 18 46 36 329 I - 35 17 - - - 3 41 1 3 - 52 3 45 43

10J - 5 12 - 50 - 5 28 - - - 17 55 28 28

11K - 6 12 - 50 2 - 30 - - - 18 52 30 31

12L - 5 7 - 43 1 5 35 - - 4 12 49 39

3813

M - 3 7 - 60 - 4 23 - - 3 10 64 26 2414

N - 2 2 - 95 - - 1 - - - 4 95 1 115

O - 6 12 - 12 5 10 53 - - 2 18 27 55 6316

P - - - - 97 - - 1 - - 2 0 97 3 117

Q - 8 16 - 6 - 17 50 - - 3 24 23 53 6018

R - 4 10 - 60 - 8 10 - - 8 14 68 18 1119

S - 5 12 - 52 6 - 20 - - 5 17 58 25 27

Dua metode yang umum dilakukan dalam analisa mineral shale :

- XRD (X-Ray Diffraction)

- FTIR (Infra-red Spectometry)

Mineral yang mempengaruhi pada brittleness

BI = (Q+ Dol) / (Q + Dol +Lm + Cl + TOC)

Di mana:

BI = Brittleness Index

Q = kuarsa

Cl = mineral lempung

Dol = Dolomit

Lm = Batugamping (Kalsit)

TOC = Total Organic Carbon)

Mineral lainnya yang mempengaruhi secara minor antara lain:

(fosfat, pirit, organisme (kalsit, silika, kerang, dll)

(Wang dan Gale, 2009)

Brittleness:

< 30% = poor

30 – 50% = moderate

> 50% =good


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Porosity and Permeability

Sample no PERMIABILITY POROSITY Grain DensmD (%) (g/cc)

A 1.27 13.02 2.506B 0.04 5.8 2.424C 0.01 5.04 2.459D 0.1 8.36 2.393E 0.1 9.52 2.427F 0.13 8.86 2.386G 0.09 8.41 2.376H 7.65 10.71 2.405I 0.08 8.15 2.422J 0.73 8.08 2.369K 0.08 8.72 2.465L 0.08 7.88 2.372M 0.14 7.79 2.417N 0.1 7.4 2.37O 0.08 7.32 2.392P 0.36 6.61 2.454Q 0.09 5.32 2.405R 0.09 5.88 2.369S 0.06 4.76 2.412

f k


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SEM for Pore type & Networks

f k


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Porous Floccules

Microfractures

Organo-porosity

Intraparticle grains/ pores

SEM for Pore type & Networks

G h i


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Geochemistry

• Geochemical screening results from the samp les characterized by very good to excellent organic richness (2.00 to 6.23 wt.%) .• Rock-Eval pyrolysis data reveal high to very high Hydrogen Indices (318-937) suggesting the presence of mainly oil-prone kerogen (Type I and II)

with minor gas-prone kerogen.• These samples are considered to have mostly excellent hydrocarbon generative capacity based on excellent pyrolysis potential yields (S1+S2 8.17 to

58.30 mgHC/gm rock) .• Vitrinite reflectance results reveal that most of the samples are immature . Only one sample shows early mature.• Kerogen typing analysis data for all the samples indicate the presence of predominantly oil-prone kerogen (Type I) comprising minor non-

fluorescent amorphous debris (5-30% NFA) except three samples with NFA more than 48% (48-51%) are Type I/II.• All the samples were submitted for spore colouration (TAS) analysis. The maturity results show a good agreement with the vitrinite reflectivity data.

Thermal Alteration Scale results indicate consistent values of TAS 3 throughout the all samples. This confirms that the claystone are immature.• Biomarkers present in these extracts have been analysed by computerised Gas Chromatography-Mass Spectrometry performed on saturate

fraction. Liquid chromatographic separation results show a predominance of polar compounds (NSO’s) plus asphaltene constitute a significantproportion of the total extract yields (40 to 66%), saturates aromatic compounds (11-38%). Aromatics coumpunds are present in relativelysecondary levels (5-31%). Relatively low abundance of 18 (H)-Oleanane compound, together with C 30 resins for all extracts. It can be interpreted asenvironment with very little terrigenous input .

12345678

9101112131415161718

123456789101112131415161718

P l l i


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29

? F l o r s c

h u e t z i a t r i l o b a t a

O n c o s p e r m a

t y p e

A c r o s

t i c h u m

a u r e u m

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i n i z o n o c o

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Z o n o c o s

t i t e s r a m o n a e

B o

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M a r g

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C r i c o

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D u r

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M e y e r

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t e n s i s

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i l a t r i c o

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( t h i c k e x

i n e

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P o m e

t i a

R e t

i t r i c o

l p i t e s

S a p o

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V a c c

i n i u m

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P r o x a p r t

i t e s s p p .

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( m e

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P a

l m a e p o l l e n

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S h o r e a

t y p e

L a n a g

i o p o l l i s

S p ,

S t r i a t r i c o

l p i t e s c a

t a t u m

b u s

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t r a c o p o r i t e s s p .

D i c o l p o p o l l i s

m a

l e s i a n u s

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l l u m

t y p e

P s

i l a t r i c o

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P a n d a n u s t y p e

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t y p e

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h i t r i p o r i t e s s p ,

P o

l y g a

l a t y p e

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l l e n i

t e s

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d o c a r p

i d i t e s

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A u s t r o

b u x u s

C u p a n i e

i d i t e s

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t o s p o r i

t e s s p p .

L e i o t r i l e t e s s p p .

( p s i

l a t e )

D e l

t o i d e s p o r i t e s s p

P o

l y p o

d i i d i t e s u s m e n s

i s

I n d e t e r m

i n a t e s p o r e s

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l y p o

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d i i d i t e s m e g a

b a l t i c u s

P t e r i s

t y p e

M a g n a s

t r i a t i t e s

h o w a r

d i i

A 2 1 ? 1 3 2 2 2 ? 2 1 1 3 1 4 3 1 1 AOM with fine black materialB 1 2 3 3 2 ? 1 1 4 1 Flock AOMC 2 1 ? 1 ? 3 5 1 1 1 1 2 2 1 1 1 15 6 2 9 2 2 2 2 AOM with fine black materialD 1 4 1 1 2 2 1 AOM with fine black materialE 1 1 3 1 3 1 2 1 2 Flock AOMF 1 2 2 3 1 1 2 2 1 1 1 2 AOM with fine black materialG 1 1 1 1 1 1 1 1 3 3 5 1 1 4 1 2 2 1 1 1 3 2 AOM with fine black materialH ? 2 4 2 1 1 1 2 3 1 1 Flock AOMI ? 2 3 2 1 1 1 1 2 1 1 1 2 AOM with fine black materialJ 1 1 1 ? 1 1 1 1 1 1 2 AOM with fine black materialK 1 1 1 3 1 2 2 2 2 5 2 1 Flock AOML 1 1 1 4 1 1 3 1 2 1 4 2 Flock AOMM 2 1 1 4 1 2 2 1 1 1 4 7 5 3 1 2 2 2 AOM with fine black materialN 1 3 1 16 3 2 1 Flock AOMO 1 2 3 2 5 1 1 1 2 1 4 2 4 2 1 AOM with fine black materialP 2 1 4 1 1 1 1 1 Flock AOMQ 2 1 3 ? 3 1 4 1 3 1 1 1 1 1 1 1 1 AOM with fine black material

R 3 5 ? 1 3 14 1 22 1 1 5 2 6 1 1 2 1 3 3 2 1 1 1 1 1 1 13 9 1 15 2 1 7 1 1 Flock AOMS Gr. 4 B Black Woody Material

ac O t h e r P o l l e n S p o r e sMangrove

S A M P L E C O D E

B A R R E N

mangrove

G r o u p 1

G r o u p 2

G r o u p 3

G R O U

P S

OLIGOCENE

OLIGOCENE

INDETERMINATE

OLIGOCENE

INDETERMINATE

INDETERMINATE

AGE ENVIRONMENT KEROGENE TYPES

Indeterminate, oxidized

Upper deltaic plain(peat swamp) to lowerdeltaic plain (backmangrove



Florschuetzia trilobata Spinizonocolpites echinatus Meyeripollis naharkotensisMarginipollis concinnus

Paleontologi


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WELL LOGS

W ll L


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Identifikasi LitofasiesPada Data Log Sumuran

Korelasi SekuenStratigrafi Antar Sumur

Bar

Channel

Estuarine

Lacustrine

Interpretasi LingkunganPengendapan

Well Logs

Kalibrasi Data Batuan inti dan DataLog Sumuran

Analogi Untuk Pemodelan Fasiespada Top Marker Parasekuen dari

Hasil Korelasi Antar Sumur

W ll S St tig hi C l ti


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Well Sequence Stratigraphic Correlation

1 2

3 4

Penampakan struktur lembaran dari serpih Formasi Kelesa di

sungai Punti Kayu, Kawasan Kuburanpanjang, Bukit Susah,Rengat, Riau (1 &2); Musi Rawas (3), danKuantan Sengingi (4)

Outcrop Models

: Upper Shorface: Lower Shorface

: Offshore: Estuary: Fluvial: Lacustrine


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SEISMIC

SEISMIC


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DATA SEISMIC INTERPRETATION

Log Sumuran

Seismik

Picking Horizon

Interpretasi Struktur

Run RMS Attribute on TopPematang Fm.

Fault Modelingand

Time to Depth Conversion

TOP PEMATANG FM.

6 860 00 6 880 00 6 900 00 6 920 00 6 940 00 6 960 00 6 980 00

6 860 00 6 880 00 6 900 00 6 920 00 6 940 00 6 960 00 6 980 00

7

7

7

7

7

7

7

7

7

7

.

.

.

.

. 7

.

.

00.010.020.030.040.050.060.070.080.090.10.110.120.130.140.150.160.170.180.19

Surface at

RMS AMPLITUDE OFPEMATANG FM

WELL-SEISMIC TIE

PERMODELAN DARI HASIL INTEGRASI DATASEISMIK DAN LOG SUMURAN

SEISMIC


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DATA INTEGRATION FOR STRATIGRAPHICPROPERTY MODELLING

DATA INTEGRATION


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36

6 86 00 0 6 88 00 0 6 90 00 0 6 92 00 0 6 94 00 0 6 96 00 0 6 98 00 0

6 86 00 0 6 88 00 0 6 90 00 0 6 92 00 0 6 94 00 0 6 96 00 0 6 98 00 0

1 m

1:

. 1

.

.

.

.

.

. 7

.

.

.1

.11

.1

.1

.1

.1

.1

.17

.1

.1

INTERPRETASI SEISMIKINTERPRETASI WELL LOG KALIBRASI DENGAN DATA CORE

PERMODELAN PROPERTI

GEOLOGICAL PROGNOSIS

DATA INTEGRATION


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Working plan for shale gas investigation in

Central Sumatera Basin for 2013

• Eocene to Oligocene vertically depositional

environment and kerogen type changes• Eocene to Oligocene sequence stratigraphy• Burial History

• Paleogeography• G&G analysis to calculate GIP

37


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SHALE HIDROCARBON POTENTIAL IN PAPUA

Tectonostratigraphic Correlation of Papua Misool Buru Tanimbar


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Tectonostratigraphic Correlation of Papua-Misool-Buru-Tanimbar

Korelasi stratigrafi, modifikasi dari Pigram & Panggabean (1984), Hasibuan (1991), Indonesia Basin Summaries (2006) dan Charlton (2010)


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Geology of Papua (Ransiki – Bintuni, Teluk Wondamaand Enarotali-Waghete-Moenamani-Mapia transect)

Shale hydrocarbon potential target are:1. Tipuma – Aiduna Sequence (Aiduna Fm.)2. Kembelangan Sequence (Kopai Fm. & Piniya Fm.)

Shale Hydrocarbon Potential Target in Papua


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Shale Hydrocarbon Potential Target in Papua

Permian Aiduna Fm.

Cretaceous Piniya Fm.

Jurassic Kopai Fm.

Well Correlation Showing Shale Hydrocarbon Target at Papua


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42

Well Correlation Showing Shale Hydrocarbon Target at Papua

Regional Sequence Correlation ( Papua )


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Regional Sequence Correlation ( Papua )

Modified from Pertamina and Corelab (1993)


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44

Geology of Tanimbar Islands

Shale hydrocarbon potential target:1. Kembelangan Sequence (Bubuan Mud Fm.)


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45

Geology of MisoolIslands

Shale hydrocarbon potentialtarget:1. Kembelangan Sequence (Yefbi

Fm. & Lelinta Fm)

Regional Sequence Correlation ( Misool )


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46

?

?

?

NW SE

?

?

NW SE

Sekuen Pengendapan

: Top Kais (Upper Miocne)

: Top Waripi (Eocene)

: Top Jass (Upper Cretaceous)

: Top Tipuma (Triassic)

Top Marker Formasi

SW NE

??

Regional Sequence Correlation ( Misool )


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47

Geology of Buru Island

Shale hydrocarbon potential target:1. Tipuma – Aiduna Sequence (Dalan

Fm.)

Regional Sequence Correlation ( Buru )


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A A’ B

B’

B B’

A A’

Regional Sequence Correlation ( Buru )Sekuen Pengendapan

South Papua Passive Seismic Tomography Acquisition 2013


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49

South Papua Passive Seismic Tomography Acquisition 2013

General Survey Location Plan at South Papua


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1 Lokasi, Papua

Selatan, CekunganAkimeugah

2 Lokasi, PapuaSelatan, Cekungan

Sahul danAkimeugah


Akimeugah danSahul

2 Lokasi, Papua

Selatan, CekunganArafuru dan Iwur


Akimeugah


Sahul danAkimeugah

2 Lokasi, PapuaSelatan, CekunganSahul dan Arafuru


Akimeugah

2 Lokasi, Papua

Selatan, CekunganSahul dan

Akimeugah


Iwur dan Sahul


Akimeugah


Sahul danAkimeugah


Iwur dan Sahul


Sahul


Sahul danAkimeugah


Akimeugah danArafuru

1 Well , PapuaSelatan, Cekungan

Sahul

2 Well, PapuaSelatan, Cekungan

Sahul danAkimeugah

2013 2014 2015 2016

Passive Seismic Tomography(PST)

2D Seismic

Drilling

GMT (Geo-MicrobialTechnology)

KegiatanTahun

Detail Gravity Mapping

Magnetoteluric Mapping

General Survey Location Plan at South Papua


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SHALE HIDROCARBON RESEARCH PLAN


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Proposed Areas For Shale Hydrocarbon Research

4

3

1. Sumatra2. Papua

3. Sulawesi-Maluku4. Kalimantan5. Jawa

1,2,3,4,5

1

2

5

SHALE HYDROCARBON RESEARCH PLAN

AND SCOPE OF WORKPROPOSED IN INDONESIA (GEOLOGICAL

AGENCY)


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PROPOSED IN INDONESIA (GEOLOGICAL AGENCY)

BASIC AREA SELECTED:

PRIORITY OF PROPOSED AREA

SUMATRA PAPUA SULAWESI – MALUKU KALIMANTAN JAWA

SELECTED SEDIMENTARY BASINS HAVING HIGH POTENTIAL OF SHALE HYDROCARBON ADEQUATE INFRASTRUCTURE AREA AN EFFORT TO IMPROVE REGIONAL AND NATIONAL ECONOMY AN EFFORT TO IMPROVE UNCONVENTIONAL ENERGY RESOURCES

Preliminary Survey & Research - "In House" & field work and laboratory Shale hydrocarbon Assessment (Detailed Geophysics and Geology: Seismic,

Gravity, Magnetic, Drilling, Laboratory; Modeling play)

Pilot Plan in Laboratory Scale (Risk, Amdal, Economic and Production)

SCOPE OF WORK


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COAL-BED METHANE


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Program of CBM Survey• Basin Studies, localized most prospective cbm

areas in each basin

• Data Digitalization: South Sumatra 2007,Kalimantan 2009

• Desorption test (direct gas measured), mostprospective basins – Barito, Kutai, SouthSumatera, and Ombilin Basins

• Sorption isotherm (Storage gas capacity)

• Human Resources Development

CompletableCoal

Thickness

Direct GasMeasurement/Dessorpt Test

SorptionIsothermTest

DATA ACQUISITION


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Pengeboran CBM di Cekungan Ombilin oleh Badan Geologi ( 2009)

DATA ACQUISITION

DATA ACQUISITION


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DATA ACQUISITION

Coal sampling for desorbtion gasanalysis

DATA ACQUISITION


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DATA ACQUISITION

Desorbtion and composition gasmeasured


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CBM RESOURCES (SPECULATIVE) IN SEDIMENTARY BASIN OF INDONESIA (ARII, 2003)

NO REGION BASIN GAS IN PLACE (Tcf)

1 SUMATERA SOUTH SUMATERA 183,0

CENTRAL SUMATERA 52,3

OMBILIN 0,5

BENGKULU 3,62 KALIMANTAN BARITO 101,8

KUTAI 80,4

PASIR &ASAM-ASAM 3,0

NORTH TARAKAN 17,5

BERAU 8,4

3 JAWA JATIBARANG 0,8

4 SULAWESI SOUTH SULAWESI 2,0Total Gas In Place 453,3

TOTAL SPECULATIVE RESOURCES OF CBMINDONESIA: 453,3 TCF

ARII : Advance Resource International Inc.


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CBM RESOURCES OF INDONESIA (ARII, 2003)

NO BASINFORMA

TION

COALTHICKNESS

(FT)

COALRANK

Ro (%)

DEPTH(FT)

GASCONTENT

(ft3/ton)

ASH(%)

MOIST(%)

CO2(%)

AREA(Mi2)

GAS INPLACE

(TFt3)

1SOUTH

SUMATRAMUARA

ENIM120 0.47 2500 223 10 7.5 3 7350 183

2 BARITO WARUKIN 90 0.45 3000 195 10 10 2 6330 102

3 KUTAI BALIKPAPAN 70 0.5 3000 195 10 5 2 610080.4

4CENTRAL

SUMATRA

MUARA

ENIM50 0.4 2500 223 10 10 2 5150 52.5

5NORTH

TARAKANTABUL 48 0.45 2300 147 12 6 5 2734 17.5

6 BERAU LATIH 80 0.45 2200 144 10 7.5 2 780 8.4

7 OMBILINSAWAH

TAMBANG80 0.8 2500 267 10 3 50 47 0.5

8 PASIR-ASAM2 WARUKIN 50 0.45 2300 164 7.5 7.5 2 385 3.0

9 NW JAVA T. AKAR 20 0.70 5000 422 15 3 5 100 0.8

10 SULAWESI TORAJA 20 0.55 2000 223 15 4 5 500 2

11 BENGKULU LEMAU 40 0.4 2000 133 10 10 5 772 3.6

TOTAL 453.3

ARII : Advance Resource International Inc.)

DATA OF CBM FROM SOME DRILLING LOCATIONS (Geological Agency, 2012)


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BADAN GEOLOGI

COAL-BED METHANE RESOURCES OF INDONESIA (Geological Agency, 2012)


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No Location Year Area(Km2)

Hypothetic Resources Average CH4 Content(SCF/Ton) CO2 Content (%)

Coal (Ton) CH4 (SCF)

1 Loa Lepu(East Kalimantan)

2006 2 x 1 191.726.612 150.711.520 0,78 0,21 – 71,86

2 Buana Jaya(East Kalimantan)

2007 2 x 1 534.261.545 606.588.270 1,13 20,43 – 26,89

3 Tanah Bumbu(South Kalimantan)

2008 2 x 1 112.733.226 402.255.325 3,57 0,71 – 1,58

4 Tamiang(South Sumatera)

2008 1 x 1 31.792.000 9.114.082 0.28 0,00 – 0,17

5 Tanjung Enim(South Sumatera)

2009 2 x 1 1.181.594.858 758.792.398 5,20 0,05 – 0,86

6 Ombilin(East Sumatera)

2009 1 x 0,4 7.987.200 1.624.346.374 200,23 8,84 – 35,20

7 Jangkang(Central

Kalimantan)

2010 - 16.567.200 15.724.004 0,08-4,49 0,00 – 1,12

8 Nibung(South Sumatera) 2010 7,5 x0,58 100.394.426 1.637.175.754 14,35 0,00 – 9, 01

9 Paser(East Kalimantan)

2010 2,7 x1,00

1.858.168 806.663 0,36 0,00 – 1, 20

10 Sawahlunto(East Sumatera)

2011 10.995.060 603.806.535 70,63

11 Bayunglencir 2012 17.170.000 83.446.200 4,86

Total Resources (hypothetic) : 2.201.786.038 tons (coal) ; 6.64 BCF (methane)


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PROPORTION OF CBM GAS CONTENTGEOLOGICAL AGENCY (GA) VS ARII

No BasinGas Content (SCF)

GA (Direct Measured) ARII (assumption)

1 Ombilin 216 - 356 267

2 South Sumatera 4.86 – 14.35 223

ARII : Advance Resource International Inc.


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BASIS OF SELECTION OF RESEARCH SITE1. Sedimentary basin that have the potential of coal2. Areas with good infrastructure3. To advance the national economy4. To develop the potential of unconventional energy

SELECTION OF SITE

1. Sumatera Selatan Basin2. Barito Basin3. Kutai Basin4. Central Sumatera Basin5. Ombilin Basin6. Berau Basin

7. Pasir & Asam-asam Basin

SCOPE OF WORK1. Preliminary survey, drilling work, and laboratorium work to identify

distribution, thickness and depth of coal seam and coal quality2. CBM asessment CBM( geology and geophysic works and data interpretation

to identify the 3D form of subsurface coal seam)3. Determination of drilling site to gain sweet-spot CBM

SELECTION SITE AND SCOPE OF WORK OF CBM RESEARCHOF GEOLOGICAL AGENCY

CLOSING REMARKS


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Indonesia has 128 sedimentary basins of various types.Indonesia is very impressive and promising potential to conduct shalehydrocarbon and CBM exploration.Total speculative resources of shale gas is 574.07 tcf, distributed in 14major basins (brown and green basins).Indonesia oil shale resources in 2007 up to 11.24 million tons where

10.09 million tons is speculative resources and 1.15 milliontones inferred resource Indonesia CBM resources up to 453,3 TCF (speculative) or 6.64 BCF

(hypothetic)Shale hydrocarbon and CBM potential is remarkably large, thereforeneed a comprehensive and integrated research to be done in order toproof its resource and reserve.Surface and subsurface geological & geophysical data have to be donein order to discover unconventional shale hydrocarbon and CBMresource and reserve.


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LAMPIRAN

WORK FLOW


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SYARAT SHALE GAS UNTUK DIEKSPLORASI


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Komposisi terdiri dari serpih ≤ 50%,dan mineral getas ( brittle minerals ) ≥50%, agar mudah saat dilakukanfracturing.

Kehadiran mineral lempung ( clayminerals ) sebaiknya < 10%, dengankomponen campuran perlapisansangat rendah.

Kandungan TOC ( total organiccarbon ) > 2%.

Tipe kerogen, umumnya kerogentipe II, dari lingkungan marine , atautipe III dari lingkungan terrestrial.

Tingkat kematangan termal tinggi,pada gas window ; untuk kerogen tipeII Ro > 1.1% hingga 1.4%; tingkatBTU dan kandungan CO 2 rendah.

Gambar : Haley, 2009

SYARAT SHALE GAS UNTUK DIEKSPLORASI


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Gambar : Haley, 2009

Ketebalan sedimen > 100 ft atausekitar 30 meter. Batas ketebalan dankedalaman berkaitan dengan rasio

kesuksesan proses fracturing padareservoir shale gas.

Kedalaman antara 1000 hingga 5000meter, dengan gradient tekanan > 0.5psi/ft.

Porositas > 5%, berupa microporosity maupun dari rekahan alami(natural fractures ).

Tingkat kegetasan ( brittleness )diindikasikan oleh nilai rasio Poissonyang rendah dan nilai modulus Youngyang tinggi.

Memiliki nilai Gas in Place (GIP) yangtinggi.

Well Logs


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Identifikasi LitofasiesPada Data Log Sumuran

Korelasi SekuenStratigrafi Antar Sumur

Bar

Channel

Estuarine

Lacustrine

Interpretasi LingkunganPengendapan

Kalibrasi Data Batuan inti dan DataLog Sumuran

Analogi Untuk Pemodelan Fasiespada Top Marker Parasekuen dari

Hasil Korelasi Antar Sumur


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INTEGRASI DATA


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6 86 00 0 6 88 00 0 6 90 00 0 6 92 00 0 6 94 00 0 6 96 00 0 6 98 00 0

6 86 00 0 6 88 00 0 6 90 00 0 6 92 00 0 6 94 00 0 6 96 00 0 6 98 00 0

1 m

1:

. 1

.

.

.

.

.

. 7

.

.

.1

.11

.1

.1

.1

.1

.1

.17

.1

.1

INTERPRETASI SEISMIKINTERPRETASI WELL LOG KALIBRASI DENGAN DATA CORE

PERMODELAN PROPERTI

GEOLOGICAL PROGNOSIS


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2013-2014

• Eocene to Oligocene vertically depositionalenvironment and kerogen type changes

• Eocene to Oligocene sequence stratigraphy• Burial History• Paleogeography• G&G analysis to calculate GIP

77


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WORK FLOW


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Permian Aiduna Fm.


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Interbedded & interlamination of clay andvery fine grain sst with intercalation of coal,lacustrine Permian deposit, Aiduna Fm.

Gunung Botak, Ransiki transect.


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Jurassic Kopai Fm.


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Formasi Kopai ini dicirikan oleh batulempung menyerpih, berlapis baik,warna lapuk coklat kemerahan, warna segar, abu-abu, karbonan dibeberapa tempat, terdapat pirit, dan di beberapa stasiun pengamatanditemui struktur sedimen parallel laminasi.

Lingkungan pengendapan Formasi Kopai ini dinterpretasikandiendapkan pada laut dangkal/ shallow marine.

Cretaceous Piniya Fm.


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Formasi Piniya disusun oleh batulanau, danbatulempung menyerpih, karbonan, warna lapukcoklat kemerahan, warna segar abu-abu kecoklatan,masif, keras, terdapat fosil cetakan moluska,bersisipan batupasir halus, di beberapa tempattermalihkan.Lingkungan pengendapan Formasi Kopai inidinterpretasikan pada pada lingkungan Marine.


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Peta rencana lokasi survei umum di Papua Selatan


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Documents

Unconventional Oil and Gas Potential