WORKSHOP ON SHALE GASSHALE GAS, SUMBER ENERGI ALTERNATIF MASA DEPAN

TECTONICS AND SEDIMENTATION IN RELATION TO SHALE HYDROCARBON IN INDONESIABy: AGUS GUNTORO Email: guntoroagus51@yahoo.com Jurusan Teknik Geologi, Fakultas Teknologi Mineral, Universitas Trisakt

Pomelotel Hotel, Jakarta i 28 29 November 2012

PRESENTATION FRAMEWORKI. INTRODUCTION II. EXPLORATION CONCEPT III. PLATE TECTONICS IN RELATION TO BASIN FORMATION IV. TECTONICS AND SEDIMENTATION V. CONCLUSIONS

I. INTRODUCTIONA. BACKGROUND THEME : SHALE HYDROCARBON POTENTIAL FLOW OF THINKING SHALE GAS POTENTIAL

DATA EXPLORATION

NON TEHNICAL SHALE GAS SYSTEMS

TEHNICALTECTONICS & SEDIMENTATION

EXPLORATION CONCEPT

DIVERSIFICATION IN EXPLORATION CONCEPTOIL IS FOUND IN THE MIND OF MAN IT IS A MATTER OF CONCEPT DEVELOPED IN ONE MIND TO SEARCH OF HYDROCARBON

ONE OF THE ALTERNATIVE IN RELATION TO DIVERSIFY OF EXPLORATION CONCEPT IS TO FIND OIL AND GAS NOT IN THE KNOWN CONVENSIONAL HYDROCARBON, BUT IN THE SO CALLED UNCONVENSIONAL HYDROCARBON. ONE OF THEM IS IN THE SHALE HYDROCARBON

B. DEFINITIONWHAT IS SHALE GAS??? & WHAT IS THE EXPLORATION CONCEPTS ??? & WHAT IS SHALE GAS SYSTEMS ???

WHAT IS SHALE GAS Shale gas is natural gas produced from shale. Gas shales are thought of dually system as hydrocarbon source rocks and finegrained tight-gas reservoirs. Shale gas refers to in situ hydrocarbon gas present in organic rich, fine grained, sedimentary rocks (shale and associated lithofacies). Gas is generated and stored in situ in gas shales as both sorbed gas (on organic matter) and free gas (in fractures or pores). As such, gas shales are self-sourced reservoirs. Low-permeable shales require extensive fractures (natural or induced) to produce commercial quantities of gas.

Typical of shale

Dark beds are shale, light beds are limestone. Part of the dark colour in the Utica Shale comes from organic matter. A writing pen is shown for scale.

SHALE HYDROCARBONShale rocks are formed by compaction and because of this they tend to have low porosity and extremely low permeability. As a result of their physical properties, extraction of gas from shale rocks is challenging and requires efficient and improved techniques, such as fracturing and horizontal drilling.

Sample of shale from Utica Shale near town of Donnaconna, Quebec

SHALE GAS in SUB-SURFACE

USGS 2003A shale gas system is a self-contained source reservoir system. In this system, shales that generated the gas also function as low matrix permeability and low porosity reservoir rocks.

DIAGRAM OF SOURCE ROCK MATURITYDiagram of source rock maturity in order to generate hydrocarbon by increasing depth and temperature

Claypool (1998) separated shale gas systems by gas type: Biogenic Gas, Thermogenic Gas, Mixed Gas.

Dan Jarvie et al. (2007) classified the shale gas systems into several types: 1. High-thermal maturity shales (e.g. Barnett Shale). 2. Low-thermal maturity shales (e.g. New Albany Shale). 3. Mixed lithology intraformational systems (e.g. Bossier Shale of East Texas). 4. Combination plays that have both conventional and unconventional gas production (e.g. in Woodford shale gas and conventional gas accumulation in Anadarko Basin).

Schematic Of Oil & Gas GenerationWhy is there more gas at higher thermal maturity?S H A L E O I L

S H A L E G A S

GEOLOGICAL FACTORS IN SHALE GASSTRATIGRAPHIC FACTORS-Mineral composition

-TOC, organic richness and type, gas content -Grain size -Bed thickness -Clay abundance and type -Porosity -Fractures and permeability barriers -Frequency of laminations -Small to large scale stratigraphy; paleogeography -Rock strength -Biogenic features (micro-trace fossils; micro-and macro-body fossils)

ARE RELATED

STRUCTURAL FACTORS-Stress regime

-Structural position and proximity both folds and faults -Intensity of structural deformation -Tectonic and burial history; thermal maturity; Present Oil or Gas window -Depth and depth windows -Pressure of reservoir -Temperature of reservoir

Scale-Different factors operate at different scales (pore-to regional-scale)

SHALE GAS SYSTEMSHALE GAS SYSTEMS IS THE NECESSARY ELEMENTS NEEDED TO HAVE FOR THE POSSIBILITY WHERE SHALE GAS COULD BE GENERATED, THE ELEMENTS ARE:

US experience shows a wide variety of shales can be commercially productive

THIS INDICATES THAT THERE IS NO UNIQUE PARAMETER FOR SHALE GAS TO BE DEVELOPED AND ALSO FOR GEOLOGICAL CONDITION

Realities of Shale Gas Resources: Yesterday, Today and Tomorrow John B. Curtis, CSM David G. Hill, EnCana Paul G. Lillis, USGS

Newton, Hamzah and Morrison, 2012.

II. Exploration concept

EXPLORATION CONCEPTEXPLORATION CONCEPT IS GEOLOGICAL MODELS DEVELOPED TO EXPLORE WHERE THE POSSIBLY SHALE HYDROCARBON IS LOCATED LOCATED. OCATED

WORKING HYPOTHESIS

PLATE TECTONIC THEORYPLATE INTERACTION TYPE OF BASIN FORMATION, BASIN BASIN FILLING AND BASIN STRUCTURISATIONCRITERIA OF BASIN CLASSIFICATION CLASSIFICATION (Dickinson (1974)1. The type of crust on which the basin rest 2. The position of the basin relative to plate margins 3. The type of plate interaction occurring during sedimentation

RELATED TO THE POTENSIAL OF SHALE HYDROCARBON USING SHALE HYDROCARBON SYSTEM ELEMENT ANALYSES

APPROACHTECTONO-STRATIGRAPHY

SEDIMENTARY MEGA CYCLE

STRUCTURAL STYLE TENSIONAL COMPRESSIONAL TRANTENSIONAL/ TRANSPRESSIONAL

SEDIMENTARY CYCLE

SHALE GAS SYSTEMS MINERALOGICAL COMPOSITION

SOURCE ROCK PREDICTION

POTENTIAL SHALE HYDROCARBON AREA

MEGA-CYCLE CONCEPTTHE CYCLE SHOWING THE TRANSGRESSIVE AND REGRESSIVE CYCLES AND INLINE WITH TECTONIC DEVELOPMENT AS HALF-GRABEN. THE GRABEN AREA TOWARD THE DEEP WATER ALSO SUBJECT TO THE PRESENCE OF SOURCE ROCKS

SEDIMENTARY MEGA-CYCLES OF INDONESIATHE CYCLE ALMOST CAN BE FOUND IN TERTIARY BASIN IN INDONESIA AND SHOWING CYCLE OF TRANSGRESSIVE AND REGRESSIVE AND THE CYCLE CAN BE CORRELATED TO THE SOURCE ROCKS AND RESERVOAR ROCKS DEVELOPMENTAS. THE CYCLE IS USED AS THE MAIN TOOL IN EVALUATING THE PRESENCE OF ELEMENTS OF SHALE GAS SYSTEMS

Kelts 1988; Cohen 1989; Katz 1999

Petroleum System Chart OF East Java

THE RELATION BEETWEEN TECTONICS IN FORMING THE BASIN AND THE PROCESS OF BASIN FILLING IN RELATION TO THE DEVELOPMENT OF ELEMENTS OF PETROLEUM SYSTEMS AND MIGRATION PATHWAYS OF THE HYDROCARBON

III. PLATE TECTONICS IN RELATION TO BASIN FORMATION

Tectonic Plates as the main basic knowledge in understanding basin formation in related to plate boundary

PLATE BOUNDARIES IN RELATION TO BASIN FORMATION AND SEDIMENTATION

Map showing various timing of major tectonic activities in different Areas of southeast Asia (After Schereus 1966)

Regional Tectonics

Tectonics configuration of Indonesian archipelago located in the three major plates. Tectonically Indonesian in divided into western Indonesian (of asian affinities), and eastern Indonesia of Australian affinities

Regional Tectonics

Plate reconstruction of Indonesian region showing in the Mesozoic Kalimantan, East Java and SW Sulawesi is part of a single microcontinent which then break apart to the present position. The East Sulawesi is still far away and was part of Australian Plate.

(Robert Hall, 1996)

Regional Tectonics

Plate recontruction from 30 15 Ma showing the sequence movement of East Sulawesi to collide with West Sulawesi.

(Robert Hall, 1996)

Regional Tectonics

Plate reconstruction from 10 and 5 Ma showing the event of Banggai Sula collison and timing of the ophilite emplacement to north of east Sulawesi

(Robert Hall, 1996)

BASIN DEVELOPMENT BASIN FILLING BASIN STRUCTURISATION

TEMPORAL & SPATIAL

EXISTING TERT TERTIARY BASIN DISTRIBUTION MAP

60 POTENTIAL TERTIARY BASIN (IAGI BPPKA) CONCEPT OF BASIN CLASSIFICATION NEWLY DISCOVERED BASIN

TECTONIC MAP AND BASIN

BPMIGASBPMIGAS -LAPI ITB (2008)

Indonesias Shale Gas Potential

N0 400 km

Basin Data Source: Inameta PT. PND

Western Java Gumai Shale Telisa Shale Baong Shale

Tarakan BasinKlasafet Formation Kutai Basin Barito Basin Eastern Java

IV. TECTONICS AND SEDIMENTATION

Geological OverviewTectonic Setting and basin development

Simplified tectonic element and crustal distribution for Indonesia Region

NORTH SUMATRA BASIN

STRUCTURAL FRAME WORK OF NORTH SUMATRA BASIN

STRATIGRAPHY REGIONAL NORTH SUMATRA BASIN

LOWER BAONG FORMATION

SECONDARY TARGET

Deposited as deltaic environment

MAIN TARGET

BAMPO FORMATIONDeposited during rifting process

CENTRAL SUMATRA BASIN

REGIONAL STRUCTURE

F3

F0; Pre-Tertiary F1; Eocene-Oligocene rifting in N-NNE F2; L Oligocene- M Miocene extensional N-NNW F3; Plesitocene Recent in NW SE Direction

Structural Framework of the Basement in Central Sumatra Basin

F2

F2

F2

F3Structural Map of Central Sumatera Basin showing the N-S structural orientation as older structure and NE-SW structural orientation as younger structure.

(Heidrick & Aulia 1996)

TECTONOSTRATIGRA PHY CHART CENTRAL SUMATRA BASIN

1.Rift 1.Rift phase - Eocene to early Miocene Pematang Group deposition. 2. PostPost-rift phase - Early Miocene to middle MioceneDeposition of Sihapas GroupSHALE GAS PLAY

3. Inversion phase - Middle Miocene to Pliocene Deposition of Petani Group

Wain et al., 1995

REGIONAL GEOLOGY; STRATIGRAPHY (Wain et al., 1995)

SHALE GAS PLAY

BASEMENT MAP CENTRAL SUMATRA BASIN

(Heidrick & Aulia 1996)

FORMATION CANDIDATE FOR SHALE GAS

NE-SW Geological CrosssectionARE WITH LESS TECTONICS DURING PLIO-PLESITOCENE

ARE WITH MORE ACTIVE TECTONICS DURING PLIO-PLESITOCENE

(Heidrick & Aulia 1996)

SOUTH SUMATRA BASIN

GEOLOGY REGIONAL OF SOUTH SUMATRA BASIN102 103 104 105 106

N

2

JAMBI SUBBASIN CENTRAL PALEMBANG SUBBASIN

3

PAGAR JATI GRABEN

BENGKULU

SOUTH PALEMBANG SUBBASINKEDUANG GRABEN KEPAYANG GRABEN

4

BENGKULU BASINSCALE0 50 100 KM

5

(De Coster, 1974)

GENERAL STRATIGRAPHIC COLUMN AND TECTONIC EVENTS OF SOUTH SUMATRA BASIN(PR. DAVIS. 1984)

M. YEAR

200 150 100 50 PLIO PLEISTOCENE OROGENY

0

-50

PLEISTO CENE PLIOCENE5

N 23 N 22 N 21 N 20 N 19N 18

ThALLUVIAL ALLUVIAL KASAI FORMATION ALLUVIAL KASAI FORMATION MUARA ENIM FORMATION

COMPRESSION

TgMUARA ENIM FORMATION MUARA ENIM FORMATION

LATE

N 17 N 16

Compression and Uplift

MIOCENE

DELTAIC CLASTIC

Upper GUF & ABF

10

Upper GUF, ABF BRF LMST LAHAT. TAF & GUF SHALE TAF

MIDDLE

N 12

Tf

15

N9

2

N 11 N 10 N8

AIR BENAKAT FORMATION

AIR BENAKAT FORMATION

AIR BENAKAT FORMATION GUMAI FORMATION

N7 N6

EARLY

N5

5

20

GUMAI FORMATION

TRM TALANG AKAR FORMATION TALANG AKAR FORMATION GRM

N4

LOWER

OLIGOCENE

25

Sag Basin and Growth Fault

LATE

1 - 4

P 22

P 21

30P 20

EARLY

Tc - Td

??LAHAT FORMATION

LAHAT FORMATION

LAHAT FORMATION

P 19

T E N S I O N

TALANG AKAR FORMATION

35

P 18 P 17

Graben Fill

EOCENE

LATE

P 16

40

P 15 P 14

Tb

COMPRESSION

METAMORPHIC

PRE TERTIARY

IGNEOUS / INTRUSSIVE

Strike Slip, Block Faulting and Intrusion

( Haq et.al, 1987)

FLUVIAL, DELTAIC CLASTIC & CARBONATE ( TAF & Eq. BRF )

Te

TAF & GUF SHALE

UPPER

GUMAI BRF BRF FORMATION

BRF

BRF

1

(FRONT - PLAIN)

ABF SHALE

3

N 15 N 14 N 13

DEEP

RISING

DROP

SEALS

EPOCH

JAMBI SUB BASIN

NORTH PALEMBANG SOUTH PALEMBANG SUB BASIN SUB BASIN

LITORAL

HISTORY

SHALLOW

(HAQ et.al. 1987)

PLAY TYPES

RESERVOIR ROCKS

NERITIC

SOURCE ROCKS

A G ELETTER STATES BLOW ZONES

SOUTH SUMATRA BASIN

TECTONIC

TERRESTRIAL

EUSTATIC CURVE GEOLOGICAL

ENVIRONMENT

EXPLORATION PLAY

(INDONESIA BASIN SUMMARIES, 2006)

VARIOUS BASIN STRUCTURISATION IN SOUTH SUMATERA BASIN WITH DIFFERENT SHALE GAS

NORTH WEST JAVA BASIN

SCHEMATIC CROSS SECTION OF JAVA

BASEMENT CONFIGURATION NORTHWEST JAVA BASIN106 30 106 00 106 30 107 00 107 30 108 00 108 30 109 00 109 30 110 00

SUMATRA05 00

YANI-NST

Sunda Platform

ASRI

05 30

CENTRAL ARJUNA

VERA

SUNDASeribu Platform06 00

SOUTH ARJUNA

JAKARTA

JATIBARANG06 30

CIPUTAT

CIREBON

KEPUH PASIRBUNGUR CIPUNEGARA E 15 Graben TANJUNG PEMALANG KENDAL

07 00

TWT Scale< 0.5 0.5 - 1.0 1.0 - 1.5 1.5 - 2.0 2.0 - 2.5 2.5 - 2.0 > 3.0

N

J A50 MI

V

A

0

PETA KONTUR BATUAN DASAR CEKUNGAN JAWA BARAT UTARACompiled by : Nobel-IND-ADT/96 @ IND-1996

Regional Stratigraphy

(Purnomo J & Purwoko 1994)

NORTH EAST JAVA BASIN

HC HABITATS AND TECTONIC SETTINGS

(Satyana and Purwaningsih, 2003)

The East Java basin is the most structurally and stratigraphically complex of the Indonesian back-arc basins

REGIONAL STRATIGRAPHY AND TECTONIC EVENT

Chronostratigraphic column of Northeast Java Basin (Mudjiono et al 2001)

KALIMANTAN

REGIONAL TECTONIC SETTING Extensional movement in the late Cretaceous-early Miocene (Syn- and post-rifting phases) Compression movement in the Plio-Pleistocene created reverse fault and fold structures

(modified after BEICIP,1985)

KALIMANTAN CROSS SECTON

REGIONAL STRATIGRAPHY KALIMANTAN

KUTAI BASIN

TECTONIC ELEMENTS OF KUTAI BASIN

(INDONESIA BASIN SUMMARIES, 2006)

STRATIGRAPHY REGIONAL OF KUTAI BASIN

SHALE GAS BEARING FORMATION

SHALE GAS BEARING FORMATION

KUTAI BASIN CROSS SECTION

CROSS SECTION EAST KALIMANTAN

W

E

TARAKAN BASIN

North Tarakan Block

PHYSIOGRAPHY OF TARAKAN BASIN1. Muara subsub-basin, the southernmost depocentre developed exclusively offshore. offshore. 2. Berau subsub-basin and mostly 3. onshore

located in the south. south. Tarakan subsub-basin, mostly offshore but including Bunyu andBerau Block

Tarakan Islands. Islands. 4. Tidung subsub-basin, the most northerly basin

Satyana et al. (1999)

and mainly onshore. onshore.

REGIONAL CROSS SECTION OF TARAKAN BASIN

Hidayatiet al. (2007)

REGIONAL STRATIGRAPHY OF TARAKAN BASIN

Awang Harun Satyana, Petroleoum Geology of Indonesia HAGI 2009

BARITO BASIN

Barito Basin: Simplified Geology & Major Structural Features

Barito Basin area; approx. 70,000 sq km total, 50,000 sq km onshore. Bounded to west by Schwaner Mountains, east by the Meratus Mountains (accretionary and ophiolitic affinity), north by the Adang flexture and to the south by the Florence high in the Java Sea. Basin formation mechanism unresolved. Contains a thick sequence of Cenozoic non-marine and marine sediments depicting a complete transgressive to regressive sequence.

Barito cross section

REGIONAL STRATIGRAPHY BARITO BASIN

75

REGIONAL STRATIGRAPHY BARITO BASIN

The Eocene age Tanjung Formation is syn-rift & post-rift; initially fluvial, then shallow marine. Shale was formed in near-coastal environment. Berai Formation is Oligocene Warukin Formation early to late Miocene; regressive sequence, including shale. The Dahor Formation was deposited after the Meratus uplift

SHALE Bearing Warukin Formatio n SHALE Bearing Tanjung Formatio n

:\Data\WSO\transforma siep\RoadshowDOHD

D:/Data/Shy/BhnRapimEPrev

SALAWATI BASIN

REGIONAL TECTONIC

REGIONAL STRATIGRAPHY

V. CONCLUSIONSIT IS APPARENT THAT INDONESIA HAS HUGE POTENTIAL OF SHALE HYDROCARBON SHALE HYDROCARBON HAS SEVERAL REQUIREMENT TO BE SUCCESS, SUCH AS TOC, BRITTLENESS INDEX, THICKNESS, MATURITY, ETC. SHALE HYDROCARBON POTENTIA IS UNIQUE IN EVERY BASIN. TECTONICS AND STRATIGRAPHY ARE THE MAIN CONTROL IN BASIN DEVELOPMENT AND ASSOCIATED WITH BASIN FILLING XPLORATION CONCEPT CAN BE APPROACH USING TECTONO-STRATIGRAPHY CONCEPT IN DEFINING SOURCE DEVELOPMENT

THANK YOU FOR YOUR ATTENTION

The Steers Horns2-4 km 6-8 8 km SAG: IS (Interior Sag) MS (Marginal Sag) DS (Delta Sag)

RIFT:IF (Interior Rift)

10-30km

80-300km