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NORTH SUMATRA BASIN: ITSNORTH SUMATRA BASIN: ITS EVOLUTION AND SEDIMENTATION
EVOLUTIONEVOLUTION
ALIT ASCARIA Ph.D.
CCOP. P1W2: North Sumatra-Mergui Basin Case Study. g yMedan & Parapat, 27 – 30 April 2010
Agenda
• IntroductionIntroduction• Regional Geology of North Sumatra
P l h• Paleogeography• Petroleum Systems• Conclusion
INTRODUCTION
Comparison of the Carboniferous, Permian, and Triassic sequences in the Sibumasu
BASEMENT LITHOLOGY
and Triassic sequences in the Sibumasu terranes of eastern Sumatra, West Malaysia and Thailand, and Gondwana Terrane in NW Australia
(Barber et al., 2005)
C f C fComparison of the Carboniferous, Permian, and Triassic sequences of the eastern Sumatra Sibumasu Terrane and GRDC map sheets, the Indochina Terranes of west S d h M l P i lSumatra and the eastern Malay Peninsula
Cross section of the Sumatra Subduction System from the floor of the Indian Ocean to the Malay Peninsula
(Barber et al., 2005)
BASEMENT TYPE
BASEMENT CONFIGURATION
(In Barber et al., 2005)(Hutchison,1994)
(Barber et al., 2005)
CONFIGURATION
During the Mid – Late Triassic, the whole of Sumatra and Peninsular Malaya were subjected to NE- SW extension with the f ti f l th th d NWformation of several north - south and NW –SE graben structures, the Kualu and Tuhur basins in Sumatra and the Semantan and Semanggol Basin in Malaya, separated by intervening horst blocks.
(Barber et al., 2005)
2741 64 2741 7m Argillaceous
Sample From POLONIA‐1
2741.64 – 2741.7m Argillaceous Sandstone (Kualu Fm.); the chief detrital grains of this sample are quartz; the grains have tangential and straight grain contacts withintergranular spaces infilled with authigenic clays and calcite cementclays and calcite cement.
PPT‐2A PPT‐1
Polonia‐1BHR‐1
PPT 2APPT‐2A
Sample PPT‐1 Well, 2595m; fine SS; quartz grains, and chert rock fragments with slightly sutured grain contacts; visible porosity
l % l ll i d 10 1 %generaly 5%, locally increased to 10 – 15%.
Mulhadiono, 1984
Kualu Fm.Eq. (2,525 ‐2,725m); Max.porosity is 12%, average 2‐5%, Sw is about 85%, and K is <10mD, with very fresh water <1000ppm Cl. Sample PPT‐2 Well, 2650.8 – 2650.86 m; lithic SS; quartz grains
dominant, poorly sorted, and individual grains are– 15%.
PPT‐2A PPT‐1
Polonia‐1BHR‐1
Mulhadiono, 1984
(Andreason et al., 1997)
(Andreason et al., 1997)
Schematic cross section showing geological model of N. Sumatra basin
(Widarmayana, 2007)(Widarmayana, 2007)
(Barber et al., 2005 modified)
(Hakim et al 2007)(Hakim et al., 2007)
North Sumatra Tectonic Elements (Present day)
( h d )(Sosromihardjo, 1999)
Tertiary structural and basin
(Barber et al., 2005)
yevolution of Sumatra
Present day internal framework of the North Sumatra Basin
STRUCTURAL FRAMEWORK OF N SUMATRA BASIN
(modified after Kamili et al., 1976)
(Clure, 2005)
STRUCTURAL FRAMEWORK OF N.SUMATRA BASIN
(Collins et al., 1996)
Basin development : Syn rift period Basin development : Late rift & Sag periods
Schematic cross section showing geological model of N. Sumatra basin
(Collins et al., 1996)
Play Concept and Risk
BOUGUER GRAVITY IMAGES AND CONTOUR LINES MAP
4.0
4.250km
3.4
3.6
3.8
20
25
30
35
mGal
98 2 98 4 98 6 98 8 99 0 99 2 99 4 99 6 99 8 100 0
3.0
3.2
-15
-10
-5
0
5
10
15
98.2 98.4 98.6 98.8 99.0 99.2 99.4 99.6 99.8 100.0
gravity in mGal, contour intervals 1 mGal
(Geo Prima Energi, 2009) BASEMENT CONFIGURATION (BASED ON SEISMIC MAPPING & GUIDED BY GRAVITY DATA)
BURIAL HISTORY BASED ON POLONIA‐1 WELL
Top Oil Window at 2400 m
Expulsion onpPliocene (4 Ma)
RANTAU DEEPNorth Sumatra Basin
0 HPPMO MISS SEUREULASEUREULAFm GEBANG LOW
MATURATION MODELLING ON STRUCTURAL HIGH AND LOW
U D
98°00'98°30' 99°00'
NRANTAU DEEP
Dep
th (m
)
1000
2000
3000
4000
KEUTAPANG
BAONG
BELUMAI
PRE-BELUMAIEarly Mature (oil)0.7 to 0.8 (%Ro)Mid Mature (oil)0.8 to 1 (%Ro)Late Mature (oil)1 to 1 3 (%Ro)
North Sumatra Basin
Dep
th (m
)
0
1000
2000
HPPMO MISS SEUREULASEUREULA
KEUTAPANG
BAONG
Fm
D U
U D
U D
U D
4°30'
U D
PTD
KSB
KST
PTT
Age (my) 0102030
50005200
1 to 1.3 (%Ro)Main Gas Generation1.3 to 2.6 (%Ro)
Age (my) 0102030
D
3000
4000
5000
BELUMAI
BAMPO
BSMTEarly Mature (oil)0.7 to 0.8 (%Ro)Mid Mature (oil)0.8 to 1 (%Ro)Late Mature (oil)1 to 1.3 (%Ro)Main Gas Generation1.3 to 2.6 (%Ro)
DARAT UTARA-1ANorth Sumatra Basin
CMP=FM;TH=THF;MAT=LL
TG=1;TI=0.5;EXP=TR;PRM=MKC
DI=1.000
interpreter: nhr
0 HPPMKEUTAPANG
Fm
BURIAL HISTORY & MATURITY DIAGRAM DARAT UTARA-1a WELL
D UD U
U D
D U
4°00'
PPT
PTD
SECGEB
PTTGEBANG LOW
Dep
th(m
)
1000
2000
3000
H KEUTAPANG
BAONG
BELUMAI
BAMPO
Batumandi Selatan-1
North Sumatra Basin
CMP=FM;TH=THF;MAT=LL
TG=1;TI=0.5;EXP=TR;PRM=MKC
DI=1000
interpreter: nhr
0HPPMO MISS SEUREULAFm
BURIAL HISTORY & MATURITY DIAGRAM BATUMANDI SELATAN - 1 WELL
DRU-1A
D UU D
TEBIN
G T
MEDAN
3°30'
LEGEND :
Age (My)0510152022
4000
4500 t = 0
Early Mature (oil)0.5 to 0.7 (%Ro)Mid Mature (oil)0.7 to 1 (%Ro)Late Mature (oil)1 to 1.3 (%Ro)Main Gas Generation1.3 to 2.6 (%Ro)
nana/c/mydocu/bmod-1d/nsb/dru1mat.ppt
h(m
)
1000
SEUREULA
KEUTAPANG
TING
GI D
EEP
3°00'
HIGH
LOCAL LOWBASIN SLOPE
LOCAL HIGH
LOW
BASILAM-A1a
North Sumatra Basin
CMP=FM;TH=THF;MAT=LL
TG=1;TI=0.5;EXP=TR;PRM=MKC
DI=1000interpreter: nhr
h(m
)
0
1000
HPPM MISS SEUREULA
SEUREULA
KEUTAPANG
Fm
BURIAL HISTORY & MATURITY DIAGRAM BASILAM-A1a WELL Dep
th
2000
BAONG
TRANSITIONBELUMAI
BSMT
Early Mature (oil)0.5 to 0.7 (%Ro)
Mid Mature (oil)0.7 to 1 (%Ro)
Late Mature (oil)1 to 1.3 (%Ro)
BAS-
BMS-1
GONDWANA,1980KSBGAS SAMPLES
Age (My)05101520
Dep
th
2000
3000
3600
BAONG
BELUMAIBAMPO
BSMT
t = 0
Early Mature (oil)0.5 to 0.7 (%Ro)Mid Mature (oil)0.7 to 1 (%Ro)Late Mature (oil)1 to 1.3 (%Ro)Main Gas Generation1.3 to 2.6 (%Ro)
Age (My)010203040
3000 t = 0Main Gas Generation1.3 to 2.6 (%Ro)1A
NORTH
Malaysia104
PEUTUSRG - 5
GOS-1
RTU-1
Platform Edge
Outer Platform NORTH
3
0
Sumatra
Index Map
indonesia Sea
0 10 km
PEUTU
Middle Platform
BELUMAI
MALACCA STRAIT
TST-1
RT-52
KS-2
SR-2
KLD-1
ARO-2
ARO-1
GOS-2A
ABS-1
SEC-4BES-1
SCG-1GEB-9
BES-2
SEK-1
DIS-2
P.BERANDAN
WP-2
BAS-AL
DRU-1
BMS-1
PPT-2A
BTM-1BTM-1BTM-1BTM-1
MEDAN
NSO
ASAHAN-01
PUSHUNG
Inner Platform
SumatraLEGEND
TEBING TINGGI
TWA-1
POL-1
BHR-1
Transistional
Middle Neretic
Environmental Set-Up
ra Shear Fault System
Outer-Middle Neretic
Outer Neritic
Sediment Transport Direction
LEGEND
Platform Edge
Sediment Transport DirectionSediment Transport DirectionSediment Transport Direction
Shelf Clastics /Isolated CarbonatesShelf Clastics / Isolated Carbonates
Nearshore Transistional/Inner PlatformLittoral
Open Shelf
Ashan
High
Ash
DEPOSITIONAL FACIES MAP : BELUMAI-PEUTU FM.
Sedimentology, PetrographyMiddle Miocene - NSB
DUYUNG SAND
SW NESL
HSTLST
N 11 - DUYUNG SAND
TSTQuartz arenite
S blithareniteQ
BAMPOBRUKSAH/PARAPAT
SLN 12 - GEBANG SAND
Subarkose Sublitharenite
Lithi
NORTHERN SOURCE
HST/SMSTGEBANG SAND
HST
BRUKSAH/PARAPAT
TSTF
ArkosicArenite
LithicArenite
L0 25 1007550
Q
SL
HST LST
MIDDLE BAONG SAND
GEBANG SAND
Subarkose
SOUTHERN SOURCE
.........Sublitharenite
LST
HST/SMST
HST LST GEBANG SAND
MFS/DLSF
F
ArkosicArenite
LithicArenite
L0 25 1007550
BARISAN UPLIFT
SR-AS NOT TO SCALE
LANGSA
RTU-1MukuLO
KO
P K
RT-521
2
KSTKSB-1
98 FASerang Jaya
TANJU
NG
PU
K.Simpang Timur
Medan
- 3°
- 0°
101 °
N
Rantau Str.
KU
TACA
NE FAU
LT
AULT
UR
A FAULT
SR-02KLD-1SRG-A1
SBU-A
Kuala Dalam
K.Simpang Timur
RANTAUSLP-1
Sungai-A3PTB
Pulau Panjang
SungaiA-1
SUS-A1
P. SembilanA R O
ABYPLW-1
Susu-A1Sem-A1
Paluh Tabuhan Timur
J-O-EIA
R-O-5R-O-6
R-O-7
J-R-E2Pusung-1
SCG-1TKM-1Gebang
PSL-1
SEK-A1
INDEX MAPBTR
Perapen
SCG 1SecuraiPBR-1
Telaga SaidTST-1A1
Telaga DaratB1
DRU-1
TAP-1
SAL-90
A R ULANGKAT - MEDAN Basilam - A1
Pantai Pakam Timur
SEK A1
M E D A N
Pantai Pakam Timur
PPA-1
PPA-2
Wampu
BMS-1
TPS-1
Batu Mandi12
3
Polonia
Diski
DISTRIBUTION MAP OF PROVEN STRUCTURE (Mod. DOH Nad 2005)
TWT Structure Middle BaongGebang-deep & Tanjung Pura AreaTWT Structure Belumai
Gebang-deep & Tanjung Pura Area
TWT Structure Basal SandGebang-deep & Tanjung Pura
Area
Reservoir Thickness and Quality
N-S wells correlationS
NN
BelumaiFmPreTertiary
Carbonate
NSO-NSO
100m
Divs.
PreTertiary
Kerinci-1
1S NSO-3S
PreTertiaryCarbonate
Kambuna-1
Kemiri-1Pusung-1 Kerinci-1
Kambuna-1Kemiri-1Pusung-1Tonjol-1NSO-1S
NSO-3S
Belumai FmTonjol-1
1
Water Bottom
Julu Rajeu
ASH05-43A
Julu Rajeu
Seurula
Keutapang
Middle Keutapang
Baong
BelumaiBelumai
PreTertiary
Series of Half Graben System
W EWater Bottom
Julu Rajeu
Seurula
Keutapang
Middle Keutapangp g
Baong
Belumai
PreTertiary
Glagah oilAccumulation
-fractured PreTertiaryLimestone
Untested Play in West Glagah
East Perlak-1East Perlak 1
Spud date: oct.1981
Objective: Turbidite sandstone Baong Formation, carbonate Peutu FormationFormation, carbonate Peutu Formation and sandstone of Brukash Formation.
Deep well drilled in Perlak Platform
R lt f E t P l k 1Result of East Perlak-1Baong Formation consists mainly of interbedded fine sandstone and shalePeutu Carbonate consists of interbedded fi d t d l kt i ffine sandstone and planktonic foram bioclastic wackestone in the upper part and planktonic foram bioclastic wackestone in the lower part. Depositional environment is
i ditiopen marine condition.Brukash Formation composed of interbedded fine sandstone and shale. TD at Pre-Tertiary Dolomite?
Bouguer Gravity Map
Gravity map showing main structural trends. Blue denotes thick and red denotes thinthick and red denotes thin.
Correlations – Northern Basin
Correlations – Southern Slope Area
Well data with results
NS
NSB-D1
GR DT
Baong
Bampo
Parapat
Baong
Oil Generation
Early Oil Generation
In BLD-1 Well at the time < 4 million year ago estimated had happened early stages of the oil generation in the upper part of Prapat Formation
Thermal Geohistory
OilOil Generation
Estimated the formation of hydrocarbons in the BLD-1 Well happened on the upper part of Prapat Formation at temperature 105° - 120° C and occurred in 2 million years ago
Conclusion
• There are potential for pre-Tertiray play in North Sumatra Basin (NSB)
• Oligo-Miocene carbonate still the main target for exploration in NSB.
• Finding prolific basin like Java and Lho Sukon Deeps is a must in NSB for high impact exploration target (Arun/NSO size).
• Distribution of Middle Baong sandstone still poorly understood g p yespecially in Andaman area.
• For sandstone play need to have a good trap since tectonic is relatively intense during Plio-Pleistocene.y g
• Despite all the risk, NSB still have a potential for exploration to finding big hydrocarbon resources.
• Gas shortage to LNG/PIM/DMO need to fulfilled by explore the NSBGas shortage to LNG/PIM/DMO need to fulfilled by explore the NSB