77606055 eksploration of th north madura platform
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IPA01-G-138
PROCEEDINGS, INDONESIAN PETROLEUM ASSOCIATION
Twenty-Eighth Annual Convention & Exhibition, October 2001
EXPLORATION OF THE NORTH MADURA PLATFORM,
OFFSHORE EAST JAVA, INDONESIA
Rachmat Mudjiono*
Gadjah Eko Pireno*
ABSTRACT
Cities Service initiated exploration of the offshore East
Java Basin in the late nineteen-sixties, holding the vast
(157,000 sq km) North East Java PSC from 1969 until
1979. Cities shot 46,295 km of seismic data and
drilled 48 wells, including three on the North Madura
Platform. This feature is a stable high flanked by
known hydrocarbon kitchens to the northwest (Central
Deep) and south (Madura Basin), and it attracted
more drilling by later operators. Like the Cities wells,
these wildcats found teasing shows of oil and gas but
no commercial accumulations. Exploration continued
to focus on shelf edge buildups close to hydrocarbon
source areas in adjoining depositional troughs. The
wells encountered problems with reservoir quality, and
sharp velocity gradients confounded attempts to image
b i d t t ith i i d t
The new (2001) Bukit Tua and Jenggolo oil and gas
discoveries targeted reservoirs in layered Kujung
carbonates near the center of the North Madura
Platform, 10 to 20 km from the fringing reefs.
Porosity development in this area may result fromrepeated exposure on the crest of the old Madura
Platform. Migration pathways connect these
reservoirs to distant source kitchens via permeable
Kujung I carbonates and near-basement carrier beds
such as basal clastics and Ngimbang and Kujung II/III
carbonates. Confirmation of porosity and
hydrocarbon occurrence in these discoveries opens
the stable platform area to exploration. Fringing reefsremain a viable play, as indicated by other recent
discoveries in the Ketapang PSC (Bukit Panjang,
2000; Payang 2001) and nearby West Madura blocks
© IPA, 2006 - 28th Annual Convention Proceedings, 2002Disc Contents
Contents
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buried structures with seismic data 2000; Payang 2001) and nearby West Madura blocks
Cities Service initiated offshore exploration in 1967 on
their vast Northeast Java PSC, which covered
157,700 sq km offshore from Java, Madura, and Bali.Cities acquired 46,295 km of seismic data and drilled
48 wells. Most of these wells tested structural
features and/or reefal buildups in the top of the
Kujung Formation (Figure 2). Three of the Cities
wells were classified as oil discoveries, four were gas
discoveries, and one was an oil and gas discovery. Of
these, Cities produced only Poleng Field (located west
of the North Madura Platform, Figure 1) for a fewyears and then relinquished the block in 1979 without
a commercial success.
Five of the early Cities wells were drilled in the
vicinity of the North Madura Platform, although none
were located near the crest of the feature. Cities
drilled the JS 3-1 a few km northeast of the platform
(Figure 1) in 1970. This well encountered oil showswithin the Kujung and a poor oil show in the deeper
Ngimbang Formation, but it was not tested. Also in
1970, Cities drilled JS 8-1 in the Kujung reef trend
along the southeast flank of the platform. JS 8-1
encountered an oil show in the Ngimbang Formation.
Cities drilled the JS 2-1 in 1971 to test a fault closure
just off the north edge of the platform. This well
tested 4.6 mmscfd from thin carbonates within theKujung. Two more wells were drilled by Cities
Service in the Kujung reef trend along the southern
edge of the North Madura Platform before
Inpex operated a block covering this area starting in
1990. Inpex acquired a tight grid of seismic data,
concentrating on the southern portion of the NorthMadura Platform. They drilled three wells:
Cassiopea-1 to the north of the platform plus
Perawan-1 and Waluku-1 along the shelf edge trend
to the south (Figure 1). Of these, Perawan reported
oil shows and all were plugged and abandoned.
Gulf Indonesia signed the Ketapang PSC in 1998 and
proceeded to reprocess 5,634 km of existing seismicdata on the block. An additional 2,300 km of data
were acquired in 1999, filling in gaps to construct a
closely spaced grid of 2D seismic lines (Figure 3)
across the block.
REGIONAL TECTONICS
The East Java Basin is situated on the southernmargin of the stable Sunda craton and covers an area
of approximately 50,000 sq km. The basin formed in
the Eocene as a back arc basin associated with a
volcanic arc to the south (Figure 4). The
Karimunjawa Arch marks the western limit of the
East Java Basin , and to the east it is bounded by deep
water environments of the oceanic Lombok, Flores,
Salayar, and South Makassar basins. The East JavaBasin extends northeastward from the volcanic arc
offshore across the Java sea and back onshore in the
southeastern corner of Kalimantan and the adjoining
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This extends southwestward across the Java sea and
appears as a band of basic igneous basement to the
northwest of the Ketapang PSC (Figure 5). Lowgrade metasediments surround the band of basic
igneous rocks and extend into the northwestern corner
of the Ketapang block. Southeast of the
metasedimentary basement are northeast-southwest
trending bands of acidic and intermediate igneous
rocks, indicating presence of a continental fragment
within the suture complex.
With continuing compression, the East Java Basin
underwent uplift and peneplanation during the early
Tertiary. A series of northeast–southwest trending
ridges and grabens then developed along the
southeastern edge of Sunda shield, perhaps in
response to back arc spreading. From west to the
east, the major features in this extensional complex
are the Karimunjawa Arch, the Muria h Trough, theBawean Arch, and the Tuban-North Madura High
(Figure 4). These features extend onshore, bending to
the west into an east northeast-west southwest
alignment.
The rift basins filled initially with a thick sequence of
non-marine clastics, including lacustrine shales,
starting in the Middle Eocene (Figure 2). A sag phasefollowed the rift episode, and basin fill in the grabens
changed upward into a fully marine Late Eocene to
Early Oligocene sequence of shale with local
series of depositional cycles. This study is limited to
the basal two cycles, the Ngimbang and Kujung,
which constitute petroleum systems now beingexplored in and around the North Madura Platform.
Pre-Tertiary basement underlying these units in the
vicinity of the Ketapang block consists of low grade
metasediments and acidic to intermediate igneous
rocks (Figure 5).
Ngimbang Cycle
The earliest sediments deposited on pre-Tertiary
basement were largely controlled by the underlying
basement architecture. These comprise the
Ngimbang Formation, which accumulated within the
grabens from the Middle to Late Eocene through the
Lower Oligocene (Figure 2). The lower Ngimbang
consists of a series of interbedded quartz sandstones
and gray to brown carbonaceous shales with minorcoals, which accumulated in brackish to lacustrine
environments. Lacustrine environments probably
developed in the graben depocenters during Middle
Eocene time, making the Lower Ngimbang a likely
hydrocarbon source rock in the East Java Basin.
Basinal sag resulted in widespread incursion of marine
environments during the Late Eocene, and marinesediments dominate the upper Ngimbang Formation.
These onlap the southern flank of the North Madura
Platform, as shown by the paleogeographic
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The overlying Kujung II reflects a change to quiescent
tectonic conditions accompanied by regional
subsidence. These deposits consist of a transgressivesequence of shallow water carbonates and calcareous
shales. Localized carbonate build-ups developed on
stable high areas. Irregular and discontinuous seismic
events characterize the Kujung II and Kujung III
intervals in the North Madura Platform area,
indicating abundant lateral variation in sedimentary
facies. Deposition of these units was controlled to
large extent by the pre-existing northeast-southwesttrending structural pattern. Both Kujung II and III
units are important reservoir targets for current
exploration in the North Madura Platform area.
The Kujung I interval is a thick (1300 ft) carbonate
section that lacks the significant shale intercalations of
the underlying Kujung II. Figure 7 shows the
interpreted paleogeography for the Kujung I. Buildupsoccur as linear reefs fringing uplifts and isolated patch
reefs on stable platforms. A prominent shelf-edge
reef tract developed along an east-west trend parallel
with a present day Madura and Java northern coast
line.
Overburden
Four additional depositional cycles followed the
Kujung in the North Madura Platform area. Each
follows the pattern of starting with clastic
Trough area along the western edge of the
offshore East Java Basin (Figure 4). Although
quite shallow (3,000 ft) over the North MaduraPlatform, the Ngrayong remains a secondary
objective in this area.
3. Wonocolo (Middle to Late Miocene), widespread
deep marine shales and marls with minor sands
capped in offshore areas by major accumulations
of platform and reefal carbonates. These were
exposed in the Late Miocene and incised by aseries of channels, some cutting entirely through
the carbonate complex. Velocity contrasts
between slow channel fill deposits and fast
carbonates and the resultant sag in deeper seismic
events causes difficulty in interpreting depth
structure. These are discussed in the following
section on Depth Conversion.
4. Late Miocene to Recent deposition started with
renewed transgression and accumulation of highly
varied sedimentary facies. These include marls
and reworked sandstone, globigerinoid chalks and
reefal limestones, and a large influx of
volcaniclastic sandstone from the volcanic arc to
the south starting in the latest Pliocene. Local
tectonic effects became more severe with timeand have the greatest control on sedimentary
facies. Volcaniclastics and globigerinoid chalks
are major reservoirs in the early onshore
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sources, but the study noted that the Eocene
Ngimbang is believed to have sourced 95% of the oil
and gas in the East Java Basin. Studies of particularareas within the basin by Phillips and others (1991,
Kangean Island area) and by Manur and Barraclough
(1994, Bawean area) also concluded that the Eocene
Ngimbang is the source for oil in those regions.
Source Rock Maturity
Corrected logging temperatures from wells drilledthroughout the East Java Basin indicate an overall
range in geothermal gradients from 1.4 to 2.4 deg
F/100 feet. In the vicinity of the Ketapang Block, the
average geothermal gradient is 1.95 deg F/100 feet.
Maturation models were generated using local log and
seismic data to examine the history of hydrocarbon
generation for two areas flanking the North Madura
Platform: the Central Deep to the northwest and theMadura Basin to the south (Figure 4).
The model for the southern part of the Central deep
(Figure 8) uses a geothermal gradient of 1.8 deg.
F/100 feet, based on local well control. It shows that
lacustrine and alluvial source rocks in the lower
Ngimbang sequence, with kerogen types I and II,
entered the window for oil generation (Ro 0.7-1.0)during Oligocene and Miocene time between 34-11
million years BP. Maximum generation (Ro 1.0-1.3)
occurred over a broad span of time from Late
Pliocene and remains there now (Figure 9). The
upper Ngimbang started maximum oil generation
about 6 million years BP and entered the gas windowonly about 1.5 million years ago. Kujung and
shallower strata are still in early oil generation or
thermally immature.
Results from the maturation modeling for the deep
basins adjoining the North Madura Platform indicate
that lacustrine and alluvial facies in the lower
Ngimbang are likely sources for oil and gas in the North Madura Platform area, but that marine kerogen
in the upper Ngimbang may also contribute. The long
history of oil generation and predominance of kerogen
types I and II in the lower Ngimbang bode well for oil
accumulation on early structures connected by faults
or carrier beds to the basinal source kitchens. Late
forming traps and those connected to current gas
generating areas may be more prone to accumulatedgas.
Reservoirs, Traps and Seals
Reservoir targets in the North Madura Platform area
include:
1. lower Ngimbang clastics developed on the flanksof the Platform,
2. upper Ngimbang carbonates, except for crestal
areas where this unit may be absent due to
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inversion, and upthrown and downthrown closures
occur in association with major and minor faults in this
structurally complex area. Kujung gas tests in JS 2-1and the recent Payang-1 discovery show that some
fault traps work in this area, but the risk of fault timing
and seal remains a potential dry hole hazard. Less
vexing four way dip closures are recognized as low
relief structures on the undulatory surface of the
Platform and as structures formed by drape over
reefal buildups in the Kujung. Unfortunately,
significant velocity gradients pose a major challenge todepth conversion of structural interpretations on
seismic data. Imaging these subtle closures requires
accurate depth mapping, and proper depth conversion
of seismic time maps is a key factor in recognizing
prospect size and selecting well locations. Methods
used in siting the recent Ketapang discoveries are
described below.
The flanks of the North Madura Platform also have
potential for stratigraphic traps formed by onlap of
basal clastics in the Ngimbang. Several wells flanking
the Platform recorded oil shows in this unit, but as yet
there have been no commercial tests. The onlap edge
remains difficult to identify with confidence, but this
will likely improve with acquisition of 3D seismic data
and additional well control.
Shale in the Tuban Formation provides a regionally
extensive seal for Kujung fault traps and dip closures.
Payang (Figure 10). Faults may also be important in
plumbing source kitchens to carrier beds, which then
transport oil and gas updip into traps.
Play Concepts
Lack of success over 30 years of exploration has not
downgraded the exploration potential of the North
Madura Platform. Good oil and gas shows in several
early wells indicates that hydrocarbons have migrated
into the block. On the north side of the Platform,Kujung oil and gas shows encountered in the JS 2-1
and JS 3-1 wells proved hydrocarbon migration into
this area from the Central Deep. The southern margin
of the Platform has oil and gas shows in Kujung and
Ngimbang formations in the JS 19-1, JS 44A-1 JS 8-1
and Perawan-1 wells. This documents hydrocarbon
migrating from the southern kitchen area in the
Madura Basin. Recent study indicated that the previous wells were not located in optimum locations,
due in part to problems with velocity gradients and
seismic depth conversion. The best areas appeared
as yet untested.
Play concepts for this area are illustrated with a
regional northwest–southeast cross section fromCamar field to the Island of Madura, constructed from
both well and seismic data (Figure 11). Figure 11-A
shows generalized structure, stratigraphy, and source
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Presence of gas in and around the North
Madura Platform was previously recognized from gas
shows in dry holes and from abundant hydrocarbonindicators on seismic data. Velocity gradients,
however, masked the significance of the gas shows
and confounded attempts to determine whether the
wells were optimally located. Recent detailed velocity
studies and new well control help address those
questions, and indications of gas reservoirs in all four
recent wildcats in the Ketapang PSC indicate the
widespread occurrence of Kujung gas in this area.Acquisition of 3D seismic data and more drilling are
still needed to quantify the size of these discoveries
and indicate remaining exploration potential for the
North Madura Platform.
Oil potential for this area was recognized by
maturation modeling following analysis of source rock
type and quality, geothermal gradients, and regional
structure and stratigraphy. This study showedmigration pathways providing access from Central
Deep and Madura Basin kitchen areas to potential oil
reservoirs in the Ngimbang and Kujung. Timing for
old dip closures on the crest of the Madura Platform is
ideal to receive hydrocarbons starting with the onset
of hydrocarbon generation. Fault traps need careful
study, but most appear to have formed in time to
capture oil generated during much of the period of peak oil generation.
Several wells drilled in the vicinity of the North
challenge to exploration success in the North Madura
Platform area. Problems with depth conversion of
seismic maps result from two types of velocitygradients: abrupt lateral changes in velocity caused by
channels in the shallow Wonocolo carbonate section,
and much less severe velocity gradients associated
with lithologic or thickness changes in the underlying
section.
The Wonocolo channels cause the biggest problems.
Prominent north-south and northwest-southeast
channels show clearly on the Top Wonocolo time map(Figure 12). These features are about 2 km wide, and
they incise deeply (250 ms, approximately 750 ft) into
platform carbonates of the Wonocolo. The channel
fill is much slower in seismic velocity than the
surrounding carbonates, causing a significant sag in
seismic events beneath the channels (Figure 13). This
sag indents deeper horizons such as the inter-Tuban
marker (Figure 14) beneath the shallow channels.Similar effects occur at the prospective Ngrayong,
Kujung, and Ngimbang horizons, and these shallow
artifacts must be removed to properly image structural
closures.
To remove effects of the shallow channels, time maps
for reservoir horizons were corrected prior to depth
conversion. Horizons between the Wonocolo andKujung formations are quite uniform in thickness
throughout the North Madura Platform area, indicating
relatively uniform sedimentation without major
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seismic data. Average velocities generally increase
southward toward the shelf edge reef complex,
reflecting the change from interbedded limestone andshale in the platform area to massive carbonate in the
shelf edge reef tracts. Average velocity maps were
constructed and used for conversion of the seismic
time for the final depth maps.
CONCLUSIONS
1. The Central Deep and Madura Basin constituteeffective hydrocarbon kitchen areas for the North
Madura Platform. Hydrocarbon shows in wells
along the southern flank document oil and gas
charging from the Madura Basin. The JS 2-1,
which tested 4 mmscfd, indicates hydrocarbon
migration into the north Platform area from the
adjoining Central Deep. Gas tested in the Kujung
at Payang is closest to the Central Deep, butsourcing from either kitchen area remains
possible.
2. Long distance (25 km) migration along carrier
beds in the Ngimbang and/or Kujung charged the
central part of the North Madura Platform, as
indicated by oil and gas discoveries at Bukit Tua-1
and Jenggolo-1.
3. Reservoir thickness and quality remain poorly
defined for the North Madura Platform due to the
ACKNOWLEDGEMENTS
The authors wish to thank the Gulf Resources
Management, partner Petronas Carigali (Ketapang)
Ltd., and Pertamina for approval to publish this paper.
The contributions by the Gulf exploration staff,
particularly Chuck Caughey, Jim Parkin and the
drafting team are gratefully acknowledged. We also
recognize John N. Wilson and Christopher C. Gibson-
Robinson for recognizing the exploration potential ofthe North Madura Platform and leading early phases
of exploration.
REFERENCES CITED
Ardhana, Wayan, 1993. A Depositional Model for the
Early Middle Miocene Ngrayong Formation andImplications for Exploraton in the East Java Basin,
Proc. of the Indonesian Petroleum Assoc., 22nd
Annual Convention, v. 1, p. 395-443.
Bransden, P.J.E., and S.J. Matthews, 1992. Structural
and Stratigraphic Evolution of the East Java Sea,
Indonesia, Proc. of the Indonesian Petroleum Assoc.,
21st
Annual Convention, v. 1, p. 418-453.
Courteney, S., Cockcroft, P. Miller, R., Phoa, R.S.K.,
and A.W.R. Wight, ed., 1989. Oil & Gas Fields Atlas,
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Vol. 1 - 715
FIGURE 1 - Location of North Madura Platform and Ketapang PSC, offshore East Java, Indonesia. Wells in the vicinity of the
Ketapang PSC are shown.
F
i
g
TUBAN-1
JENU-1
JS 13-1
JS 10-1JS 6A-1
JS 31A-1 KE-1
Poleng Field
Camar Field
KE-17KE-2
KE-23KE-8KE-9
KE-7
JS 20-2
JS 19W-1
JS 20-3
AROSBAYA-1
JS 33A-1
KETAPANG-1
JS 14A-1
JS 13A-1
GUGUL
PAMOROH
KONANG-1
KONANG-2
LERPAK TANJUNG
KECODUR & W. KECODURDUKO
SUMBERLANTUNG
DURBUK
XX-1
MS-1-1
CAMPLONG-1
PAKAAN-1
RANCAK-1
GIGIR-1
PRANCAK
KERTENGENEH
MANDALABUJUR
CASSIOPEIA-1
PASIAN-1
MADURA
113°00'E 114°00E
7
°
0
0
'
6
°
3
0
'
S
112°30'E 113°30'E
0
KM
2510
JS 1-1
JS 1-2 / CAMAR-2
BUNKU-1
JS 1-3
KE-5
KE-12KE-6
Ujung Pangkah-1KE-2 Field
KE-5 Field
BD-1
BD-2
JS-18-1
KE-4
Payang-1
JS-2-1 JS-3-1
KETAPANG BLOCK
SERGANG-1
JS-19-1
JS-44-1
Bukit Tua-1
Bukit Panjang-1
JS-8-1 Perawan-1
Jenggolo-1
LamonganPEGAT-2
KUJUNG-1
EAST JAVA
KUTI
KE 11-AKRUKA
Gresik
NGIMBANG-1 BOGOMIRING
LIDAH
LINGSIR SEPAT-1 (LIS-1)
GRIGIS BARAT-1
GONDANG-1
NGASIN-1
SURABAYA
METATU
SEPAT
PETIKEN
SEKARKORONG
Tambak Boyo-1 Sidayu-1
22ST1
3
N O R T
H M A D
U R A P
L A T F
O R M
MW-1
MBD-1
CD-1
MS 2-1A
MS 2-1
KALIMANTAN
J A V A
SULAWESI
SINGAPORE
PHILIPPINES
BALI
P A C I F I C
O C E A NPHILIPPINES
INDONESIA
Jakar ta
1000 KMS.
0°
06°S
12°S
IRIAN JAYA
06°N
106°E 112°E 118°E 130°E 136°E
P
A
P
U
A
124°E
BRUNEI
SARAWAK
SABAH
SOUTH CHINA SEA
J A V A S E A
ARAFURA SEA
SULAWESI SEA
B A N D A S E A
I N D I A N O C E A N
E. JAVA BASIN
LOCATION
AREA
ANYER
WALUKU-1
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M
Y
AGE/SERIES
Stratigraphy of the
East Java Basin
L
a
t
e
L
A
T
A
T
L
A
E
A
M
I
M
I
E
a
r
A
I
D
D
0
1
5
10
15
20
30
Ledok
Madura Strait/Onshore East Java / Madura Offshore, East Java Sea
Platten Lst
carbonate platform and reefs
Rancak Lst.
Karren
clastics and volcaniclastics
V
MAIN
PHASES
KUJUNG CYCLE
TUBAN & NGRAYONG
CYCLES.
Renewed clastic deposition ;
widespread quartz sandoccurs across East Java
WONOCOLO CYCLES
Widespread deep marinemarl with minor sands.
BDTrend
KerekVolcaniclastics
K
A
L
I
B
E
Gulf Resources (Ketapang) Ltd
Figure 2
V
VV
V
V
Wonocolo Formation
Ngrayong Formation
Tuban Formation
Prupuh - Kujung Unit I
chalky lst.
Kujung Unit II
Ku jung Uni t I I I
Kujung Formation
l
LATE MIOCENE - RECENT
Beginning 7 MYBP,local tectonic events controlfacies development. From latestPliocene, modern volcanic arc
contributes huge quantities of feldspathic / lithic sand.
Initial regressive phasedeposits clastics, then a major trangressive and carbonaterich phase as regional
subsidence continues.
PLEISTOCENE
P
L
I
O
C
E
N
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Vol. 1 - 717FIGURE 3 - Location of Seismic Data and Well Control for the Ketapang PSC.
KETAPANG BLOCK
113 °12' 00" E 113 °24' 00" E 113 °36' 00" E 113 °48' 00" E
6
6
6
JS-2-1
KE- 4
JS-44A-1
JS-8-1PERAWAN-1
SERGANG-1
JS-3-1
JENGGOLO-1
JS-19-1
PAYANG-1
BUKIT TUA-1
BUKIT PANJANG-1
740000 760000 780000 800000
9
2
4
0
9
2
6
0
0
0
0
9
2
8
0
0
0
0
MADURA ISLAND
113 °00' 00" E
JS-14A-1
PASIAN-1
CASSIOPEIA-1JS-33A-1
KETAPANG-1Camar-3
Camar-4Camar-1
JS-1-1
KE-2A-6
JS-19W-1KE-2A-5
KE-2B-1
JS-20-3
KE-23
9
3
0
0
0
0
0
6
F
i
g
1999 VINTAGE
PRE 1999 VINTAGES
0 10
KM.
N
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Vol. 1 - 718
FIGURE 4 - Regional Tectonic Setting for the East Java Basin.
B D S O U T
H H - G R
A B E N
0 50
Kilometers
100
111°00 E 109°00 E
7
°
0
0
5
°
0
0
3
°
0
0
9
°
0
0
JAVA
KARIMUNJAWA ISL.
: HIGH AREA
: INTERMEDIATE AREA
: LOW AREA
: RECENT VOLCANIC ARC
LEGEND :
113°00 E 115°00 E 117°00 E 119°00 E
PASIRBASIN
B A R I T O
S H E L F
P A T E R N O S T E R
H I G H
S E B U K U
S H E L F
M E R A
T U S
B A R I T O
B A S I N
R I D G E
A S E M
- A S E M
B A S I N
LAUTISL.
KALIMANTAN SULAWESI
SOUTHMAKASSAR
BASIN
M A K A S S A R H A L F G
R A B E N
M U R I A
H T R O U G H
F L O
R E N C E T R O U G H
W E
S T
BAWEAN ISL.
E A S T
C E P U
H I G H
M A D U R A
B A S I N
C D H - G R
A B E N
B A S I N
W E S T
C E P
U H I
G H
D O A N G
T R
O U G H
S A L A Y
A R
B A S I N
H I G H
2 0 0 0
m
FLORESBASIN
S I B A R U
H I G H
P U L A U
L A U T
R I D G E
P A G E R U
N G A N
H A L F G
R A B E N
LOMBOK BASIN
J S - 5 T R O U G H
M A S A L I M A T R O U G H
M A S
A L I M
A
M D A H - G
R A B E N
B D R I D G E
PO RO NG H A LF
G R A B E N
NORTHERN PLATFORM
N O R T H M
A D U R
A H I G H
KETAPANGBLOCK
CARBONATE
PLATFORM
C E N T R A L B AS
I N
N G I M B A
N G
J S - 1 R I D G E
J S - 1 T R O
U G H
B A W E
A N A R C H
T U B A
N T R
O U G H
T R O U G H
F L O R E
N C E
E A S T
K A R I M
U N J A W A
A R C H
S U N D
A - L A N
D
SOUTHERN B ASIN
CENTRAL HIGH
SOUTH HIGH
F
i
A D A N G F A U L T Z O N E
C E N T R
A L D E E
P
MADURA
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Vol. 1 - 719
FIGURE 5 - Distribution of Ma or Litholo ies in re-Tertiar basement East Java Basin.
MBD-1
CD-1
MS2-1AMS2-1
Tuban
Bojonegoro
Lamongan
Mojokerto
Ngawi
Blora
AROSBAYA-1NGRAYONG
BANYUBANG
BANYUASINLEDOK
DANDANGILO
NGIMBANG-1
DERMAWU-1
MUDI-1
KLUWEH(gas)
WONOCOLO,KAWENGAN,NGUDAL, &KINDANGAN
METES
LUSIPETAK
KEDINDING
BALUN-TOBO
SEMANGGI NGLOBO
DANDER-1
BODJONEGORO-1
PEGAT-2
KUJUNG-1
KEMBANG BARU-1
KEMBANG BARU-2
WUNUT-1
KE11-G
PETIKEN
METATU
SEKARKORONG
BOGOMIRING
LIDAH
GUGUL
PAMOROH
KRUKA
KUTI
LINGSIRSEPAT-1(LIS-1)
KONANG-1KONANG-2
PORONG-1
GRIGIS BARAT-1
GONDANG-1
NGASIN-1
SEPAT
LERPAK TANJUNG
KECODUR & W. KECODUR
DUKO
SUMBERLANTUNG
DURBUK
KE 11-C
KE11-E
BD-1
XX-1
BD-2
MS-1-1
CAMPLONG-1
PAKAAN-1
RANCAK-1
GIGIR-1
KE11-A
PRANCAK
KERTENGENEH
MANDALABUJUR
0 5025
KM
JAVA
MADURA
KETAPANG BLOCK
SURABAYA
7
°
0
0
S
114°00E
Tuffaceous Ss.
Slate
RhyodacitesSlate
F
i
g
TUBAN-1
JENU-1
JS28-1
KUTILANG-1
JS13-1
JS10-1JS6A-1
KE-5JS-20/Poleng Field
KE-17UJUNG PANGKAH-1
KE-2
KE-23KE-8
KE-9
KE-7
JS20-2
JS19W-1
JS13A-1
PLATUNGAN
TAWUN GEGUNUNG
JATIROGO-1
BLIMBING-1
112°00E
6
°
0
0
S
Quartzite
Phyllite + Ss.
Px-Basalts
Metashale + Siltstone
Phyllite
Phyllite
JS 2-1
JS33A-1
KETAPANG-1
MONTOR-1
JS14A-1
CASSIOPEIA-1
PASIAN-1
MetaSiltstone
Gabbro
Diabase
Meta-tuff+lava
Meta-Sediments
JS31A-1
KE-6
KE-1
KE-12 JS20-3
KE-4
JS1-1
JS1-2/ CAMAR-2
113°00E
Basalt
Ande sit e
Basic Igneous
PAYANG-1
JS 8-1
JS 44A-1
PERAWAN-1
SERGANG-1MonzoniteVitr ic Tuff
Diorite
BUKIT PANJANG-1
JS 19A-1
BUKIT TUA-1JENGGOLO-1
JS 3-1
Meta-greywacke
: Acidic Igneous Rocks
: Intermediate Igneous Rocks
: Basic Igneous Rocks
LEGEND :
: Low Grade Metamorphic Rocks
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FIGURE 6 - Interpreted Paleogeography during deposition of the upper Ngimbang Formation
(Late Oligocene) in the East Java Basin.
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FIGURE 8 - Maturation Model for Hydrocarbon Source Rocks in the Central Deep of the East Java
Basin. The geothermal gradient is assumed to be 1.80 degrees F per 100 feet.
CENTRAL DEEP MATURATION MODEL
Age
D
ept
h
0
500
1000
1500
2000
2500 5
5
4
3
2
1
0
t = 0
Basement L. Ngimbang Type I/II U. Ngimbang Type II/III
Kujung
Kujung
Kujung
Tuban Ngrayong Wonocol Pliocene Pleistocene
Mature0.7 to
Peak Generation1 to 1.3
Main Gas1.3 to 2.6
GG. 1.8 F/100'
MADURA STRAITS MATURATION MODEL
GG. 1.51 F/100'
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FIGURE 10 - Interpreted Distribution of Hydrocarbon Kitchen Areas and Migration Pathways
for the North Madura Platform Area of the East Java Basin.
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Vol. 1 - 723FIGURE 12 - Top Wonocolo Time Structure Map. Note prominent north-south trending channels.
Seismic line segment located in west center area is shown in Figure 13.
0 10
KM.
N
MADURA ISLAND
4
8
0
5 6 0
720
6 4 0
5
6 0
4 0 0
8 0
1 6 0
480 5
6
0
5
6
0
6 4 0
1040
1 1 2 0
7 2 0
4 0 0
3 2 0
6 40
7
2
0
560
7 2 0
80 0
8
0
0
4 8 0
4 0 0
3 2 0
540
113° 12' E 113° 24' E 113° 36' E 113° 48' E
6
°
6
°
6
°
C.I. 20 ms
JENGGOLO-1 BUKIT TUA-1
PAYANG-1
BUKIT PANJANG-1
JS - 44A - 1
JS - 8A - 1 PERAWAN-1
JS - 19 - 1
JS - 2 - 1 JS - 3 - 1
SERGANG-1
KE - 4
KETAPANG BLOCK
9
2
8
0
9
2
6
0
9
2
4
0
740 000 760 000 780 000 800 000
S E I S M I
C L I N E
F
i
g
u
CHANNELS
CHANNELS
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FIGURE 13 - Seismic Line Segment from the west central part of the Ketapang PSC. Note prominent Wonocolo channel in the center of
the line at about 500 ms., causing sag in deeper horizons. Line segment is located on Figures 12, 14, and 15.
99GKT- 023
T i m e
2.5 KMSW NE
F
i
g
Top Wonocolo
Top Ngrayong
Intra- Tuban
Top Basement
Top Kujung III
Top Kujung II
Top Kujung I
Top Rancak
CHANNEL
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FIGURE 14 - Uncorrected Time Structure Map for Intra-Tuban Horizon. Note presence of sag caused by shallower
Wonocolo topography. Seismic line segment located in west center area is shown in Figure 13.
F
i
g
u
1 1 0 0
1 1 0 0
1 1 0 0
1 1 0 0 1
2 0 0
1 1 0 0
1 0 0 0
8 0 0
7 0 0
1 0 0 0
11 0 0
1 1 0 0
10 0 0
1
1
0
0
1 1 0 0
1
1
0
0
1 0 0 0
9 0 0
8 0 08
0 0
7 0 0
8 0 0
9 0 0
1 0 0 0
1 1 0 0
1 1 0 0
11 0 0
1 1 0 0
1000
9 0 0
9 0 0
1 2 0 0
1200
1 1 0 0
1 0 0 0
800
6 0 0
7005 0 0 6
0 0
7 0 0
7 0 0
6 0 0
6 0 0
5 0 0
7 0 0
1 1 0 0
1 3 0 0
1200
1 4 0 0
1600
1 1 0 0
1 8 0 0
1 8 0 0
1 6 0 0
1 4 0 0
1 2 0 0
1 2 0 0
1 3 0 0
1200
1 0 4 0
1
0 4
0
1
0
4
0
JENGGOLO-1 BUKIT TUA-1
PAYANG-1
BUKIT PANJANG-1
JS - 44A - 1
JS - 8A - 1 PERAWAN-1
SERGANG-1
KE - 4
JS - 19 - 1
JS - 2 - 1
JS - 3 - 1
9
2
8
0
9
2
6
0
9
2
4
0
740 000 760 000 780 000 800 000
0 10
KM.
N
C.I. 20 ms
113° 12' E 113° 24' E 113° 36' E 113° 48' E
6
°
6
°
6
°
KETAPANG BLOCK
S E I S
M I C L I N
E
7
0
0
AREA OF SAG
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FIGURE 15 - Corrected Time Structure Map for Intra-Tuban Horizon. Wonocolo topography is no longer
recognizable. Seismic line segment located in west center area is shown in Figure 13.
1000
1000
9 0 0
9 0 0
1 1 0 0
1 2
0 0
1 1 0 0
1 2
0 0
1 3 0 0
1 2 0 0
800
6 0 0
1 0 0 0
7 0 0 7
0
0
1 1 0 0
1 1 0 0
1 4 0 0
1 2 0 0
1 6 0 0
1 4 0 0
1 6 0 0
1 4 0 0
7 0 0
6 0 0
8 0 0
8 0 0
7 0 0
4 0 0
7 0 0 6 0 0
5 0 0
9 0 0 1 0 0 0
1 0 0 0
9 0 0
7
0
0
6 0 0
5 0 0
4 0 0
10 0 0
5 0 0
5 0 0
6 0 0
8 0 0
1 0 0 0
5 0 0
5 0 0
5 0 0
4 0 0
6 0 0
700
8 0 0
1 0 0 0
1
1
0
0
1 1 0 0
1 2 0 0 1 1 0 0
1 1 0 0 1
1
0
0
9 0 0
10 0 0
1 0 0 0
9 0 0
1 1 0 0 1 1 0 0
1 0 0 0
9 0 0
1 1 0 0
1 1 0 0
JENGGOLO-1 BUKIT TUA-1
PAYANG-1
BUKIT PANJANG-1
JS - 44A - 1
JS - 8A - 1 PERAWAN-1
SERGANG-1
KE - 4
JS - 19 - 1
JS - 2 - 1
JS - 3 - 1
9
2
8
0
9
2
6
0
9
2
4
0
740 000 760 000 780 000 800 000
0 10
KM.
N
C.I. 20 ms
113° 12' E 113° 24' E 113° 36' E 113° 48' E
6
°
6
°
6
°
KETAPANG BLOCK
MADURA ISLAND
S E I S M I
C L I N E
F
i
g
u
1 8 0 0