U. S. DEPARTMENT OF THE INTERIOR
U.S. GEOLOGICAL SURVEY
Petroleum Systems of the Northwest Java Province, Java and Offshore
Southeast Sumatra, Indonesia
by Michele G. Bishop
Open-File Report 99-50R
2000
JATIBARANG/TALANG AKAR-OLIGOCENE/MIOCENE
(382402) ARDJUNA ASSESSMENT UNIT (38240201)
Source Rock and Maturation
The major source rocks in the
Ardjuna assessment unit are deltaic carbonaceous shales and coals in the
upper Talang Akar Formation of late Oligocene age that were deposited in
a late synrift to post-rift tectonic setting (Noble and others, 1997; Gordon,
1985; Nugrahanto and Noble, 1997; Haposan and others, 1997; Gresko and
others, 1995; Ponto and others, 1988). This source rock is type II
and III and is oil- and gas-prone with TOC of 40—70 wt% in the coals and
0.5—9 wt% in the shales (Ponto and others, 1988), and HI of 200—400.
An estimate of expelled hydrocarbon from Talang Akar source rocks is 64
billion barrels (Ponto and others, 1988). Minor source rocks are
represented by lacustrine strata of the lower Talang Akar Formation (Noble
and others, 1997; Nugrahanto and Noble, 1997; Haposan and others, 1997)
and possibly from the Jatibarang Formation in the Jatibarang subbasin (Fig.
6) (Gresko and others, 1995; Noble and others, 1997). Hydrocarbon
generation may have begun as early as 25 Ma for lower units of the Talang
Akar and as late as 1 Ma for later units (Fig. 7) (Pertamina, 1996).
Several grabens with thick sections
of Talang Akar Formation are considered to contain mature source rocks
(Noble and others, 1997). These subbasins are combined into one petroleum
system comprised of coaly, oil-prone source rock, although differences
in the oils migrated from these source areas may allow separation into
several high-resolution petroleum systems (Noble and others, 1997).
The westernmost area of mature source rock is Ciputat where the Talang
Akar Formation is thin and mostly marine influenced (Fig. 3) (Noble and
others, 1997). Oils in fields to the west and north have been traced
to this source rock (Noble and others, 1997). The Kepuh and Pasir
Bungur areas of mature source rock contain thick coals of the Talang Akar
Formation (Fig. 8) (Noble and others, 1997). Hydrocarbons migrating
from these mature areas charge clastic reservoirs of the Talang Akar Formation
and carbonate reservoirs of the Mid-Main in both onshore and offshore fields
to the north (Fig. 3 and Fig. 4) (Noble and others, 1997). Migration
of oil from the Cipunegara area of mature Talang Akar source rocks is also
primarily to the north to both onshore and offshore fields (Fig. 3) (Noble
and others, 1997).
The areas of mature
source rock that are located offshore include the South and Central Ardjuna
subbasins (Fig. 3 and Fig. 8). Seismic data across the Central subbasin
indicate fault throws of greater than 3,000 ft (912 m) at depth and 200
ft (60 m) in shallow horizons (Carter and Hutabarat, 1994). More
than 100 ft (30 m) of coal source rock occurs in the South subbasin and
sources Main and Massive clastic reservoirs and some Talang Akar clastic
reservoirs in surrounding fields (Noble and others, 1997). Hydrocarbons
generated in the Central subbasin migrate to fields to the south and may
have charged as yet undiscovered accumulations to the north (Noble and
others, 1997).
Overburden
Transgression during the early
Miocene continued as subsidence in the individual and connected basins
decreased. Carbonates of the Batu Raja Formation were developed over
the Talang Akar source rocks on a shallow carbonate platform and reefs
developed on paleohighs (Fig. 4). Mixed clastic and carbonate deposits
overlie the Upper Cibulakan Group (Haposan and others, 1997). Biostromal
and biohermal limestones of the Parigi Formation were developed across
the entire province, followed by deposition of claystone with sandstone,
conglomerate, and limestone of the Cisubuh Formation (Haposan and others,
1997). The late Miocene to Plio-Pleistocene Cisubuh Formation coarsens
and shallows up representing regression to the south with sediment input
from the east and west (Pertamina, 1996).
Traps
Anticlines are the most
numerous traps that have been drilled to date in the Ardjuna assessment
unit, making up almost 65% of the fields and containing almost 50% of the
oil equivalent reserves (Petroconsultants, 1996). The productive
reservoirs in most of these anticlines are sandstones of the Cibulakan
Formation although some carbonate reservoirs are involved (Petroconsultants,
1996). Fault blocks and other structural traps account for almost
40% of the equivalent reserves in the unit (Petroconsultants, 1996).
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