xxiii. indonesia
TRANSCRIPT
XXIII. Indon
June, 2013
XXIII.
SUMMA
In
formation
deposits,
deposited
nearby c
lacustrine
Source: AR
esia
. IND
ARY
ndonesia ha
ns, as well a
, Figure XXI
d shales w
conventional
e source roc
I, 2013
DONESI
as shale ga
as more exte
III-1. The b
ithin the Ce
oil and gas
ck shales wit
Fig
XX
IA
as and sha
ensive shale
est overall p
entral and S
fields. Kal
th oil and ga
gure XXIII-1. S
EIA/ARI W
XIII-1
ale oil pote
e resources
potential app
South Suma
imantan’s K
as potential.
Shale Basins o
World Shale Ga
ential within
within non-m
pears to be
atra basins,
Kutei and Ta
of Indonesia
s and Shale Oil
selected m
marine and o
mostly oil-p
, which sou
rakan basin
Resource Asses
marine-depo
often coaly s
prone, lacus
urced the p
s also have
ssment
osited
shale
strine-
rolific
thick
XXIII. Indon
June, 2013
In
recovera
shale ga
NuEnerg
PSC’s ha
RReservoir
Ph
ilE
tt
BiD
t
esia
ndonesia ha
ble shale ga
s and shale
gy) have rep
ave been aw
Table X
Table
ONIA
Resource Gas Phase
GIP ConcentratiRisked GIP (Tcf)Risked Recovera
Properties Reservoir Press
Average TOC (wThermal MaturitClay Content
Physical Exten
t Prospective Are
Thickness (ft)
Depth (ft)
Basic Data Basin/Gr
Shale FoGeolog
Depositional
Reservoir
Properties Reservo
AverageThermaClay Co
Physical Exten
t Prospec
Thickne
Depth (f
Basic Data
Depo
Resource
Oil Pha
OIP Con
Risked
Risked
as an estim
as and shal
e oil in-place
ported early
warded nor h
XXIII-1. Shale
XXIII-2. Shale
C
(3
BrPL
Organically RichNet Interval 6,5Average
A
on (Bcf/mi2))able (Tcf)
sure
wt. %)ty (% Ro)
ea (mi2)
ross Area
ormationgic Age Environment
Organically RNet IntervalAverage
oir Pressure
e TOC (wt. %)al Maturity (% Ro)ontent
ctive Area (mi2)
ess (ft)
ft)
Basin/Gross Area
Shale FormationGeologic Age
ositional Environmen
ase
ncentration (MMbbl/m
OIP (B bbl)
Recoverable (B bbl)
XX
mated 46 T
e oil resour
e, Tables XX
y-stage eval
has shale-rel
e Gas Reservo
e Oil Reservo
C. Sumatra
36,860 mi2)
S. S
(45,1
rown Shale TalanPaleogene Eocene-Lacustrine Lac
4,700 15
295 9266 3
560 - 10,496 3,3008,530 7
Normal No
6.0% 50.80% 0.
Medium H
Assoc. Gas Asso
19.6 241.5 63.3
C. Sumatra
(36,860 mi2)
Brown ShalePaleogeneLacustrine
4,700
Rich 295266
6,560 - 10,4968,530
Normal
6.0%0.80%
Medium
Oil
32.8
69.4
2.77
nt
mi2)
EIA/ARI W
XIII-2
Tcf and 7.9
ces out of 3
XIII-1 and XX
uations of s
lated drilling
oir Properties
ir Properties a
umatra
70 mi2)
Kute
(35,840 m
ng Akar Balikpa-Oligocene Mid.-U. Mioustrine Lacustr
5,490 1,630
918 900367 4500 - 8,000 3,300 - 15,000 9,000
ormalHighly
Overpre5.0% 4.0%70% 0.70%
High High
oc. Gas Assoc. G
25.0 62.167.8 16.24.1 1.3
S. Sumatra
(45,170 mi2)
e Talang AkarEocene-Oligocen
Lacustrine
15,490
918367
6 3,300 - 8,0007,000
Normal
5.0%0.70%High
Oil
50.2
136.2
4.09
World Shale Ga
9 billion ba
303 Tcf and
XIII-2. Seve
shale gas p
activity bee
and Resource
and Resource
i
mi2)
pan Naintupoocene L. Mioceneine Lacustrine
0 1,010
750375
5,000 6,600 - 16,000 30 11,500y
ess.Normal
% 5.0%% 1.50%h High
Gas Dry Gas
170.734.55.2
Kutei
(35,840 mi2)
Balikpapanne Mid.-U. Miocene
Lacustrine
1,630
900450
3,300 - 15,0009,000
Highly Overpress
4.0%0.70%High
Oil
64.7
16.9
0.68
s and Shale Oil
arrels of ris
234 billion
eral compan
potential in
en reported.
es of Indones
es of Indonesia
Meliat TabuMid. Miocene U. Mioc
Lacustrine Lacustr
880 510
1,000 1,500400 600
3,300 - 13,120 3,300 - 610,000 5,000
Normal Norm
3.0% 3.0%1.15% 0.70%High High
Wet Gas Assoc.
142.3 37.325.1 3.83.8 0.2
Tarakan
(7,510 mi2)
MeliatMid. Miocene U
Lacustrine L
880
1,000400
3,300 - 13,120 3,10,000
. Normal
3.0%1.15%High
Condensate
7.1
1.3
0.04
Tarakan
(7,510 mi
Resource Asses
sked, techn
barrels of r
nies (AWE, B
Sumatra, bu
ia.
a.
Bintuni
(15,200 mi2)
ul Aifam Groupcene Permianrine Marine
0 3,340
0 1,0000 5006,600 5,000 - 15,0000 9,500
mal Normal
% 1.5%% 1.50%h Low
Gas Dry Gas
3 213.8114.328.6
TabulU. MioceneLacustrine
510
1,500600
300 - 6,6005,000
Normal
3.0%0.70%High
Oil
103.7
10.6
0.32
n
i2)
ssment
nically
risked
Bukit,
ut no
XXIII. Indon
June, 2013
In
the non-
but is st
tectonica
INTROD
In
of coal, o
oil produ
since 20
billion ba
major ex
during 2
rising fas
import te
In
investme
industry.
and wor
highest c
investme
these sig
D
foreign c
oil comp
ownersh
partly sta
including
include C
Indonesia
esia
n general, w
marine shal
ructurally m
ally more com
DUCTION
ndonesia is t
oil, and natu
uction and in
04. In 2011
arrels of pro
xporter of L
011 while e
ster than its
rminals are
ndonesia’s M
ent policy an
A separate
k programs
court unexp
ent. Indones
gnificant cha
Domestic an
companies o
pany, plans
ip. PGN (Pe
ate- and pu
g pursuing u
Chevron, To
an and forei
western Indo
e types, wh
more comple
mplex but ha
the world’s f
ral gas. For
ncreasing do
1 Indonesia
oved reserve
LNG and pip
exporting 3.7
output. Ga
being const
Ministry of E
nd awards e
e organizatio
. However
pectedly diss
sia’s 2001 O
nges and cle
d foreign c
perating the
to eventua
erusahaan G
ublicly owne
unconvention
otal, Conoco
gn operators
XX
onesia has c
hereas easte
ex. Eastern
as excellent
fourth most p
rmerly an oil
omestic con
produced a
es, while co
peline-conve
7 Bcfd.1 H
as prices ha
ructed in Jav
Energy and
exploration a
on BPMIGA
r, a recent
solved BPM
Oil and Gas L
ear up the c
companies a
e bulk of prod
ally transitio
Gas Negara
ed, is gradu
nal gas dev
oPhillips, Ex
s.
EIA/ARI W
XIII-3
comparative
ern Indones
Indonesia
marine-depo
populous co
l exporter an
sumption ha
an average
onsuming 3.
eyed natura
owever, Ind
ave risen sig
va, Indonesi
Mineral Res
and producti
AS administe
(November
MIGAS, direc
Law is expe
urrent regula
are active in
duction. Pe
on into a l
a), the domin
ually moving
velopment.
xxonMobil,
World Shale Ga
ely simple st
sia has abun
(Sulawesi,
osited shale
ountry (250 m
nd OPEC m
ave made th
2.5 million b
1 million bb
al gas, prod
donesia’s do
gnificantly in
ia’s most de
sources (MI
on licenses
ers the imple
2012) judic
cting MIGAS
ected to be r
atory uncert
n Indonesia
ertamina, Ind
isted compa
nant natural
g into the u
Foreign com
and BP, as
s and Shale Oil
tructure but
ndant marin
Seram, Bur
e source rock
million) and a
ember, Indo
he country a
bbl/day of c
bl/day. Indo
ducing an a
omestic gas
recent yea
ensely popula
IGAS) admi
in the coun
ementation o
cial decision
S to implem
revised durin
tainty.
a’s oil and
donesia’s wh
any with s
gas pipeline
upstream b
mpanies act
s well as nu
Resource Asses
is dominate
e shale dep
ru, Irian Jay
ks.
a major prod
onesia’s dec
a net oil imp
rude oil from
onesia rema
verage 7.4
s consumpti
rs and new
ated island.
nisters upst
ntry’s oil and
of these lice
n by Indone
ment oil and
ng 2013 to c
gas sector,
holly state-ow
ignificant pr
e operator th
usiness as
tive in Indo
umerous sm
ssment
ed by
posits
ya) is
ducer
clining
porter
m 4.0
ains a
Bcfd
on is
LNG
tream
d gas
enses
esia’s
d gas
clarify
with
wned
rivate
hat is
well,
nesia
maller
XXIII. Indon
June, 2013
A
onshore
and Sout
smaller,
basins in
and/or ex
T
Eocene t
depositio
deltaic en
are non-
the upst
resource
been rep
Figu
ERA PER
QUATE
CARBONDEVOSILU
PALE
OZO
IC PER
JURA
TRIA
MES
OZO
IC
CRETA
CEN
OZO
IC
TERT
esia
ARI’s review
sedimentary
th Sumatra b
structurally
n Indonesia a
xcessive stru
The petroleu
to Pliocene,
onal setting r
nvironments
marine coal
tream oil an
es at 574 Tc
ported.
re XXIII-2. Stra
RIOD EPOCH
ERNARY Pleistocene
Pliocene
Upper
Upper
Middle
MiddleLower
Upper
Lower
NIFEROUSONIAN
URIAN
Peutu/Ar
Oligocene
MIAN
Lower
ASSIC
Lower
ASSIC
Paleocene
ACEOUS
Upper
Eocene
Miocene
TIARY
BASIN NO
w of publishe
y basins whi
basins on S
complex ba
appear to be
uctural comp
m source ro
with older P
ranges from
s in central a
y deposits t
nd gas reg
cf. Howeve
atigraphy of S
CENT
run/BelumaiBa
Bampo
Jeuku
Julu Rayou
Serula
Keutapang
Baong
Bruksah Pem
SUMARTH SUMATRA
XX
ed geologic
ich may hav
umatra Islan
asins in eas
e less prosp
plexity.
ocks in onsh
Permian sou
deepwater
and western
that may not
gulator in In
er, neither th
Source Rocks
RAL SUMATRA SOUTH SU
Minas Kasa
Batu R
Source R
F
angko BekasanGuma
Manggala Talang
Petani
Muara E
Telisa/Duri
Air Ben
matang KelesaLemata
Laha
ATRA
EIA/ARI W
XIII-4
literature in
ve shale gas
nd; the Kutei
stern Indone
pective due t
hore Indones
urce rocks p
marine in ea
Indonesia.
t be brittle e
ndonesia, h
he methodo
and Conventi
UMATRA
al
Raja
Rock
O R M A
Conventional Reservoi
ai
Akar
Enim
akat
Pamaluan
ang
at
Atan
Bebulu
BOH
Balikpapan
Klinjau
Kampung Baru
EAST KAKUTEI
World Shale Ga
dicates that
s/oil potentia
i and Taraka
esia (Salawa
to low TOC,
sian basins
resent in the
astern Indon
Many of Ind
enough for s
as estimate
logy nor the
ional Petroleu
Tabul
T I O N
ir Absent/Unknown
Bas
Bangg
TomoSujan
Sembakung
MeliatM
NaintopoMesaloi M
DomaringPoh
Seilor
TarakanK
LIMANTANTARAKAN TO
s and Shale Oil
t Indonesia
al. These inc
an basins in
ati, Bintuni,
high clay an
are relative
e east, Figu
nesia to mos
donesia’s or
shale develo
ed the coun
e basis of t
um Reservoirs
BULA
Sawai
Kola Sh
KanikehSaku
sal clastic
Tehoru/Taunusa
Manusela/Saman Saman
Lst
gai Granites
Nief
ori
Minahaki
Matindok
/Mantawa
Salas
BiakWahai/Fufa
Kintom
EAST INDOMORI
Resource Asses
has a numb
clude the Ce
Kalimantan
Tomori). O
nd CO2 cont
ely young, m
re XXIII-2.
tly lacustrine
rganic-rich s
opment. MI
ntry’s shale
his estimate
s in Indonesia
AinAiAim
Sirga
Tipuma
Aifam
Aifa
mG
roup
Kemum
Jass
Kembelang
(Roabiba-
Aalenian S
Kembelang
Tipuma
FaumaiFaumai
Klamogun New Guinea
Waripi Waripi
Klasafet
Kais Kais
Klasaman
Klasafet
SeleSteenkool
DONESIASALAWATI BINTUNI
ssment
ber of
entral
n; and
Other
tents,
mostly
Their
e and
hales
GAS,
e gas
e has
.
nimfat
mau
gan
-
Ss)
Lst
t
I
XXIII. Indon
June, 2013
1 N
1.1 In
S
Central,
conventio
this basi
Central S
thermal E
Basin pr
coalbed
largely b
deposited
Fi
Source: AR
esia
NORTH, CE
ntroduction
Sumatra has
and South S
onal gas bot
n and the A
Sumatra Ba
EOR field, a
oduces both
methane de
arren of coa
d and poorly
igure XXIII-3.
I, 2013
ENTRAL, A
n and Geo
s shale oil a
Sumatra bas
th onshore a
Arun LNG e
asin produce
and is a majo
h oil and inc
eposits also
al. All three
y lithified sed
Prospective S
XX
AND SOUTH
logic Setti
and gas po
sins, Figure
and offshore
export facility
es mainly o
or consume
creasing vol
occur in So
basins are
dimentary ro
Shale Areas in
EIA/ARI W
XIII-5
H SUMATR
ng
tential in th
XXIII-3. Th
e. However
y is being c
il onshore,
r of natural
lumes of ga
outh and Ce
back-arc tec
ocks. Heat fl
n the Central a
World Shale Ga
RA BASINS
hree deep b
e North Sum
r, gas produc
converted to
notably 300
gas for stea
as from ons
entral Suma
ctonic settin
low and CO2
and South Sum
s and Shale Oil
S
basin compl
matra Basin
ction has de
o handle LN
0,000 bbl/da
am fuel. The
hore fields.
atra, while N
ngs containin
2 content oft
matra Basins,
Resource Asses
exes: the N
produces m
eclined shar
NG imports.
ay from the
e South Sum
Major coa
North Suma
ng young, ra
ten are eleva
Indonesia.
ssment
North,
mainly
ply in
The
Duri
matra
l and
tra is
apidly
ated.
XXIII. Indon
June, 2013
N
during th
deep ma
water de
Lower B
Bampo b
source ro
and is the
T
low, seld
contamin
the Peutu
low in TO
young ag
and we d
C
Sumatra
north and
as a resu
The basi
by uplifte
marine s
transgres
Paleogen
Petani G
T
importan
60 billion
Menggal
consistin
1,500 mD
esia
North Suma
he Early Olig
arine claysto
eltaic facies
aong shale
black shale,
ock.2 The B
e main sour
Thermal mat
dom exceed
nation are fa
u carbonate
OC and pos
ge. There ha
do not consid
Central Sum
Basin is a
d south. It d
ult of the Ind
n comprises
ed horst blo
ediments. S
ssive/regres
ne Pematan
roup are the
The Brown
t oil-generat
n barrels an
a sandstone
g of well-so
D of permea
atra Basin.
gocene, bec
nes, shales
formed in t
and the Ea
which form
Bampo conta
ce rock for g
urity of the
ing 1% (Typ
irly common
reservoir co
sibly ductile
ave been no
der it to be p
matra Basin
trans-tensio
developed d
dian Ocean
s a series of
ocks. The t
Sedimentatio
sive marine
ng Group, L
e main Tertia
Shale Form
ting formatio
nd sourced
es are the
orted quartzo
ability.
XX
A series of
came filled w
and shallow
he southeas
arly Miocene
med in localiz
ains thick, de
gas fields in
Baong, Bel
pe III) while
n: output from
ontains 82%
due to thei
o reports of s
prospective f
n. Sumatra’
onal pull-apa
uring the La
plate subdu
f north-south
troughs bec
on began wit
e cycle that
ower Mioce
ary units.
mation withi
on in the So
the giant D
main conve
ose to suba
EIA/ARI W
XIII-6
f north–sout
with predom
w water limes
st. The main
e Belumai c
zed thick an
eep marine
the northern
umai, and B
clay is abu
m the Arun g
% CO2. Over
r shallow de
shale explor
for shale gas
’s most imp
art basin bo
ate Cretaceo
ucting at an
h trending fa
came filled w
th deposition
started in L
ene Sihapas
n the Pem
outh Sumatra
Duri and Mi
entional pet
rkosic sands
World Shale Ga
th trending
minantly mari
stones on st
n source ro
calcareous
nd euxinic d
claystones,
n part of the
Bampo shal
undant (mos
gas field ave
rall, these so
epth, rapid b
ration activity
s/oil develop
portant oil-pr
ounded by m
ous to Early
oblique ang
ault-bounded
with non-ma
n of contine
Late Oligoce
s Group, an
matang Grou
a Basin, hav
nas oil field
troleum res
stones with
s and Shale Oil
ridges and
ine deposits
tructural hig
cks are the
shale. The
deposits, is a
mudstones
North Suma
les is gas-p
stly smectite
erages abou
ource rocks
burial, high c
y in the Nort
pment.
roducing reg
major strike-
Tertiary in a
gle beneath
d troughs th
arine clastic
ntal sedime
ene or Early
d Middle M
up is consi
ving genera
ds.3,4 The
ervoirs in C
average >2
Resource Asses
grabens, fo
s. These inc
hs, while sh
Middle Mio
e Late Oligo
another pote
and dark s
atra Basin.
rone but TO
e). CO2 and
t 20% CO2,
appear to b
clay content
th Sumatra B
gion, the Ce
-slip faults t
a back-arc se
Southeast
hat are sepa
c, lacustrine
nts followed
y Miocene.
iocene/ Plio
idered the
ted an estim
overlying m
Central Sum
20% porosity
ssment
ormed
clude
hallow
ocene
ocene
ential
hales
OC is
d H2S
while
be too
t, and
Basin
entral
o the
etting
Asia.
arated
, and
d by a
The
ocene
most
mated
marine
matra,
y and
XXIII. Indon
June, 2013
T
system w
to local f
during s
organic m
10,500 ft
basin is a
25.3 mg
T
facies co
15% TOC
brown la
contains
T
rich, but
Pliocene
grey clay
biogenic
sequence
environm
gas/oil de
S
area as
early Ol
Thermal
incursion
standing
of organ
rocks. No
XXIII-4.
of being
esia
The Brown S
with anoxic b
facies chang
ource rock
matter. The
t deep in the
approximate
HC/g rock p
Two organic-
onsist of dar
C that consis
minated car
average 3.4
The Keruh, K
these are re
Binio Form
ystones and
gas. The B
e of claysto
ment.7 The B
evelopment.
South Suma
well as a fo
igocene de
subsidence
ns to depos
blocks. Co
ic-rich deep
ortheast-dire
An estimate
triggered du
Shale is a lac
bottom cond
ges which re
deposition
organic-rich
e troughs (a
ely 3.7%, rea
petroleum ge
-rich facies o
rk brown to
sts of Types
bonate and
4% TOC, de
Kiliran, Sang
elatively imm
mation, part
d minor san
Binio Fm is
ones, siltsto
Binio and Ko
.
atra Basin.
ocus of coal
eposits of c
followed rift
sit fine-grain
ontinued sub
-water shale
ected compr
ed 50-90% o
uring large-sc
XX
custrine-form
ditions. Varia
eflect the dis
that resulte
h portion of t
average dept
aching 7.3%
eneration ca
occur within
black, well
s I and II ker
terrigenous
rived from a
gkarewang,
mature therm
of the Petan
ndstones tha
overlain by
ones, sands
orinci format
This basin
lbed methan
clastic sedi
ting in the la
ned marine
bsidence dro
es and marl
ression and
of the faults i
cale hydraul
EIA/ARI W
XIII-7
med unit, de
ation in oil c
stribution of
ed in varyin
the Brown S
th 8,500 ft).
at the well-
pacity.5
n the Brown
laminated,
rogen. The s
mudstones
lgae that res
Lakat, and
mally and m
ni Group, co
at are charg
y the Late P
stones, and
tions are no
is a signific
ne exploratio
ments in t
ate Oligocen
sequences
owned the ca
s that later
tectonic inve
in the basin
lic fracturing
World Shale Ga
eposited in a
composition
productivity
g proportion
Shale is abo
Mean TOC
-exposed Ka
Shale Form
non-calcare
shallow lacu
with occasio
sulted in oil-
Kelesa Form
may not be b
ontains a se
ged with low
Pliocene Kor
minor coa
ot considered
cant conven
on. The ba
transpressio
ne to the ear
in lows an
arbonate sy
became ga
ersion began
are potentia
g.8
s and Shale Oil
a freshwater
within the b
and paleoc
ns of algal
ut 295 ft thic
C for this un
arbindo coal
mation. The
eous shales
ustrine facies
onal coal str
-prone Type
mations also
brittle. The
equence of
w-CO2 and
rinci Format
al deposited
d to be pros
ntional oil an
asin contains
onal pull-ap
rly Miocene,
nd reefal bu
ystem and ca
s-prone hyd
n in the mid
ally active an
Resource Asses
r to brackish
basin is attrib
climate cond
and terrige
ck and is 66
nit throughou
mine, with m
e deep lacus
, containing
s consists o
ringers. This
I kerogen.6
o can be org
U. Miocene
medium- to
isotopically
ion, a regre
d under a f
spective for s
nd gas prod
s late Eoce
art depress
enabling m
uildups on
aused depo
drocarbon so
-Miocene, F
nd may be a
ssment
h lake
buted
itions
enous
600 to
ut the
mean
strine
g 1 to
f red-
s unit
ganic
to L.
o light
y light
essive
fluvial
shale
ucing
ne to
sions.
marine
high-
sition
ource
Figure
at risk
XXIII. Indon
June, 2013
Fi
Source: Hen
P
and brac
Akar For
to early O
B
Talang A
1,300 ft t
(Ro 0.5%
averagin
esia
igure XXIII-4.
nnings et al., 20
Petroleum so
ckish-water s
rmation.9 Th
Oligocene in
Because of l
Akar Format
thick. TOC
%) down to a
g about 0.7%
Regional and
12
ource rock s
sediments in
hese units re
age, the La
limited data
ion is up to
ranges from
about 6,000
% Ro at 7,00
XX
Detailed Cros
shales in the
n the Lahat F
each a gross
ahat can be o
, the Lahat
over 1 km t
m 1.7% to 8
0 ft depth, in
00 ft.
EIA/ARI W
XIII-8
ss Sections of
e South Su
Formation a
s thickness o
oil- or gas-p
Formation
thick in the
.5%, locally
ncreasing to
World Shale Ga
f the South Su
matra Basin
and coals an
of approxima
rone depend
was not qu
South Palem
reaching 16
o about 0.9%
s and Shale Oil
umatra Basin,
n include al
nd coaly sha
ately 1 km.
ding on loca
uantitatively
mbang sub-
6%. Therma
% Ro at a d
Resource Asses
, Indonesia.
luvial, lacus
ales in the Ta
Mid-late Eo
ation.
assessed.
-basin, avera
al maturity i
depth of 8,0
ssment
strine,
alang
ocene
The
aging
s low
00 ft,
XXIII. Indon
June, 2013
T
coal and
an overa
coal, and
within tro
brittle no
developm
1.2 R
T
basins is
the shale
exploratio
that abou
North Su
C
the Cent
Within th
of 8,530
gradient
S
within a
average
considere
1.3 R
C
Shale are
and 69 b
shale oil
Indonesia
present i
esia
The Miocene
coalbed me
all regressive
d coaly shal
oughs up to
on-marine d
ment.
Reservoir P
The general
s well constra
e formations
on in these
ut 5% of the
umatra Basin
Central Sum
tral Sumatra
his prospecti
ft. Average
is normal an
South Suma
large 15,49
5% TOC a
ed high.
Resource A
Central Sum
e estimated
billion barrels
resource in
a, particula
n what is the
e Muara En
ethane resou
e cycle, resu
e.10 Therma
4,000 ft de
deposit, too
Properties
location of t
ained by pub
s.11 Howev
basins prov
total basin a
n is not cons
matra. The h
a Basin is es
ve area the
e TOC is est
nd the clay c
atra Basin.
90-mi2 area
and 0.7% R
Assessmen
matra Basin
at 3.3 Tcf o
s of shale g
n the Centra
rly given th
e country’s m
XX
im Formatio
urces that w
ulting in a th
al maturity i
ep. Overall
shallow an
(Prospecti
he prospect
blic data but
ver, proprieta
ided improv
area could b
sidered prosp
high-graded
stimated at 4
Brown Shal
timated at 6.
content is co
The Eocene
and estima
Ro. The pre
nt
n. Risked,
of associated
as and shal
al Sumatra B
he extensive
most importa
EIA/ARI W
XIII-9
on of the So
were deposite
hick sequenc
s quite low,
, the Muara
nd thermally
ive Area)
tive deep tro
t, unfortunat
ary maps d
ed control o
be depth- an
pective.
prospective
4,700-mi2 ba
le averages
.0% and is i
onsidered me
e to Oligocen
ated to have
essure grad
technically
d gas and 2.
e oil in-plac
Basin to be
e drilling an
ant oil-produ
World Shale Ga
outh Sumat
ed in a coas
ce of mainly
reaching o
a Enim Fm i
y immature
oughs in the
tely, not the
developed b
on depth and
nd thermal-p
e area for th
ased on the
266 ft thick
n the oil win
edium.
ne Talang A
e a 367-ft t
dient is norm
recoverable
8 billion bar
ce (all figures
the most p
nd transport
ucing region.
s and Shale Oil
tra Basin co
stal plain en
y clastic san
only about 0
s a coaly an
e to be fav
e Central and
detailed dep
by ARI for c
d thermal m
prospective f
he Brown Sh
e extent of th
k (net) with a
ndow (Ro of
Akar Formati
thick high-g
mal and the
e resources
rrels of shale
s risked). A
rospective s
rtation infras
.
Resource Asses
ontains impo
vironment d
dstone, silts
.4% to 0.45
nd probably
orable for s
d South Sum
pth distributi
coalbed met
aturity, indic
for shale oil.
hale Formati
he deep trou
an average d
0.8%). Pres
on is prospe
raded zone
e clay conte
from the B
e oil out of 4
ARI consider
shale potent
structure alr
ssment
ortant
during
stone,
% Ro
non-
shale
matra
ion of
thane
cating
The
ion in
ughs.
depth
ssure
ective
e with
ent is
Brown
42 Tcf
rs the
tial in
ready
XXIII. Indon
June, 2013
S
billion ba
136 billio
estimated
on the Ta
1.4 S
F
initiated
studies,
evaluatin
(NZOG).
studies e
Figure X
Source: Mod
esia
South Suma
arrels of tec
on barrels of
d Brown Sha
alang Akar.
Shale Leas
our shale g
by MIGAS i
the main s
ng these bloc12 Although
eventually co
XXIII-5. Locati
dified from AWE
atra Basin.
hnically reco
f shale gas
ale oil resou
ing and Ex
gas joint stu
n March 20
ource rocks
cks, includin
Indonesia d
ould lead to
ion of Several
E Limited, April 2
XXI
The Talang
overable sh
and oil in-p
urce in Centr
xploration A
udies totalin
12, Figure X
s here actu
ng Bukit Ene
does not yet
Indonesia’s
l Approved Sh
2012
EIA/ARI W
II-10
g Akar Form
ale gas and
lace (all figu
ral Sumatra,
Activity
ng 5,000 km
XXIII-5. (No
ally are in
ergy Inc., AW
t have forma
first shale ga
hale Gas Joint
World Shale Ga
mation has a
d shale oil re
ures are risk
, there is mu
m2 in the C
ote that altho
the oil wind
WE Limited,
al shale licen
as PSCs.
t-Study Areas
s and Shale Oil
an estimated
esources, o
ked). While
uch less pub
Central Sum
ough classif
dow.) Four
and New Ze
nsing regula
in The Centra
Resource Asses
d 4.1 Tcf an
out of 68 Tc
e larger tha
blic data ava
matra Basin
fied as shale
r companies
ealand Oil &
ations, these
al Sumatra Ba
ssment
d 4.1
f and
n the
ilable
were
e gas
s are
& Gas
e joint
asin.
XXIII. Indon
June, 2013
C
participat
basins.
and antic
E
about the
based N
(Bohorok
shale ga
anywhere
2 K
2.1 In
T
portion c
the seco
Indonesia
market w
Bontang
productio
T
contains
shales of
platforms
deposited
main sou
fluvial-de
conventio
esia
Calgary-base
tes in seve
Bukit also h
cipates an aw
Earlier this ye
eir study du
NZOG holds
k) Sumatra b
as opportuni
e in Indones
KUTEI AND
ntroduction
The Kutei (o
entered arou
nd largest o
a’s largest g
within this l
has been
on in East Ka
The 7,510-m
a similar se
f Late Eocen
s. Finally M
d. The enti
urce rocks a
eltaic sandst
onal reservo
ed Bukit is
eral convent
has applied
ward during
ear Australia
ring Q3 201
s convention
basins, partn
ties nearby
sia.
D TARAKAN
n and Geo
r Kutai) is I
und the Mah
oil and gas p
gas producer
ightly popul
operating
alimantan.
mi2 Tarakan
edimentary s
ne age are o
Mid-Miocene
ire sequenc
are Mid-Late
tones of the
oirs.
XXI
a small pri
tional petrol
for unconve
2013.
a-based AW
12, but to da
nal petroleu
nering with B
. No shale
N BASINS
logic Setti
Indonesia’s
hakam Delta
producing re
r. The Bont
lated region
at about 1
Basin, loca
sequence as
overlain by O
to Quaterna
ce has been
Miocene co
e Tabul and
EIA/ARI W
II-11
vate oil and
leum licens
entional sha
WE announce
ate no decis
um PSC’s i
Bukit in eac
e-related dril
ng
largest sed
a in eastern
egion in Indo
ang LNG ex
n, with a ca
6 million t/
ated north u
s the Kutei
Oligocene to
ary fluvio-de
gently defo
oals and coa
Plio-Pleisto
World Shale Ga
d gas E&P
ses in the C
le gas/oil ex
ed that they
sion has bee
in the Cent
h block, and
lling has be
dimentary ba
Kalimantan,
onesia after
xport facility
apacity of 2
/yr due to
up the coa
Basin. Fluv
o Early Mioc
eltaic sandst
ormed with
aly shales o
ocene Tarak
s and Shale Oil
company
Central and
xploration b
planned to
en released.
tral (Kisaran
d also report
een disclose
asin, its 36,
, Figure XXI
r Central Su
on the coas
22.5 million
declining c
st in northe
vio-deltaic to
cene open m
tone, shales
NE-SW tren
of the Tabul
kan Formati
Resource Asses
that operate
d North Sum
locks in Sum
make a dec
.13 New Zea
n) and Nor
ts it is evalu
ed in Sumat
000-mi2 ons
II-6. The Ku
matra as we
st is the main
t/yr. How
conventional
east Kalima
o shallow m
marine carbo
, and coals
nding folds.
Formation,
ion are the
ssment
es or
matra
matra
cision
aland
rthern
uating
tra or
shore
utei is
ell as
n gas
wever,
l gas
antan,
marine
onate
were
The
while
main
XXIII. Indon
June, 2013
Fig
Source: AR
T
on the w
depositio
center du
basin ed
these ma
esia
gure XXIII-6. P
I, 2013
The Kutei Ba
west, and t
on during th
uring the late
ge. Figure
arine mudroc
Prospective S
asin is bound
he Paternos
e mid-late E
e Eocene to
XXIII-7 sho
cks are mos
XXI
Shale Areas in
ded by the M
ster High o
Eocene. De
o late Oligoc
ows the gene
tly deeper th
EIA/ARI W
II-12
the Kutei and
Mangkaliat P
on the south
eep marine
cene, with a
eral structur
han 5 km in
World Shale Ga
d Tarakan Bas
Platform on
h. It devel
sediments w
carbonate p
re of the Ku
the onshore
s and Shale Oil
sins, Eastern K
the north, t
loped by rif
were depos
platform dev
utei Basin an
e basin exten
Resource Asses
Kalimantan.
the Kuching
fting and sy
sited in the
veloped alon
nd illustrates
nt.
ssment
High
yn-rift
basin
ng the
s that
XXIII. Indon
June, 2013
Figu
Source: Ram
T
and carb
from thes
shale ga
formed d
mudston
0.6% to 0
T
characte
kerogen.
The inter
to the top
while Mio
appears
S
trending
during th
being tra
ranging u
esia
ure XXIII-7. GeShowi
mdhan and Gou
The main sou
bonaceous s
se shallower
s/oil explora
deltaic sedim
es. Therma
0.9% Ro.14
The mostly d
rized by a d15 TOC ran
rbedded sha
p of the oil g
ocene rocks
to be largely
Structural de
anticlines w
he Neogene
apped in lith
up to more
eneralized Easng Marine Mu
ty, 2011
urce rocks r
hales, with e
r Neogene fl
ation targets
ments, which
al maturity o
deltaic Mioc
depositional
ges from 2%
ale, sand, an
generative z
s become o
y confined to
eformation s
with more ge
resulted in
hifying sand
than twice h
XXI
st-West Trendudrocks Mostly
recognized in
essentially a
luvio-deltaic
s in the basi
h are rich in
f this seque
cene shales
environmen
% to 6% (av
nd coal sequ
zone (0.7% R
overmature f
o the eastern
started durin
entle synclin
significant o
stones due
hydrostatic l
EIA/ARI W
II-13
ding Structuray Deeper than
n the Kutei
all of the conv
deposits. T
n. Prograd
n Type III o
nce in the d
s of the Bal
nt rich in lan
verage 4%) b
uence is ove
Ro) average
for gas belo
n Kalimantan
ng the midd
nes. Rapid
overpressur
to interbed
levels (1.0 p
World Shale Ga
al Cross-Section 5 Km in the O
Basin are M
ventional oil
These source
ing depositi
organic matt
deeper troug
likpapan Gr
nd-plant mat
but some int
er 3,000 feet
s 9,000 feet
ow 19,000 f
n coast and
dle Miocene
deposition
re, caused b
dded mudsto
psi/ft), is pre
s and Shale Oil
on Across theOnshore Area
Mid-Late Mio
l and gas pro
e rocks also
on during th
ter in coal s
ghs is oil-pro
roup in the
terial and co
tervals have
t thick in ma
t in the onsh
ft depth. S
productive M
e, forming s
followed by
by gas gene
one seals.
esent throug
Resource Asses
e Kutei Basin, as.
ocene mudst
oduction sou
o are the prin
he early Mio
seams and
one, ranging
Kutei Basin
ontaining Ty
e over 20% T
any areas. D
hore Kutei B
hale oil pote
Mahakam D
teep north-s
basin unloa
eration and w
Overpressu
ghout the co
ssment
tones
urced
ncipal
ocene
coaly
from
n are
ype III
TOC.
Depth
Basin,
ential
elta.
south
ading
water
uring,
oastal
XXIII. Indon
June, 2013
portion o
below ab
30°C and
Figure XX
Source: Ram
F
deposits
were dep
Formatio
Unfortun
prospect
T
content,
Type II.
ft thick).
burial his
averagin
less matu
esia
of the Kutei
bout 12,000
d the averag
XIII-8. PressuThermal
mdhan and Gou
urther north
overlain by
posited unde
on, along wi
ately, these
ive for shale
The Naintupo
ranging from
Well penetr
Depth rang
story modeli
g 1.5%). Lo
ure levels, w
Basin starti
ft, Figure XX
ge geotherm
re Gradients i Maturity is O
ty, 2011
in the Tara
y mostly no
er deltaic co
ith the Early
three sourc
e gas explora
o contains
m 1.6% to 12
rations indica
ges from 6,0
ing indicate
ocal structur
where it could
XXI
ng below a
XIII-8.16 The
al gradient is
in the Kutei Bil-Prone to Im
akan Basin, t
n-marine cla
onditions. T
y Miocene
ce rocks are
ation.
deltaic sequ
2.1% (averag
ate the Nain
000 ft to ov
the Naintup
ral uplifts m
d be oil pron
EIA/ARI W
II-14
depth of ab
e average s
s about 30°C
asin Can Reacmmature, with a
the basin co
astic sedime
The principal
Naintupo an
e coal-rich d
uences of s
ge 5%). Ke
ntupo Fm is
ver 16,000 fe
po Fm is in
ay elevate t
ne.
World Shale Ga
bout 7,000 f
surface temp
C/km.
ch 1.0 psi/ft Ba Very Low Ro
ontains Eoce
ents of Mio
l source roc
nd Middle M
deltaic depos
shale with f
rogen is ma
1,000 to 1,5
eet (average
the dry gas
the Naintupo
s and Shale Oil
ft and accel
perature in th
Below Depths o/Depth Gradi
ene to Mioce
cene and y
ck is the Lat
Miocene Me
sits that are
fair to good
ainly Type III
500 feet thic
e 11,500 ft)
s window (R
o to shallow
Resource Asses
erating mar
he Kutei Ba
of About 12,0ient.
ene deep m
younger age
e Miocene T
eliat formatio
e considered
d organic ca
along with s
k (average 1
). Well data
Ro 1.3% to 2
wer and ther
ssment
rkedly
sin is
00 ft.
marine
e that
Tabul
ons.17
d less
arbon
some
1,250
a and
2.0%,
rmally
XXIII. Indon
June, 2013
T
with sand
0.7% to
3,300 to
13,000 fe
Meliat ha
T
Tabul Fo
in coal-ri
Formatio
while de
reflectan
2.2 R
K
Balikpap
Delta, ba
mapping
thermally
Reservoi
T
(oil- to g
coalbed
cross-sec
structura
within its
Ro). The
window (
(Ro 1.5%
esia
The overlying
dstone, coal
6.5% (avera
6,600 ft thi
eet in the tr
as wet gas m
The predomi
ormation, ag
ch sequence
on averages
pth ranges
ce averages
Reservoir P
Kutei Basin.
an Fm are
ased on limit
. These sh
y immature
ir pressure is
Tarakan Bas
as-prone).
methane m
ction across
l conditions
s 510-mi2 pro
e Meliat Fo
(Ro 1.15%), w
%).
g Middle Mi
, and dolom
age 3% TOC
ck (average
roughs (ave
maturity (1.0
nant source
ain a non-m
es. Both lith
about 3,30
from 3,300
s 0.7%, in th
Properties
Lacustrine
estimated t
ted cross-se
hales are oi
basin. Ne
s elevated a
sin. Three
Depth was
maps develop
s the onsh
. The L. Mi
ospective ar
ormation occ
while the Na
XXI
ocene Melia
mite layers. T
C), mainly T
e 5,000). D
erage depth
to 1.3% Ro)
e rocks of th
marine, delta
hologies con
0 feet thick
feet to 6,6
e oil window
(Prospecti
e mudstones
to be prosp
ection data a
il-prone (Ro
et thickness
above hydros
shale-beari
estimated b
ped by ARI
hore north-c
iocene Tabu
rea, and has
curs at 10,0
aintupo Form
EIA/ARI W
II-15
at Formation
Total organic
ype III kerog
epth varies
10,000 ft).
.
he Tarakan
ic sequence
ntain mixture
, of which a
00 feet. W
w.
ive Area)
s and carbon
ective within
and augmen
0.7%) even
is estimate
static.
ng targets a
based on lim
. Figure XX
central Tara
ul Fm avera
s 3.0% avera
000-ft averag
mation avera
World Shale Ga
n includes s
c carbon of t
gen. The M
from 3,300
Thermal h
Basin are
e. TOC rang
es of Type II
approximate
Well data an
naceous sha
n a 1,630-m
ted by ARI-p
n at averag
ed at 450 ft
are present
mited cross-s
XIII-9 is a w
akan Basin,
ges 600 ft t
age TOC th
ge depth an
ages 11,500
s and Shale Oil
shales and c
the deltaic c
Meliat Forma
feet on bas
history analy
shales of th
ges from 0.5
I and III kero
ly 1,500 fee
nd modeling
ales in the M
mi2 area nea
proprietary c
ge 9,000 ft
ft, with aver
at varying
section data
west-east tr
, showing g
thick (net) a
at is in the o
nd is mostly
ft deep and
Resource Asses
claystones a
clays ranges
ation ranges
sin highs to
ysis indicate
he Late Mio
5% to 4%, h
ogen. The T
et is organic
indicate vit
Mid-Late Mio
ar the Maha
coalbed met
depth within
rage 4.0% T
thermal ma
a and propri
ending struc
generally s
nd 5,000 ft
oil window (
y in the wet
is dry-gas-p
ssment
along
s from
from
over
s the
ocene
higher
Tabul
c-rich,
trinite
ocene
akam
thane
n this
TOC.
aturity
ietary
ctural
imple
deep
(0.7%
t gas
prone
XXIII. Indon
June, 2013
Figure XBasin, S
Pro
Source: Sub
2.3 R
K
the Kutei
shale ga
billion ba
T
barrels o
billion ba
formation
out of 35
small vol
2.4 A
N
basins.
esia
XXIII-9. West-Showing Geneospective Dep
broto et al., 2005
Resource A
Kutei Basin.
i Basin has a
as and shale
arrels. Note
Tarakan Bas
of technically
arrels of sha
ns have an e
5 and 25 Tcf
ume (0.04 b
Activity
No shale gas
-East Trendingerally Simple pths of 1 to 2 K
5
Assessmen
Based on
an estimated
e oil resourc
that this unit
sin. The oil-
y recoverab
ale gas and
estimated 5
f of risked sh
billion barrels
s/oil leasing o
XXI
g Structural CStructural CoKm with Oil-p
nt
the geologic
d 1.3 Tcf and
ces, out of r
t is coaly an
-prone Tabu
le shale gas
shale oil in-
and 4 Tcf of
hale gas in-p
s) of technic
or exploratio
EIA/ARI W
II-16
Cross-section nditions. Sourone Ro of 0.6
c conditions
d 0.7 billion
risked shale
d may not b
ul Formation
s and shale
place (riske
f risked, tech
place, respe
ally recovera
on activity ha
World Shale Ga
Across the Ource Rocks of 6% to 0.7%. Ve
described a
barrels of ris
e gas and o
be brittle.
has an esti
e oil resourc
d). The gas
hnically reco
ectively. In a
able conden
as been repo
s and Shale Oil
nshore Northf the Tabul Forertical Exagge
above, the B
sked, techni
oil in-place o
mated 0.2 T
ces, out of 3
s-prone Nai
overable sha
addition, the
nsate from s
orted in the
Resource Asses
-Central Tarakrmation Occueration = 3x.
Balikpapan F
cally recove
of 16 Tcf an
Tcf and 0.3 b
3.8 Tcf and
ntupo and M
ale gas resou
Meliat Fm h
hale.
Kutei or Tar
ssment
kan r at
Fm in
erable
nd 17
billion
10.6
Meliat
urces
has a
rakan
XXIII. Indon
June, 2013
3 E
3.1 In
E
Indonesia
Sulawes
deposited
window.
single Ea
Source: AR
esia
EASTERN I
ntroduction
Eastern Indo
a, with sign
i and the i
d (non-lacus
These bas
astern Indon
I, 2013
NDONESIA
n and Geo
onesian sedi
nificantly old
slands of e
strine) shale
sins tend to
esian region
Figure XXIII-1
XXI
A BASINS
logic Setti
imentary ba
der deposits
eastern Indo
e. Thermal
be small an
n for analysis
0. Prospectiv
EIA/ARI W
II-17
ngs
asins are ma
s generally
onesia have
maturity is h
nd tectonica
s, Figure XX
ve Shale Areas
World Shale Ga
arkedly diffe
reflecting a
e some of
higher too, p
ally complex
XIII-10.
s in Eastern In
s and Shale Oil
erent from t
a more ma
the country
predominate
, thus we g
ndonesia.
Resource Asses
those in we
arine charac
y’s only ma
ely in the dry
roup them i
ssment
estern
cter.18
arine-
y gas
nto a
XXIII. Indon
June, 2013
T
contain t
from ove
source ro
which co
sandston
Klasama
Type II/II
over 2,00
ft in the
gas level
T
0.6% to
Salawati
from less
oil seeps
1.0% in d
B
appears
Indonesia
The stra
Mesozoic
These ar
shales o
sandston
Kembela
L
occurred
field, whi
is export
shales, s
esia
The Salawat
hick source
ermature Ju
ock is Late M
ontain Types
nes of the Pl
n and Kais/
II kerogen, a
00 feet thick
Sele Strait a
ls (1.0% Ro)
The Klasama
2.3%), main
Basin, abo
s than 3,000
s in the north
deeper parts
Bintuni Basi
to have the
a region. T
atigraphic se
c, and Tertia
re unconform
of shallow m
nes of the T
angen Forma
imited oil p
during the
ich produces
ted via the
since they ar
ti and Bintu
rocks of Pe
rassic marin
Miocene ma
s II/III kerog
io-Pleistoce
/Klasafet fo
albeit with re
in deep trou
and Salawa
at a depth o
an Formatio
nly Type II
ut 15 to 20
0 ft to more
h, where cal
s of the Sala
in. The Bint
e simplest st
he Bintuni B
ection resem
ary units. B
mably overla
marine origi
Triassic-Jura
ation.
roduction fr
1930’s. In t
s from Midd
Tangguh LN
re typically im
XXI
ni basins in
ermian age t
ne shales co
rine shales
gen. The K
ne Klasama
rmations are
elatively low
ughs, with d
ti Island to
of 10,000 fee
n contains o
and III kero
% of which
than 10,000
culated vitri
wati Basin.
tuni Basin, lo
tructural con
Basin is bord
mbles that
asement co
ain by Carbo
in (Aifam G
assic Tipuma
rom New G
the 1990’s A
dle Jurassic
NG facility.22
mmature and
EIA/ARI W
II-18
n the Bird’s
that are rich
ontaining Ty
and marlsto
Klasafet is o
an Formation
e potential
w TOC of 0.3
epth ranging
the north an
et.21
organic-rich
ogen. It ran
contains el
0 ft. Biomar
nite reflecta
ocated in the
nditions and
dered to the
of the Sala
nsists of Sil
oniferous an
Group). Ne
a Formation
uinea Grou
ARCO Indon
“Roabiba” a2 Some so
d low in orga
World Shale Ga
s Head regi
in Type III
ypes II/III ke
ones of the K
overlain by
n.19 Marine m
shale oil ta
3% to 1.1%
g from 5,000
nd west. Th
shales with
nges from 3
levated TOC
rker data ind
nce values
e eastern sid
d best shale
e east by the
awati Basin,
urian and D
nd Upper Pe
ext are inte
n and Creta
p limestone
nesia discov
and “Aalenia
urce rock s
anic content
s and Shale Oil
on of weste
coals with s
erogen. Ho
Kais and Kla
thick regres
marlstones a
rgets. They
%.20 The Kla
0 ft in the ea
hermal matu
h average 1
3,000 to 5,00
C above 1%
dicate the Kl
approach 0.
de of the Bir
e prospectivi
e Lengguru
, with prese
Devonian me
ermian clasti
erbedded flu
aceous delta
es (Kais/Kla
vered the W
an” sandston
tudies disco
t, mostly und
Resource Asses
ern West P
some contrib
owever, the
asafet format
ssive shales
and shales o
y contain m
asafet is 1,0
ast to over 12
urity reaches
.7% TOC (r
00 ft thick i
%. Depth ra
lasaman sou
.7% Ro and
rd’s Head re
ty in the ea
Fold/Thrust
erved Paleo
etamorphic r
ic sediments
uvial shales
aic shales o
safet equiva
Wiriagar Deep
ne reservoirs
ount the Kla
der 1% TOC
ssment
Papua
bution
main
tions,
s and
of the
mainly
00 to
2,000
s wet
range
n the
anges
urced
up to
egion,
astern
Belt.
ozoic,
rocks.
s and
s and
of the
alent)
p gas
s and
asafet
.23
XXIII. Indon
June, 2013
M
potential
Permian
Bintuni.
relatively
feet, whil
T
more del
10,000 fe
index is
Ainim co
In
hydrocar
the shallo
Tipuma r
Jurassic
T
basins, f
within the
Pliocene
exploratio
2001.24
shales w
T
target fo
limestone
averagin
higher Ty
depth of
esia
More importa
. The Aifat a
Aifam Grou
The older
y modest TO
le depth can
The overlying
taic setting.
eet. This un
over 300 m
mpared with
n addition t
rbon source.
ow marine s
ranges from
shales are i
The Tomori B
from which i
e greater Ba
collision a
on began du
Oil and gas
within the con
The Lower M
r shale exp
e and coal,
g 2 to 4% a
ype II keroge
7,200 ft, bec
ant are the
and Ainim fo
up and con
Aifat cons
OC of 1.0%
n exceed 12,
g Ainim Form
Source roc
it contains a
mg HC/g. V
h the older A
to the Per
. The Tipum
shales indica
4,000 to ne
n the immat
Basin of eas
it was trans
anggai-Sula
and thrusting
uring the 19
are produce
ntemporaneo
Miocene Tom
ploration. It
with the up
and consisti
en but TOC
coming gas
XXI
Permian an
ormations a
nsidered to
ists of blac
to 1.8%, av
000 ft in the
mation also c
ck thickness
adequate or
itrinite reflec
Aifat, indicati
mian, the
ma contains
ate maximum
arly 8,000 fe
ture-mature
tern Sulawe
ported along
a micro-conti
g of contine
80’s, resultin
ed from frac
ous Tomori F
mori Fm, ran
comprises
per section
ing of Type
generally is
prone (> 1.0
EIA/ARI W
II-19
d Jurassic s
are the respe
be the mai
ck marine c
veraging 1.5
e Bintuni Bas
contains cal
is approxim
rganic matte
ctance is sh
ng an uncon
Jurassic Ti
sandstones
m TOC of 4.5
eet deep. N
oil window, a
esi shares m
g strike-slip
inent, a fold
ental crust
ng in the dis
ctured limest
Formation, w
nging from 5
marine and
typically mo
II/III keroge
s less than 1
0% Ro) below
World Shale Ga
sediments, a
ective lower
n hydrocarb
calcareous s
5%. Gross
sin.
lcareous sha
mately 2,400
er with abund
harply lower
nformity with
puma Form
and carbon
5 and 7.6%,
Near the Bint
at about 0.6
many similarit
faults. The
d-thrust syst
over ophio
scovery of th
tones of the
which is sim
500 to 1,000
d carbonace
ore deltaic i
en. The low
%. The Tom
w a depth of
s and Shale Oil
analyzed be
r and upper
bon generat
shales. Lim
thickness ca
ales, althoug
feet. Depth
dant coal se
(0.66% Ro)
hin the Perm
mation may
naceous sha
, mainly hum
tuni Basin’s
6% Ro.
ties with the
e Tomori is
em that dev
litic materia
he Senoro “g
Lower Mioc
ilar to the Kl
0 ft thick, a
eous shale a
n origin. TO
wer marine
mori Fm atta
f about 11,30
Resource Asses
elow for sha
members o
ting rocks in
mited data
an exceed 3
gh deposited
h averages a
eams. Hydr
) in the ove
mian.
be a pot
ales. Analys
mic kerogen.
western limi
e Salawati/B
a foreland
veloped follo
al. Oil and
giant” gas fie
cene, source
asafet Fm.
lso is a pote
along with s
OC is fairly
section con
ains 0.5% R
00 ft.25
ssment
ale oil
of the
n the
show
3,500
d in a
about
rogen
rlying
ential
ses of
The
it, the
intuni
basin
owing
d gas
eld in
ed by
ential
some
high,
ntains
o at a
XXIII. Indon
June, 2013
F
marine p
assembla
oil, sour
produced
sandston
3.2 R
O
and reso
analysis.
B
across th
here are
prospect
Further e
prospect
the Leng
F
central B
Ainim for
simple, a
Aifam G
central B
esia
inally, the B
pelagic and
age later co
rced from T
d from fractu
nes and lime
Reservoir P
Only the Bint
ources, while
Bintuni Bas
he east-cen
too deep b
ive depths o
east this unit
ive Klasafet
guru Fold an
igure XXIII-
Bintuni Basin
rmations) is
and within th
roup shale
Bintuni Basin
ula Basin in
oceanic dep
ollided with I
Triassic-Jura
ured Jurass
estones.27
Properties
tuni Basin h
e the other a
in. Figure
tral Bintuni
but marine s
of 2.5 to 5
t is structura
t shale area
nd Thrust be
12 shows a
n. Here the
about 1.0 to
he volatile o
region is as
.
XXI
northeast S
posits, inclu
rian Jaya an
assic marine
sic limestone
(Prospecti
ad sufficien
areas (Salaw
XXIII-1 sho
Basin.28 A
shales within
km, althoug
ally deforme
is inferred t
elt, but this u
a west-east
e organic-ric
o 3.5 km de
oil to wet ga
ssumed to
EIA/ARI W
II-20
Seram island
ding clays,
nd the Austr
e carbonate
e as well as
ive Area)
t data to ev
wati, Tomori,
ows a WSW
According to
n the Klasaf
h as noted
d by thrustin
to be a north
unit was not
trending st
h and prosp
eep (possibly
as windows
be a north-
World Shale Ga
d contains M
limestones,
ralian contin
e Type II
s from Plio-P
valuate shale
Bula) lacke
W-ENE trend
this interpr
fet Fm dip g
above thes
ng and not c
h-south elon
assessed d
tructural cro
pective Perm
y deeper fur
(Ro of 1.0%
-south elong
s and Shale Oil
Mesozoic to M
and thin sa
nental shelf.2
mudstone s
Pleistocene
e gas/oil res
ed adequate
ding structu
retation, the
gently to the
se appear to
considered p
ngated recta
ue to its low
oss-section a
mian Aifam
rther to the e
% to 1.2%).
gated rectan
Resource Asses
Mid-Tertiary
andstones.
26 Convent
source rock
marginal m
servoir prope
data for det
ral cross-se
Permian s
e east and a
o have low T
prospective.
angle just we
w TOC (<1%)
across the w
Group (Aifa
east), struct
The prospe
ngle in the w
ssment
open
This
tional
ks, is
marine
erties
tailed
ection
hales
are at
TOC.
The
est of
).
west-
t and
urally
ective
west-
XXIII. Indon
June, 2013
FigureShowing
Source: Hill
Figure Xrich a
Source: Che
esia
e XXIII-11. Ge Marine Shale
Fu
et al., 2001
XXIII-12. West-and Prospectiv
Structurally S
evalier et al., 198
eneralized WSes in the Klasarther East this
-east Structurve Permian AiSimple, and W
86
XXI
SW-ENE Trendafet Fm Dippins Unit is Struc
ral Cross-sectfam Group (A
Within the Vola
EIA/ARI W
II-21
ding Structurang Gently to thcturally Deform
ion Across WAifat and Ainimatile Oil to Wet
World Shale Ga
al Cross-sectiohe East at Promed and Not P
West-central Bim formations) t Gas Window
s and Shale Oil
on Across theospective DepProspective.
intuni Basin. is about 1.0 to
ws (Ro of 1.0%
Resource Asses
e Bintuni Basinths of 2.5 to 5
Here the Orgao 3.5 Km Deep to 1.2%).
ssment
n, 5 Km.
anic-p,
XXIII. Indon
June, 2013
3.3 R
B
Tcf of tec
as define
shale ga
services.
3.4 S
N
4 O
In
gas/oil d
siltstone,
frac shale
BScoPFmmIncog
OthdsSinmtr
Soe
esia
Resource A
Bintuni Basi
chnically rec
ed by the Ro
as target in
.
Shale Leas
No shale gas
OTHER BAS
ndonesia’s o
development
, coal, and c
e well comp
Bengkulu BasSouth Sumaontains pred
Pleistocene aormation as
mudstone, comarine envirntense faultioaly non-brias/oil develo
Ombilin Basinhe eastern seveloped dupaced folds
Sangkarewannto fluvial demarine Mioceransgression
Several shallnly a few ncountered
Assessmen
in. The pros
coverable sh
o contours o
n Indonesia,
ing and Ex
s/oil leasing o
SINS
other onshor
t. These
coaly shale
letions.
sin. Locatedtra Basin, tdominantly age. Geochs a potentiaoal seams, ronment thang, steep sittle lithologyopment.
n. This smaside of the Buring the Eos trending nng formationeposits of thene Ombilinn.
low coal minconventionaconventiona
XXI
nt
spective are
hale gas res
of 1.2% to 1
, although
xploration A
or exploratio
re sedimenta
areas conta
that are not
d in southwethis relativenon-marine hemical anaal source rosandstone,
at transitionestructural dipy all appear
all non-produBarisan Mouocene to Midorthwest-so
ns were dephe Late Olign Formation
nes are in oal oil & gaal sandstone
EIA/ARI W
II-22
as of the Pe
sources out
.8%. This m
its location
Activity
on activity ha
ary basins a
ain mainly
t considered
est Sumatraly small anclastic and
alyses have ock. This
and congloed into manps, low thermr to make th
ucing basin untains. It isddle Oligoceutheast. T
posited in lacgocene Sawn which resu
operation aloas explorate reservoirs c
World Shale Ga
ermian Aifam
of 114 Tcf o
marine-depo
is relatively
as been repo
appear to ha
non-marine
d stable and
a across the nd structurad sedimenta
identified thunit consistomerate depngrove and mal maturityhe Bengkulu
is located ins a transpreene and wahe basal Ecustrine rift
wahtambangulted from a
ong the edgion wells hcontaining n
s and Shale Oil
m Group has
of gas in-pla
osited unit c
y remote fr
orted in east
ave limited p
e sequence
brittle enou
Barisan Molly deformery rocks of
he Mid-Late ts of mudstposited in a
freshwater y (Ro averagu Basin uns
n west-centraessional pullas later defoocene Bransettings. T
g Formation,a global se
ge of the Omhave been natural gas w
Resource Asses
s an estimate
ace (both ris
could be the
rom market
tern Indones
potential for s
s of sands
ugh for horiz
ountains fromd fore-arc Eocene thrMiocene Le
tone, calcara mainly shr environmeges 0.40%)
suitable for s
al Sumatra al-apart basinormed into tni and OligoThis later evo, followed b
ea level rise
mbilin Basindrilled. T
with high leve
ssment
ed 29
sked),
e best
t and
sia.
shale
stone,
zontal
m the basin rough emau reous allow nts.29 , and shale
along n that tightly ocene olved y the
e and
n, but These els of
XXIII. Indon
June, 2013
CScoOB
TstNaOdetica MBTTothaaBw
Tstrocoofso TpthHth1TbT
esia
CO2 (50-90%Sawahlunto, ontain Type
Overall, the cBasin shales
The Northwetructures on
Northwest Jand interbedd
Oligocene aneposited in volved to mame subsidearbonates.
Miocene sanBasin, sourceTalang Akar Total organic
rganic-rich (hick, comprisbout 7,500 tnd gas pron
Basin are cowells.
The Barito Btructurally socks which onventional f the basin iouthern Bar
The Middle Eetroleum so
hin coal depHigh-TOC shhick in the d2,000 ft, av
TOC is unceasin, reachi
Tanjung Fm a
%). Geochemand Ombilin
e III kerogencomplex struappears to
st Java BasJava Island
ava Basin, fded lacustrinnd Early M
fluvio-deltaainly carbonence dimini
dstone is thed mainly bFormation.
c carbon (TO(0.5 to 9%).3
sing coal seto 11,500 ft.ne, becominoaly and unl
Basin in soimple basinunconformaoil productios non-produito.
Eocene to laource rock, cosits.33 The
hale and madeep southeveraging aboertain. The ng dry gas mare coaly an
XXI
mical analysn formations n that mostlyucture, high make them
sin northeastd. The Jatibaformed by rine shales weiocene, formaic, coastal,nate during thished, with
he primary cby carbonac
Organic mOC) reaches32 The inter-eams, limest These nong increasinglikely to be
outhern Kalin containing ably overlie on (of 30-40uctive. Rece
ate Early Oconsisting ofe formation iarl is concenern Barito Baout 6,000 ft Tanjung ha
maturity in thnd probably n
EIA/ARI W
II-23
ses indicateare the bes
y has reachCO2 conten
poorly suited
t of Jakarta arang sub-bifting during ere depositeming a seq, and shallohe Middle M
deposition
conventionaleous shale
material conss 40-70% in -bedded shatone, and san-marine to mgly more mabrittle enou
mantan is up to 6 kmthe igneou
° API gravityent coalbed
Oligocene Taf fluvial and is over 3,30ntrated in itsasin.35 Dep
deep in thas entered the deepest not brittle.
World Shale Ga
e that shalesst source roched the oil wnt, and non-d for shale g
is one of thbasin, the on the Eocene
ed.31 Subsiduence of sow marine
Miocene. By of regres
l oil and gasand coal o
sists mainlycoal, while
ale-clastic seandstone. marginal ma
ature offshorugh for hydr
a large (70m of Eocenus and metay) occurs in methane ex
anjung Formmarginal ma0 ft thick in s upper secpth to the Tae shallow cthe oil windregions. Ho
s and Shale Oil
s within thecks in the bawindow (Tma
-brittle naturgas/oil devel
he larger of shore extene when volc
dence continhale, coal, environmen
y Late Miocessive clastic
s reservoir iof the Late Oy of Type II the shales a
equence canDepth to thearine sourcere. Shales raulic fractur
0,000 km2 e and younamorphic bathe northernxploration is
mation is thearine clasticTanjung Fie
ction, which anjung rangeconventionaldow throughowever, the
Resource Asses
e Sangkarewasin. These
ax 435-447° re of the Omopment.
the small grnsion of the lcaniclastics,
nued into theand sandst
nts. Depone to Quate
cs and pla
in the JatibaOligocene Uand III kero
also can be n be over 1,0e Talang Ak
e rocks can bin the Jatibaring in horiz
onshore exnger sedimeasement. Mn Barito, but underway i
e most impoc strata, inclueld in the noreaches 2,4es from 3,0l anticlinal f
hout much oshales withi
ssment
wang, units C).30
mbilin
raben arger tuffs
e Late tones sition
ernary atform
arang Upper ogen. fairly
000 ft kar is be oil arang zontal
xtent), entary Minor most
in the
ortant uding orth.34 400 ft 00 to fields. of the in the
XXIII. Indon
June, 2013
OMthdlans
REFERE
1 Energy Inf
2 Ryacudu, Indonesia
3 Katz, B.JInternation
4 Hwanga, Sumatra O
5 Camell, ADetailed GSixth Ann
6 RodriguezTrough, N
7 Yuwono, Rin Bentu Article #10
8 Hennings“RelationsBulletin, A
9 Bishop, MSystem.”
10 Muksin, Muara EnAssociatio
11 Doust, H
12 AWE Lim
13 AWE Lim
14 Curiale, Basin, Ind
15 Saller, ABasin, Ind
16 RamdhaRadical R
esia
Overlying theMiocene Berahe overlyingeltaic sedim
ack of signifiorthernmosthale gas/oil
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XXI
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Morgan Stanley S
Annual General M
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