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XXII. Thaila
June, 2013
XXII.
SUMMA
W
large So
the Khora
nd
THA
ARY
While no sha
utheast Asia
at, Northern
Figu
S
AILAND
ale gas/oil e
an country h
Intermontan
ure XXII-1. Pro
ource: ARI, 201
XX
D
exploration a
has significa
ne and Cent
ospective Sha
3
EIA/ARI W
XII-1
activity has
ant prospect
tral Plains ba
ale Gas and Sh
World Shale Ga
been report
tive shale ga
asins, Figure
hale Oil Basin
s and Shale Oil
ted to date
as and shal
e XXII-1.
s of Thailand.
Resource Asses
in Thailand
e oil potenti
.
ssment
d, this
ial, in
XXII. Thaila
June, 2013
T
recovera
Intermon
paucity o
and may
potential
T
Triassic
These s
pressure
and suita
local drill
developm
T
within th
Oligocen
including
nd
The Khorat B
ble shale ga
ntane and Ce
of available
y complicate
is promising
Table XX
Thailand’s gre
shale sourc
hales can
ed. Deposite
able for hyd
ling rigs, and
ment.
Thailand’s sh
he Northern
ne to Early M
g the 30,000
Basin in no
as resource
entral Plains
public data.
e future sha
g but needs
XII-1. Shale G
eatest poten
ce rocks in
be locally t
ed under sh
raulic fractu
d active inde
hale oil pote
Intermonta
Miocene ag
-b/d Sirikit-1
Reservo
ir
Properties Re
AvThCl
Resource
Ga
GI
Ri
Ri
Physical Exten
t Pr
Th
De
Basic Data
XX
rtheast Tha
s, Table XX
s basins cou
Block faul
ale drilling a
to be better
Gas Reservo
ntial appears
the Khorat,
thick, organ
allow marine
uring. The K
ependent oil
ential appea
ne and Ce
e. These u
oil field. Th
OrgNetInteAve
eservoir Pressure
verage TOC (wt. %hermal Maturity (%lay Content
as Phase
IP Concentration
isked GIP (Tcf)
isked Recoverabl
rospective Area (m
hickness (ft)
epth (ft)
Basin/Gros
Shale FormGeologic
Depositional En
EIA/ARI W
XII-2
iland has a
XII-1. In add
uld be subst
ting has dis
nd developm
defined by f
oir Properties
s to be shale
the countr
nic-rich, dry
e conditions
Khorat Basi
l and gas pr
ars to be m
ntral Plains
units source
hermally imm
ganically Richt ervalerage
e
%)% Ro)
(Bcf/mi2)
e (Tcf)
mi2)
ss Area
mation Age
nvironment
World Shale Ga
an estimated
dition, shale
tantial but w
srupted Thai
ment. Over
further data
s and Resour
e gas depos
ry’s largest
gas prone
s, they are li
n has an ex
roducers wh
more limited.
s basins con
ed the basin
mature oil s
Khorat
(32,400 mi2)
Nam Duk FmPermianMarine
1,750
400200
6,000 - 12,0009,000
Mod. Overpres
3.0%2.50%Low
Dry Gas
83.0
21.8
5.4
s and Shale Oil
d 5 Tcf of r
oil potentia
was not quan
iland’s onsh
rall, Thailan
gathering a
rces of Thail
sits contained
onshore se
e, deeply bu
kely to mine
xisting gas p
hich could fa
Small iso
ntain organ
n’s conventio
hale deposit
m
0
ss.
Resource Asses
risked techn
al in the Nor
ntified due t
ore shale b
nd’s shale g
nd analysis.
and.
d in Permian
dimentary b
uried, and
eralogically b
pipeline netw
acilitate shale
olated sub-b
ic-rich shale
onal oil dep
ts that are lo
ssment
nically
rthern
to the
asins
as/oil
n and
basin.
over-
brittle
work,
e gas
asins
es of
osits,
ocally
XXII. Thaila
June, 2013
mined at
Tertiary s
content w
INTROD
D
productio
Bcfd of n
fields in
Approxim
including
E
sandston
were dril
carbonat
reports o
tangible
Statoil a
unconve
A
onshore
1. These
basins (s
being mi
1 oil field
P
overlying
resource
thermal m
Basin ho
group of
nd
t the surfac
shales were
with low “frac
DUCTION
During the pa
on industry.
natural gas i
the Gulf
mately 40%
g most of the
Essentially al
ne and carb
led in Thaila
tes are being
of unconven
sign of activ
and PTTEP
ntional resou
ARI’s review
sedimentary
e include the
such as Ma
ned; and the
d.
Permo-Triass
g Permian c
e potential.
maturity win
osts an exist
active indep
ce may cont
deposited u
ckability”.
ast three de
The country
in 2011.1 N
of Thailand
of Thailand
e country’s p
l of the oil a
bonate reser
and during 2
g targeted in
tional shale
vity for Thai
in January
urces in Tha
w of publishe
y basins wh
e large Khor
ae Sot) in th
e similarly co
sic shale so
carbonate c
These mari
dow, often o
ing gas pipe
pendent oil a
XX
tain mobile
under lacust
ecades Tha
y produced
Nearly 90% o
d, with onl
d’s primary
ower genera
nd gas curre
rvoirs. Whi
2004-6, witho
n convention
e/tight oil or
land’s uncon
y 2011 cov
ailand and ot
ed geologic
ich may hav
rat Basin in t
he Northern
omplex Cen
ource rocks
conventional
ne-deposite
over-pressur
eline networ
and gas prod
EIA/ARI W
XII-3
hydrocarbon
rine sedime
iland has bu
393,000 b/d
of its curren
y limited p
energy co
ation and gro
ently produc
le a handfu
out commerc
nal anticlinal
gas explora
nventional r
vering poten
ther countrie
c literature i
ve unconven
the northeas
Intermonta
ntral Plains B
in the Khor
reservoirs,
ed shales ar
red, and ma
k, a local su
ducers.
World Shale Ga
ns at depth
ntary condit
uilt up a su
d of crude oi
t petroleum
production f
nsumption
owing vehic
ced in Thaila
ul of coalbed
cial success
traps in the
ation & deve
resources w
ntial joint s
es.2
ndicates tha
ntional oil an
st; a series o
ne Basin, w
Basin, which
rat Basin, th
, may offer
re thick, org
ay be minera
upply of suita
s and Shale Oil
h. However
ions and ma
bstantial oil
l and liquids
output com
from small
is supplied
le fuel usage
and comes fr
d methane
s, and some
e Khorat, the
elopment to
as an MOU
studies of c
at Thailand
nd gas poten
of smaller, is
where shale
h hosts the 3
hought to h
Thailand’s
ganic-rich, w
alogically br
able drilling
Resource Asses
r, these low
ay be high in
and natura
s in 2011 an
mes from offs
onshore f
by natural
e.
rom convent
exploration
low-permea
ere have bee
o date. The
signed betw
conventional
has three
ntial, Figure
solated pull-
oil deposits
30,000-b/d S
ave sourced
best shale
within the dry
rittle. The K
rigs, and a
ssment
w-rank
n clay
al gas
nd 3.6
shore
fields.
gas,
tional
wells
ability
en no
e only
ween
and
main
XXII-
-apart
s are
Sirikit-
d the
e gas
y gas
Khorat
small
XXII. Thaila
June, 2013
O
available
downdip
scale in t
in the C
lacustrine
available
1. KHO
1.1 In
T
potential
within the
Ringed b
Drained
Thailand
mainly ag
T
Phan ant
Shan Th
sequence
numerou
Tertiary/
of the Kh
primary s
offer add
conventio
T
widespre
Carbonife
apart into
reef depo
nd
Oil-prone sha
e geologic in
extension o
the northern
Central Plain
e origin, low
e subsurface
ORAT BASI
ntroduction
The Khorat B
. Thailand’s
e southern h
by mountain
by the Moi
, with more
gricultural ba
The Khorat B
ticline. The
hai and Sou
e comprises
us unconform
Quaternary
horat Basin.3
source rock,
ditional sourc
onal petroleu
The structura
ead deposit
erous Si Tha
o numerous
osits of the
ale/tight res
nformation i
of lacustrine
n inter-monta
ns Basin. T
w apparent
e geologic da
IN
n and Geo
Basin in nor
s largest ons
half of the K
n ranges, the
n and Chi
extreme dry
ased, with fe
Basin is sep
Khorat rests
uth China p
s a series of
mities and
deposits. F3 The shallo
, while the fl
ce rock pote
um reservoir
al Khorat Ba
tion of clas
at Formation
horst and g
Pha Nok Kh
XX
sources in T
s scanter.
e oil shale (s
ane basins.
These oil-pr
thermal ma
ata.
logic Setti
rtheast Thai
shore sedime
Khorat Plate
e Plateau it
Rivers, the
y and wet s
ew large citie
parated from
s on the Indo
plates to th
Late Camb
dominated
Figure XXII-2
ow marine to
uvial to lacu
ential. Perm
rs.
asin depress
stic and ca
n.4 Tectonic
raben block
hao Formatio
EIA/ARI W
XII-4
Thailand ap
The most o
solid minera
Similar sha
rone shales
aturity, as w
ng
land appear
entary basin
au, a large
tself is relati
Khorat Pla
easonality.
es or industr
m the Sakon
ochina tecto
he west and
rian through
by Permo-
2 illustrates
o basinal Pe
ustrine Trias
mian dolomite
sion was init
arbonate se
c extension d
s separated
on formed o
World Shale Ga
ppear to be
obvious oil-
al) deposits
ale/tight oil d
s appear le
well as the
rs to have t
n, the 35,000
roughly circ
ively flat wit
ateau receiv
The local e
rial centers.
Nakhon Ba
onic micropla
d north, res
h Recent stra
-Carbonifero
the stratigra
ermian Sara
ssic Kuchina
e and karste
tiated during
edimentary
during the Ea
by high-ang
on regional h
s and Shale Oil
e less prosp
prone shale
which are m
deposits also
ss prospect
general pa
the country’s
0-mi2 petrolif
cular physiog
th 200-m av
es less rain
economy of
asin to the n
ate, which is
spectively.
ata, which a
ous, Triassi
aphy and pe
buri Group i
arai and Hua
ed limestone
g the Middle
rocks, beg
arly Permian
gle normal fa
highs, while
Resource Asses
pective, alth
e potential i
mined on a
o may be pre
tive due to
aucity of pu
s best shale
ferous Khora
graphic prov
verage eleva
nfall than ce
this rural ar
north by the
s bordered b
Its sedime
are interrupte
c/Mesozoic,
etroleum sys
is considere
ai Hin Lat Gr
es form the
e Paleozoic,
ginning with
n broke the
aults. Carbo
clastic and s
ssment
hough
s the
small
esent
their
ublicly
e gas
at lies
vince.
ation.
entral
rea is
e Phu
by the
entary
ed by
and
stems
ed the
roups
main
, with
h the
basin
onate
shale
XXII. Thaila
June, 2013
deposits
approach
deposited
caused r
erosion r
Figure XXGroup is
Also H
Source: Tha
nd
of the Na
hing 20,000
d during the
regional upli
removed 3,0
XII-2. Stratigrs the Primary SHave Potential
ailand Ministry of
am Duk Fo
feet thick.
e Middle to
ft and thrust
000 to 9,000
raphy and PetSource Rock. . Permian Do
f Energy, 2007.
XX
ormation we
Mixed sed
Upper Perm
ting. Seism
feet of sedim
roleum System The Fluvial to
olomite and KaR
EIA/ARI W
XII-5
ere deposit
iments of th
mian. Later
mic and therm
mentary cov
ms of the Khoo Lacustrine Tarsted LimestoReservoirs.
World Shale Ga
ted in the
he Hua Na
basin-scale
mal maturity
ver during th
orat Basin. ShTriassic Kuchones are the M
s and Shale Oil
troughs, w
Kham Form
e compressio
y data indica
is event.
hallow Marinehinarai and HuMain Convent
Resource Asses
with some a
mation were
on and inve
ate that uplif
Permian Sarauai Hin Lat Groional Petroleu
ssment
areas
then
ersion
ft and
aburi oups um
XXII. Thaila
June, 2013
F
the Kuch
A secon
clastics w
to Late
deposited
and clas
orogeny
F
western
Group so
These st
are not c
Saraburi
F
Basin. H
reservoir
rock doe
source ro
faulted a
prelimina
shale gas
F
illustratin
- the prim
the basin
complica
nd
ollowing the
hinarai Grou
d orogenic
were deposit
Jurassic, a
d. After a
tics of the M
brought abo
igure XXII-3
Khorat Basi
ource rock s
trata are ove
considered p
Group and,
igure XXII-4
Here, the low
rs of the Pe
es not appea
ock is relati
and overlain
ary informati
s exploration
igure XXII-
ng conventio
mary targets
n. The patc
ate shale gas
e Indosinian
p began to
collision ma
ted. A furth
after which
Middle Cret
Mahasarakha
out regional u
3 shows a
in. It highlig
shales and c
erlain by fluv
prospective
to a lesser
4 is a south
w-TOC Carbo
rmian Pha N
ar to be pres
vely thin. T
by fluvial a
ion suggests
n than the ea
5 is a sch
nal petroleu
s -- are quite
chy shale di
s exploration
XX
orogeny, Ea
unconforma
arked by vo
er erosional
non-marine
taceous peri
am Formatio
uplift and ero
southwest-
ghts possibl
carbonates, w
vial and alluv
due to their
extent, Kuch
h-north orien
oniferous Si
Nok Khao F
sent in this
These Carb
and alluvial
s that the w
ast.
hematic, no
m play conc
e discontinu
istribution a
n in the Khor
EIA/ARI W
XII-6
arly Triassic
ably fill the e
olcanics foll
or non-dep
e clastics a
iod of defor
on were dep
osion, remov
northeast o
e Permian S
which may b
vial clastic ro
r low TOC c
hinarai Grou
nted seismic
That Forma
Formation. T
part of the b
oniferous, P
clastic rock
western Kho
on-directiona
cepts. Note
uous, block f
nd structura
rat Basin.
World Shale Ga
c continental
extensional g
lowed, after
ositional hia
nd shales
rmation and
posited. Fin
ving up to 6
oriented seis
Saraburi Gr
be prospecti
ocks of the J
content. No
up rocks.
c time secti
ation is over
The primary
basin, while
Permian, an
ks of the Ju
orat Basin m
al cross-sec
the Permo-
faulted, and
al and erosio
s and Shale Oil
and lacustr
grabens of t
r which Late
atus occurred
of the Kho
volcanic ev
nally, the Te
,000 feet of
smic time s
roup and Tri
ive for shale
Jurassic Kho
ote significa
ion from the
lain by poss
y Saraburi F
e the Huai H
nd Triassic r
urassic Kho
may be more
ction of th
Triassic sou
d eroded in
onal comple
Resource Asses
rine sedimen
the Khorat B
e Triassic f
d until the M
orat Group
vents, evapo
ertiary Hima
rock.
section from
iassic Kuchi
e gas explora
orat Group; t
ant faulting o
e eastern K
sible convent
Formation so
Hin Lat Form
rocks were
rat Group.
e prospectiv
e Khorat B
urce rock sha
many portio
exity are like
ssment
nts of
Basin.
fluvial
Middle
were
orites
layan
m the
inarai
ation.
these
of the
Khorat
tional
ource
mation
block
This
ve for
Basin
ales -
ons of
ely to
XXII. Thaila
June, 2013
Figure XXGroup an
Source: Tha
FiguCarbo
FormatioWhile th
Source: Tha
nd
XII-3. Southwend Triassic Ku
ailand Ministry of
ure XXII-4. Sooniferous Si Ton. The Sarabhe Huai Hin La
ailand Ministry of
est-Northeast Suchinarai Grou
Clas
f Energy, 2007.
outh-North Sehat Formationburi Formationat Formation S
f Energy, 2007.
XX
Seismic Time up Source Rocstic Rocks of t
ismic Time Sen Overlain by n Source Roc
Source Rock isCarbonif
EIA/ARI W
XII-7
Section in Weck Shales andthe Jurassic K
ection from EaConventional k Does Not Aps Relatively Tferous Sequen
World Shale Ga
estern Khoratd Carbonates, Khorat Group.
astern Khorat Reservoirs oppear to be Prhin. Note Signce.
s and Shale Oil
t Basin, Show Overlain by F
Basin, Showiof the Permianresent in this
gnificant Fault
Resource Asses
ws Permian SaFluvial and All
ing Low-TOC Pha Nok Kha Part of the Baing of the Per
ssment
raburi luvial
ao asin, rmo-
XXII. Thaila
June, 2013
FigurPetroleu
Faulte
Source: Tha
A
gas disco
reservoir
organic-r
Cretaceo
rifting.5
F
interpreta
rock “kitc
clockwise
U
Basin. A
planning
Earlier th
reportedl
opportun
blocks bu
nd
re XXII-5. Schm Play Conceed, and Partly
ailand Ministry of
Although the
overies have
rs within ant
rich Permo-T
ous burial, a
igure XXII-
ation of a sm
chen”, the up
e rotation alo
UK-based ind
At last repor
its first exp
his year Yan
ly entered i
nities in the
ut have not r
ematic Non-depts. Note they Eroded acros
f Energy, 2007.
Khorat Bas
e been mad
ticlines and
Triassic shal
nd then pos
-6 illustrate
mall gas fie
plifted anticli
ong strike-sl
dependent S
rt, Salamand
ploration we
nchang Petro
nto a contra
Khorat. C
reported act
XX
irectional Croe Primary Permss the Basin.
Ex
sin is overma
de. These f
stratigraph
les, with gas
sibly migrati
es a detail
ld in the ce
nal fold that
lip faults tha
Salamander
der was acq
ll in 2012-1
oleum, Chin
act with Th
Coastal Ener
ivity in the p
EIA/ARI W
XII-8
oss-section of mo-Triassic So This Structurxploration.
ature for oil,
fields target
ic traps. N
s being gene
ing along fra
ed seismic
ntral Khorat
t formed a co
t created thi
Energy hol
quiring 3D s
3 to test co
na’s fourth la
ailand’s Min
rgy and Hes
past two year
World Shale Ga
the Khorat Baource Rock Sral Complexity
a small num
Permian ca
Natural gas
erated durin
actures and
c structure
t Basin. No
onventional
s local struc
lds several
eismic, cond
onventional
argest state-
nistry of En
ss also hav
rs.7,8
s and Shale Oil
asin, Showinghales are Disc
y may Complic
mber of con
arbonate an
likely was s
g the Early T
faults cause
time map
ote the deep
gas trap, an
cture.
license bloc
ducting bas
Permian ca
-owned petr
ergy to exp
ve interests
Resource Asses
g Conventionacontinuous, Bcate Shale Ga
nventional na
d Triassic c
sourced by
Tertiary follo
ed by extens
p and struc
p Triassic so
nd the interp
cks in the K
in modeling
arbonate targ
roleum comp
plore natura
in Khorat B
ssment
al Block as
atural
clastic
older
owing
sional
ctural
ource
preted
Khorat
, and
gets.6
pany,
l gas
Basin
XXII. Thaila
June, 2013
Figure XXDeep Tria
Source: Sal
1.2 R
T
occur at
depth-sc
prone to
basinal s
Permian
producin
S
depths b
thermally
Early Pe
marine s
depth ra
The calc
shale tar
nd
XII-6. Seismicassic Source
amander Energy
Reservoir P
Thick, organ
prospective
reened area
over-matur
sedimentary
carbonate
g gas fields.
Shallow mari
below 13,00
y over-matu
ermian Nam
sediments, in
nges from 8
culated vitrin
rget that is u
c Structure TimRock “Kitchen
y PLC.
Properties
ic-rich sourc
e depth in t
as is not po
re, with little
y conditions,
and Triass
.
ine shales a
00 feet.9 H
re and not
Duk Forma
ncluding som
8,000 to mo
nite reflectan
nlikely to be
XX
me Map and Inn”, Anticlinal
(Prospecti
ce rock sha
the Khorat
ossible with
e or no liqu
, these sha
sic clastic r
also occur in
However, ba
prospective
ation contain
me organic-
re than 10,0
nce is over 2
prospective
EIA/ARI W
XII-9
nterpretation Fold, and Inte
Faults.
ive Area)
ales and ca
Basin, altho
current data
uids potentia
les are thou
eservoirs o
n the Carbo
asin maturit
for shale g
ns several t
-rich shale.
000 feet and
2.5%, thus t
e for liquids.
World Shale Ga
of Small Gas erpreted Clock
arbonates of
ough mappi
a. These sh
al. Deposite
ught to hav
f this regio
oniferous Si
ty modeling
gas develop
thousand fe
TOC repor
d the format
the Nam Du
s and Shale Oil
Field in the Kkwise Rotation
f Permian a
ng the loca
hales are th
ed under sh
ve sourced
on, including
That Forma
estimates
ment (Ro of
eet of contin
rtedly can e
tion often is
uk Fm is a
Resource Asses
horat Basin. n along Strike
and Triassic
ation and siz
hermally dry
hallow marin
the convent
g two signif
ation, typica
that this u
f 3 to 4%).
nental to sh
exceed 3%,
s over-press
potential dry
ssment
Note e-Slip
c age
ze of
y-gas-
ne to
tional
ficant
ally at
nit is
The
hallow
while
sured.
y gas
XXII. Thaila
June, 2013
F
identified
thickness
within the
liquids po
1.3 R
A
suitable d
developm
Triassic
available
suitable
these pa
shale pla
A
Permian
depositio
clay), TO
0.6 vs 0.
and fault
Basin Wo
the analo
T
average
is discon
be rigoro
(~1,750 m
much les
extent, th
ARI assu
nd
luvial and
d as petroleu
s. The Kuc
e basin. Th
otential (Ro>
Resource A
As discussed
depth and th
ment. Additi
Kuchinarai F
e data on th
thickness, d
arameters we
ays that have
A good North
Basin, We
onal setting
OC content (
7 psi/ft for th
ed than the
olfcamp is le
ogy is imperf
The Nam Du
TOC, and fa
tinuously pr
ously mappe
mi2). Net o
ss than 20%
he pressure
umed 6% po
lacustrine d
um source ro
hinarai Grou
hermal matu
> 2.0%).
Assessmen
d above, the
hermal matu
ional shale g
Fm, but thes
he Khorat B
depth, TOC,
ere estimate
e been more
h American a
est Texas.1
(shallow ma
(average 3%
he Wolfcam
Permian Ba
ess thermall
fect.
uk Fm is we
alls within th
esent within
ed due to la
organic-rich s
of formation
gradient wa
orosity based
XXI
deposits of
ocks in the K
up reportedl
urity modelin
nt
Permian Na
urity and app
gas potentia
se were not
Basin is not
, thermal m
ed and augm
e thoroughly
analog for th10 These
arine), thickn
%), over-pres
p). The Kho
asin but the d
ly maturity, r
ll over 1,000
he dry-gas th
n the basin d
ack of data b
shale thickn
n thickness.
as assumed
d on the Wol
EIA/ARI W
II-10
the Triass
Khorat Basin
y averages
ng suggests
am Duk For
pears to be t
al may exist
assessed d
t sufficient t
aturity, and
mented by a
studied.
he Nam Duk
formations
ness (>1,000
ssuring (unc
orat Basin a
difference is
ranging from
0 ft thick, w
hermal matu
due to uplift a
but is assum
ess also is u
Known to b
to be 0.6 ps
lfcamp analo
World Shale Ga
sic Kuchinar
n, with high-
a prospecti
it reaches t
rmation cont
the most pro
in other orga
due to lack o
to constrain
prospective
nalogs with
k Fm could b
share sim
0 ft), litholog
certain in the
ppears to be
s not extreme
m the black
ith reported
urity window
and erosion
med to be 5
uncertain bu
be over-pres
si/ft, slightly
og.
s and Shale Oil
rai Group
-TOC interva
ive 6,500 to
the dry gas
tains organic
ospective tar
anic-rich sha
of data. Th
n the region
e area. Av
commercia
be the Wolfc
milar age (L
gy (high in c
e Khorat bu
e structurally
e. Furtherm
oil to wet ga
average 9,0
(Ro > 2.5%
. Prospectiv
5% of the K
ut is assume
ssured but n
below the W
Resource Asses
also have
als of unrep
7,000 feet
window, wi
c-rich shales
rget for shale
ales, such a
e limited pu
nal distributio
verage value
l North Ame
amp Shale i
Lower Perm
carbonate, lo
ut assumed
y more defo
more, the Per
as windows,
000 ft depth
). The Nam
ve area coul
horat Basin
ed to be 200
ot known to
Wolfcamp an
ssment
been
ported
deep
th no
s with
e gas
as the
ublicly
on of
es for
erican
in the
mian),
ow in
to be
ormed
rmian
, thus
h, 3%
m Duk
ld not
area
0 feet,
what
nalog.
XXII. Thaila
June, 2013
B
estimated
recovera
and map
Basin.
1.4 R
N
2. CEN
2.1 In
T
including
Praya Ri
like the
discontin
The pro
Petchabu
T
Miocene
deposited
appear to
which m
discontin
S
punctuat
were dep
Middle M
sediment
some are
nd
Based on the
d to have
ble shale ga
p these para
Recent Activ
No shale gas
TRAL PLA
ntroduction
Thailand’s Ce
g the Bangko
ver. Coveri
Khorat but
nuous half-g
vince includ
un petrolifero
The Central
sandstone
d shales, wh
o have Thai
ay be ident
nuous nature
Similar to m
ed by period
posited durin
Miocene, de
ts were the
eas, up to 26
ese data and
22 Tcf of
as resources
ameters and
vity
s activity has
AINS BASIN
n and Geo
entral Plains
ok region an
ing a 25,000
rather com
rabens of T
des the pro
ous sub-bas
Plains Bas
reservoirs a
hich are orga
land’s best p
tified by fut
e of the sub-
most of Tha
ds of extens
ng Oligocen
epositing int
n deposited
6,000 feet of
XXI
d assumption
risked shal
s, Table XXI
d estimate t
s been repor
N
logic Setti
s Basin is l
nd the highly
0-mi2 area, t
mprises a n
Tertiary age,
ominent Ph
sins, among
sin is oil-pro
as well as p
anic-rich an
potential for
ure work a
basins.
iland’s basi
sion and sub
ne to Early M
terbedded f
towards th
f Cenozoic s
EIA/ARI W
II-11
ns, the Nam
e gas in-pl
II-1. More d
the full shal
ted in Thaila
ng
ocated in th
y productive
the Central P
number of
formed due
hitsanulok, S
others.
one and cu
pre-Tertiary
d considere
shale oil ex
re likely to
ins, the stru
bsequent ero
Miocene tim
luvial sands
e end of th
strata have b
World Shale Ga
m Duk Forma
lace, with 5
detailed stud
le gas reso
and’s Khorat
he south-ce
e rice-growin
Plains Basin
small, deep
e to transpre
Suphan Bu
urrently prod
fractured gr
d the primar
xploration. H
be limited
uctural histo
osion. Lacu
me.11 An act
stones and
he Tertiary a
been preserv
s and Shale Oil
ation in the K
5 Tcf of ris
dy is recomm
urce potent
t Plateau.
entral portion
ng regions o
n is not a co
p, north-sou
essional pul
uri, Kampha
duces oil fr
ranites. Mio
ry source ro
However, sh
in size, refl
ory of the
ustrine shale
tive margin
mudstones
and into the
ved.
Resource Asses
Khorat Basin
sked, techn
mended to d
ial of the K
n of the cou
of the lower
ontinuous de
uth trending
ll-apart tecto
aeng Saen,
om convent
ocene lacus
ocks in this b
hale oil pros
lecting the
Central Pla
es and sedim
developed i
s. Alluvial-f
e Quaternary
ssment
n was
nically
define
Khorat
untry,
Chao
eposit
g and
onics.
and
tional
strine-
basin,
pects
small
ain is
ments
n the
fluvial
y. In
XXII. Thaila
June, 2013
M
conventio
Phitsanu
productio
The oil is
the S1 fie
next 10 y
while co
advanced
In
Miocene
equivalen
These ty
indices re
rich sha
Chumsae
feet. Oil
large ran
F
Central B
the Cent
within th
Clastic ro
under all
by Late M
Himalaya
F
Phitsanu
main sou
Saeng G
Significa
nd
Middle Mioce
onal target
lok Basin. T
on in the ea
s inferred to
eld from Tha
years. Duri
ntinuing to
d drilling and
n the Phitsa
Chumsaeng
nt sediments
pe I/II sourc
eaching ove
le interval o
eng and Ear
generation
nge in therma
igure XXII-7
Basin. Oligo
tral Basin, re
e Oligocene
ocks of the
uvial plains
Miocene to
an Orogeny.
igure XXII-8
lok Basin, o
urce rocks a
Group, which
nt normal fa
ene sandsto
in the variou
Thailand’s la
arly 1980’s,
have been s
ai Shell in 20
ing Q3-2012
drill new de
d exploration
anulok Basin
g Fm, which
s are also no
ce rocks disp
er 700 mg H
of at least
rly Miocene
depths in th
ally mature d
7 illustrates
ocene Nong
est unconfo
e to Early M
Oligocene L
settings, are
Recent allu
8 shows a w
one of nume
are fluvial to
h appear to
ulting may h
XXI
ones (and m
us Central P
argest onsho
with over 2
sourced from
003 and plan
2 PTTEP pr
evelopment
n techniques
n, the main
h was depos
oted in the S
play high to v
C/g.14 Gros
600 feet.
lacustrine s
he smaller S
depths for liq
the stratigr
g Bua and S
ormably on p
Miocene Ch
Lan Krabur a
e the conve
vial fan dep
west-east or
erous sub-b
lacustrine s
be disconti
hinder shale
EIA/ARI W
II-12
more recently
Plains sub-b
ore oil field,
50 wells dri
m the underl
ns to extract
roduced an
wells there.
s.12
organic-ric
sited in a de
Suphan Buri
variable TOC
s thickness
In the dee
shales may r
Suphan Buri
quids produc
raphy and c
Sarabop form
pre-Tertiary
hum Saeng
and Miocene
ntional rese
posits source
riented, unin
basins within
shales within
inuously pre
oil developm
World Shale Ga
y pre-Tertia
basins, such
the Sirikit (n
illed and 17
lying lacustr
t an addition
average 30
. PTTEP’s o
h lacustrine
eep lake en
and other s
C (average >
averages 1
eper parts o
reach maxim
Basin avera
ction.
conventiona
mations, the
basement.
Group act
e Pratu Nam
ervoir targets
ed by region
nterpreted se
n the overal
n the Oligoc
esent on top
ment in this
s and Shale Oil
ary granites)
h as at Sirik
now called S
70 MMBO p
rine shales.
nal 40 to 50
,000 b/d of
onshore foc
e shales com
nvironment.
ub-basins, u
>2.0%13), wi
,300 feet, w
of Central P
mum depths
age 7,000 fe
al petroleum
oldest sedi
Fluvial to
as the ma
m Nan forma
s. These in
nal uplift ass
eismic time
l Central Pla
cene to Early
p of pre-Mio
basin.
Resource Asses
) are the pri
kit field withi
S-1) comme
roduced to
PTTEP acq
MMbbls ove
oil from Sir
cus has bee
mprise the
Stratigraph
usually unna
ith high hydr
ith a net org
Plain basins
of nearly 15
eet, suggest
m systems o
mentary roc
lacustrine s
ain source r
ations, depo
turn are ove
sociated wit
section from
ains Basin.
y Miocene C
ocene basem
ssment
imary
n the
enced
date.
quired
er the
ikit-1,
en on
Early
hically
amed.
rogen
ganic-
s, the
5,000
ting a
of the
cks in
hales
rocks.
osited
erlain
th the
m the
The
Chum
ment.
XXII. Thaila
June, 2013
Figure XXwithin thClastics
Figure XXThe Main
Group
Source: Tha
nd
XII-7. Stratigrahe Oligocene ts of the Oligoc
XII-8. West-Ea Source Rock
p, Discontinuo
ailand Ministry of
aphy and Petroto Early Miocecene Lan Krab
Source: Tha
st Seismic Tims are Fluvial t
ously Present
f Energy, 2007
XXI
oleum Systemene Chum Saebur and Mioce
iland Ministry of
me Section in to Lacustrine Son Top of Pre
EIA/ARI W
II-13
ms of Thailandeng Group areene Pratu Nam
f Energy, 2007
the PhitsanulShales within
e-Miocene Bas
World Shale Ga
d’s Central Base the Main Sou
m Nan Formati
lok Sub-basin the Oligocen
sement. Note
s and Shale Oil
sin. Fluvial tource Rocks, wons are Conv
n within the Cee to Early Mio
e Significant N
Resource Asses
o Lacustrine Swhile Alluvial Pventional Targ
entral Plains Bocene Chum SNormal Faultin
ssment
Shales Plain ets.
Basin. Saeng ng.
XXII. Thaila
June, 2013
3. NOR
3.1 In
T
north-cen
quite unl
numerou
Several o
conventio
In additio
small-sca
thermally
map this
M
more pr
Intermon
900 mi2,
Gently u
averages
T
having th
units ove
basins a
formation
H
geologist
an oil sh
conducte
Division
nd
RTHERN IN
ntroduction
Thailand’s N
ntral and no
ike the relat
us small an
of these pul
onal sandsto
on, solid oil
ale mining d
y more matu
due to very
Mae Sot Sub
rominent in
ntane region
with one-thi
ndulating h
s about 650
The Mae Sot
he thickest s
erlying Perm
and half gra
ns, the latter
Hydrocarbon
ts in the late
hale reserve
ed feasibility
has renewed
NTERMONT
n and Geo
orthern Inte
rthwestern p
tively continu
nd complete
l-apart basin
one reservoi
shale miner
development
ure and con
sparse data
b-Basin. T
ntermontane
. This nort
rd of the are
ills and allu
feet above s
t Basin is div
sedimentary
ian to Juras
abens. Th
r recognized
exploration
e 1930’s. In
e evaluation.
y analyses o
d its researc
XXI
TANE BAS
logic Setti
ermontane B
portions of t
uous Khorat
ely isolated
ns, such as
irs that were
ral resource
t. These or
ntain mobile
a control.
The Mae Sot
e basins in
h-south tren
ea extending
vial plains c
sea level.
vided into no
y section. It
sic carbonat
hese units i
for its oil sh
n of the M
n 1947 Thail
. During th
of the oil sha
ch on Thailan
EIA/ARI W
II-14
IN
ng
Basin is a la
he country.
t Basin, the
structural t
the Fang B
e sourced by
s near the s
rganic-rich la
oil in the d
t Sub-basin
n this topo
nding basin
g across the
comprise th
orth and sou
contains m
te and clasti
nclude the
hale deposits
Mae Sot Ba
land’s Depa
e 1980’s, th
ale potentia
nd’s oil shale
World Shale Ga
arge loosely
Similar to t
Northern Int
troughs tha
Basin, produ
y organic-ric
surface in th
acustrine-de
deeper troug
of northwe
ographically
extends ov
e Moei River
he topograph
uth sub-bas
mainly non-m
ic rocks that
Mae Rama
s.
asin began
artment of M
he German
l. Since 20
e deposits.
s and Shale Oil
y defined a
the Central
termontane
at are sepa
ce oil in ant
ch Miocene l
he Mae Sot
eposited sha
ghs, althoug
stern Thaila
y mostly r
er an area
into Myanm
hy of the ba
ins, with the
marine Cenoz
t were depos
at, Mae Pa
with Swiss
Mineral Reso
and Japane
000 Thailand
Resource Asses
rea covering
Plains Basin
Basin comp
arated by u
ticlinal traps
acustrine sh
Basin are u
ales may bec
gh ARI coul
and is one o
ugged Nor
of approxim
mar on the w
asin itself, w
e southern re
zoic sedime
sited in pull-
a, and Mae
s and Japa
ources condu
ese governm
d’s Mineral F
ssment
g the
n and
prises
plifts.
from
hales.
under
come
d not
of the
rthern
mately
west.15
which
egion
entary
-apart
e Sot
anese
ucted
ments
Fuels
XXII. Thaila
June, 2013
F
located
containin
a steep m
an avera
througho
first com
Figure XXwithin th
Clasti
Source: Tha
D
Himalaya
sediment
younger
undiffere
the sedim
T
Fang an
claystone
in an allu
layers wi
nd
ang Sub-B
about 150
ng Cenozoic
mountain ran
age elevatio
out the half-g
mercial oil fi
XII-9. Stratigrahe Oligocene tcs of Oligoce
ailand Ministry of
During the e
an collision
ts were dep
alluvium a
entiated grav
mentary seq
The stratigra
d underlying
e occur in th
uvial-fluvial e
ithin the Mae
asin. The
km north o
sediments,
nge to the ea
on of 1,500
graben, evid
eld, over 24
aphy and Petroto Early Miocene Lan Krabu
f Energy, 2007
arly Tertiary
opened up
posited durin
and marked
vels, sands, s
uence reach
phy of the T
g Mae Sot
he Late Mioc
environment
e Sot Forma
XXI
crescent-sh
of Chiang M
Figure XXII
ast. The Fan
feet above
denced by ho
0 wells have
oleum Systemene Chum Saer and Miocene
y, extension
the basin.
ng the Eoce
by a sign
soils, and cl
hes 10,000 f
Tertiary rock
formations.
cene to Pleis
and averag
ation have b
EIA/ARI W
II-15
aped Fang
Mai, is a f
I-9. The 220
ng Basin is g
e sea level.
ot springs in
e been drille
ms of Thailandeng Group aree Pratu Nam N
al faults and
Syn-rift seq
ene to Mioc
nificant unco
ays of Quate
ft.
ks generally
Interbedde
stocene Mae
e 1,400 feet
been the prin
World Shale Ga
Sub-basin
fault-bounde
0-mi2 trough
generally fla
.16 A high
n the northe
ed to date in
d’s Central Base the Main SouNan Formation
d rifting ass
quences of
cene, followe
onformity.
ernary to Re
can be div
ed coarse s
e Fang Form
t thick. Belo
nciple reserv
s and Shale Oil
in the far n
ed intermont
h trends NW
at with slightl
geotherma
rn region. S
the Fang Su
sin. Fluvial tource Rocks, wns are Conven
sociated with
alluvial-fluvi
ed by post-r
Overlying t
ecent age. T
ided into tw
sandstone a
mation; these
ow this unit,
voirs for con
Resource Asses
orth of Tha
tane depoc
W-SE and bo
ly rolling hills
l gradient e
Site of Thaila
ub-Basin.
o Lacustrine Swhile Alluvial Pntional Target
h the Indian
al and lacus
rift sequenc
these rocks
Total thickne
wo units, the
nd red to y
e were depo
fluvial sands
ventional oi
ssment
iland,
center
orders
s and
exists
and’s
Shales Plain s.
n and
strine
ces of
s are
ess of
Mae
yellow
osited
stone
l field
XXII. Thaila
June, 2013
productio
productiv
Chaiprak
lacustrine
oil explor
3.2 R
M
conglome
Tertiary s
maximum
Oligocen
and mar
deposits
low-TOC
Mae Pa
undeterm
T
which is
relatively
maximum
calcite, d
lacustrine
mainly of
weight).
typically
Formatio
0.7% thre
F
into three
lacustrine
claystone
nd
on in the ba
ve locale, th
karn were ab
e mudstones
ration target
Reservoir P
Mae Sot Su
erate, sand
strata.17 Th
m total dept
ne Mae Pa F
ls, along wi
can occur w
C strata. The
formations
mined shale
The most org
dominated
y thin (10 t
m thickness
dolomite, a
e oil shale
f exinite, wit
Oil shale g
about 2,000
on appears t
eshold.
ang Sub-Ba
e units: a lo
e claystone,
e, mudstone
sin, beginni
he Fang Ba
bandoned in
s and shales
within the F
Properties
b-Basin. T
dstone, lime
he Mae Ram
th of availa
Formation, w
th prevalent
within the 30
e Mae Pa F
are not con
thickness an
ganically rich
by shale wit
to 15 feet)
can exceed
nd clay (pr
deposits are
h immobile o
grade is hig
0 feet deep
too shallow a
asin. The M
ower section
, shale, and
e, and sands
XXI
ng in the 19
asin has yi
n the mid 19
s within the
Fang Basin.
(Prospecti
The Paleoce
estone, and
mat Fm is up
ble well da
which conta
t limestone
00-ft thick M
Fm averages
nsidered via
nd low therm
h shale in the
th minor clas
oil shales
d 33 feet.
roportions n
e grey to gr
oil content ra
hest in the
p across mu
and immatu
Mae Sot Fo
n of brown t
d coal with i
stone along
EIA/ARI W
II-16
920’s. As th
ielded six o
80’s. These
Mae Sot Fo
ive Area)
ene Mae Ra
mudstone
p to 700 fee
ata). Overly
ins lacustrin
lenses in th
ae Pa Fm, a
s about 3,00
able source
mal maturity.
e Mae Sot B
stics. One
beds within
Rock miner
not reported
reen and ne
anging from
middle-lowe
uch of the M
re for shale
rmation of M
to reddish sa
nterbedded
with fossil i
World Shale Ga
he Northern
oil fields, al
e reservoirs
ormation itse
amat Forma
units that
et thick and
ying the Ma
ne and fluvia
he southern
albeit interbe
00 ft deep. O
rocks due
Basin is the M
interval with
n sandy sh
ralogy is dom
d). In the
early 100 fe
2.5 to 62 ga
er section of
Mae Sot Ba
oil develop
Miocene to P
andstone; a
sandstone;
inclusions.
s and Shale Oil
Intermonta
lthough the
apparently
elf, most like
ation contain
unconforma
deeper than
ae Ramat F
al deposits,
sub-basin.
edded with
Overall, the
to lack of o
Miocene Ma
hin the Mae
hale assemb
minated by
northern s
eet thick. K
allons per to
f the unit. T
asin. Overa
ment, with R
Pliocene ag
a middle zon
and an upp
The conven
Resource Asses
ne region’s
Pong Nok
were source
ly the main s
ns mostly al
ably overlie
n 3,300 feet
Fm is the U
including s
Minor oil s
large amoun
Mae Rama
organic rich
ae Sot Forma
Sot Fm con
blages, alth
quartz, feld
sub-basin, t
Kerogen con
on (1% to 26
This formati
all, the Mae
Ro well below
e can be div
ne of organic
per layer of
ntional sands
ssment
most
k and
ed by
shale
luvial
pre-
t (the
Upper
hales
shale
nts of
at and
ness,
ation,
ntains
hough
dspar,
these
nsists
6% by
ion is
e Sot
w the
vided
c-rich
f gray
stone
XXII. Thaila
June, 2013
reservoir
16 to 38
T
calculate
be up to
feet thick
feet, but
history m
minimum
of the Fa
prospect
REFERE
1 U.S. Energ
2 PTTEP, ne
3 Polachan, p.
4 KoysamraDepartmePetroleum
5 Schenk, CSurvey, 72
6 Salamandmention th
7 Coastal En
8 Hess Corp
9 Departmen
10 FairhurstGeologic Search an
11 Ronghe, Suphan B
12 PTTEP, 2
13 Patience,Evolution
nd
rs have 25%
degrees AP
The rich bitu
ed total orga
2,100 feet,
k (net). The
these likely
modeling su
m depth for m
ang Basin a
ive area give
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