Chris Schenk Bangkok SPE 2010 3
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U.S. Department of the InteriorU.S. Geological Survey
Assessment of UndiscoveredOil and Gas Resources of
Southeast AsiaChristopher J. Schenk
U.S. Geological SurveyDenver, Colorado USA
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USGS World Resources Project
Purpose: assess the potential forundiscovered conventional and
unconventional resources in basins worldwide
SE Asia: 23 basins, assessed for conventional
oil and gas resources Unconventional resource plays- some defined
but not assessed at this time
Shale gas, tight gas, coal-bed gas, shale oil,tight oil
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Conventional vs Unconventional
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Conventional Resource Summary
23 basins
Undiscovered oil mean: 21.6 BBO
Undiscovered gas mean: 299 TCFG
Oil (BBO): 8.9 (F95)—21.6 (Mean)—41.6 (F5)
Gas (TCF): 129 (F95)—299 (Mean)—557 (F5)
Ranges reflect geologic uncertainty
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Undiscovered Oil Resources-Means
Baram-Brunei Basin: 4.2 BBO
Kutei Basin 3.2 BBO
South China Sea 2.5 BBO Cuu Long Basin 1.7 BBO
Thai Basin 1.2 BBO NW Java Basin 0.7 BBO
Nam Con Son 0.68 BBO
Malay Basin 0.66 BBO
Greater Sarawak 0.64 BBO
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Undiscovered Gas Resources-Means
Kutei Basin 46 TCF
Greater Sarawak 38 TCF
East Java 32 TCF
Baram-Brunei 26 TCF
South China Sea 25 TCF
Thai Basin 15 TCF
Nam Con Son 14 TCF
Phu Khahn 13 TCF
Song Hong 12 TCF
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Offshore:
92% of oil resources
93% of gasresources
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Assessment Methodology
Convert geologic knowledge into volumes ofundiscovered resources
Geologic model for assessment Review process (CORE)
Distribution of Sizes of undiscovered fields
Distribution of Numbers of undiscoveredfields above a minimum size
Deposit simulation, prospects/risk, discoveryprocess, geologic analogs
Monte Carlo simulation
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Geologic Analogs
Database of geologic and production data for250+ assessment units of the world
Conventional resources only
Query geologic characteristics
Field size distributions; largest field sizes Density of fields per area for a given
minimum field size, for given geologic
parameters
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PattaniTrough
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Pattani Trough- Geologic model for
assessment
Oil and gas generated from Oligocene
lacustrine shales and Miocene shalesmigrated into fluvial, deltaic and alluvialreservoirs within rift and post-rift sag
structures; most gas in post-rift structures(open, gently dipping, faulted anticlines)
Known: 23 oil fields; 24 gas fields
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Pattani Trough- Geologic model for
assessment
Numbers: Oil: 1-30-60: Gas; 1-40-80
Sizes: Oil; 5-15-200: Gas; 30-100-2000
MEL: Oil; 80 MMBO; Gas; 800 BCFG
Largest fields found; going to smaller sizes
Exploration at mid-maturity
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Pattani Trough- assessment
Oil (BBO): 0.39 (F95)- 0.63 (mean)-0.95 (F5)
Gas: (TCFG): 6 (F95)- 10.3 (mean); 15 (F5)
Largest fields found; going to smaller sizes
Exploration at mid-maturity
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MalayBasin
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Malay Basin-Tho Chu AU-geologic
model for assessment
Oil and gas generated from Oligocene
lacustrine shales and Miocene marginalmarine shales in the Late Miocene migratedvertically into synrift alluvial-fluvial, deltaicand shallow marine reservoirs, and postriftmarine, shallow to deep water clastic
reservoirs
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From Maynard and others, 2002
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Khmer Trough AU-geologic model
for assessment
Oil and gas generated from Oligocene
lacustrine shales and Miocene marginalmarine shales in the Late Miocene migratedvertically into synrift alluvial-fluvial, deltaicand shallow marine reservoirs, and postriftmarine, shallow to deep water clastic
reservoirs; inversion of traps in Late Miocene
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Malay Basin
Main Malay-Tho Chu AU
Numbers: Oil: 1-40-90; Gas: 1-70-160
Sizes: Oil: 1-6-200; Gas: 6-48-3000
MEL: Oil: 70 MMBO; Gas: 1000 BCFG
Khmer Trough AU Numbers: Oil: 1-13-40; Gas: 1-15-50
Sizes: Oil: 1-6-500; Gas: 6-36-3000 MEL: Oil: 80 MMBO; Gas: 500 BCFG
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Malay Basin- assessment
Main Malay-Tho Chu AU
Mean Oil: 0.45 BBO; Mean Gas: 10 TCFG
MEL: 70 MMBO; Gas: 1000 BCFG
Khmer Trough AU
Mean oil; 0.2 BBO: Mean gas; 2.3 TCF MEL: Oil: 80 MMBO: Gas: 500 BCFG
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O h Rif B i AU l i
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Onshore Rift Basins AU- geologic
model for assessment Oil and gas generated from lacustrine source
rocks migrated into synrift and possibly post-rift reservoirs; traps mainly related to faciesagainst bounding faults; rifts are complex,
many fault compartments resolved onseismic
Unconventional reservoirs??
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O h Rift B i AU l i
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Onshore Rift Basins AU- geologic
model for assessment Numbers: Oil: 1-50-150; Gas: 1-10-30
Sizes: Oil: 1-3-250; Gas: 6-18-800
MEL: Oil: 180 MMBO; Gas: 250 BCFG
Not well explored, but clearly going to small
field sizes; Oil vs gas (modeling); fielddefinition
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Onshore Rift Basins AU- assessment
Oil (BBO): 0.16 (F95)-0.4 (mean)-0.7 (F5)
Gas (TCFG): 0.2 (F95)-0.6 (mean)-1.3 (F5)
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Khorat
Plateau
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Permian Carbonates AU geologic
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Permian Carbonates AU- geologicmodel for assessment
Gas generated from Triassic source rocksin the Paleogene (following Cretaceous
burial) migrated along faults associatedwith rift basins and into karst or fracturedcarbonate platform reservoirs of thePermian, or Triassic clastics; AU relatedto distribution of Triassic rifts in the
Khorat Plateau; rifts considered to extendthroughout plateau
171,000 square kilometers
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Permian Carbonates AU geologic
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Permian Carbonates AU-geologicmodel for assessment
Numbers: Gas: 1-40-120 BCFG
Sizes: Gas: 3-12-1000 BCFG
MEL: 300 BCFG
Assessment (TCFG): 0.5 (F95)- 1.3 (mean)-2.4 (F5)
Khorat Group Sandstones AU
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Khorat Group Sandstones AU-geologic model for assessment
Gas generated from Triassic source rocks
in the Paleogene migrated vertically alongfaults into Cretaceous low- and high-sinuosity fluvial sandstones within theregional fluvial distributary system thatformed across the Khorat plateau;
regional salt seal
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Khorat Group Sandstones AU
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Khorat Group Sandstones AU-geologic model for assessment
Numbers: Gas: 1-20-80
Sizes: Gas: 3-12-1000 BCFG
MEL: 200 BCFG
Assessment (TCFG): 0.1 (F95)- 0.66(mean)-1.5 (F5)
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SongHong
Basin
Song Hong Basin geologic model for
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Song Hong Basin-geologic model forassessment
Oil and gas generated from rift-relatedlacustrine shales, deltaic coals, and mirine
shales in the Late Miocene-Pliocene migratedup faults into synrift includes alluvial-fluvial,deltaic, and lacustrine clastics, and post-rift
nearshore marine, shelf, to slope and basin-floor fan clastics and carbonates onstructural highs; extensional structuresinverted along RRFZ on Late Miocene
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From Dang, 1997
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Song Hong Basin
Numbers: Oil; 1-10-30; Gas: 1-90-250
Sizes: Oil: 5-12-300; Gas: 30-72-2000
MEL: Oil: 60 MMBO; Gas: 900 BCFG
Largest fields found; early in explorationhistory; mainly gas; geologic analog for PhuKhanh Basin
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Song Hong Basin- assessment
Oil (BBO): 0.08 (F95)-0.2 (mean)- 0.4 (F5)
Gas (TCFG): 6 (F95)- 12 (mean)- 20 (F5)
Largest fields found; early in explorationhistory; mainly gas; geologic analog for PhuKhanh Basin
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From Fyhn and others, 2009
Phu Khanh Basin-geologic model for
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Phu Khanh Basin geologic model forassessment
Oil and gas generated from rift-relatedlacustrine shales, deltaic coals, and mirine
shales in the Late Miocene-Pliocene migratedup faults into synrift includes alluvial-fluvial,deltaic, and lacustrine clastics, and post-rift
nearshore marine, shelf, to slope and basin-floor fan clastics and carbonates onstructural highs; extensional structuresinverted along RRFZ on Late Miocene
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Phu Khahn Basin
Paleogene-Neogene Reservoirs AU; frontierarea, no discoveries
Mean oil; 0.2 BBO: Mean gas; 13 TCF
Reservoirs include synrift fluvial, alluvial and
lacustrine; post-rift deltaic to deep waterclastics; platform margin carbonates
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DangerousGrounds
AU
G
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Dangerous Grounds AU
Oil and gas generated from Late Eocene toOligocene lacustrine and marine shales in the
Late Miocene to Pliocene migrated intoextensional structures and stratigraphic trapswith reservoirs ranging from deltaic to deep
water clastics and platform margincarbonates
Seals a source of significant risk?
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From Thies and others, 2006
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From Thies and others, 2006
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23 basins
Mean oil: 21.6 BBO
Mean gas: 299
TCFG
Offshore potentialsignificant
U ti l
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Unconventional resources
Screening for coal-bed gas, shale gas, tightgas, shale oil
Less opportunity here with most of resourceoffshore
US analogs for assessment purposes
M i f ti
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More information:
USGS Fact Sheet 2010-3015