Locations of 23 provinces of southeast Asia assessed in this study
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Figure 1. Locations of 23 provinces of southeast Asia assessed in this study. Thai Basin Penyu-West Natuna Basin
Malay Basin Sulu Sea Basin Palawan Shelf Basin
Khorat Plateau Thai
Cenozoic Basins
Cuu Long Basin Nam Con Son Basin
Baram Delta/ Brunei-Sabah Basin South China Sea Platform Greater
Sarawak Basin Kutei Basin North Sumatra Basin Central Sumatra Basin South Sumatra
Basin Song
Hong Basin Phu
Khanh Basin
Northwest Java Basin East Java Basin Barito
Basin Tarakan
Basin 3605 Palawan Shelf Hanoi Manila
Jakarta Bangkok
Rangoon Singapore Vientiane Phnom Penh Kuala Lumpur 120°E
110°E 100°E
20°N 10°N
0° 10°S
Sulu Sea Gulf of Thailand Java Sea Andaman Sea South China Sea Celebes Sea Indian Ocean MALAYSIA
BRUNEI PHILIPPINES BORNEO SULAWESI
MALAYSIA SUMATRA
JAVA AUSTRALIA CHINA THAILAND
BURMA VIETNAM
CAMBODIA LAOS
Indian Ocean Southeast Asia Assessment Area I N
D O N E S I A 0
500 Kilometers 0 125 250 Miles Explanation Assessed Provinces C H I N A Pearl River Mouth Basin U.S. Department of the Interior U.S. Geological Survey Fact Sheet 2010–3015 June 2010 World Petroleum Resources Assessment Project Assessment of Undiscovered Oil and Gas Resources of Southeast Asia, 2010 Printed on recycled paper Using a geology-based assessment methodology, the U.S. Geological Survey estimated a mean of 21.6 billion barrels of oil and a mean of 299 trillion cubic feet of undiscovered natural gas in 23 provinces of southeast Asia. Introduction The U.S. Geological Survey (USGS) assessed the potential for undiscovered conventional oil and gas fields within geologic provinces of southeast Asia as part of the USGS World Petroleum Resources Assessment Project (fig. 1). Twenty-three provinces were assessed in this study (table 1), including provinces entirely or partially within Thailand, Laos, Cambodia, Vietnam, Myanmar, Malaysia, Indonesia, Brunei, China, and Philippines. Many of the oil and gas basins within these geologic provinces originated as extensional basins that evolved into a post-rift thermal subsid- ence phase, which is characterized by carbonate platform deposits or prograd- ing clastic wedges typical of passive mar- gins. This simple sketch does not reflect the complexity of the tectonic history in southeast Asia, which has included rift- ing and attenuation of continental crust, opening and closing of ocean basins, development of regional fault systems and associated structures, collision and suturing of terranes, formation of accre- tionary prisms and local uplifts (Morley, 2001, 2002; Hutchinson, 2004; Hall and others, 2008). Petroleum systems in provinces of southeast Asia reflect the complex tectonic evolution, but generalities can be made concerning the origin of oil and gas in what are mainly Cenozoic basins (Todd and others, 1997; Doust and Sum- ner, 2007; Hall, 2009). Petroleum source rocks mainly are synrift deep-basin lacustrine and marginal lacustrine shales; post-rift marginal marine to marine coaly mudstones, coals, and marine shales (Todd and others, 1997). Oil predominantly is gen- erated from synrift lacustrine shales, whereas gas is generated from the post-rift coaly mudstones, coals, and shales, and by cracking of earlier-formed oil. As gas generation Table 1. Southeast Asia assessment results. [MMBO, million barrels of oil. BCFG, billion cubic feet of gas. MMBNGL, million barrels of natural gas liquids. Results shown are fully risked estimates. For gas accumula- tions, all liquids are included as NGL (natural gas liquids). Undiscovered gas resources are the sum of nonassociated and associated gas. F95 represents a 95-percent chance of at least the amount tabulated; other fractiles are defined similarly. AU, assessment unit. AU probability is the chance of at least one accumulation of minimum size within the AU. TPS, total petroleum system. Gray shading indicates not applicable. Largest expected oil field size in MMBO; gas field size is in BCFG]
AU prob- ability Field
type Largest
expected field size Total Undiscovered Resources Oil (MMBO) Gas (BCFG) NGL (MMBNGL) F95 F50 F5 Mean F95 F50 F5 Mean F95 F50 F5 Mean Pearl River Mouth Basin Province (Paleogene Lacustrine TPS) Eocene-Miocene Reservoirs AU 1.0
Oil 97 279 567 1,079
608 290
694 1,526
773 10 26 63 30
2,371 3,279
8,078 18,047 9,035
102 256
588 289
Song Hong Basin Province (Eocene-Miocene Composite TPS) Paleogene-Neogene Reservoirs AU 1.0
Oil 62 80 183 399
204 405
945 2,112
1,061 4 11 25 12
922 5,782 10,599 18,625 11,205 121 226
399 238
Phu Khanh Basin Province (Paleogene TPS) Paleogene-Neogene Reservoirs AU 1.0
Oil 107
48 166
593 223
244 854
3,152 1,162
3 9 37 13 Gas 1,955
4,268 10,679 23,532 11,878 89 226 507 253
Khorat Plateau Province (Mesozoic TPS) Permian Carbonates AU 1.0
– 0 0 0 0 0 0 0 0 0 0 0 0
279 502
1,171 2,426
1,278 3 6 14 7 Khorat Group Sandstones AU 1.0
Oil – 0 0 0 0 0 0 0 0 0 0 0 0
202 187
568 1,478
665 1 3 8 4
Syn-Rift Reservoirs AU 1.0
Oil 427
726 1,599
3,204 1,735
1,463 3,359
7,339 3,748
40 92 203 103 Gas 315
112 487
1,750 649
3 14 50 19 Nam Con Son Basin Province (Eocene-Miocene Composite TPS) Oligocene-Miocene Reservoirs AU 1.0
Oil 146
321 643
1,192 685
1,165 2,376
4,524 2,547
38 79 151 85 Gas 1,800
6,196 11,488 19,899 12,053 190
353 616
371 South China Sea Platform (Miocene TPS) Dangerous Grounds- Reed Bank AU 1.0
Oil 703
764 2,192
5,380 2,522
3,058 8,889 22,683 10,370 58 168
437 197
Gas 4,217
4,609 13,151 32,381 15,149 260
756 1,928
881 Thai Basin Province (Eocene-Miocene Composite TPS) Pattani Trough AU 1.0
80 386 615 946
634 2,406
3,939 6,200
4,071 66 109 173 113
Gas 787
3,739 6,055
9,419 6,253
148 242
379 250
Offshore Western Cenozoic Rifts AU
1.0 Oil 181
152 479
1,347 578
942 3,041
8,812 3,716
26 84 247 103 Gas 257
136 426
1,360 543
5 17 55 22 Thai Cenozoic Basins Province (Eocene-Miocene Composite TPS) Onshore Cenozoic Rifts AU 1.0
76 162 362 727
391 104
240 503
263 2 5 10 5
136 123
321 804
372 2 5 13 6
Eocene-Miocene Reservoirs AU 1.0
101
84 226
609 270
54 147
417 179
2 5 13 6 Gas 514
319 984
3,035 1,229
10 30 94 38 Tarakan Basin (Neogene TPS) Deltaic AU 1.0
38 22 64 198
81 32 96 307 123
1 3 10 4 Gas 406
573 1,310
2,803 1,447
7 16 36 18 Turbidite AU 1.0
235
100 380
1,421 516
311 1,213
4,674 1,673
10 38 151 54 Gas 2,376
2,076 6,441 17,361 7,668 24
223 95 Mangkalihat Carbonates AU 1.0
Oil 71 14 64 370
110 83 380 2,274 675
2 12 71 21 Gas 590
162 710
3,343 1,089
4 16 76 25 Sulu Sea Province (Miocene TPS) Sandakan Reservoirs AU 1.0
178
58 231
997 339
84 345
1,536 515
3 11 53 18 Gas 2,448
2,211 6,907 18,205 8,159 26
234 101
Baram Delta/Brunei-Sabah Basin Province (Brunei-Sabah TPS) Brunei-Sabah Deltaics AU 1.0
67 350 608 1,012
635 1,208
2,165 3,678
2,269 23 41 70 43
444 2,905
5,130 8,618
5,366 90 160 270 168
Brunei-Sabah Turbidites AU 1.0
Oil 551
1,766 3,448
6,180 3,643
4,866 9,900 18,563 10,581 91 188
358 202
Gas 1,352
3,384 7,515 15,100 8,159 128
290 594
316 Total Petroleum Systems (TPS) and Assessment Units (AU) AU prob- ability Field
type Largest
expected field size Total Undiscovered Resources Oil (MMBO) Gas (BCFG) NGL (MMBNGL) F95 F50 F5 Mean F95 F50 F5 Mean F95 F50 F5 Mean Greater Sarawak Basin Province (Sarawak Basin TPS) Central Luconia AU 1.0
– 0 0 0 0 0 0 0 0 0 0 0 0
2,492 11,849 20,048 32,212 20,759 318 542
878 562
Balingian AU 1.0
Oil 80 361 618 1,013
643 1,435
2,529 4,233
2,641 27 48 81 50
687 2,340
4,189 7,169
4,392 132
243 425
256 East Natuna Carbonate AU 1.0
– 0 0 0 0 0 0 0 0 0 0 0 0
1,913 4,729
9,646 18,038 10,281 126
260 494
278 Malay Basin Province (Oligocene-Miocene Composite TPS) Main Malay-Tho Chu AU 1.0
71 240 430 732
450 893
1,658 2,945
1,756 11 21 37 22
1,158 4,200
7,661 13,049 8,008
87 160
275 167
Khmer Trough AU 1.0
Oil 82 60 179 493
214 215
681 1,974
835 3 8 25 10
535 415
1,259 3,346
1,489 8 26 71 31
Barito Foredeep Structures AU 1.0 Oil 84 20 94 460
146 32 160 816 256
1 3 16 5 Gas 997
589 2,108
6,444 2,617
9 32 100 40 Central Sumatra Basin Province (Brown Shale-Sihapas TPS) Pematang/Sihapas Siliciclastics AU 1.0
Oil 14 84 142 233
148 70 133 240 141
6 12 23 13 Gas 99 85 222 562
259 2 5 12 6
East Java Carbonates AU 1.0
Oil 190
173 435
1,146 514
1,031 2,639
7,128 3,154
32 82 224 99 Gas 1,742
3,049 6,319 12,670 6,879 68
288 155
East Java Siliciclastics AU 1.0
Oil 294
633 1,400
2,816 1,522
1,310 2,925
5,984 3,192
67 151
311 165
Gas 2,358
8,286 17,078 32,285 18,264 613
1,291 2,471
1,381 Kutei Basin TPS Kutei Basin Deltaics AU 1.0
32 91 160 269
168 471
847 1,464
892 5 9 16 10
952 1,299
3,056 6,652
3,401 58 143 331 162
Kutei Basin Turbidites AU 1.0
Oil 615
1,371 2,851
5,393 3,047
9,643 20,104 38,035 21,478 101
216 423
233 Gas 2,471
11,212 19,416 31,896 20,230 187
328 546
342 North Sumatra Basin (Bampo-Cenozoic TPS) North Sumatra AU 1.0
12 48 77 119
79 288
478 763
495 5 10 17 10
183 534
934 1,570
977 36 66 121 71 Mergui Basin AU 1.0 Oil 169
71 280
1,018 374
423 1,711
6,434 2,338
8 33 137 48 Gas 1,493
2,796 6,486 13,524 7,096 188
461 1,031
516 Northwest Java Basin (Eocene-Miocene Composite TPS) Sunda-Asri Basins AU 1.0
31 90 161 274
169 152
279 495
296 5 9 16 9
100 80
581 262
0 1 3 1 Ardjuna Basin AU 1.0
46 73 152 310
166 326
692 1,487
772 12 28 64 32
378 625
1,350 2,729
1,474 15 33 71 36 Biliton-Vera Basins AU 1.0 Oil 116
136 348
797 391
606 1,588
3,818 1,819
23 63 163 74 Gas 90 8 41 408
106 0 1 10 3
Gabus-Udang-Urang Sandstones AU 1.0
24 27 66 150
74 109
284 699
329 1 4 10 5
153 598
1,048 1,754
1,094 24 43 72 45
South Sumatra AU 1.0
Oil 82 133 321 681
353 537
1,338 2,967
1,491 11 28 65 32
639 1,398
3,112 6,194
3,367 48 110 228 120
Total Conventional Resources 8,922 19,541 41,558 21,632 128,908 272,848 557,051 298,761 3,828 8,270 17,216 9,099 Table 1. Southeast Asia assessment results.—Continued [MMBO, million barrels of oil. BCFG, billion cubic feet of gas. MMBNGL, million barrels of natural gas liquids. Results shown are fully risked estimates. For gas accumula- tions, all liquids are included as NGL (natural gas liquids). Undiscovered gas resources are the sum of nonassociated and associated gas. F95 represents a 95-percent chance of at least the amount tabulated; other fractiles are defined similarly. AU, assessment unit. AU probability is the chance of at least one accumulation of minimum size within the AU. TPS, total petroleum system. Gray shading indicates not applicable. Largest expected oil field size in MMBO; gas field size is in BCFG]
is later than oil, gas is focused into the younger, post-rift clastic and carbonate reservoirs. Volumetrically, gas would be expected to be more prevalent than oil in these provinces where post-rift sources have achieved the appropriate thermal maturity for generation (Doust and Sumner, 2007). The methodology for the assessment included a complete geologic framework description for each province mainly based on published literature and defini- tion of petroleum systems and assessment units within these systems. Exploration and discovery history was a critical part of the methodology used to estimate sizes and numbers of undiscovered accumulations. In areas where there are no discoveries (for example, Phu Khanh Basin) geologic analogs were used as a basis for volumes of undiscovered oil and gas resources. Each assessment unit was assessed for undiscovered oil and nonassociated gas accumulations, and coproduct ratios were used to calculate the volumes of associated gas (gas in oil fields) and natural gas liquids.
The USGS assessed undiscovered conventional oil and gas resources in assessment units within 23 geologic provinces (table 1). For conventional oil resources, the mean total is 21,632 mil- lion barrels of oil (MMBO), with a range from 8,922 to 41,558 MMBO; for undiscovered conventional gas the mean total is 298,761 billion cubic feet (BCFG), with a range from 128,908 BCFG to 557,051 BCFG; and a mean total of 9,099 million barrels of natural gas liquids (MMBNGL), with a range from 3,828 to 17,216 MMBNGL. Of the mean oil total of 21,632 MMBO, about 70 percent is estimated to be in six provinces—Baram Delta/Brunei-Sabah Basin (mean of 4,278 MMBO), Kutei Basin (mean of 3,215 MMBO), South China Sea Plat- form (mean of 2,522 MMBO), East Java Basin (mean of 2,036 MMBO), Cuu Long Basin (mean of 1,735 MMBO), and Thai Basin (mean of 1,212 MMBO). In addition, several provinces are estimated to have potential oil volumes greater than 500 MMBO—Northwest Java Basin (mean of 726 MMBO), Tarakan Basin (mean of 707 MMBO), Nam Con Son Basin (mean of 685 MMBO), Malay Basin (mean of 664 MMBO), Greater Sarawak Basin (mean of 643 MMBO), and Pearl River Mouth Basin (mean of 608 MMBO). For the mean undiscovered gas total of 298,761 BCFG, about 60 percent is estimated to be in six provinces—Kutei Basin (mean of 46,001 BCFG), Greater Sarawak Basin (mean of 38,073 BCFG), East Java Basin (mean of 31,489 BCFG), Baram Delta/Brunei-Sabah Basin (mean of 26,375 BCFG), South China Sea Plat- form (mean of 25,519 BCFG), and Nam Con Son Basin (mean of 14,600 BCFG). Several other provinces are estimated to have potential gas volumes greater than 10,000 BCFG—Thai Basin (mean of 14,583 BCFG), Phu Khanh Basin (mean of 13,040 BCFG), Tarakan Basin (mean of 12,675 BCFG), Song Hong Basin (mean of 12,266 BCFG), and Malay Basin (mean of 12,088 BCFG). Overall, the assessment indicates that (1) more than 90 percent of the undis- covered oil and gas resources are offshore, and (2) there is more than twice as much undiscovered gas resource (298,761 BCFG, or 49,794 MMBOE) than undiscovered oil resource (21,632 MMBO) in the provinces of southeast Asia using a barrels of oil equivalent conversion.
Doust, H., and Sumner, H.S., 2007, Petroleum systems in rift basins—a collective approach in southeast Asia basins: Petroleum Geoscience, v. 13, p. 127–144. Hall, R., 2009, Hydrocarbon basins in SE Asia: understanding why they are there: Petroleum Geoscience, v. 15, p. 131–146. Hall, R., van Hattum, M.W.A., and Spak- man, Wim, 2008, Impact of India— Asia collision on SE Asia: the record in Borneo: Tectonophysics, v. 451, p. 366–389. Hutchinson, C.S., 2004, Marginal basin evolution: the southern South China Sea: Marine and Petroleum Geology, v. 21, p. 1129–1148. Morley, C.K., 2001, Combined escape tectonics and subduction roll-back- backarc extension: a model for the Tertiary rift basins in Thailand, Malay- sia, and Laos: Journal of Geological Society of London, v. 158, p. 461–474. Morley, C.K., 2002, A tectonic model for the Tertiary evolution of strike-slip faults and rift basins in SE Asia: Tecto- nophysics, v. 347, p. 89–215. Todd, S.P., Dunn, M.E., and Barwise, A.J.G., 1997, Characterizing petroleum charge systems in the Tertiary of SE Asia, in Fraser, A.J., Matthews, S.J., and Murphy, R.W., eds., Petroleum geology of Southeast Asia: Geological Society of London Special Publication v. 126, p. 25–47.
Supporting studies of the geologic models and the methodology used in the assessment of Southeast Asia Basins are in progress. Assessment results are available at the USGS Energy Program website, http://energy.cr.usgs.gov/oilgas/.
Christopher J. Schenk (Task Leader; schenk@usgs.gov), Michael E. Brown- field, Ronald R. Charpentier, Troy A. Cook, Timothy R. Klett, Mark A. Kirsch- baum, Janet K. Pitman, and Richard M. Pollastro. Yüklə 136,62 Kb. Dostları ilə paylaş:
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