gas hydrate - CCOP

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The Government of Indonesia through Presidential Decree No. 5/2006 has set out a target for an optimum energy-mix by 2025. The contribution of each energy type to the total energy supply in year 2025 is expected to be changed to less than 20 % for oil, more than 30% for natural gas, more than 33% for coal, more than 5% for biofuel, more than 5% for geothermal and more than 5% for other new and renewable energy resources such as 1-2% for CBM and 2% for liquefied coal, biomass, nuclear, hydro, solar and wind energy. The increase in the target for the contribution of natural gas to the energy mix, from 27% in year 2005 to more than 30% in year 2025, will place great pressure on the exploration for gas resources. As the discovery of new conventional gas reserves is proving to be difficult, there is a need to develop alternative gas sources to meet the increasing demand. One of the most prospective alternative gas sources in Indonesia is Coalbed Methane (CBM). CBM POTENTIAL IN INDONESIA Indonesia has a large low rank coal deposits distributed within eleven onshore coal basins that are prospective for coalbed methane development (Figure 1). 5 o N 0 o 5 S CENTRAL SUMATRA BASIN Medan SUMATRA Duri Steamflood Singapore Brunei KUTEI BASIN N. TARAKAN BASIN Pacific Ocean Plate o Pakanbaru OMBILIN KALIMANTAN BASIN BARITO Balikpapan BASIN SULAWESI SOUTH SUMATRA Palembang BASIN Banjarmasin Ujung SOUTHWEST PASIR AND Pandang SULAWESI Jakarta ASEM ASEM BENGKULU BASINS BASIN 0 Kilometers JATIBARANG 1000 BASIN I N D O N E S I A Indian Ocean Plate AUSTRALIA Active Volcano Subduction Zone Strike-Slip Fault Relative Plate Motion JAVA BERAU BASIN JAF01836.CDR Figure 1. Location of Indonesian Coal Basin (Stevens, 2006). The potential for coalbed methane in Indonesia has been studied since early 1990’s and was pioneered by the Bandung Institute of Technology (Institut Teknologi Bandung, ITB). In 1998 a joint study was conducted by Advanced Resources International Inc (ARI), PT Caltex Pacific Indonesia (CPI) and PERTAMINA. This study suggested an estimated CBM resource potential of 337 Tcf. ARI has also performed a comprehensive assessment of Indonesia’s CBM resources based on available petroleum and coal mining data. This study was supported by the Asian Development Bank and Directorate General of Oil and Gas (Ministry of Energy and Mineral Resources the Republic of Indonesia). It identified 453.3 Tcf of prospective CBM resources within the eleven onshore coal basins (Table 1). 144 New Energy Resources in the CCOP Region - Gas Hydrates and Coalbed Methane
Table-1. Summary of CBM reservoir properties and estimated CBM resources (Stevens, 2006) Basin Province Target Completeable Coal Avg High- CBM Resources Form- Coal Rank Depth Graded Complet- Concenation Thickness Area able tration (m) (R o %) (m) (km 2 ) (Tcf) (Bcf/mi 2 ) 1 S. Sumatra Sumatra M.Enim 37 0.47 762 7,350 183.0 24.9 2 Barito Kalimantan Warukin 28 0.45 915 6,330 101.6 16.0 3 Kutei Kalimantan Prangat 21 0.50 915 6,100 80.4 13.2 4 C. Sumatra Sumatra Petani 15 0.40 762 5,150 52.5 10.2 5 N. Tarakan Kalimantan Tabul 15 0.45 701 2,734 17.5 6.4 6 Berau Kalimantan Latih 24 0.45 671 780 8.4 10.8 7 Ombilin Sumatra Sawaht 24 0.80 762 47 0.5 10.7 8 Pasir/Asem Kalimantan Warukin 15 0.45 701 385 3.0 7.9 9 NW Java Java T. Akar 6 0.70 1524 100 0.8 7.6 10 Sulawesi Sulawesi Toraja 6 0.55 610 500 2.0 4.0 11 Bengkulu Sumatra Lemau 12 0.40 610 772 3.6 4.7 Total 30,248 453.3 15.0 The potential CBM resources in Indonesia (Stevens, 2006) were summarized in the following paragraphs. The South Sumatra Basin appears to be the most prospective for CBM development. The preliminary prediction suggests that recoverable CBM resources in the South Sumatra Basin at target depths of 300-1,000 m are estimated at 183 Tcf, accounting for 40% of the total national resources. The Muara Enim Formation, as a target formation, contains a thickness of 37 m of high vitrinite sub-bituminous coal with extremely low ash content. Furthermore, the South Sumatera basin, as a petroleum producing basin, has much data relevant to operational logistics and gas markets. The Central Sumatera Basin has an estimated recoverable CBM source of 53 Tcf at an average target depth of 762 m. The target formation for CBM development is the Upper Petani Formation. This formation contains a thickness of 15 m of lignite to sub bituminous coal with 10% ash and 2% CO 2 contents. The Central Sumatera basin is a significant petroleum producing basin. Gas markets and operational logistics are well established. TheBarito basin is also prospective for CBM development. The CBM resource at a target depth of approximately 800 m is estimated at 102 Tcf and represents the 2 nd largest CBM resource in Indonesia. The target formation for CBM development in the Barito basin is the Warukin Formation. This formation contains a thickness of 28 m of sub-bituminous coal with low ash and CO 2 contents. The Barito basin is not a significant petroleum producing basin and data concerning operational logistics and gas markets are therefore inferior to those in South Sumatera. The Kutai basin has an estimated CBM resource of 80.4 Tcf at a target depth of approximately 900 m. This basin contains 2 primary target formations for CBM development, the Kamboja and Prangat Formations of the Balikpapan Group which has 21 m of bituminous coal thickness with low ash and CO 2 contents. As a major oil and gas producing basin, the Kutai Basin has established gas markets and operational logistics. New Energy Resources in the CCOP Region - Gas Hydrates and Coalbed Methane 145
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Coordinating Committee for Geoscien
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Thematic Session on New Energy Reso
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CONTENTS Page OPENING REMARKS……
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OPENING REMARKS by Chen Shik Pei Di
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WELCOME ADDRESS by Tai-Sup Lee Pres
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WELCOME ADDRESS by Keun-Pil Park Di
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CONGRATULATORY ADDRESS by David Pri
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PART I GAS HYDRATE: EXPLORATION, RE
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Partial differential equations for
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RESULTS AND DISCUSSION In the follo
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REFERENCES Berner R. A. (1980) Earl
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features of the seabed than those o
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secure the stability of the solutio
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trends depending on the following f
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Organic carbon in sediments is of i
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Sedimentological and Geochemical As
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Figure 3. Sedimentation rate of the
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Marine Gas Hydrate off W. Canada an
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Several methods for computing the Q
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0.035 0.03 Amplitude 0.025 0.02 0.0
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60 50 Amplitude 40 30 20 10 0 0 50
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REFERENCES Dallimore, S.R. and T.S.
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Frequency % 20 16 12 8 HAMA #5, MV=
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Figure 3. Experimental procedures f
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Figure 7 shows two cases of the com
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Seismic Characteristics of Gas Hydr
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Purpose The purpose of this paper i
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The dissociation zone created by th
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hydrate that forms near the wellbor
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dissociation, composite thermal con
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Figure 9. The Advanced Light Source
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Experimental Studies and Developmen
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Natural gas hydrate exploitation an
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Natural gas Free gas layer Figure 5
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Figure 7. One-dimensional developme
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Temper at ur e 2 1 0 -1 -2 -3 -4
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From the above discussion, the heat
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INTRODUCTION Clathrate hydrates are
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MATHEMATICAL MODEL The mathematical
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Where the hydrate-aqueous radius of
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REFERENCES Brooks, R.H., and A.T. C
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86 New Energy Resources in the CCOP
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In this paper, an overview of the M
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The brief tasks in the Phase I are:
Page 90 and 91: In "Development of the dissociation
Page 92 and 93: Figure 5. Preparation equipment. AN
Page 94 and 95: Other recent research subjects in t
Page 96 and 97: same crystalline structure directly
Page 98 and 99: Another important aspect of the pre
Page 100 and 101: a + CO 2 CH 4 C 2 H 6 b CH 4 in sII
Page 102 and 103: REFERENCES Collett, T.S. and Kuuskr
Page 104 and 105: Figure 1. Physiographic and crust m
Page 106 and 107: Figure 3. Seismic profile showing s
Page 108 and 109: Figure 7. Distribution of echo char
Page 110 and 111: Figure 10. Seismic profile and its
Page 112 and 113: In the early stage of back-arc open
Page 114 and 115: PART II COALBED METHANE (CBM)
Page 116 and 117: Supply and demand infrastructure of
Page 118 and 119: Amisan, Jogyeri, Baegunsa, and Seon
Page 120 and 121: PROPERTIES OF ANTHRACITE The coals
Page 122 and 123: Table 4. Average chemical compositi
Page 124 and 125: CONCLUSIONS 1. Most of the coals em
Page 126 and 127: INTRODUCTION Coal (total reserves 2
Page 128 and 129: ีีีีีีีีี ั ิ
Page 130 and 131: RESULTS By Government: The outcomes
Page 132 and 133: The gas composition (12 samples ana
Page 134 and 135: Table 4. Coal Depth Interval Hole N
Page 136 and 137: The results of studies made on 11 c
Page 138 and 139: CONCLUSION CBM is still hoped to be
Page 142 and 143: The Berau basin is a major coal pro
Page 144 and 145: PP: CBM - 1 Rambutan (GOI Sponsor)
Page 146 and 147: Overview of Project for CO 2 Seques
Page 148 and 149: The organic geochemistry research g
Page 150 and 151: 3.5 25 3.0 20 Ar(%) C O 2(%) 2.5 2
Page 152 and 153: 20 8 10 0 6 δ13C of CO2(‰) -10 -
Page 154 and 155: Figure 1. Index map of Akabira Coal
Page 156: ORIGIN OF AKABIRA CBM In Akabira mi
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