gas hydrate - CCOP

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The Berau basin is a major coal producing area but only limited oil and gas producers are operating in this area. Although operational logistic data are available in this area, the gas market is limited. Furthermore, the required data control to evaluate CBM potential in more detail in this area is also limited. The CBM resources at a target depth of approximately 670 m are estimated at 8 Tcf. The target formation for CBM development is the Latih formation which contains a thickness of 24 m of sub-bituminous to high-volatile bituminous coal with low ash and CO 2 contents. The North Tarakan Basin has CBM resources of 17.5 Tcf at an average target depth of 700 m. The target formation for CBM development is the Tabul Formation which consists of subbituminous to bituminous coal, 15 m in thickness and with low ash and CO 2 contents. The basin currently has limited onshore oil and gas production, thus limited information is available to evaluate CBM potential in this basin in greater detail. The other basins indicated (Figure 1) have some limited CBM resource potential but they appear to be less prospective than the South Sumatera, Central Sumatera, Barito, Kutei, Berau, and North Tarakan Basins. The prospective CBM area in the Ombilin Basin is relatively small (50 km 2 ) and contains coal with a high CO 2 content (40-70%). The coal seams in the Jatibarang Basin are found at a depth of more than 2,000 m. The Bengkulu Basin is considered too structurally complex for CBM development and the South Sulawesi Basin contains only thin coal seams. PROGRESS ON CBM DEVELOPMENT As indicated above, a recent study has indicated vast CBM resources in Indonesia and CBM is probably one of the most promising alternative resources for energy generation. It is expected that development of CBM resources will substantially increase national gas reserve and contribute to energy back up in the near future. Although Indonesia’s onshore coal basins have not yet been subjected to significant testing for CBM, the interest to developing CBM has become greater since the success of low-rank CBM development in the Powder River Basin, Wyoming, USA and also with the improved understanding of the characteristics of Indonesia’s likely CBM-coal seams. Moreover, the Government of Indonesia fully supports the development of Indonesia’s CBM resource. GOI initiated the first pilot project for CBM exploration in Indonesia in 2003 the Rambutan Field, South Sumatera Province, with the Muara Enim Formation (South Sumatera Basin) as the target formation CBM development. The pilot project is scheduled to be finished by the end of 2007. LEMIGAS, a governmental R&D Centre for Oil and Gas Technology under the Agency of Research and Development for Energy and Mineral Resources, was been assigned to lead the first CBM pilot project with the ultimate goal of stimulating CBM development in Indonesia. In this first pilot project, LEMIGAS has entered into partnership with Medco E&P Indonesia (MEPI) as national oil and gas ‘Production Sharing Contractor (PSC)’. MEPI operates an oil and gas working area in South Sumatera, including the Rambutan Field. 146 New Energy Resources in the CCOP Region - Gas Hydrates and Coalbed Methane
The pilot project has two objectives covering both R&D and business achievements. The R&D objective includes increasing the capabilities of the national human resources and developing a centre of excellence for CBM Development in Indonesia. The other objective includes establishing the CBM reserves and CBM producibility at the location of the pilot project, developing an ‘investment window’ through a CBM database and initiating CBM exploration in the South Sumatra Basin (Legowo, et al, 2006). It is planned to drill five CBM pilot wells in the Rambutan Field. A tightly spaced pattern of the five wells has been chosen based on the experience of CBM exploration in USA. This pattern of production pilot wells is also designed to study the nature of CO 2 injection in relation with both enhanced CBM recovery as well as CO 2 sequestration in the Rambutan Field. Recently, two pilot wells, CBM-1 and CBM-2, have been drilled with depths of 610 m and 950m, respectively. Approximately 100 ft of core samples of Muara Enim coal from CBM-1 have been sampled and analyzed for detailed CBM reservoir properties as well as methane gas potential. At least five main coal seams with thicknesses varying from 25-45 ft have been indicated from well CBM-1. The gas content measured from CBM-1 core samples varied from 0.5 to 3.6 m 3 /t. The seam gas consisted mainly of methane (80 to 93%) with smaller ammounts of CO 2 (6 to 19%), N 2 and heavier hydrocarbons (less than 1%). The so-called Seam 3 shows the maximum gas content of 3.6 m 3 /t. Overall, the measured properties show that Seam 3, with the highest gas content, porosity, diffusivity and methane saturation, is the most suitable for methane production (Legowo, et al, 2006). Currently (late 2006), analyses of CBM-2 core samples are being conducted but the results have not yet been reported. During the drilling of well CBM-2, a gas surge was observed from the top of Seam 3, suggesting that the seam is rich of free gas. In order to complete pattern of five pilot wells, three more wells are being drilled and should be completed by the end of 2006. Following the completion of drilling, several programs to test CBM reducibility, including fracture stimulation and dewatering, will be conducted in 2007. ROAD MAP OF CBM DEVELOPMENT Recently, the Government of Indonesia through Presidential Regulation no. 5/2006, has set out the target for an optimum mix energy by 2025 (see ‘Introduction’ above). As a new energy source, CBM is expected to contribute around 1 – 2 % of the total energy in year 2025. In consideration of this expected CBM contribution in 2025, a road map for the CBM development program has been established (Figure 2). New Energy Resources in the CCOP Region - Gas Hydrates and Coalbed Methane 147
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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:
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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 140 and 141: The Government of Indonesia through
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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