gas hydrate - CCOP

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The results of studies made on 11 coal core samples from the two observation wells and 13 coal core samples from the production well indicated that the desorption of gas averaged about 0.2-0.31 cubic centimeter per gram or 7.2-10.95 cubic foot per ton. The properties of the gases were determined by collecting them in 10 canisters from both production and observation wells and analyzing using gas chromatographic techniques. The composition of the total gas released from the coal is as follows: Methane gas about 60% Nitrogen about 28% Carbon Dioxide about 12% Gas flow rate Gas flow rate from the production well was analyzed using a well stimulation technique by pumping water from the coal beds to allow coalbed gases to flow into the well. The following procedure was used: A submersible pump was installed in the production well below the lower coal seam. The installation depth was 311.0 m including the length of the pump. The lower coal seam is found from 281.0 - 287.0 m depth. A pumping test was commenced by pumping water out of the well. Flow rate was measured and at the same time water levels in both production and observation wells were recorded. The data received were used for preliminary determination of coal permeability. Water was continuously pumped so as to keep the water level below the level of the coal seam. Pumping was suspended at predetermined time-intervals while the water level was always kept below the coal seam. Gas flow is measured by a system of gas flow meters. The results of well stimulation reveal that the water flow rate from the coal seam into the well was approximately 1.0 cubic meter per day or 0.04 cubic meters per hour. This water flow rate is considered to be very low, yielding a positive effect during the gas production. The gas flow during the first 10 days was measured at 19 liters. The resulting flow rate is 1.9 liters per day or 0.067 liters per hour which is considered to be very low. The pumping test data were used to calculate the coal permeability by a hydrogeological technique yielding a result of 5 x 10 -6 cm per second. The pumping test was continued for 45 days and it was found that after the first 10 days the gas flow had completely ceased. The reasons may be due to the low permeability of the coal and clogging by bentonite mud. Estimation of reserves of coal and coalbed methane The reserve estimation of coal in the Mae La Mao basin employed the circular method recommended by USGS (USGS Circular 891). Using the grid reference of the well as the center, circles with radii of 400, 1,200, and 4,800 m respectively are drawn to delimit the reserve areas. The coal reserves are then calculated as measured coal, indicated coal, and inferred coal respectively. The thickness of coal used in the reserve calculation is derived from an isopach map by integrating the entire thickness of all coal beds. In the current calculation, the total thickness of coal beds is the sum of the upper and lower beds. 140 New Energy Resources in the CCOP Region - Gas Hydrates and Coalbed Methane
The specific gravity of the coal from the upper coal seam and lower seam, as derived from the analyses, averages 1.40, while density of the coal as determined by the water replacement technique in the canister, averaged t 1.41 gm/cc. The two values are very similar; either value can be used as the coal density in reserve calculation. The reserve of coal is calculated based on the following formula: Coal reserve (metric ton) = Area x Thickness x Density In the calculation, there are two classes of areas, one is the area enclosing three new drilled wells and the other is the area enclosing existing exploratory drilled holes: The calculated reserve of coal in the area enclosing the three new drilled wells is as follows: Measured coal = 4,571,637.0 ton Indicated coal = 70,503,660.3 ton Inferred coal = 1,208,820,046.5 ton The calculated reserve of coal in the area enclosing existing exploratory drilled holes is as follows: Measured coal = 60,881,895.5 ton Indicated coal = 188,324,000.2 ton Inferred coal = 584,067,610.8 ton The reserve of coalbed methane is calculated based on the following formula: Reserve of gas (cubic foot) = Reserve of coal x Released gas In the estimation, the coal reserve calculated is based on a measured coal method. The gas released from canisters is measured at 0.31 cubic meters per ton or about 10.95 cubic foot per ton. Therefore, the gas reserve in the area enclosing three new drilled wells is calculated at 50.1 million cubic feet and the gas reserve in the area enclosing existing exploratory drilled holes is estimated as 666.7 million cubic feet respectively. A PRIVATE COMPANY VENTURE In the 18 th petroleum licensing round, the DMF (Government) awarded one petroleum block for CBM exploration in Surathanee province, Southern Thailand, under Thai III. The private company awarded the block was SVS. SVS drilled two wells with no success due a lack of, or very thin, coal beds encountered. After this disappointing result, SVS totally relinquished the block. NEW PROJECTS The Department of Mineral Fuels (DMF) and the Electricity Generating Authority of Thailand (EGAT) have combined in 2006 in new projects to study oil shale in the Mae Sod basin in Tak Province and CBM in the Fang basin, Chiang Mai Province, located in the Northern part of Thailand. The objectives of the study are to determine the reserves, quality and to establish guidelines for future development of Oil Shale and CBM as alternative energy sources. New Energy Resources in the CCOP Region - Gas Hydrates and Coalbed Methane 141
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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
Page 86 and 87: In this paper, an overview of the M
Page 88 and 89: 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 138 and 139: CONCLUSION CBM is still hoped to be
Page 140 and 141: The Government of Indonesia through
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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