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Title Presented at & Date Author Project Team / Research Division Abstract 11468 Japanese National Programs on the Methane Hydrate Research 6th International Workshop on Methane Hydrate Research & Development (Fiery ice)2008/5/13-16 Koji Yamamoto (Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Japanese National Programs on the Methane Hydrate Research 11467 Resource Assessment of Methane Hydrate in the Eastern Nankai Trough, Japan 6th International Workshop on Methane Hydrate Research & Development (Fiery ice)2008/5/13-15 Tetsuya Fujii, Tatsuo Saeki, Toshiaki Kobayashi, Takao Inamori, Masao Hayashi, Osamu Takano, Tokujiro Takayama, Tatsuji Kawasaki, Sadao Nagakubo, Masaru Nakamizu, Kenichi Yokoi (Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Resource assessment of methane hydrate (MH) in the Eastern Nankai Trough was conducted through probabilistic approach using 2D/3D seismic data and drilling survey data from METI exploratory test wells “Tokai-oki to Kumano-nada” We have extracted more than 10 prospective “MH concentrated zones” characterized by high resistivity in well log, strong seismic reflectors, seismic high velocity, and turbidite deposit delineated by sedimentary facies analysis. The amount of methane gas contained in MH bearing layers was calculated using volumetric method for each zone. Each parameter, such as gross rock volume (GRV), net-to-gross ratio (N/G), MH pore saturation (Sh), porosiry, cage occupancy, and volume ratio was given as probabilistic distribution for Monte Carlo simulation, considering the uncertainly of these evaluations. The GRV for each hydrate bearing zones was calculated from both strong seismic amplitude anomaly and velocity anomaly. Time-to-depth conversion was conducted using interval velocity derived from Seismic Vision While Drilling (SVWD). Risk factor was applied for the estimation of the GRV in 2D seismic area considering the uncertainly of seismic interpretation. The N/G was determined based on the relationship between LWD resistivity and grain size in zones with existing wells. Seismic ficies map created by sequence stratigraphic approach was also used for determination of the N/G in zone without well controls. Porosity was estimated using density log, together with calibration by core analysis. The Sh was estimated by the combination of density log and NMR log, together with the calibration by observed gas volume from onboard MH dissociation tests using Pressure Temperature Core Sampler (PTCS). The Sh in zone without well control was estimated using relationship between seismic P-wave internal velocity and Sh from NMR log at well location. Total amount of methane gas in place contained in MH within survey area in the eastern Nankai Trough was estimated to be 40 tcf as Pmean value. Total gas in place for MH concentrated zone was estimated to be 20 tcf (Half of total amount) as Pmean value. Sensitivity analysis indicated that the N/G and Sh have higher sensitivity than other parameters, and they are important for further detail analysis. 11466 Elastic Property Changes of Bitumen Reservoir during Steam Injection 2008 CSPG CSEG CWLS Convention 2008/5/12 Ayato Kato, Shigenobu Onozuka (Japan Oil, Gas and Metals National Corporation), Toru Nakayama (Japan Petroleum Exploration Co., Ltd.) Geology & Geophysics Research Division [Abstract] Elastic property changes of oil sands reservoir during steam injection are poorly understood. We measured and analyzed ultrasonic velocities of the oil sands and then obtained a relation of the velocities with temperature and pressure individually. We also investigated validity of the Gassmann equation for predicting velocity changes and confirmed that the Gassmann equation can be applicable at temperatures greater than 80℃. We combined the laboratory measurement results to obtain a sequential rock physic model that can predict velocity changes induced by steam injection. We predicted elastic property changes during the steam injection according to the model. P-wave velocity is a relatively all-around player for distinguishing steam fronts, while S-wave velocity can be used only for distinguishing a gentle-warmed area. 11465 NOC-JOGMEC Joint Study on “Produced Water Treatment and Oily Soil Remediation” First International Petroleum Environmental Conference and Exhibition 2008/5/12 Hiroyuki Sekino (Japan Oil, Gas and Metals National Corporation) Petroleum Engineering Research Division [Abstract] 1) JOGMEC has been conducting a joint study with Libya NOC regarding “Produced Water Treatment and Oily Soil Remediation” on a few selected oil fields (model site). The study team consists of topnotch specialists on water treatment, soil remediation, NORM survey, GIS and plant engineering. Based on the environmental site survey of evaporation ponds and produced water in the model site conducted as Phase 1 (October-December2007) of the study, findings and subsequent practical countermeasures will be presented in the final report at the end of Phase 2 (January-October 2008). 2) In the site survey conducted during Phase 1, utilizing hand-held instruments such as multi parameter water quality monitoring system, several parameters of surface water and soil including pH, electrical conductivity, etc. were measured at over 50 spots and 14 samples were collected and later analyzed chemically at LPI and laboratories in Japan. 3) In Phase 2, sample collection in trenchs/pits is planned to identify oil contamination mechanism. We will also research on internationally-accepted laws and regulations in relation to environmental protection and try to come up with appropriate countermeasures adoptable in Libya. 11464 Extraction of methane hydrate concentrated zone for resource assessment in the Eastern Nankai Trough, Japan 2008 Offshore Technology Conference 2008/5/7 Tatsuo Saeki, Tetsuya Fujii, Takao Inamori, Toshiaki Kobayashi, Masao Hayashi, Sadao Nagakubo, Osamu Takano (Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Aiming commercialization of methane hydrate development, the Research Consortium for Methane Hydrate Resources in Japan (MH21) has been executing geological and geophysical surveys around the eastern Nankai Trough since 2001 as a national project. Interpretation and analysis studies based on 2D/3D reflection seismic surveys, multi-wells drilling campaign and other geological surveys revealed existences of methane hydrate concentrated zones, of which reservoirs were composed of turbidite sand layers. In the view of resource explorations, methane hydrate concentrated zones are more attractive than other methane hydrate bearing zones because they can reserve much amount of methane hydrate locally. We developed an optimal interpretation workflow for delineation of methane hydrate concentrated zones. The workflow includes evaluation and integration of following four indicators: (A) BSR, (B) Turbidite sequence, (C) Strong seismic reflector and (D) relatively higher interval velocity. It enabled in the eastern Nankai Trough to extract more than 10 methane hydrate concentrated zones and evaluate their rock volume successfully. 11463 Resource Assessment of Methane Hydrate in the Eastern Nankai Trough, Japan 2008 Offshore Technology Conference 2008/5/7 Tetsuya Fujii, Tatsuo Saeki, Toshiaki Kobayashi, Takao Inamori, Masao Hayashi, Osamu Takano, Tokujiro Takayama, Tatsuji Kawasaki, Sadao Nagakubo, Masaru Nakamizu, Kenichi Yokoi (Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Resource assessment of methane hydrate (MH) in the Eastern Nankai Trough was conducted through probabilistic approach using 2D/3D seismic data and drilling survey data from METI exploratory test wells “Tokai-oki to Kumano-nada” We have extracted more than 10 prospective “MH concentrated zones” characterized by high resistivity in well log, strong seismic reflectors, seismic high velocity, and turbidite deposit delineated by sedimentary facies analysis. The amount of methane gas contained in MH bearing layers was calculated using volumetric method for each zone. Each parameter, such as gross rock volume (GRV), net-to-gross ratio (N/G), MH pore saturation (Sh), porosiry, cage occupancy, and volume ratio was given as probabilistic distribution for Monte Carlo simulation, considering the uncertainly of these evaluations. The GRV for each hydrate bearing zones was calculated from both strong seismic amplitude anomaly and velocity anomaly. Time-to-depth conversion was conducted using interval velocity derived from Seismic Vision While Drilling (SVWD). Risk factor was applied for the estimation of the GRV in 2D seismic area considering the uncertainly of seismic interpretation. The N/G was determined based on the relationship between LWD resistivity and grain size in zones with existing wells. Seismic ficies map created by sequence stratigraphic approach was also used for determination of the N/G in zone without well controls. Porosity was estimated using density log, together with calibration by core analysis. The Sh was estimated by the combination of density log and NMR log, together with the calibration by observed gas volume from onboard MH dissociation tests using Pressure Temperature Core Sampler (PTCS). The Sh in zone without well control was estimated using relationship between seismic P-wave internal velocity and Sh from NMR log at well location. Total amount of methane gas in place contained in MH within survey area in the eastern Nankai Trough was estimated to be 40 tcf as Pmean value. Total gas in place for MH concentrated zone was estimated to be 20 tcf (Half of total amount) as Pmean value. Sensitivity analysis indicated that the N/G and Sh have higher sensitivity than other parameters, and they are important for further detail analysis. 11446 Water, CO2-WAG and Flue Gas IOR/EOR Injection Pilot Studies in South Chicontepec Reservoirs, Mexico Second International Oil Congress and Exhibition in Mexico 2007/6/28-30 M. Abbaszadeh (IPS), Kenji Ohno(Japan Oil, Gas and Metals National Corporation) Technology Research & Development Department [Abstract] This paper presents results of water, CO2, CO2-WAG and flue gas injection simulation studies in sector models in the fields of south Chicontepec deposit complex. The paper first introduces a general methodology for integrated geostatistical reservoir characterization to construct fine-scale geocellular models of the reservoir, incorporating sources of data at different scales. Sector models for pilot injection studies are extracted from fine-scale geostatistical realizations, upscaled into coarse-grid simulation models and calibrated to production performance data to serve as reliable predictive tools for IOR/EOR recovery process scenarios. EOS analyses and slim-tube simulations are performed to evaluate MMP with CO2 of varying N2 impurity. Detailed studies of various CO2 injection scenarios investigate applicability and limitations of CO2-EOR, and provide information on conditions under which CO2-EOR could be beneficial. Continuous water and CO2 injection studies determine limiting values of injectivity and incremental oil recovery factors. WAG studies for mobility control determine optimum slug size and WAG ratio, considering limitations on CO2 availability and excessive CO2 gas breakthrough. Flue gas, as an alternative fluid injection, is considered for EOR recovery process and pressure maintenance. Simulated recovery data indicates that flue gas injection is inefficient compared to waterflood and CO2-WAG injections, and that CO2-WAG injections at high pressures outperform waterflooding. 11445 Physical modeling of overburden effects Geophysics Vol.72 2007/7 Mu Luo (JGI), Mamoru Takanashi(Japan Oil, Gas and Metals National Corporation), Kazuo Nakayama, Teruya Esaka (JGI) Geology & Geophysics Research Division [Abstract] Physical modeling of overburden effects 11442 RISER MOTION ESTIMATION OF OIL PRODUCTION SYSTEM FOR ULTRA DEEP WATER FIFTH CONFERENCE ON BLUFF BODY WAKES AND VORTEX=INDUCED VIBRATIONS 2007/12/12-15 Shunji Kato, Shotaro Uto, Sotaro Masanobu (National Maritime Research Institute), Hideyuki Suzuki (Tokyo Univ.), Hiroaki Hirayama, Koji Mochida(Japan Oil, Gas and Metals National Corporation) Petroleum Engineering Research Division [Abstract] RISER MOTION ESTIMATION OF OIL PRODUCTION SYSTEM FOR ULTRA DEEP WATER 11440 Fusion of 3D seismic exploration and seafloor geochemical survey for methane hydrate exploration Exploration Geophysics, 2007,38,1-6 2008/1 Sadao Nagakubo, Toshiaki Kobayashi, Tetsuya Fujii, Takao Inamori(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] The MH21 Research Consortium has conducted a high-resolution 3D seismic survey and a seafloor geochemical survey, to explore methane hydrate reservoirs in the eastern Nankai Trough, offshore Japan. Excellent geological information about shallow formations was obtained from the high-resolution 3D seismic survey, which was designed to image the shallow formations where methane hydrates exist. The information is useful in constructing a geological and geochemical model, and especially to understand the complex geology of seafloor, including geochemical manifestations and the structure of migration conduits for methane gas or methane-bearing fluid. By comparing methane seep sites observed by submersibles with seismic sections, some significant relationships between methane hydrate reservoirs, free gas accumulations below he seafloor, and seafloor manifestations are recognised. Bathymetric charts and seafloor reflection amplitude maps, constructed from seismic reflections from the seafloor, are also useful in understanding the relationships over a vast area. A new geochemical seafloor survey targeted by these maps is required. The relationships between methane hydrate reservoirs and seafloor manifestations are becoming clearer from interpretation of high-resolution 3D seismic data. The MH21 Research Consortium will continue to conduct seafloor geochemical surveys based on the geological and geochemical model constructed from high-resolution 3D seismic data analysis. In this paper, we introduce a basis for exploration of methane hydrate reservoirs in Japan by fusion of 3D seismic exploration and seafloor geochemical surveys. 11439 A Mathematical Model for the Formation and Dissociation of Methane Hydrates in the Marine Environment Journal of Geophysical Research, Vol.113, B01201 2008/1/12 Sabodh K. Garg, J. W. Prichett (Science Applications International Corporation), Arata Katoh (JGI), Kei Baba (JAPEX), Tetsuya Fujii(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] A Mathematical Model for the Formation and Dissociation of Methane Hydrates in the Marine Environment 11436 Introduction of the 2007-2008 JOGMEC/NRCan/Aurora Mallik Gas Hydrate Production Research Program, NWT, Canada 2007 AGU Fall Meeting 2007/12/10-14 Koji Yamamoto, Masaaki Numasawa, Masato Yasuda, Kasumi Fujii, Tetsuya Fujii(Japan Oil, Gas and Metals National Corporation), Scott R Dallimore, J. Fred Wright, F. Mark Nixon (NRCan) Methane Hydrate Research Project Team [Abstract] Introduction of the 2007-2008 JOGMEC/NRCan/Aurora Mallik Gas Hydrate Production Research Program, NWT, Canada 11434 Research and Development Studies of the Mallik Gas Hydrate Deposit, Mackenzie Delta Geological Association of Canada Annual Meeting 2007/5/23-25 Scott R. Dallimore (NRCan), Kenichi Yokoi, Yutaka Imasato(Japan Oil, Gas and Metals National Corporation), A.Applejohn(Aurora Research Institute) Methane Hydrate Research Project Team [Abstract] Research and Development Studies of the Mallik Gas Hydrate Deposit, Mackenzie Delta 11431 Core Velocity Measurements of Oil Sands for Quantitative Interpretation of Seismic 3D Seismic Steam Front Monitoring. SEG Development & Production Forum "Heavy Oils" 2007/7/31 Shigenobu Onozuka, Ayato Kato(Japan Oil, Gas and Metals National Corporation), Toru Nakayama (JAPEX), Ray E. Nasen(JACOS) Geology & Geophysics Research Division [Abstract] Core Velocity Measurements of Oil Sands for Quantitative Interpretation of Seismic 3D Seismic Steam Front Monitoring. 11416 Application of Oil-Water Kr/Pc Upscaling Methodology Based on Pore-Type Ratios 2007 International Symposium of the Society of Core Analysts 2007/9/12 Kazuhito Oseto, Osamu Himeno, Makoto Watanabe, Toshinori Nakashima(Japan Oil, Gas and Metals National Corporation) Petroleum Engineering Research Division [Abstract] Our methodology provides fast and robust computation of upscaling by introducing a new averaging technique as a part of the capillary limit method, that is basically suited to giant, heterogeneous and oil wet reservoirs. In our past studies, its effectiveness was verified at core scale upscaling, i.e. pore scale to core scale, as well as reservoir simulation scale upscaling, i.e. fine model to coarse model. This paper introduces a practical approach for upscaling which bridges the various scales. In this study, the reservoir rock from a giant carbonate reservoir in the Middle East was characterized as the aggregate of three Pore-Types. The representative Kr/Pc curves for each Pore-Type were derived from core flood simulation as a result of matching with water-oil displacement tests. Then, Pore-Type Ratio, i.e. the population ratio of each Pore-Type, was quantified by the geological observation of the core slabs for the whole interval of the reservoir. Based on the Pore Type Ratios, Kr/Pc curves were upscaled to the simulation grid scale using an in-house software called CAVLUP. The simulation results showed that the Pore Type Ratio model reasonably reproduced water cut performances without any history matching manipulations. As a result, applied methodology in this study demonstrated its effectiveness to upscale pore scale data to reservoir simulation scale. This advantage is suited especially to the upscaling of big and heterogeneous geological models. 11415 Comprehensive Approach of Core Analysis to Predict Waterflooding Performance in a Heterogeneous Carbonate Reservoir International Energy Agency Collaborative Project on Enhanced Oil recovery 2007/9/7 Kazuhito Oseto, Komei Okatsu(Japan Oil, Gas and Metals National Corporation) Petroleum Engineering Research Division [Abstract] The field of interest is a heterogeneous carbonate reservoir, offshore Abu Dhabi. A pore system in the field is classified into three categories based on the pore throat size, i.e. Macropore, Mesopore and Micropore. Such pore size variation is a key parameter that controls oil/water displacement, especially when imbibition/drainage processes can frequently take place in a reservoir in conjunction with subsequent wettability alteration. This study deeply evaluates the cross-correlation between the pore system, imbibition/drainage processes, wettability alteration and oil recovery by integrative core analyses. Two core waterflooding tests were conducted under different wettability conditions, i.e. water wet and oil wet. The oil recoveries were both high while there were some differences in Swir. These similarity and differences can be explained by different controls with different pore size in the proposed pore system. 11413 Detailed analysis of methane hydrate concentrated zone of lobe type 2007 AGU Fall Meeting 2007/12/11 Toshiaki Kobayashi, Tatsuo Saeki, Takao Inamori, Tetsuya Fujii, Naoyuki Shimoda(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Japan Oil, Gas and Metals National Corporation (hereinafter called JOGMEC), as a member of MH21 Research Consortium, takes charge of a study of the Research for Resources Assessment, and is pursuing a possibility that methane hydrate, which is presumed to be distributed around ocean area of Japan, will be energy resources. JOGMEC is currently conducting analysis of seismic data which was acquired by 3D seismic survey conducted from Tokai-Oki to kumano-nada in the eastern Nankai Trough by METI (Ministry of Economy, Trade and Industry) in 2002 under the national program of assessment for methane hydrates as energy resources. It was understood that methane hydrate was correlated to high resistivity and high velocity based on the results of drilling surveys and velocity analysis, and that methane hydrate concentrated zones can be roughly classified into the channel type and lobe type by seismic geomorphology because they were characterized with reserves consisting turbidite sand bodies. In this study, the detailed analysis of the inner structure of the methane hydrate concentrated zone of lobe type was conducted to understand the occurrence configurations of methane hydrates. The reflected waves that construct the methane hydrate concentrated zones in the seismic data were extracted and those reflected waves were classified into some groups every one reflector. As the result, some reflectors that construct the methane hydrate concentrated zones were revealed. Those reflectors show the layers including methane hydrates, and the detailed distribution of the methane hydrates in those layers was revealed by the intensity distribution of the amplitude. This time, we introduce the example of the detailed analysis of the methane hydrate concentrated zone in the lobe of submarine fan. 11412 Methane Hydrate reservoir model around the Eastern Nankai Trough area offshore Japan 2007 AGU Fall Meeting 2007/12/10-14 Takao Inamori, Masao Hayashi, Toshiaki Kobayashi, Naoyuki Shimoda, Osamu Takano, Tokujiro Takayama, Tetsuya Fujii, Sadao Nagakubo, Tatsuo Saeki(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] The Research Consortium for Methane Hydrate Resources in Japan (hereafter the MH21 Research Consortium) was established to undertake research in accordance with Japan's Methane Hydrate Exploitation Program. In 1996 and 2001, 2D seismic surveys were conducted and delineated the BSR distribution. The 3D seismic survey was conducted in this area in 2002. Bottom Simulating reflectors (BSRs) were widely found on the marine seismic data acquired in the shelf-slope in the Eastern Nankai Trough area. BSRs indicate the existence of methane hydrates. However, we cannot estimate detail reservoir information from distribution of BSRs. The gas hydrate-bearing sediments are heterogeneous and complex both vertically and horizontally, because methane hydrate-bearing layers are mainly turbidite sands - channel-levee or lobe sediments. The occurrence of methane hydrates was first confirmed by corings and borehole logging data around the Eastern Nankai Trough offshore Japan in 2000. METI conducted two drilling campaigns around the eastern Nankai Trough area. Total 38 boreholes were drilled, and recorded many logging data by wireline or LWD. We separate three types of methane hydrate reservoir among methane hydrate-bearing zone from reviewing the well logging data mainly the resistivity and P or S wave velocity. One is low saturation-type, the other is uncontinuous high saturation-type, the last is the continuous high saturation-type, and also we call the methane hydrate-concentrated zone as this type. If we will explore and exploit the methane hydrate, our main target is the continuous high saturation-type, as the methane hydrate-concentrated zone. We delineated the methane hydrate reservoir by the picking the reflector as the methane hydrate sub reservoir body for the turbidite channel-levee or lobe system around the eastern Nankai Trough area. On the other hand, we received the P or S wave velocity and the methane hydrate saturation at the wells in the methane hydrate-concentrated zone. We estimated the matrix-support or pore-filling model from the relationship between the P or S wave velocity and the methane hydrate saturation. 11411 Extraction of methane hydrate concentrated zone in the eastern Nankai Trough 2007 AGU Fall Meeting 2007/12/10-14 Tatsuo Saeki, Tetsuya Fujii, Takao Inamori, Toshiaki Kobayashi, Masao Hayashi, Sadao Nagakubo, Osamu Takano(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Methane hydrate, a solid compound formed from methane and water, occurs naturally in permafrost regions on-land and in deep continental slopes offshore and has been examined as future energy resources. The existence of methane hydrate in the eastern Nankai Trough region, offshore Japan, was confirmed by drilling the MITI well "Nankai Trough" in 1999. Aiming commercialization of methane hydrate production, the Research Consortium for Methane Hydrate Resources in Japan (MH21) has been executing geological and geophysical surveys around the eastern Nankai Trough since 2001 as a nation project. Interpretation and analysis studies based on 2D/3D reflection seismic surveys, multi-wells drilling campaign and other geological surveys revealed existence of methane hydrate concentrated zones, of which reserves were constructed with turbidite sand layers. In the view of resource explorations, methane hydrate concentrated zones are more attractive than other methane hydrate bearing zones because they can save much amount of methane hydrate locally. We developed the geological interpretation workflow optimized for delineation of methane hydrate concentrated zones. The workflow consists of following 4 factors: (1) BSR interpretation, (2) Delineation of turbidite sand bodies, (3) Detection of Strong seismic reflectors suggesting methane hydrate concentrated sand layers, and (4) high density velocity analysis. It enabled in the eastern Nankai Trough to extract methane hydrate concentrated zones and evaluate their rock volume successfully. 11410 Origin and Migration of Gas in Gas Hydrate-bearing Sediments In the eastern Nankai Trough, Japan 2007 AGU Fall Meeting 2007/12/10-14 Amane Waseda(JAPEX), Tetsuya Fujii(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Origin and Migration of Gas in Gas Hydrate-bearing Sediments In the eastern Nankai Trough, Japan 11409 Relation between methane hydrate -bearing formations and geological phenomena on the seafloor In the eastern Nankai Trough, Japan 2007 AGU Fall Meeting 2007/12/10-14 Sadao Nagakubo, Toshiaki Kobayashi, Takao Inamori, Tatsuo Saeki, Naoyuki Shimoda, Tetsuya Fujii(Japan Oil, Gas and Metals National Corporation), Sumito Morita, Manabu Tanahashi(AIST) Methane Hydrate Research Project Team [Abstract] In 2002, a series of high-resolution 3D seismic surveys was conducted in the Tokai-Oki, the Daini-Atsumi Knoll, the Kumano-nada In the eastern Nankai Trough, Japan. Research Consortium for Methane Hydrate Resources in Japan(MH21) conducted resource assessment of methane hydrate In the eastern Nankai Trough by various seismic data analyses combining results of the exploratory wells conducted in 2005. By these analyses, occurrence of methane hydrate In the eastern Nankai Trough is coming to light. The MH21 has also interpreted the relation between methane hydrate-bearing formations and various geological phenomena on the seafloor, such as pockmarks and carbonate outcrops, using the 3D seismic data in the three survey areas. Bathymetric maps and seafloor amplitude maps constructed by the high-resolution 3D data provided lots of information on the seafloor. Some areas show very high intensity on the seafloor amplitude maps. It is expected that the areas showing strong amplitude correspond to the distribution of carbonate outcrops which are likely precipitated by methane seep activities. By checking the seafloor amplitude maps, seismic sections and methane seep sites observed by the previous submersible dives, some significant correlations are recognized between methane hydrate-bearing formations and various phenomena on the seafloor. It may be likely that the occurrence of methane hydrate and the geological phenomena on the seafloor have a strong implication with some typical geologic structures, e.g. shallow fault, highly-permeable sediments and hydraulic fractures, which may control the fluid migration. Besides, in this study we learnt that bathymetric map and seafloor amplitude map constructed by the high-resolution 3D seismic data are very useful not only for interpretation of relation between methane hydrate-bearing formation and various phenomena on the seafloor but also for designing the following seafloor investigations. This study is conducted by the MH21. 11408 The particle size effect on Gas hydrate Formation in powdered silica particles 2007 AGU Fall Meeting 2007/12/10-14 Tatsuji Kawasaki(Japan Oil, Gas and Metals National Corporation), Hailong Lu, John A.Ripmeester, Huang Zeng(National Research Council Canada), Tetsuya Fujii, Masaru Nakamizu(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Based on the investigations in the past years, it has been recognized that methane hydrates in Nankai Trough primarily occur in turbidite sediments (Fujii et al. 2005; Uchida et al., 2005). Turbidite is composed of a set of sediments, generally becoming finer upward in particle size, from coarse sand to clay (Bouma, 1962). In natural environment the formation of methane hydrate will be inevitably subject to the influence of sediments, so the modes of gas hydrate formation and occurrence might be different in the sediments with various particle sizes and mineral compositions. The elucidation of this issue, how sediments affect methane hydrate formation and occurrence will help in efficient hydrate exploration, accurate estimation of hydrate reserve, and the design of hydrate production method. In this research, we especially studied the particle size effect on the water conversion degree to hydrate using a set of powdered silica particles with the size from medium silt (<20 μm) to medium sand (250-500 μm). The test specimens were saturated with 3.5% NaCl solution, simulating the interstitial water of marine sediments, and reacted with methane gas at the pressure of 〜 10 MPa and temperature of 3 ℃. The water conversion degree to hydrate in a test specimen was estimated with the amount of gas that was clathrated in hydrate. The obtained results indicate a clear relationship between water conversion degree to hydrate and particle size: only 3.2% when particle size is <20μm, increasing dramatically from 5.7% to 82.8% when particle size changes from 〜30μm(coarse silt ) to 〜200μm(fine sand), and almost stable at 〜80% when particle size is > 250μm (medium sand). Because the test materials are all silica, the difference in water conversion degree to hydrate should be resulted from physical properties of silica particle, specific surface area, and/or the property confined by silica particle, pore size. This study was carried out as a part of Research Consortium for Methane Hydrate Resources in Japan(MH21). 11407 Resource Assessment of Methane Hydrate In the eastern Nankai Trough, Japan 2007 AGU Fall Meeting 2007/12/10-14 Tetsuya Fujii, Tatsuo Saeki, Toshiaki Kobayashi, Takao Inamori, Masao Hayashi, Osamu Takano(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Resource assessment of methane hydrate(MH) in the eastern Nankai Trough was conducted through probabilistic approach using 2D/3D seismic survey data and drilling survey data from METI exploratory test wells "Tokai-oki to Kumano-nada"[1,2,3]. We have extracted several prospective "MH concentrated layers (structures)" [4] characterized by high resistivity in well log, seismic high amplitude, seismic high velocity, and turbidite deposit by sedimentary facies analysis. The amount of methane gas derived from MH bearing layers were calculated using volumetric method for each structure. Each parameter, such as Gross Rock Volume (GRV), net-to-gross ratio (N/G), MH pore saturation (Sh), porosity, cage occupancy, and volume ratio was given as probabilistic distributions for Monte Carlo simulation considering the uncertainly of these value. GRV for each hydrate bearing structures was calculated from both strong seismic amplitude anomaly and velocity anomaly. Time-to depth conversion was conducted using interval velocity derived from SVWD (Seismic Vision While Drilling). Risk factor was applied for the estimation of GVR in 2D seismic area considering the uncertainty of seismic interpretation. N/G was determined based on the relationship between LWD resistivity and grain size in the structure with existing wells. 3 ohm-m was used for the typical cut off value for the net intervals. Seismic facies map created by sequence stratigraphic approach [5] was also used for the determination of N/G in the structure without well controls. Porosity was estimated using density log, together with the calibration by core analysis. Sh was estimated by combination of density log and NMR log (DMR method), together with the calibration using observed gas volume from onboard hydrate dissociation tests of PTCS (Pressure Temperature Core Sampler) [6]. Sh in the structure without well control was estimated using relationship between P-wave interval velocity and Sh from NMR log at well location. Cage occupancy was determined to be around 0.95 by refereeing recent field observations. Constant value of 172 in standard condition was used for volume ratio. Total amount of methane gas in place contained in MH in the eastern Nankai Trough within survey area was estimated to be 40 tcf as Pmean value (10 tcf as P90 value, 82 tcf as P10 value). Total gas in place for MH concentrated layer was estimated to be 20 tcf (Half of total amount) as Pmean value. Sensitivity analysis indicated that sensitivity of N/G and Sh is higher than other parameters, and important for further detail analysis. [1] Takahashi et al. (2005): Proc. of 2005 OTC, 2-5 May, Houston, Texas, U.S.A.. [2] Fujii et al. (2005): Proc. of 5th ICGH, Trondheim, Norway, 974-979. [3] Tsuji et al. (2007): AAPG Special Publication (in press) [4] Saeki et al. (2007): Abst. of 2007 Technical Meeting of the JAPT, June 5-7, 2007, Tokyo, p49. [5] Takano et al. (2007): Abst. of 2007 Technical Meeting of the JAPT, June 5-7, 2007, Tokyo, p34. [6] Fujii et al. (2007): AAPG Special Publication (in Press). 11406 Turbidite channel as methane hydrate concentrated zone - study results of 3D seismic data interpretation - 2007 AGU Fall Meeting 2007/12/10-14 Naoyuki Shimoda, Tatsuo Saeki, Takao Inamori, Toshiaki Kobayashi, Tetsuya Fujii(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] 3D seismic data were acquired In the eastern Nankai Trough area, offshore Japan by METI in 2002 in order to evaluate resource potential of methane hydrates. Through the studies on these seismic data and the results of multi-well drilling surveys carried out in 2004, more than 10 methane hydrate concentrated zones were delineated in this area. The methane hydrate concentrated zones were characterized by turbidite sand bodies which can be roughly classified into channels and lobes in the seismic geomorphology point of view. We focused our attempt to reveal internal structure of a channel type methane hydrate concentrated zone using high resolution 3D seismic data. Basically, channel complex can be recognized by reflectors suggesting erosion surfaces and internal bodies of sand layers. The whole channel is vertically divided to the upper and lower parts bounded by BSR. As it is difficult to interpret the internal structure in the lower part due to the less continuous reflectors, only the upper part was geomorphologically analyzed by picking the high amplitude reflectors which suggest the hydrate concentrated sand dominated bodies. The group of the picked reflectors suggests the 3D feature of the channel development. The channel was bended during its sediment deposition. The original channel flowed from northeast to south. And later, the flow was from northeast to west-southwest. Thus, we can find the detailed shape of each sand dominated body within channel, and therefore, it is expected that detailed analysis of many reflector patches in the channel can teach us the properties of methane hydrate bearing thin sand dominated bodies by classifying their shapes. Further, such properties will contribute to the future precise volume estimation of methane hydrates, and also to the model construction for production simulation. This study is carried out for Research Consortium for Methane Hydrate Resources in Japan (MH21). 11405 Numerical Simulation of Generation and Migration of Methane and Accumulation of Methane Hydrate In the eastern Nankai Trough 2007 AGU Fall Meeting 2007/12/10-14 Ryosuke Aoyagi(Mizuho Information and Research Institute), Tetsuya Fujii(Japan Oil, Gas and Metals National Corporation), Minoru Yoshikawa, Yutaka Nakama(Mizuho Information and Research Institute), Tatsuji Kawasaki, Sadao Nagakubo, Tokujiro Takayama, Toshiaki Kobayashi, Takao Inamori, Masaru Nakamizu(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] We have developed 2-D numerical simulator "SIGMA-MH" for methane hydrate(MH) accumulation in order to simulate geological/physicochemical phenomena related to MH deposits formation in deepwater sediment and to clarify controlling factors for MH accumulation. SIGMA-MH is a modified version of "SIGMA-2D", basin simulator for petroleum system developed by JOGMEC. SIGMA-MH has models such as microbial methane generation model and MH formation/dissociation model, with which MH accumulation can be simulated. An empirical model is used for microbial methane generation model. In this model, maximum gas generation rate is estimated from organic accumulation rate, which are derived from ODP gas sample analysis. Kinetic reaction model is applied for MH formation/dissociation. MH formation/dissociation rate is expressed as a function of the difference between the fugacity of methane at gas phase and fugacity of methane at the three-phase equilibrium for MH-water-methane gas. Using SIGMA-MH, case studies were conducted for two sections including boreholes at Tokai-Oki and Daini-Atsumi area where MH concentration is detected. Geological structure used in the simulation was estimated by seismic survey. Rock facies were determined by logging and core sample. Heat flow was calibrated by present temperature measured by geothermometer. Base case, shallow case, and deep case were conducted as a sensitivity analysis for paleo-water depth. As a result, a series of recycling process, that is, methane gas generation, MH formation, MH dissociation, gas migration, and MH formation, was simulated. MH accumulation estimated by simulation nearly corresponds to that of actual borehole. The phenomena that methane gas migrates through permeable sand layers and MH accumulates in them suggests that permeability are a key of MH accumulation. It was found that paleo-water depth plays an important role because it affects on present MH accumulation. For future work, we will conduct sensitivity analyses of quantitative parameters and paleo-water depth and improve SIGMA-MH as a tool for understanding controlling factors of MH accumulation. This study was carried out as a apart of Research Consortium for Methane Hydrate Research in Japan(MH21). 11404 The Stabilization of Methane Hydrate by Pressurization with He or N2 Gas The Journal of Physical Chemistry 2007/12 Hailong Lu (National Research Council Canada), Yoshihiro Tsuji(Japan Oil, Gas and Metals National Corporation), John A. Ripmeester(National Research Council Canada) Geology & Geophysics Research Division [Abstract] The behavior of methane hydrate was investigated after it was pressurized with helium or nitrogen gas in a test system by monitoring the gas compositions. The results obtained indicate that even when the partial pressure of methane gas in such a system is lower than the equilibrium pressure at a certain temperature, the dissociation rate of methane hydrate is greatly depressed by pressurization with helium or nitrogen gas. This phenomenon is only observed when the total pressure of methane and helium (or nitrogen) gas in the system is greater than the equilibrium pressure required to stabilize methane hydrate with just methane gas. The following model has been proposed to explain the observed phenomenon: (1) Gas bubbles develop at the hydrate surface during hydrate dissociation, and there is a pressure balance between the methane gas inside the gas bubbles and the external pressurizing gas (methane and helium or nitrogen), as transmitted through the water film; as a result the methane gas in the gas bubbles stabilizes the hydrate surface covered with bubbles when the total gas pressure is greater than the equilibrium pressure of the methane hydrate at that temperature; this situation persists until the gas in the bubbles becomes sufficiently dilute in methane or until the surface becomes bubble-free. (2) In case of direct contact of methane hydrate with water, the water surrounding the hydrate is supersaturated with methane released upon hydrate dissociation; consequently, methane hydrate is stabilized when the hydrostatic pressure is above the equilibrium pressure of methane hydrate at a certain temperature, again until the dissolved gas at the surface becomes sufficiently dilute in methane. In essence, the phenomenon is due to the presence of a nonequilibrium state where there is a chemical potential gradient from the solid hydrate particles to the bulk solution that exists as long as solid hydrate remains. 11403 Development and experimental feasibility study of the prediction method for hot corrosion of gas turbine components International Gas Turbine Congress 2007 Tokyo 2007/12/2 Hironori Kamoshida, Hideki Tamaki, Yoshitaka Kojima (Hitachi Research Lab., Hitachi, Ltd.), Tomoko Watanabe(Japan Oil, Gas and Metals National Corporation) Petroleum Engineering Research Division [Abstract] Development and experimental feasibility study of the prediction method for hot corrosion of gas turbine components 11401 Pore space reconstruction of vuggy carbonates using microtomography and multiple-point statistics Water Resources Research Vol.43 2007/11/29 Hiroshi Okabe(Japan Oil, Gas and Metals National Corporation/Imperial College London), Martin J. Blunt(Imperial College London) Petroleum Engineering Research Division [Abstract] To reconstruct complex porous media, such as carbonates, we propose a two-step approach to combine different types of images: microtomography at the resolution of a few microns to resolve large pores and vugs, with statistically reconstructed high-resolution images for smaller features. Two-dimensional (2-D) thin sections provide multiple-point statistics which describe the statistical relation between multiple spatial locations that can be used to generate 3-D images with accurate connectivity. These statistical reconstructions are combined with images directly measured by microtomography. The integrated method is tested on carbonates for which 3-D images of disconnected vugs are captured, while 2-D thin sections characterize the small-scale structure. The integrated images have permeabilities computed using the lattice Boltzmann method that are similar to laboratory-measured values. 11400 A Wave Propagation-based Method for Improved Seismic Fracture Prediction ASEG (Australian Society of Exploration Geophysicists) 2007/11/21 Mu Luo (JGI, Ink.), Mamoru Takanashi(Japan Oil, Gas and Metals National Corporation) Geology & Geophysics Research Division [Abstract] Using physical model data, this study first physically confirms the significance of P-wave overburden effect, and most importantly, tests the wave-propagation based concept in developing our methodology to study fracture/anisotropy. The 70 m width of fractures in our model, comparing with a minimum offset of 600 m, was produced for conducting fracture study or clarify the observed anisotropy signatures (amplitude and velocity) originated from the fractured model. The model itself, comparing with the wavelength, is optimized for evaluating the fracture and the heterogeneous overburden effect. The vertical fractures contained in the model may be viewed as simplified fracture zone of randomly dispatched fracture swaps or carbonate/channel with fractures and anomalous amplitude and velocity, while the strong source radiation could represent a poor field acquisition. Nevertheless, test results indicate that the new method could identify interval/location of fracture-related velocity slowdown and amplitude attenuation. This will highly contribute to correct interpretation and prevent from misinterpretation of the layer below anomaly, which can be also helpful in the field examples. Another important indication is that the velocity anisotropy, normally considered higher along the fractures than perpendicular to the fractures, could not be true due to overburden heterogeneity. 11399 Application of prestack depth migration across the Ichthys field, Browse basin ASEG (Australian Society of Exploration Geophysicists) 2007/11/21 Masamichi Fujimoto(INPEX Browse Ltd.), Mamoru Takanashi(Japan Oil, Gas and Metals National Corporation), Mike Szczepaniak, Takeshi Yoshida(INPEX Browse Ltd.) Research Project Team on Subsurface Technologies for Field Development [Abstract] This study aimed to reduce uncertainty of reservoirs’ depth and improve image quality in the Ichthys field, Browse Basin. The following method, detailed tomographic velocity modelling combined with prestack depth migration (PSDM), isotropic Kirchhoff PSDM and the well calibration were implemented. Initial stacking velocity analysis for 3D prestack time migration (PSTM) revealed geologically implausible and undulating RMS velocity patterns at reservoir depths across the main section of the field, which reduced image quality and reservoir depth accuracy. Further investigation with forward modelling revealed that the velocity distortions might be primarily induced by shallow Tertiary sequences, containing highly contrasting, narrow, elongate velocity anomalies. Layered/blocky modelling combined with dense residual moveout picking and 3D finite-offset tomography enabled the construction of a complex velocity model in the shallow section. Subsequent gridded/smoothed velocity tomography with constraints was then used for updating the entire velocity field. The final derived velocity field was more systematically correlated with that observed at the wells and the corresponding depth structure produced from PSDM appeared to contain less distortion and be more geologically realistic. The resultant velocity model is currently being incorporated into the structural evaluation for the Ichthys Field. 11398 Investigation of Overburden Heterogeneity Effects and Their Removal through High Resolution Tomography and Prestack Depth Migration ASEG (Australian Society of Exploration Geophysicists) 2007/11/21 Mamoru Takanashi(Japan Oil, Gas and Metals National Corporation), Dimitri Chagalov, Pierre Plasterie(CGGVeritas), Masamichi Fujimoto(INPEX Browse Ltd.) Research Project Team on Subsurface Technologies for Field Development [Abstract] For contributing to precise depth delineation in the Ichthys giant gas field offshore northwest Australia, we investigated shallow velocity heterogeneity effects using forward modelling and seismic data review. We discovered that their removal through applications of high-resolution tomographic velocity modelling and prestack depth migration (PSDM) enabled correct representation of the target reservoir structure. Analysis of synthetic seismic pre-stack gathers generated from forward modelling demonstrated that small velocity anomalies, such as channels, in shallow overburdens could give rise to apparent seismic RMS velocity artefacts at deeper target levels. Delineation of “true” velocity anomalies and implementation of PSDM using precise shallow velocity model were required for solving these problems. In accordance with the phenomenon predicted by forward modelling, examination of coinciding patterns of time-thickness, amplitude and deep prestack time migration (PSTM) velocity allowed determination of the shallow heterogeneous layers that caused target velocity undulation. We employed two iterations of tomographic velocity model updating for PSDM velocity model building. First, the shallow heterogeneous velocity patterns were successfully identified by utilising the dense residual moveout picking and the layer-based 3D high-resolution finite-offset tomography. Subsequent grid-based global tomography with constraints was used for updating the entire velocity field and delivered stable velocity pattern at the deep. This two-step approach successfully eliminated deep velocity artefacts. 11396 A Japanese perspective on the use of new technologies Windsor Energy Group Houston Meeting 2007/11/6 Yoshihiro Tsuj(Japan Oil, Gas and Metals National Corporation) Geology & Geophysics Research Division [Abstract] The importance of new technology in Exploration and Production to extend the reserves and high production rate is recognized. Therefore, associated with the recently published 'Japan's New National Energy Strategy' by the Ministry of Economy, Trade and Industry (METI), Technology and Research Center (TRC) of Japan Oil, Gas and Metals National Corporation (JOGMEC) has estimated the medium to long term R&D strategy toward 2030. In order to identify the goals to be reached by 2030 in individual prioritized technological fields, "10 Core Projects" were proposed. Those are related to (1) EOR to have 70% oil recovery, (2) Reservoir total visualization for the accuracy of reserves assessment in exploration and development, (3) Offshore oil field development to the depth of 3000m, (4) Well drilling to increase the drilling and completion efficiency, (5) Next-generation advanced resource development to find out technological breakthrough through incorporating leading-edge technologies such as IT, robotics, nanotechnology and biotechnology, (6) National methane hydrate project from exploration to development of methane hydrate, (7) Ultra heavy oil by incorporating upgrading and other technologies into oil-field development upstream technologies, (8) Next-generation Non-conventional Hydrocarbon Exploitation to develop enhanced coal bed methane (ECBM) technology and other next-generation technologies after the SAGD process, (9) GTL using the Japanese GTL process utilizing CO2 effectively, and (10) Next-generation oil and gas effective utilization by establishing new natural-gas transportation technology. To make the goals of the projects fruitful, JOGMEC-TRC recognizes that training of the participating engineers and geoscientists within the project, cooperation and collaboration with Universities, National Oil Countries, Technological consultants, other R&D institutes, oil companies, and utilizing the field demonstration are very important, and it is committed to the technological advancement in the world of petroleum exploitation. 11392 DIRECT SYNTHESIS OF PROPANE/BUTANE FROM SYNGAS LP Gas Global Technology Conference 2006 2007/10/19-20 Kaoru Fujimoto(The University of Kitakyushu) Research Project Team on Emerging Gas Technologies [Abstract] DIRECT SYNTHESIS OF PROPANE/BUTANE FROM SYNGAS 11390 Mitigation of Asphaltene Deposition Problems SPE Applied Technology Workshop(ATW) "Second Stage Field Development" 2007/10/17 Hideharu Yonebayashi(Japan Oil, Gas and Metals National Corporation) Research Project Team on Subsurface Technologies for Field Development [Abstract] Mitigation of Asphaltene Deposition Problems 11389 Methane Hydrate Exploration around the eastern Nankai Trough The 37th Annual Conference of the Underwater Mining Institute 2007/10/15-17 Tatsuo Saeki, Tetsuya Fujii, Masaru Nakamizu, Kenichi Yokoi(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Methane hydrate, a solid compound formed from methane and water, occurs naturally in permafrost regions on-land and in deep continental slopes offshore and has been examined as future energy resources. The existence of methane hydrate In the eastern Nankai Trough region, offshore Japan, was confirmed by drilling the MITI well “Nankai Trough” in 1999. Aiming commercialization of methane hydrate production, the Research Consortium for Methane Hydrate Resources in Japan (MH21, core associations: JOGMEC[*1], AIST[*2] and ENNA[*3]) under METI [*4] has been executing geological and geophysical surveys around the eastern Nankai Trough since 2001 as a nation project.  *1: Japan Oil, Gas and Metals National Corporation  *2: National Institute of Advanced Industrial Science and Technology  *3: Engineering Advancement Association of Japan  *4: Ministry of Economy, Trade and Industry, originally MITI Interpretation and analysis studies based on reflection seismic survey (2D:2001, 3D:2002), multi-wells drilling campaign (2004) and other geological surveys revealed existences of methane hydrate high concentrated zones, which are much attractive in the view of resource explorations. The concentrated zones are recognized in geological layers with porous sediments, which are turbidite sand layers in most cases. The JOGMEC Geology & Geophysics group and partners developed the geological interpretation workflow optimized for methane hydrate resource assessment including delineation of methane hydrate concentrated zones, and evaluated resource potential around the eastern Nankai Trough. In this presentation, we will introduce the outline of above surveys and interpretations. 11388 Multidisciplinary Approach to Solve Borehole Instability Problems in a Shale Formation SPE Applied Technology Workshop(ATW) "Second Stage Field Development" 2007/10/15 Hirofumi Okano, Daisuke Kuramoto, Koji Yamamoto(Japan Oil, Gas and Metals National Corporation) Petroleum Engineering Research Division [Abstract] Wellbore failures occur, when stress on wellbore exceeds the rock strength. Shale is the major source of instability, because it has a complex nature which we cannot describe using linear elastic, isotopic and homogeneous models. In this paper, we clarified the characteristics such as chemical activity, anisotropy and fissured nature. In addition, 3D proelastic models were used to estimate failed regions. The results of the numerical simulations showed that the hole conditions cannot be improved with too much weight of drilling mud. 11387 Gas to Wire System (GTW) for Developing "Small Gas Fields" and Exploiting "Associated Gas" SPE Applied Technology Workshop(ATW) "Second Stage Field Development" 2007/10/15 Tomoko Watanabe, Hirofumi Okano, Daisuke Kuramoto(Japan Oil, Gas and Metals National Corporation) Petroleum Engineering Research Division [Abstract] A Gas to Wire system (GTW) is proposed as a new development concept for marginal gas fields. The aim of this project is to commercialise small stranded gas fields with a reserve between 10 bcf and 1tcf. GTW adopts onsite power generation utilising produced gas and has high efficiency, because there is no need to transport the produced gas. JOGMEC, Hitachi, JGC Corporation, Toyohashi University of Technology, and Arabian Oil Company conducted the research on high efficiency, low cost and low emission GTW by applying Gas Turbine Combined Cycle System (GTCC). The project includes a feasibility study on associated gas from a Middle East offshore oil field. 11386 Geochemical Study of Microbial Methanogenesis and Gas Hydrate Formation International Conference on Gas Hydrate 2007/10/5 Amane Waseda(JAPEX), Tetsuya Fujii(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Geochemical Study of Microbial Methanogenesis and Gas Hydrate Formation 11379 High pressure air injection into light oil reservoirs: experimental study on artificial ignition International Energy Agency Collaborative Project on Enhanced Oil Recovery 2007/9/5 Takeshi Onishi(Japan Oil, Gas and Metals National Corporation), Katsumi Katoh(AIST), Katsumo Takabayashi, Hiroshi Uematsu(Teikoku Oil Co., Ltd.), Komei Okatsu(Japan Oil, Gas and Metals National Corporation), Yuji Yada, Yuji Ogata(AIST) Petroleum Engineering Research Division [Abstract] Recently, High Pressure Air Injection (HPAI) is considered to be an effective EOR method to light oil reservoirs. HPAI has some remarkable merits as follows. (1)Injection gas source can be supplied anywhere for free. (2)Initial cost is relatively inexpensive because the main facility required is only air compressor. (3)The method can be applied even in low permeable reservoirs where water cannot be injected. On the other hand, the evaluation of HPAI is difficult, because the mechanism and the reactions of oxidation and combustion are complicated. A Japanese domestic oil field has been investigated to apply HPAI as tertiary mode. Experimental and numerical simulation results suggest that it is possible to obtain the incremental oil recovery by HPAI. But they also suggest that the ignition temperature of the oil may be higher than the reservoir temperature. If ignition doesn’t occur in reservoir, thermal effect on recovery mechanism can not be expected and oxygen may be early breakthrough to producer because of low oxygen consumption. So, oxygen consumption is important not only for the efficiency of incremental oil recovery but also for safety operation. Ignition method has to be ensured for the application of HPAI to the oil field. Accelerating Rate Calorimeter (ARC) Tests are carried out to assess the influence of oxygen slug and linseed oil on ignition temperature. The experimental results suggest that in case of oxygen slug the ignition temperature decreases but doesn’t reach the reservoir temperature even if high concentration of oxygen is applied. They also suggest that the ignition temperature decreases to the reservoir temperature in case of high concentration of linseed oil. 11378 Wettability evaluation by big borehole MRI International Energy Agency Collaborative Project on Enhanced Oil Recovery 2007/9/5 Yasuyuki Mino, Kazuhito Oseto (Japan Oil, Gas and Metals National Corporation) Petroleum Engineering Research Division [Abstract] It is difficult to predict fluid flow through heterogeneous reservoir rocks such as carbonates without knowing detail distributions of petrophysical properties of the rocks. Among those properties the wettability is of particular importance, however, any methods currently do not provide its spatial distribution. Magnetic Resonance Imaging (MRI) is expected to provide such a wettability distribution rapidly comparing to the Amott and USBM methods. We use a medical MRI machine with a big borehole that can handle bigger samples and subsequently provides a whole picture of the core sample. However, there have been very few studies conducted to investigate the correlation between the MRI signals and the wettability using such big borehole machines while several researchers have used small borehole machines. In our study, the correlation between the T1 relaxation time and the wettability was investigated although further studies are necessary to obtain the wettability index in detail. 11377 Recent Activities of R&D Program on Methane Hydrates in Japan First International Energy Week & Exhibition and Symposium 2007/9/4-8 Koichi Sugiyama, Kenji Ohno(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] The exploratory test well "Nankai Trough" drilled in 2000 by MITI (Ministry of International Trade and Industry) offshore Japan confirmed, for the first time, methane hydrates in pore space of turbiditic reservoir sand like conventional gas resources. Japan's Methane Hydrate Exploration Program was issued on July 2001 envisaging a promotion of technical development for economical drilling, production and recovery of gas from methane hydrates, and a facilitation of its utilization for the long-term stable energy supply to Japan. The program shall define whether methane hydrates presumed to develop offshore Japan become the future energy resources for the country in accordance with the following framework of 16 years. Phase 1 (FY2001 to FY2008) Seismic survey, logging and coring. Onshore production tests in Canada. Phase 2 (FY2009 to FY2011) Offshore production tests. Phase 3 (FY2012 to FY2016) Study of economic feasibility, arrangements for commercial production and evaluation of environmental issues. Final report of the program will be submitted in the end of FY 2016. Research Consortium for Methane Hydrate Resources in Japan (MH21 Resources Consortium) has been established in March 2002. The consortium comprises of three leading organizations namely; Technology Research Center-Japan Oil, Gas and Metals National Corporation (JOGMEC-TRC), National Institute of Advanced Industrial Science and Technology (AIST) and Engineering Advancement Association of Japan (ENAA). The numbers of participants under the said Consortium are about 300 persons and about 30 organizations. The three leading organizations mentioned above represent the following working groups respectively to perform effectively R&D program in collaboration with MH21 Research Consortium Secretariat; 1. Research group of assessment of methane hydrates resources 2. Research group of production method and modeling 3. Research group of assessment of environment impact 11376 Pore-scale analysis of carbonates using 3D micro-CT imaging: effects of inclusion of microporosity IEA Collaborative Project on Enhanced Oil Recovery, 28th Annual Workshop and Symposium 2007/9/4-7 Hiroshi Okabe(Japan Oil, Gas and Metals National Corporation/Waseda Univ.), R. M. Sok, C. H. Arns(Australian National Univ.), M. A. Knackstedt(Australian Univ./University of New South Wales), T. J. Senden, A. P. Sheppard, H. Averdunk(Australian National Univ.), W. V. Pinczewski(Australian Univ./University of New South Wales) Research Project Team on Subsurface Technologies for Field Development [Abstract] Carbonate reservoirs increasingly become important as they contain more than 50% of the world’s hydrocarbon reserves. Carbonate rocks are diverse and their pore space complex, therefore, they require detailed studies at the different level from micro to macro scale. Large variations in petrophysical properties of carbonates are caused by wide variations in pore type, shape and interconnectivity. Petrophysical properties are directly related to the amount and type of porosity, the dominant feature size and the interconnectivity of different porosity groups. While the properties strongly depend on pore-scale physics, accurately measuring these attributes requires the detail analysis of pore structure in 3D. We describe the imaging of carbonate core samples in 3D and calculate some of petrophysical properties such as drainage capillary pressure and resistivity directly on the images. Then we correlate the resultant petrophysical properties to the pore structure of the rock. Connectivities of pores are studied as the bioclastic core samples have significant proportions of both connected and disconnected (separate) macropores. It is shown that inclusion of larger pores associated with the smaller pores results in complete connectivity of the macroporous phase and the inclusion of microporosity has a dramatic effect on the petrophysical properties for the bioclastic sample. Three dimensional imaging and analysis of carbonate core material at the pore scale can provide a basis for more accurate petrophysical models, narrow the range of uncertainty in estimates of petrophysical properties and improve the quantification of the resource within carbonate reservoirs. 11374 Hydrogen production from dimethyl ether by steam reforming over copper alumina catalysts prepared by the sol-gel method EUROPACAT VIII 2007/8/30 Kaoru Takeishi (Shizuoka Univ.) Research Project Team on Emerging Gas Technologies [Abstract] New catalysts for hydrogen production from dimethyl ether (DME) have been developed. Cu-Zn/Al2O3 catalysts prepared by a sol-gel method produced large quantities of H2 and CO2 with DME steam reforming at 300 ℃. The catalysts are more useful for hydrogen production than general DME steam reforming catalysts (mixed catalysts of DME hydrolysis catalysts and methanol steam reforming catalysts). γ-alumina sites for DME hydrolysis into methanol, and copper sites for methanol steam into H2 and CO2 coexist on the surfaces of the sol-gel catalysts, and the two reaction occur systematically, and the catalysts produce H2 effectively from DME. 11373 Time-lapse 3D Seismic monitoring in the JACOS oil sands development field in Canada SEG Development & Production Forum "Heavy Oils" 2007/8/1 Toru Nakayama, Akihisa Takahashi(JAPEX), Ray Nasen(JACOS), Ayato Kato(Japan Oil, Gas and Metals National Corporation) Petroleum Engineering Research Division [Abstract] Time-lapse 3D seismic study was conducted in the Japan Canada Oil Sands Limited (JACOS) Hangingstone steam-assisted gravity drainage (SAGD) operation area, Alberta, Canada. The time-lapse surveys were acquired in February, 2002 and in March, 2006. The two seismic volumes show distinct seismic response changes around the SAGD well pairs. From our time-lapse data analysis, these differences of the seismic responses were interpreted as phenomena caused by P-wave velocity decrease of the oil sands layers due to the steam-injection. 11372 Core velocity measurements of oil sands for quantitative interpretation of time-lapse 3D seismic steam front monitoring SEG Development & Production Forum "Heavy Oils" 2007/7/31 Shigenobu Onozuka, Ayato Kato(Japan Oil, Gas and Metals National Corporation), Toru Nakayama(JAPEX), Ray Nasen (JACOS) Petroleum Engineering Research Division [Abstract] The time-lapse seismic survey was conducted in the JACOS Hangingstone SAGD operation area. The preliminary result of the survey shows significant difference of seismic response between the baseline and repeat surveys. The difference is interpreted as effect of steam injection. It is, however, not well understood how the seismic amplitude and velocity changes of the oil sands due to the variations of reservoir pressure, temperature and fluid saturation expected during the steam injection in this field. JOGMEC hence developed a novel apparatus for measuring ultrasonic core velocities of unconsolidated sample like the oil sands. We measured and analyzed P-and S-velocities of plug samples of the oil sands acquired from the field, as well as bitumen itself. We showed that behavior of bitumen strongly depends on temperature. In the temperature less than around 40C, bitumen works as like pseudo-solid, which cause several phenomena including high viscosity, low elasticity, substantial shear modulus, high attenuation and strong velocity dispersion. The core velocity measurements showed that natural logarithm function can be applied as a fitting curve for the relationship between the velocity and effective pressure, while two linear lines can be applied as a fitting curve for the relationship between velocity and temperature. In higher temperature than 80C, Gassmann equation can be applied for predicting velocity changes. From the velocity measurements and Gassmann equation analysis, we finally proposed the velocity model which can predict velocity changes of the oil sands caused by any variations of the reservoir conditions. Based on the velocity model, synthetic seismic traces at several reservoir conditions were calculated and compared to the actual seismic trace data at the well location. Seismic attenuation of the oil sands strongly depends on temperature, as well as bitumen. The attenuation information (Q value) may be able to be utilized for distinguishing area where oil sands reservoir is moderately heated (40<T<120C). We are working on quantitative interpretation integrating this study's results with the surface seismic data analysis. 11371 Direct Synthesis of Dimethyl Ether from Synthesis Gas Containing Oxygen 9th International Symposium on Biotechnology Metal Complexes and Catalysis 2007/7/28 Kaoru Takeishi (Shizuoka Univ.) Research Project Team on Emerging Gas Technologies [Abstract] I have developed the appropriate and excellent catalyst for DME direct synthesis. The catalysts, Cu-Zn/Al2O3 catalysts prepared by the sol-gel method, produce DME with high activity and high selectivity under the mild reaction temperature and pressure, even if the reaction gases contain some oxygen. 11365 Hydrogen Production from Dimethyl Ether by Copper Alumina Catalysts Prepared by Sol-Gel Method The 2nd International Conference on Advances in Petrochemicals and Polymers (ICAPP2007) 2007/6/26 Kaoru Takeishi (Shizuoka Univ.) Research Project Team on Emerging Gas Technologies Dimethyl ether (DME) is expected as a clean fuel of the next generation. I have developed new catalysts for hydrogen production by steam reforming of DME. Cu-Zn/Al2O3 catalysts prepared by a sol-gel method produce large quantities of H2 and CO2 by DME steam reforming under lower reaction temperature. H2 production by steam reforming of DME consists of two reaction steps. The first reaction is hydrolysis of DME into methanol. The second reaction is steam reforming of methanol that produces H2 and CO2. For this reason, the mixed catalysts of DME hydrolysis catalysts and methanol steam reforming catalysts are used for hydrogen production by DME steam reforming. However, the copper alumina catalysts prepared by the sol-gel method in single use are more excellent for H2 production by DME steam reforming than the mixed catalysts. The reason is that -Al2O3 sites for DME hydrolysis and Cu sites for methanol steam reforming are co-existing closely on the catalyst surface. The consecutive reactions smoothly occur, and hydrogen is produced more effectively over the sol-gel Cu/Al2O3 catalyst in single use than over the mixed catalysts. Addition of Zn, Mn, or Fe into Cu/Al2O3 catalyst activates steam reforming of DME. The Cu-Zn(29-1wt.%)/Al2O3 catalyst showed the excellent activity of DME steam reforming; the DME conversion was 95%, H2 yield was 95%, and CO concentration was 0.8 mol.%. I have developed new catalysts for H2 production from DME, and the catalysts give us a great potential for H2 supply from DME. 11347 Geomechanics Issues of the Methane Hydrate Production and Related Material Properties 18th ASCE Engineering Mechanics Conference 2007/6/4 Koji Yamamoto(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] This paper describes the importance of the mechanical properties of the methane hydrate bearing sediments for gas production from the solid form of the hydrocarbon. The dissociation and association processes of the gas hydrate in granular material are coupled phenomena of the thermodynamic condition change, fluid (gas and water) flow, and also the mechanical deformation and failure. Hydrate dissociation and association change the mechanical properties, and deformation and failure make thermal and flow conditions of the material different. This process may cause several issues on the field development for gas production, such as borehole instability, instability of the reservoir formation and surface, near wellbore phenomena and so on 11346 MECHANICAL PROPERTIES OF POST-DISSOCIATION METHANE HYDRATE BEARING SEDIMENTS AND SOLID PRODUCTION MECHANISM 18th ASCE Engineering Mechanics Conference 2007/6/4 Koji Yamamoto(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team Reported in this paper is a laboratory experimental study on mechanical properties of the core materials and solid production behaviour in post-dissociation methane hydrate-bearing formations. The compressive triaxial and direct tensile strength properties were evaluated on re-constituted core materials at room temperature. A number of laboratory solid production experiments were carried out on the same core materials to examine simulated perforation tunnel stability and solid production behaviour. It was found that at a low water saturation (〜30%), a cone shaped cavity could be formed on the sand face and remain stable for an injection pressure of 1MPa if the flowing fluid was gas. However, this injection was reduced to 0.1 to 0.2 MPa if the injection fluid was brine water. At a higher water saturation (〜70%), a stable cavity was not observed. Sand production was induced at an injection pressure of 0.1-0.2 MPa for both gas and water injection. Sand production behavior appeared not to be affected by the hole size on the sand face. 11343 Catalysts for direct synthesis of dimethyl ether from synthesis gas The 11th Korea-Japan Symposium on Catalysis 2007/5/22 Kaoru Takeishi (Shizuoka Univ.) Research Project Team on Emerging Gas Technologies [Abstract] Copper alumina catalysts prepared by a sol-gel method that is appropriate for DME steam reforming are applied for the DME direct synthesis (3H2 + 3CO → CH3OCH3 + 2CO2) that is similar reaction of DME steam reforming (CH3OCH3 + 3H2O → 3H2 + 2CO2). Much amount of DME was produced over Cu-Zn/Al2O3 catalyst prepared by the sol-gel method, at the lower reaction temperature of 250ºC. The less amount of DME was produced over the mixed catalyst of the methanol synthesis catalyst (N211) and the methanol dehydration catalyst (BK-105), at the higher reaction temperature of 310ºC. The single type catalyst that has copper sites for methanol synthesis and alumina sites for methanol dehydration on the surface is more appropriate and more excellent for DME direct synthesis than the mixed catalyst that is one of the patent catalysts for DME direct synthesis. 11329 Basin Modeling on Formation of Methane Hydrate Including Generation and Migration of Microbial Methane AAPG(American Association of Petroleum Geologists)HEDBERG CONFERENCE "Basin Modeling Perspectives: Innovative Developments and Novel Applications" 2007/5/9 Akihiko Okui(Idemitsu Oil and Gas Co., Ltd.), Ryosuke Aoyagi(Mizuho Information and Research Institute, Inc.), Martin Schoell (Gas Consult International Inc.), Tetsuya Fujii(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Exploration and development for gas hydrate is hot issue in Japan now. Estimation of its resources is essential in initial stage of investigation. Understanding of generation and migration of methane as well as formation of methane hydrate is very helpful for this kind of study like petroleum system for oil and gas exploration. A basin model, which can simulate the formation of methane hydrate as well as generation and migration of microbial methane was developed and then was used for the evaluation of methane hydrate in Nankai Trough area in Japan 11327 Estimation of Petrophysical Parameters from 3D images of Carbonate Core SPWLA Middle East Regional Symposium 2007/4/15-19 R. M. Sok, C. H. Arns(Australian National Univ.), M. A. Knackstedt(Australian National Univ/University of New South Wales), T. J. Senden, A. P. Sheppard, H. Averdunk(Australian National Univ.), W. V. Pinczewski(University of New South Wales), Hiroshi Okabe(Japan Oil, Gas and Metals National Corporation) Research Project Team on Subsurface Technologies for Field Development [Abstract] Carbonate rocks are diverse and their pore space complex. Large variations in petrophysical properties of carbonates are caused by wide variations in pore type, pore shape and pore interconnectivity. Petrophysical properties such as capillary pressure and Archie m,n values of carbonate rocks are directly related to the amount and type of porosity, the dominant feature size and the interconnectivity of different porosity groups. While the petrophysical properties strongly depend on the interconnectivity of pores and pore shapes, accurately measuring these attributes requires the analysis of pore structure in 3D. Until recently this has not been possible, and traditional descriptions of carbonate pore structure and interconnectivity have been inferred from 2D thin section analysis. In this paper we describe the imaging of a number of carbonate core samples from the UAE in 3D across a range of scales down to 2.8 microns. The samples include sucrosic dolomites and a complex bioclastic grain/packstone. We calculate drainage capillary pressure and resistivity as a function of saturation directly on the images and correlate the resultant petrophysical properties to the pore structure of the rock. While the dolomite samples exhibit a dominant and strongly interconnected macroporous phase (pore throats 4μm), the bioclastic sample exhibits a significant proportion of meso/microporosity (pore throats 4μm). Pore connectivity is studied for both sets of samples. The connectivity of the sucrosic dolomite exhibits a strong trend of lower connectivity with decreasing porosity. Other pore structural properties (e.g., pore size, pore-to-throat aspect ratio, pore and throat shape) show little variation. The bioclastic sample has significant proportions of both connected and disconnected (separate) macropores. It is shown that inclusion of larger pores associated with the mesoporous phase results in complete connectivity of the macroporous phase. The relative interconnectivity of the macropores is systematically related to the resultant Archie cementation exponent. The saturation exponent n is calculated for water-wet and oil-wet conditions. Strong differences in n with wettability are noted for the sucrosic samples. The inclusion of microporosity has a dramatic effect on the behaviour of n for the bioclastic sample. Three dimensional imaging and analysis of carbonate core material at the pore scale can provide a basis for more accurate petrophysical models, narrow the range of uncertainty in estimates of petrophysical properties and improve the quantification of the resource within carbonate reservoirs. 11326 Feasibility Study of Marine Controlled-Source Electromagnetic for Gas Hydrate The 11th International Symposium on Recent Advances in Exploration Geophysics (RAEG 2007) in Kyoto 2007/4/15-16 Kazunobu Yamane(Geothermal Energy Research & Development Co., Ltd), Tatsuo Saeki, Takao Inamori(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Marine controlled source electromagnetic method may be one of the most significant new technologies for hydrocarbon exploration. The promise for the technology lies in its ability to differentiate resistive, potentially oil-bearing intervals from surrounding, more conductive water-bearing units. The principle is the same as that used in well logging devices to identify hydrocarbon zones in well bores. The technique is not new but the capability to resolve relatively thin resistive intervals in the depth offers new promise to lower the risk through direct hydrocarbon indicators in conjunction with modern seismic methods. In this paper, we discuss the capability of marine CSEM method towards gas hydrate exploration by numerical studies of 1-D modeling and 2.5-D inversion. 11325 Geological interpretation of the northern part of the Kumano basin using 3D reflection seismic data The 11th International Symposium on Recent Advances in Exploration Geophysics (RAEG 2007) in Kyoto 2007/4/15-16 Tatsuo Saeki, Takao Inamori, Sadao Nagakubo(Japan Oil, Gas and Metals National Corporation), Sumito Morita(AIST), Osamu Takano(JAPEX) Methane Hydrate Research Project Team [Abstract] Conventionally, BSRs (bottom simulating reflectors), which are considered to be a bottom of the gas hydrate bearing sediment, have been picked as the reflectors in parallel with sea-bottom topography. The interpretation of 3D reflection seismic data revealed that the BSR in the Kumano basin include two types of local pull-up phenomenon that had no correlation with the sea- bottom topography The most remarkable BSR pull-up phenomena (type-A) occurred in the small circle area of 400m in diameter and the topography is like a mountain. The center top was closed to the sea-bottom in which the pockmark existed. Another type anomaly (type-B) consisted of several small pull-ups distributed in a line. Seismic velocity analysis showed that there were local high velocity anomalies directly above them, which could cause apparent BSR pull-ups. The geological interpretation suggested the possibility that above high velocities occurred due to concentrations of gas hydrate. On the other hand, the mountain type BSR pull-up might be related with the local variation of the thermal condition. 11317 Study on the deployment of accelerometers in reflection seismic surveys International Workshop on Underwater Technology/Scientific Use of Submarine Cables and Related Technologies 2007 2007/4/17-20 Hiroo Takahashi(OCC Corporation), Eichi Asakawa (JGI, Inc.), Yuji Kawai(Nippon Salvage Co., Ltd.), Yukitoshi Ogasawara(Kokusai Cable Ship Co., Ltd.), Tatsuo Saeki(Japan Oil, Gas and Metals National Corporation) Geology & Geophysics Research Team [Abstract] The RSCS (Real-time Seismic Cable System) is an optical submarine cable system with a series of three component velocity type sensors mounted in a pressure resistant case that can withstand hydraulic pressures up to 800 atmospheres (78.4 MPa). Spreads consisting of several of the above mentioned velocity type sensors, spaced at 50 meters interval, have been deployed during actual offshore reflection seismic survey operations. The resulting data quality acquired with RSCS was reported to be excellent and effectiveness of the system for reflection seismic survey demonstrated [Asakawa et al (2006)] Recently, the application of acceleration type sensors in the RSCS was studied. For comparison purposes, a system equipped with velocity type sensors and the acceleration type sensor was deployed during reflection seismic survey operations in an area with a water depth of about 1000m. Data acquired with both sensor types were excellent, confirming that RSCS equipped with the acceleration type sensor is also effective for reflection seismic surveys. Application of acceleration type sensors in the RSCS may allow reduction the size of sensor units because gimbal mechanism, necessary for keeping velocity sensor orientation horizontal, will no longer be necessary. 11316 Real-time Seismic Cable System (2) EGU2007 General Assembly 2007/4/15-21 Eichi Asakawa (JGI, Inc.), Yuji Kawai(Nippon Salvage Co., Ltd.), Hiroo Takahashi(OCC Corporation), Yukitoshi Ogasawara(Kokusai Cable Ship Co., Ltd.), Tatsuo Saeki(Japan Oil, Gas and Metals National Corporation) Geology & Geophysics Research Team [Abstract] RSCS (Real-time seismic Cable System) is a new real-time seafloor reflection seismic observation system. It is a series of 3-component geophones and telemetry optoelectronics equipped into a high pressure resistant housing, which enables real-time seismic data acquisition at ultra deep sea. The first reflection seismic survey was carried out in March 2006. The geophone data show the high quality with the advantage such as precise timing with GPS link on board and superior sensor directivity. It is worthwhile for P-S converted wave processing as well as for P-P processing. The data processing is different from the conventional reflection seismic such as CDP method in the viewpoint of its geometry and P-S conversion. Precise velocity analysis and prestack migration solve the problem of its elevation difference between shot (sea surface) and receiver (sea bottom) point. The second seismic survey has been carried out in December 2006, equipped with accelerometer and hydrophone. These data was also very high quality as same as the geophone data. The accelerometer implies that the geophone will be replaceable with accelerometer. It means that there is a possibility to reduce the sensor size without gimbals. The hydrophone data is similar to the geophone data except the polarity change. This characteristic enables us to separate upgoing reflection from downgoing wave which includes only direct water waves and multiple reflections. The total data quality so far is very good compared to the conventional OBS systems. The RSCS has a great potential as a seabed observation system. 11314 Characterizing gas hydrate reservoirs using well log data Hart's E&P 2006/5/25 Doug Murray, Masafumi Fukuhara, Osamu Osawa, Tatsuki Endo, Robert Kleinberg, Bikash Sinha(Schlumberger), Takatoshi Namikawa(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Characterizing gas hydrate reservoirs using well log data 11312 Contribution of Methane Accumulation and Pore Water Flow to Forming High Concentration of Methane Hydrate in Sandy Sediments 2006 AGU Fall Meeting 2006/12/11-15 Takashi Uchida, Amane Waseda(JAPEX), Tetsuya Fujii(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Contribution of Methane Accumulation and Pore Water Flow to Forming High Concentration of Methane Hydrate in Sandy Sediments 11311 Research and Development Studies of the Mallik Gas HydrateDeposit, Mackenzie Delta, NWT 34th Annual Yellowknife Geoscience Forum(2006) 2006/11/21-22 Scott R Dallimore(Geological Survey of Canada ), Kenichi Yokoi, Yutaka Imasato(Japan Oil, Gas and Metals National Corporation) , Andrew Applejohn (Aurora Research Institute) Methane Hydrate Research Project Team [Abstract] Research and Development Studies of the Mallik Gas HydrateDeposit, Mackenzie Delta, NWT 11309 Characteristics of Arenite Sand Containing Highly-Saturated Gas Hydrate in Pore System: Hydrogeological Implications for Methane and Pore Water Accumulation GSA (Geological Society of America) 2006/10/22-25 Takashi Uchida, Amane Waseda(JAPEX), Tetsuya Fujii(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Gas hydrates are widespread in many deep marine environments along continental margins worldwide as well as in several Arctic sedimentary basins associated with permafrost. Plenty of gas hydrate-bearing send core samples have been obtained from the Nankai Trough as well as Mallik areas. The Nankai Trough runs along the Japanese Island from offshore Tokai to offshore Kyushu, where forearc basins and accretionary prisms developed extensively and distinct BSRs (bottom simulating reflectors) as well as intensive thrust/growth faults have been broadly recognized. The MITI Nankai Torough wells and METI Tokaioki to Kumanonada wells were drilled in 2000 and 2004, and the Mallik 2L-38 and Mallik 5L-38 research wells were drilled at the Mallik site, Northwest Territories, Canada, in 1998 and 2002. The chloride content anomalies in extracted pore waters, core temperature depression, core observations, visible gas hydrates as well as continuous downhole well log data confirm common occurrences of pore-space hydrate as intergranular pore filling within sandy layers, which clarified the characteristics of subsurface natural gas hydrate beneath deep sea floors and permafrost zones. Gas hydrate saturations are generally evaluated up to 80% in pore volume, which may need gas accumulation associated with pore water and original pore space large enough to occur within host sediments. According to grain size distributions most of pore-space gas hydrates are contained in coarse-to very fine-grained sandy strata, and they are scarcely contained in finer-grained sediments such as siltstone and claystone. Based on the geochemical and geological data, microbial methane migration processes are estimated to be active flow to permeable sandy layers in the Nankai Trough, and long migration of thermogenic methane generated in deep mature sediments at the Mallik. Subsequent sedimentological analyses performed on gas hydrate-bearing sandy sediments and well log data also revealed important geologic and sedimentological controls on the formation and preservation of natural gas hydrate. It should be noted that in both of the terrestrial (Mallik) and the marine (Nankai Trough) areas distributions of porous and coarser-grained host rocks should be one of the most important factors to control the occurrence of pore space hydrate. This study was performed as a part of the MH21 Research Consortium on methane hydrate in Japan. 11308 Thin Bed Analysis of Gas Hydrate Bearing Sands in the Nankai Trough The 12th Formation Evaluation Symposium of Japan 2006/10/4-5 Doug Murray・Steve Alderman(Schlumberger), Tetsuya Fujii(Japan Oil, Gas and Metals National Corporation), Masafumi Fukuhara(Schlumberger) Methane Hydrate Research Project Team [Abstract] Gas Hydrates are white crystalline solids composed of gas (usually methane) and water. The gas molecules are densely packed and contain large amounts of energy. Hydrates are commonly found in deep offshore; shallow seabed sediments and below permanent frost in arctic areas where the environmental conditions of moderately low temperature and moderately high pressure are conducive to hydrate formation. Many techniques have been developed in gas hydrate reservoir formation evaluation to describe the amount of hydrate present in a rock. Mostly, these techniques depend on the measured responses of the resistivity, nuclear, acoustic and magnetic resonance geophysical logs. These techniques have proven robust and are dependent on the underlying resolution of the measurement. Depending on the measurement vintage and type, the vertical resolution of geophysical logs can vary from〜5 mm to〜3meters. This is not a significant issue when the reservoir bed thickness is greater than 3 meters but can play an important role in thinly laminated reservoirs like those found in shallow seabed sediments. This paper presents an approach to resolve some of these vertical resolution issues. Its fundamental assumption is that the highest resolution measurement can be used to model the thin bed response of the lower resolution measurements. For wireline the highest resolution device is the borehole electrical imaging tool with a vertical resolution of 〜5mm. For Logging-While-Drilling (LWD) the laterolog resistivity measured at the bit has the highest resolution at〜5cm. 11307 The Mallik Gas Hydrate Field, Mackenzie Delta, Canada: A Summary of Research and Development Studies of a Terrestrial Gas Hydrate Deposit ISC2006 2006/8/27-9/1 SCOTT R. DALLIMORE・TIMOTHY S. COLLETT(Geological Survey of Canada), Kenichi Yokoi, Yoshihiro Tsuji(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] The Mallik Gas Hydrate Field, Mackenzie Delta, Canada: A Summary of Research and Development Studies of a Terrestrial Gas Hydrate Deposit 11306 Characterization of gas hydrate-bearing sediments for an attempt to resource assessment, eastern Nankai Trough, Japan ISC2006 2006/8/27-9/1 Tetsuya Fujii, Takatoshi Namikawa, Masaru Nakamizu(Japan Oil, Gas and Metals National Corporation), Mizue Nishimura, Osamu Takano(JAPEX), Yoshihiro Tsuji(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Characterization of gas hydrate-bearing sediments for an attempt to resource assessment, eastern Nankai Trough, Japan 11305 Experimental investigation on the role of clay minerals in natural gas hydrate formation. WPGM (Western Pacific Geophysics Meeting) 2006/7/24-27 Tatsuji Kawasaki(Japan Oil, Gas and Metals National Corporation), Hailong Lu, John Ripmeester, Igor Moudrakovski, Jong-won Le (National Research Council Canada), Tetsuya Fujii, Masaru Nakamizu(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Except for those occurring at seafloor, natural gas hydrates exist in sediments, subject to the influence of sediment particles. Many of the physical and chemical properties of sediment can affect the formation of natural gas hydrate, for example, pore size, mineral compositions, size of sediment particle, etc. Unfortunately the mechanism by which these factors work during the formation of natural gas hydrate has not been well understood. Present research aims at elucidating the role of clay minerals, one of the factors, in hydrate formation through experimental investigations. The results of the P-T stability conditions of methane hydrate in various water saturated clay minerals, indicated that clay minerals are thermodynamic inhibitor for gas hydrate formation, shifting the stability condition to a regime of relatively high temperature and low pressure, while in situ observations on methane hydrate formation in clay minerals by MRI (Magnetic Resonance Imaging) found that clay minerals are kinetic promoter for gas hydrate formation, shortening the induction time greatly as compared with quartz sand. Guggenheim and Koster van Gross(2003) claimed the formation of methane hydrate in the interlayer of Na-montmorillonite with a reflection at 2 theta=〜4°in X-ray diffraction spectrum, but the results of our experiments showed that this reflection can appear without hydrate occurrence when water content in Na-montmorillonites is 59%. Thus, more effects are needed to confirm hydrate formation in the interlayer of Na-montmorillonite. 11304 Development of 2D simulator for methane hydrate accumulation in basin scale. -Evaluation of the controlling factor of methane hydrate accumulation In the eastern Nankai Trough- WPGM (Western Pacific Geophysics Meeting) 2006/7/24-27 Tetsuya Fujii(Japan Oil, Gas and Metals National Corporation), Ryosuke Aoyagi, Yutaka Nakama, Minoru Yoshikawa(Mizuho Information & Research Institute Inc.), Akihiko Okui(Idemitsu Oil and Gas Co., Ltd.), Tatsuji Kawasaki, Masaru Nakamizu(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] In order to simulate geological/geophysical phenomenon related to methane hydrate (MH) accumulation in the deep marine sediments, and to clarify the controlling factor for MH accumulation, we have developed 2-D simulator for MH accumulation. This simulator is modified version of "SIGMA-2D" which is 2-D multi phase fluid flow basin simulator for petroleum generation, migration and accumulation developed by JOGMEC (former JNOC) Technology & Research Center [1]. New models dealing with biogenic methane generation and MH formation/dissociation were installed in the prototype of the simulator for this study [2]. Empirical model by Schoell (2005) was used for the biogenic methane generation. In this model, gas generation rate is estimated from maximum gas generation rate and its vertical attenuation rate, which were derived from ODP gas sample analysis. We have also extracted biogenic methane generation parameter, which was consistent with the actual MH accumulation at one of the site In the eastern Nankai Trough. We have also modified MH formation/dissociation model in order to evaluated MH formation timing precisely. Reaction-rate model considering the temperature/pressure dependence of reaction factor was installed for the prototype simulator. We have conducted test simulation (case study) for 2-D section In the eastern Nankai Trough using core, well log and seismic data obtained from multi-well drilling program METI "Tokai-oki to Kumano-nada". The controlling factors of MH accumulation were examined based on the results. This study was conducted as a part of research consortium for methane hydrate resources in Japan (MH21). [1]Okui, A., Siebert, R.M. and Mtsubayashi, H.(1998):Simulation of oil expulsion by 1-D and 2-D basin modeling ・saturation threshold and relative permeability of source rocks. Geological Society, London, Special Publications,141,45-72. [2]Okui, A., Nakamizu, M., Fujii, T.. and Aoyagi, R.(2005): Evaluation of Methane Hydrate Formation by Computer Simulation, Abstract of 23rd Japan Symposium on Organoc Geochemistry, July 28-29,2005 Kochi Univ., Japan, O-16. 11303 Data Acquisition and Well Construction Experiments for Future Marine Gas-Hydrate Production WPGM (Western Pacific Geophysics Meeting) 2006/7/24-27 Koji Yamamoto, Maki Matsuzawa(Japan Oil, Gas and Metals National Corporation), Doug Murray, Khong Chee Kin(Schlumberger), Masato Yasuda(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Data Acquisition and Well Construction Experiments for Future Marine Gas-Hydrate Production 11295 Comprehensive Approach of Core Analysis to Predict Water Flooding Performance in a Heterogeneous Carbonate Reservoir, Offshore Abu Dhabi 12th Abu Dhabi International Petroleum Exhibition and Conference (ADIPEC) 2006/10/7 Kazuhito Oseto(Japan Oil, Gas and Metals National Corporation), A. Al-Amoudi(Abu Dhabi National Oil Company), Masayoshi Suzuki(Abu Dhabi Oil Company Ltd.) Research Project Team on Subsurface Technologies for Field Development [Abstract] The horizontal carbonate core samples were devoted to special core analysis to evaluate the field waterflooding performance in offshore Abu Dhabi under the observation of X-ray CT scanner at both fresh and aged states. Judging by visual observation of the surface and X-ray CT scanning, the core is apparently heterogeneous locally having some algal fragments which form vuggy pore spaces and some minerals which can form low porosity region. The main objective of this study was therefore to evaluate the effects of such heterogeneity on waterflooding performance and subsequent oil recovery. For fresh cores, the results of Amott and USBM tests indicated neutrally wet to water wet nature that contradicted the expected. It was inferred that the contamination of a drilling fluid might alter the original wettability condition. The water flooding experiment with this condition resulted in fairly high oil recovery. X-ray CT scanning supported the result by demonstrating uniform water frontal advancement and high sweep efficiency in consequence. The same manner was applied to an aged core where the results on Amott and USBM tests indicated oil wet nature. The oil recovery was a little less than that for the fresh core but still favorable. X-ray CT scanning demonstrated uniform flow as well. In this way, the experiments proved high oil recovery for the aged cores as well in spite of the locally existing heterogeneities. Kr curves derived by employing JBN method for both the fresh and the aged cores had a little different shape. The curves for the aged core were verified with on-dimensional coreflood simulation model. Thus, this paper presents the detail of the waterflooding under X-ray CT scanning and comprehensive approach of the core analysis as a case study. 11284 GTL Demonstration Test Project GTL tec2007 2007/1/23 Yoichi Norisugi(Japan Oil, Gas and Metals National Corporation) Research Project Team on Emerging Gas Technologies [Abstract] (1)Introduction-Development of JAPAN-GTL Process (2)Nippon GTL Technology Research Association (3)GTL Demonstration Test Project (4)Conclution 11278 230Th/234U and 14C dating of a Lowstand Coral Reef beneath the Insular Shelf off Irabu Island, Ryukyus, southwestern Japan The Island Arc 2006/12 Keiichi Sasaki (Kanazawa Gakuin Univ.), Akio Omura, Akihiro Miwa (Kanazawa Univ.), Yoshihiro Tsuji (Japan Oil, Gas and Metals National Corporation), Hiroki Matsuda (Kumamoto Univ.), Toru Nakamori, Yasufumi Iryu, Tsutomu Yamada (Tohoku Univ.), Yuri Sato (JICA), and Hiroshi Nakagawa (GeoWindow) Geology & Geophysics Research Team [Abstract] High-resolution seismic reflection profiles delineated the distribution of mound-shaped reflections, that were interpreted as reefs, beneath the insular shelf western off Irabu Island, Ryukyus, southwestern Japan. A sediment core through one of the mounded structures was recovered from seafloor at -118.2 m by offshore drilling and was dated by radiometric methods. The lithology and the coral fauna of the core indicate that the mounded structure was composed of coral-algal boundstone suggesting a small-scaled coral reef. High-precision α-spectrometric 230Th/234U dating coupled with calibrated AMS 14C ages of corals obtained reliable ages of this reef ranging from 22.18±0.63 to 30.47±0.98 ka. This proves that such a submerged reef was formed during the lowstand stage of the marine oxygen isotope stages 3 to 2. The existence of low-Mg calcite in aragonitic coral skeleton of 22.18±0.63 ka provides an evidence that the reef has once been exposed by lowering of relative sea level to at least -126 m during the last glacial maximum in the study area. There is no room for doubt that a coral reef has grown during the last glacial period on the shelf off Irabu Island of Ryukyus in the subtropical region of western Pacific. 11276 Simulating Transient Behavior of Cuttings Transport over Whole Trajectory of Extended Reach Well IADC/SPE Asia Pacific Drilling Technology Conferense and Exhibition 2006/11/13-15 Shigemi Naganawa(Tokyo Univ.), Tsuyoshi Nomura(Japan Oil, Gas and Metals National Corporation) Petroleum Engineering Research Team [Abstract] Based on our previously developed prototype simulator, a transient cuttings transport simulator using the two-layer model was developed with some modifications and improvements for more practical use. To evaluate functionality and potential of the simulator, a post analysis on hole cleaning were carried out for an actual extend reach well (ERW) drilled in Japan. Simulation results showed that the modified model successfully demonstrated transient distributions of cuttings bed height and annular pressure over the whole trajectory of the well. From the comparison with a conventional steady-state analysis, transient simulation over the whole trajectory was found to be crucial and useful for prediction of behaviors unrecognized by steady-state simulations. 11271 High concentrated gas hydrate zone imaged in seismic data 2006 AGU(American Geophysical Union) Fall Meeting 2006/12/13 Toshiaki Kobayashi, Tatsuo Saeki, Nobutaka Oikawa, Takao Inamori, Tetsuya Fujii, Tokujirou Takayama, Masao Hayashi, Masaru Nakamizu(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Japan Oil, Gas and Metals National Corporation (JOGMEC), as a member of MH21 Research Consortium, takes charge of a study of the Research for Resources Assessment, and is pursuing a possibility that gas hydrate, which is presumed to be distributed around ocean area of Japan, will be energy resources. As part of the study, 3D seismic survey was conducted from Tokai-oki to Kumano-Nada In the eastern Nankai Trough by METI (Ministry of Economy, Trade and Industry) in 2002 under the national Program of assessment for gas hydrates as energy resources. As well as 3D seismic survey, drilling program was conducted in this area and information of physical property was acquired. Additionally, velocity analysis and seismic attribute analysis were conducted. It is revealed that gas hydrate zone is correlated with high resistivity and high velocity, and a lot of gas hydrates are found in turbidite sand with much porosity. JOGMEC is conducting analysis of seismic data and is doing resources assessment of gas hydrate compiling information of physical property which was acquired by drilling, result of velocity analysis, and result of seismic attribute analysis. This time, we introduce some seismic images of high concentrated gas hydrate zone appears in Tokai-oki area. 11270 The Influences of Clay Minerals on Methane Hydrate Formation 2006 AGU(American Geophysical Union) Fall Meeting 2006/12/13 Tatsuji Kawasaki(Japan Oil, Gas and Metals National Corporation), Hailong Lu, John Ripmeester, Huang Zeng, Jong-won Lee, Igor Moudrakovski(Steacie Institute for Molecular Sciences, National Research Council Canada), Tetsuya Fujii, Masaru Nakamizu(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Natural gas hydrates exist in sediment, either filling sediment pores or locally aggregated as nodular or massive hydrate. The elucidation of the role of the sediment matrix on gas hydrate formation is crucial to understanding the formation mechanism and accumulation of methane hydrate in natural environments. Clay minerals are common constituents of natural sediments. From the results of field and laboratory investigations, as well as theoretical studies, clay minerals are likely to play an important role in controlling the occurrence of natural gas hydrate. However the mechanism of how clay minerals affect hydrate formation is still not well understood. Present research aims at elucidating the role of clay minerals in hydrate formation through experimental investigations. Three types of clays typical of natural sediments have been selected as the test materials: Na-montmorillonite, Ca-montmorillonite, and Kaolinite. Na-montmorillonite and Ca-montmorillonite are 2:1 types, among which interlayer distances (d-spacing) of Na-montmorillonite and Ca-montmorillonite can increase when soaked in water, while the former has much stronger swelling ability than the latter. Kaolinite is 1:1 type, not able to expand its interlayer distance. For the purpose of comparison, quartz was also tested. The results of the P-T stability conditions of methane hydrate in various water-saturated clay minerals, indicated that Ca-montmorillonite and kaolinite are thermodynamic inhibitors for gas hydrate formation, shifting the stability conditions to a regime of relatively lower temperature and higher pressure, while in situ observations on methane hydrate formation in clay minerals by MRI (Magnetic Resonance Imaging) found that clay minerals are kinetic promoters of gas hydrate formation, shortening the induction time greatly as compared to quartz sand. 11267 Seamount subduction to the Nankai accretionary wedge and its impact on methane hydrate accumulation: insights from analogue and numerical models 2006 AGU(American Geophysical Union) Fall Meeting 2006/12/11-15 Yasuhiro Yamada, Naoki Nagamura(Kyoto Univ.), Kei Baba(JAPEX), Toshifumi Matsuoka(Kyoto Univ.) Methane Hydrate Research Project Team [Abstract] Seamount subduction to the Nankai accretionary wedge and its impact on methane hydrate accumulation: insights from analogue and numerical models 11265 Geomechanical property of gas hydrate-bearing zone 2006 AGU(American Geophysical Union) Fall Meeting 2006/12/11-15 Masami Hato, Hiroyuki Ikeda(Kyoto Univ.), Takao Inamori(Japan Oil, Gas and Metals National Corporation), Kiyofumi Suzuki(AIST), Toshifumi Matsuoka(Kyoto Univ.) Methane Hydrate Research Project Team [Abstract] For the development of gas hydrate as possible future energy resources, the great effort has been paid for developing new seismic methods to delineate hydrate reservoir and its quantification. Not only for reservoir delineation but also for understanding gas hydrate system and geological history of hydrate sediment, we have made a geomechanical study for hydrate and non-hydrate sediment theoretically and experimentally using the well data and core samples acquired in Nankai Trough area. In first step of the study, we have tried to calculate the mechanical strength of the gas hydrate-bearing sediment based on the Coulomb-Mohr failure criterion using well-logging data. The result shows that the sediment below the gas hydrate-bearing layer is apparently mechanically weaker than gas hydrate-bearing layer. This result is consistent with our knowledge that caliper data shows the weakness of the well-bore Wall. In second step, we measured the mechanical strength of the core samples recovered by PTCS at the Nankai Trough area The measurement was made to the core samples, one of which is under in situ condition and another of which was done after dissociation. As a result, the strength of the gas hydrate-contained core with high saturation is about 4 times stronger than that of gas hydrate-dissociated core. This result is completely same as that of calculated strength using the well-logging data. These information will be important for reservoir monitoring while production and hazard prevention while drilling. 11266 Delineation of gas hydrate-bearing sediments by multi seismic attributes using 3D seismic survey in the eastern Nankai Trough 2006 AGU(American Geophysical Union) Fall Meeting 2006/12/11-15 Takao Inamori, Tatsuo Saeki, Masao Hayashi, Toshiaki Kobayashi, Nobutaka Oikawa, Tokujirou Takayama, Tetsuya Fujii, Masaru Nakamizu(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] In 2000, the occurrence of gas hydrates was confirmed by corings and borehole log measurements In the eastern Nankai Trough offshore Japan. We conducted the 3D seismic survey in this area in 2002, we decided well sites and drilled thirty-two boreholes in 2004. We had gotten many logs and cores which indicated the occurrence of gas hydrate below the sea floor. Bottom Simulating Reflectors (BSRs) were widely found on the marine seismic data acquired in the shelf - slope In the eastern Nankai Trough area. BSRs indicate the existence of gas hydrates. However, we cannot estimate detail reservoir information from distribution of BSRs. The gas hydrate-bearing sediments are heterogeneous and complex both vertically and horizontally, because gas hydrate concentrated layers are mainly turbidite sands. If we will explore and exploit the gas hydrate, we have to get the reservoir characterization of hydrate-bearing sediments, such as its concentration, porosity or thickness. In order to estimate the amount of gas hydrates accurately, we need to get the more detailed reservoir parameters from seismic data. We apply the seismic attributes analysis to 3D seismic survey data to delineate distribution of gas hydrate-bearing sediments. We calculate seismic attributes of the P- interval velocity using the dense NMO velocity analysis, P-impedance, S-impedance, and Poisson’s ratio change from pre-stack (AVO) analysis and the attenuation attribute. High P-interval velocity, High P & S impedance, low Poisson’s ratio and high attenuated layers correspond to the hydrate bearing-zones. 11263 New catalysts for hydrogen production by steam reforming of dimethyl ether 4th Asian Pacific Congress on Catalysis 2006/12/8 Kaoru Takeishi(Shizuoka Univ.) Research Project Team on Emerging Gas Technologies [Abstract] Dimethyl ether (DME) is expected as a clean fuel of this 21st century. I have developed Cu-Zn/Al2O3 catalysts prepared by a sol-gel method for hydrogen production by DME steam reforming. The catalysts produce hydrogen more effectively than mixed catalysts with DME hydrolysis catalysts and methanol steam reforming catalysts. SEM-EDS analyses have suggested that the Cu-Zn/Al2O3 catalysts have the catalyst surface structure that is appropriate for the steam reforming of DME consisting of DME hydrolysis and methanol steam reforming. Experiments on the effect of the space velocity, durability test, and other experiments have suggested that the further developments are still need but the catalysts have enough capability for practical use. 11261 History Matching with Combustion Tube Tests for Light Oil Air Injection Project SPE International Oil & Gas Conference and Exhibition in China 2006/12/6 Takeshi Onishi, Komei Okatsu(Japan Oil, Gas and Metals National Corporation), Tetsuo Teramoto(Teikoku Oil) Petroleum Engineering Research Team [Abstract] A series of experiments is essential in light oil air injection (LOAI) study. Accelerating Rate Calorimeter (ARC) test, Thermo Gravimetric Pressurized Differential Scanning Calorimeter (TG/PDSC) test and Combustion Tube (CT) test are generally conducted to evaluate a potential of air injection in fields. ARC test is used to determine the extent and continuity of reactions in the low and high temperature range. TG/PDSC test also helps to identify the temperature ranges over which oil reacts with the oxygen. The purposes of the CT test are (1) to assess the overall burning characteristics of oil, (2) to measure incremental oil production, air and fuel requirements and other parameters and (3) to measure produced gas compositions and oil and water production to provide benchmarks for monitoring future field operations. On this series of experimental work, using domestic oilfield sample, two CT tests were conducted, in low water saturation case and high water saturation case after waterflooding, to estimate the applicability of LOAI including on tertiary mode. Both tests showed stable combustion performance in terms of temperature, pressure response, produced gas compositions and incremental oil production. On the other hand, numerical simulation is important to predict field production performance. The appropriate reaction kinetics on the combustion has to be used in the numerical simulation. History matching with CT tests were conducted to obtain the kinetics, and two kinds of reactions, “oxidation reaction” and “combustion reaction” were used in the study. In the former reaction, oxygen is consumed by the oil to form oxidation compounds. In the latter one, oxygen reacts with the compounds to form carbon dioxide and water. Reaction parameters were used as matching parameters. Results of history matching with both CT tests using same reaction kinetics were obtained. This paper presents the results of the CT tests and the history matching studies with these tests and also some discussion of the air injection process. 11260 Gas to Wire System (GTW) for Developing “Small Gas Field” and Exploiting “Associated Gas” SPE International Oil & Gas Conference and Exhibition in China 2006/12/6 Tomoko Watanabe(Japan Oil, Gas and Metals National Corporation), Hiroshi Inoue, Mutsumi Horitsugi(Hitachi Ltd.), Shunichi Oya(JGC) Petroleum Engineering Research Team [Abstract] A new development concept of marginal gas field and associated gas with a reserve between 10 bcf and 1 tcf is suggested. This concept is called as a Gas to Wire System (GTW), which means onsite power generation by produced gas. Because of no need of transportation of the produced gas, GTW is considered to be high efficiency system with merits from economic and environmental perspective. Japan Oil, Gas and Metals National Corporation (JOGMEC), Hitachi, Ltd., JGC Corporation, Toyohashi University of Technology, and Arabian Oil Company have advanced the research project on high efficiency of totally 50 % thermal efficiency, low cost and low emission GTW by applying Gas Turbine Combined Cycle System (GTCC). The targets of this project are (1) the development of the new burner which is available both gas and oil (NOx emission <25 ppm for gas, <80ppm for oil/ oil + gas, and combustion efficiency >99.9%), (2) the design of the low cost pre-treatment for fuel. The technology (1) would add the cost value of the generator itself and give the GTW system the back-up fuel. The test facility for the technology (1) was prepared and the design and construction of small model burners was carried out. The result of small model burner test shows low NOx emission for both oil and gas. Investigation of particulate material /soot formation affected by fuel properties and impurities was carried out. Corrosion test equipments were designed and constructed. Process flow of available treatment equipments was composed with consideration for impurities permission levels for gas turbine as the technology (2). The tentative feasibility study was carried out. It shows that GTW system makes a marginal gas field valuable and has less power loss from well to GTCC. The subjects in near future are achievement of each target for the developments, conceptual design of GTW system for selected gas field and the assessment of economical feasibility. 11258 A new visualization era in geology and sedimentology: impact of the development of 3D seismic technology 8th Society of Exploration Geophysicists of Japan International Symposium 2006/11/28 Osamu Takano(Japan Oil, Gas and Metals National Corporation) Petroleum Engineering Research Team [Abstract] Recent developments of 3D seismic and 3D visualization technologies have provided a strong impact on geological sciences, such as sedimentology, structural geology, petrology, petroleum geology and reservoir engineering, in terms of analytical methodology and concepts. In petroleum geology, 3D seismic technology has been widely applied for exploration and development projects to detect reservoir rock distributions and to conduct effective reservoir characterization studies. In structural geology, detailed three-dimensional structures, such as folds, faults, salt domes and plate boundaries, have been discussed using 3D visualization technique. In sedimentology, detailed three-dimensional views of sediment body morphology and depositional surfaces, such as fluvial channels, incised valleys, deep-sea channels, slope failures, submarine fans, carbonate reefs and sequence boundary surfaces, have been reconstructed by 3D seismic technology. This dramatic development of paleoenvironmental visualization technique resulted in the new research field “seismic geomorphology” or “seismic sedimentology” as an integrated concept of 3D seismic technology and sequence stratigraphy. The concept and methods of seismic geomorphology have been widely applied for sediment body analysis, three-dimensional depositional process analysis and quantitative reservoir characterization. 3D seismic technology is indispensable for the future earth sciences, as an effective, efficient and precise tool of earth surface dynamics analysis. 11253 Fusion on 3D seismic exploration and seafloor geochemical survey 8th SEGJ International Symposium 2006/11/26-28 Sadao Nagakubo, Toshiaki Kobayashi, Tetsuya Fujii, Takao Inamori(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] MH21 Research Consortium (Research Consortium for Methane Hydrate Resources in Japan) has been conducting seafloor geochemical survey as a method for exploration of methane hydrate reservoir in the eastern Nankai Trough, offshore Japan. However the geological and geochemical settings between methane hydrate reservoirs and seafloor In the eastern Nankai Trough are quite complex. We have to construct a geological and geochemical model in consideration of various settings in sediment for success of seafloor geochemical survey to explore methane hydrate reservoirs. MH21 Research Consortium conducted high-resolution 3D seismic survey to explore methane hydrate reservoir in the eastern Nankai Trough. As the high-resolution 3D seismic survey was designed for shallow formation where methane hydrates exist, we could obtain excellent information about various settings in shallow formation. The high-resolution 3D seismic data provided us information about seafloor manifestations, migration conduits of hydrocarbon-bearing fluids, and geothermal structures in shallow formation. Bathymetric chart and seafloor reflection intensity map constructed by waves reflected from seafloor provided us detailed information about seafloor manifestations. Because occurrences of methane hydrates are strongly restricted by temperature, pressure and other physicochemical environments, BSR (Bottom Simulating Reflector) which is considered as the base of the hydrate stability zone, is represented as not geological event but physicochemical event in seismic sections. We estimated geothermal structures near BSR by anomaly map showing difference of predicted BSR depth by laboratory data and observed BSR depth by high-resolution 3D seismic data. MH21 Research Consortium will continue to conduct seafloor geochemical survey based on the geological and geochemical model constructed using 3D seismic data in the future. In this paper, we introduce an attempt for exploration of methane hydrate reservoirs by ‘Fusion on 3D seismic exploration and seafloor geochemical survey’ in Japan. 11252 Rock mechanical study for methane hydrate-bearing sediment 8th Society of Exploration Geophysicists of Japan International Symposium 2006/11/26-28 Masami Hato, Toshifumi Matsuoka(Kyoto Univ.), Takao Inamori(Japan Oil, Gas and Metals National Corporation), Kiyofumi Suzuki(AIST) Methane Hydrate Research Project Team [Abstract] For the development of methane hydrate (hereafter called ‘hydrate’) as possible future energy resources, the great effort has been paid for developing new seismic methods to delineate hydrate reservoir and its quantification through the first stage of MH21 national project. Not Only for reservoir delineation but also for understanding hydrate system ( methane generation, migration and accumulation as a hydrate) and geological history of hydrate sediment, we have made a rock mechanical study for hydrate and non-hydrate sediment theoretically and experimentally using the well data and core samples. As a first step in our study, we have tried to calculate the mechanical strength of the methane hydrate-bearing sediment based on the Coulomb-Mohr failure criterion. As a result, the sediment below the methane hydrate-bearing layer is apparently mechanically weaker than methane hydrate-bearing layer. This result is consistent with our knowledge that caliper data shows the weakness of the well-bore wall. As second step, we also measured the mechanical strength of the core samples recovered at Nankai Trough. The measurement was made to the core samples, one of which is under in situ condition and another of which was done after dissociation. As a result, the strength of the hydrate-contained core of high saturation is about 4 times stronger than that of hydrate-dissociated core. This result is completely same as that of calculated strength using the well-logging data and well-logging (caliper) data. 11251 METHANE HYDRATE QUANTIFICATION FROM MUD LINE TO BOTTOM SIMULATING REFLECTOR 8th Society of Exploration Geophysicists of Japan International Symposium 2006/11/26-28 Richard C. Uden(Rock Solid Images), Jack P. Dvorkin(Stanford Univ./Rock Solid Images), Takao Inamori(Japan Oil, Gas and Metals National Corporation) Methane Hydrate Research Project Team [Abstract] Methane hydrates reside in porous sediment between the sea floor and the bottom simulating reflector. The location and distribution of the sediment where hydrate may form vary laterally and vertically in a very heterogeneous manner. This heterogeneity makes the mapping the quantity of methane hydrate challenging. Here we demonstrate a method that quantifies the total methane hydrate volume accumulated within sediment beds at and below seismic resolution. We also address a problem on the opposite side of the seismic resolution spectrum --the thick layer problem- the quantification of methane hydrate within a reservoir comparable in thickness to the seismic wavelength. When beds are below seismic resolution, the problem is one of scale. Therefore, we pose the problem of hydrate reservoir characterization differently by seeking a scale-independent volumetric reservoir property and a scale-independent seismic attribute to quantify this property. Therefore we introduce a cumulative seismic attribute (CATT) that is very close to being scale independent. This is a new type of attribute formed by integrating the seismic trace impedance. We show the CATT attribute applied to synthetic seismic data to quantify the vertical hydrate accumulation, which means that this class of attribute can be readily applied to real seismic data using seismic impedance volumes. Simply speaking, our approach is to admit that we cannot quantify a reservoir property at a sub-resolution scale. Instead, we quantify the volume integral of this property (or the cumulative property) and introduce a new class of seismic attributes, the cumulative attributes that can be related by means of rock physics to the cumulative reservoir property, which in this specific example is the accumulated volume of methane hydrate. A rock physics transform that connects the gas hydrate saturation in sediment to the elastic-wave velocity still remains the cornerstone of our approach. It is based on the Dvorkin and Nur (1996) effective-medium model which relates the elastic moduli of soft unconsolidated clastic sediment to the porosity, pore fluid compressibility, mineralogy, and effective pressure. BACK 1 2 3 4 5 6 7 8 9 10 NEXT

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