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Formation pressure testing at the Mount Elbert Gas Hydrate Stratigraphic Test Well, Alaska North Slope: Operational summary, history matching, and interpretations |
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| Authors: | Brian Anderson Steve HancockScott Wilson Christopher EngerTimothy Collett Ray BoswellRobert Hunter |
| Institution: | a National Energy Technology Laboratory, 3610 Collins Ferry Road, P.O. Box 880, Morgantown, WV 26507, USA b West Virginia University, Department of Chemical Engineering, Morgantown, WV 26506-6102, USA c RPS Energy Canada, 1400, 800 Fifth Ave. SW, Calgary, Alberta, Canada T2P 3T6 d Ryder Scott Company, Petroleum Consultants, 621, 17th Street, Suite 1550, Denver, CO 80293, USA e Rock Mechanics Laboratory, Colorado School of Mines, 1500 Illinois St, Golden, CO 80401, USA f US Geological Survey, Denver Federal Center, MS-939, Box 25046, Denver, CO 80225, USA g ASRC Energy Services, 3900 C Street, Suite 702, Anchorage, AK 99503, USA |
| Abstract: | In February 2007, the U.S. Department of Energy, BP Exploration (Alaska), and the U.S. Geological Survey, collected open-hole pressure-response data, as well as gas and water sample collection, in a gas hydrate reservoir (the BPXA-DOE-USGS Mount Elbert Gas Hydrate Stratigraphic Test Well) using Schlumberger's Modular Dynamics Formation Tester (MDT) wireline tool. Four such MDT tests, ranging from six to twelve hours duration, and including a series of flow, sampling, and shut-in periods of various durations, were conducted. Locations for the testing were selected based on NMR and other log data to assure sufficient isolation from reservoir boundaries and zones of excess free water. Test stages in which pressure was reduced sufficiently to mobilize free water in the formation (yet not cause gas hydrate dissociation) produced readily interpretable pressure build-up profiles. Build-ups following larger drawdowns consistently showed gas-hydrate dissociation and gas release (as confirmed by optical fluid analyzer data), as well as progressive dampening of reservoir pressure build-up during sequential tests at a given MDT test station.History matches of one multi-stage, 12-h test (the C2 test) were accomplished using five different reservoir simulators: CMG-STARS, HydrateResSim, MH21-HYDRES, STOMP-HYD, and TOUGH + HYDRATE. Simulations utilized detailed information collected across the reservoir either obtained or determined from geophysical well logs, including thickness (11.3 m, 37 ft.), porosity (35%), hydrate saturation (65%), both mobile and immobile water saturations, intrinsic permeability (1000 mD), pore water salinity (5 ppt), and formation temperature (3.3-3.9 °C). This paper will present the approach and preliminary results of the history-matching efforts, including estimates of initial formation permeability and analyses of the various unique features exhibited by the MDT results. |
| Keywords: | Gas hydrates Reservoir simulations Production modeling Porous media Modular dynamics testing |
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