Wells – Processes – With indicating – testing – measuring or locating
Reexamination Certificate
2001-06-19
2004-04-06
Schoeppel, Roger (Department: 3672)
Wells
Processes
With indicating, testing, measuring or locating
C166S064000, C166S249000, C166S254100, C166S364000, C166S150000, C166S151000
Reexamination Certificate
active
06715551
ABSTRACT:
BACKGROUND OF THE INVENTION
1. Field of the Invention
The present invention relates to apparatus and methods for managing the exploitation of a subterranean reservoir. In another aspect, the present invention relates to apparatus and methods for producing hydrocarbons from a subterranean hydrocarbon reservoir. In even another aspect, the present invention relates to apparatus and methods for producing hydrocarbons utilizing modeling and monitoring of the subterrane hydrocarbon reservoir. In still another aspect, the present invention relates to the use of seismic data. In yet another aspect, the present invention relates to the use of time lapse vertical seismic profile data to monitor and model the subterranean hydrocarbon reservoir. In even still another aspect, the present invention relates to a method and apparatus for producing hydrocarbons from a subterranean reservoir utilizing seismic sensors, computer modeling of the reservoir from gathered seismic data, and iterative modeling with respect to time as more seismic, reservoir and production data are gathered. In even yet another aspect, the present invention relates to computer implemented methods and apparatus for monitoring and modeling a subterranean reservoir, computer readable media having stored thereon instructions for carrying out and forming such computer implemented methods and apparatus, and a propagated data signal or computer data signal having such instructions.
2. Description of the Related Art
Historically, most oil and gas reservoirs have been developed and managed by first conducting a preliminary investigation of an area using broad geological methods for collection and analysis of data such as seismic, gravimetric, and magnetic data, to determine regional geology and subsurface reservoir structure. In some instances, more detailed seismic mapping of a specific structure was conducted in an effort to reduce the high cost, and the high risk, of an exploration well.
A test well was then drilled to penetrate the identified structure to confirm the presence of hydrocarbons, and to test productivity. In lower-cost onshore areas, development of a field would commence immediately by completing the test well as a production well. In higher cost or more hostile environments such as the North Sea, a period of appraisal would follow, leading to a decision as to whether or not to develop the project. In either case, based on inevitably sparse data, further development wells, both producers and injectors would be planned in accordance with a reservoir development plan.
Once production and/or injection began, more dynamic data would become available, thus, allowing the engineers and geoscientists to better understand how the reservoir rock were distributed and how the fluids were flowing. As more data became available, an improved understanding of the reservoir was used to adjust the reservoir development plan resulting in the familiar pattern of development drilling, infill drilling, recompletions, sidetracks, well abandonment, etc.
Unfortunately, reservoir engineers typically gain knowledge in a fashion similar to pathologists who learn everything upon a patient's demise, because it is not until the time at which the field is abandoned, and when the information is the least useful, that reservoir understanding reaches its maximum.
Limited and relatively poor quality of reservoir data throughout the life of the reservoir, coupled with the relatively high cost of most types of well intervention, implies that reservoir management is as much an art as a science. Engineers and geoscientists responsible for reservoir management discussed injection, fingering, fluid movement, gas oil ratio changes, and pressure front movement as if these were precise defined processes. The reality, however, is that water predicted to take three years to break through to a producing well might arrive in six months in one reservoir but might never appear in another. Text book like “piston like” displacement rarely happens, and one could only guess at actual fluid movement.
For some time, reservoir engineers and geoscientists have made assessments of reservoir characteristics and optimized production using down hole test data taken at selected intervals. Such data usually includes pressure, composition, temperature and flow data as well known in the art. Reservoir engineers have also had access to production data for the individual wells in a reservoir. Such data as oil, water and gas flow rates are generally obtained by selectively testing production from the selected well at selected intervals.
Recent improvements in the state of the art regarding data gathering, both down hole and at the surface, have dramatically increased the quantity and quality of data gathered. Examples of such state of the art improvements in data acquisition technology include assemblies run in the casing string comprising a sensor probe with optional flow ports that allow fluid inflow from the formation into the casing while sensing wellbore and/or reservoir characteristics. The casing assembly may further include a microprocessor, a transmitting device, and a controlling device located in the casing string for processing and transmitting real time data. A memory device may also be provided for recording data relating to the monitored wellbore or reservoir characteristics. Examples of reservoir characteristics which may be monitored with such equipment include: temperature, pressure, fluid flow rate and type, formation resistivity, cross-well seismology and acoustic seismometry, perforation depth, fluid characteristics and logging data. Using a microprocessor, hydrocarbon production performance may be enhanced by activating local operations in additional downhole equipment.
Recent technology improvements include downhole flow control devices which may be used to shut off particular zones by using downhole electronics and programing with decision making capacity, the disclosure of which is incorporated by reference.
Another important emerging technology that may have a substantial impact on managing reservoirs is time lapse seismic, often referred to as 4-D seismic. In the past, seismic surveys were conducted primarily for exploration purposes. However, incremental differences in seismic data gathered over time are becoming useful as a reservoir management tool to potentially detect dynamic reservoir fluid movement. This is accomplished by removing the non-time varying seismic elements to produce a direct image of the time-varying changes caused by, for example, fluid saturation, pressure, temperature, and other physical changes which may occur in the reservoir over time. By using 4-D seismic data, reservoir engineers and geoscientists can locate bypassed oil to optimize reservoir management. Additionally, 4-D seismic processing can be used to enhance the reservoir model and history match flow simulations.
International PCT application WO 98/07049, the disclosure of which is incorporated herein by reference, describes and discloses state of the art seismic technology applicable for gathering data relevant to a producing reservoir. The publication discloses a reservoir monitoring system comprising: a plurality of permanently coupled remote sensor nodes, wherein each node comprises a plurality of seismic sensors and a digitizer for analog signals; a concentrator of signals received from the plurality of permanently coupled remote sensor nodes; a plurality of remote transmission lines which independently connect each of the plurality of remote sensor nodes to the concentrator; a recorder of the concentrated signals from the concentrator; and a transmission line which connects the concentrator to the recorder. The system is used to transmit remote data signals independently from each node of the plurality of permanently coupled remote sensor nodes to a concentrator and then transmit the concentrated data signals to a recorder. Such advanced systems of gathering seismic data may be used in the reservoir management system of the present invention as disclosed her
Cornish Bruce E.
Curtis Michael P.
Maerefat Nicida L.
Halliburton Energy Service,s Inc.
Schoeppel Roger
Vinson & Elkins L.L.P.
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