Classifications

• • G—PHYSICS
  • G01—MEASURING; TESTING
  • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
  • G01V11/00—Prospecting or detecting by methods combining techniques covered by two or more of main groups G01V1/00 - G01V9/00

Definitions

• the invention is generally related to oil and gas wells, and more particularly to a downhole-reconfigurable tool string and analyzer unit which facilitate gathering targeted measurements for formation evaluation and reservoir characterization.
• Wireline logging tools are used to measure physical, chemical, and structural characteristics of formations surrounding a borehole. For example, data gathered by logging tools can be used to interpret formation stratigraphy, lithology, and mineralogy.
• An individual wireline logging tool measures physical properties of a formation and may be divided into different sections that are assembled at the wellsite. These sections include cartridges and sondes.
• the sonde is the section of the logging tool that contains the measurement sensors.
• the cartridge contains the associated electronics and power supplies.
• the logging tool In order to prepare for a logging run, the logging tool is first lowered into the borehole on a wireline cable. Measurements are then obtained as the tool is pulled back toward the surface. Multiple logging runs are made in some boreholes to improve coverage, confirm the accuracy of logged data and monitor progressive changes in the formation. However, because of the expense associated with the duration of logging operations, particularly in the case of offshore boreholes, it is desirable to minimize the amount of time required to obtain the necessary data. [0004] In order to reduce the number of logging runs, and also because data interpretation is often based on multiple properties, logging tools are often joined together in a "tool string." The tool string permits multiple properties to be measured during a single logging run.
• Modular tool strings permit a particular hardware configuration to be selected at the surface before commencement of logging operations.
• One aspect of hardware configuration is tool selection.
• a subset of tools is selected from an available suite of tools based on expected environmental and formation characteristics.
• An example of tool selection based on expected environmental and formation characteristics is described in Griffiths, R., Barber, T.
• the present invention is predicated in-part on recognition that surface- configurable, suit-for-purpose logging tool hardware cannot always be properly configured a priori because of a lack of sufficient information about the geological formations needed to select the appropriate hardware configuration. Further, regardless of the extent to which a proper hardware adaptation has been made, it is desirable to complement the acquisition with algorithmic processing and inversion to enhance the characterization of a desired formation attribute.
• a method of obtaining targeted measurements from a logging tool in a borehole comprises the steps of: identifying at least one second order feature associated with the formation; calculating a logging tool sensor configuration for the identified second order feature; adjusting the logging tool to achieve the calculated sensor configuration, while the logging tool is in the borehole; and logging the identified second order feature with the logging tool.
• apparatus for obtaining targeted measurements from a borehole environment comprises: a logging tool operable within the borehole environment in response to data or signaling to adopt a specified sensor configuration; and an analyzer unit operable to identify at least one second order feature associated with the formation, calculate a logging tool sensor configuration for the identified second order feature, and signal to the logging tool, thereby prompting the logging tool to adjust to achieve the calculated sensor configuration, while the logging tool is in the borehole, and log the identified second order feature.
• One advantage of at least one embodiment of the invention is reduction in time required for logging.
• the reduction in time is generally provided by reducing the number of logging runs required to achieve a desired result, which is accomplished by reconfiguring the logging tool in the borehole to log different second order features, rather than configuring a tool at the surface for each logging run, and executing a new logging run for each configuration.
• Figure 1 illustrates a downhole-reconfigurable tool string which facilitates targeted measurements for formation evaluation and reservoir characterization.
• Figure 2 is a flow diagram illustrating formation evaluation and reservoir characterization with the downhole-reconfigurable tool string.
• Figure 3 illustrates an embodiment of the downhole-reconfigurable tool string in which tool spacing is adjusted by physically moving tool components.
• Figure 4 illustrates an embodiment of the downhole-reconfigurable tool string in which tool spacing is adjusted by enabling and disabling tool components.
• a downhole-reconfigurable tool string (100) is utilized to measure physical, chemical, and structural characteristics of formations surrounding a borehole (101).
• the tool string operates under the control of an analyzer unit (102) which may be disposed at the surface.
• the analyzer unit is also capable of data analysis with reference to a reservoir model maintained in a memory.
• a wireline cable (104) connects the tool string (100) to the analyzer unit (102).
• the downhole-reconfigurable tool string is lowered into the borehole to measure physical properties associated with the formation, which typically includes a reservoir (106) adjacent to an impermeable layer (108), and various other layers which make up the overburden (110).
• Data gathered by the tool may be communicated to the analyzer unit in real time via the wireline cable.
• the downhole-reconfigurable tool string (100) and analyzer unit (102) can be both hardware and software reconfigured while in the borehole, with little or no interruption of logging operations. This innovative feature facilitates gathering of targeted measurements, which in turn are utilized for formation evaluation and reservoir characterization.
• the initial step in obtaining targeted measurements is feature detection (200).
• the tool string and analyzer unit, or some other devices are utilized to detect first order features, as shown in step (202), and identify second order features, as shown in step (204).
• the first order features are major features of the borehole, such as layering adjacent to the borehole, changes in lithology or facies, etc.. These first order features may be detected in either a single step or multiple steps. In the single step approach, a priori knowledge is used to select the logging tool suite for the downhole-reconfigurable tool string, and to decide on the most useful set of measurements to be made.
• an initial logging run may be executed with either a simple, fixed configuration logging tool or the downhole-reconfigurable tool string in a basic configuration. Data gathered from the initial logging run is then used to select a more comprehensive logging tool suite for the downhole-reconfigurable tool string, as will be described in greater detail below. Depending on conditions and required accuracy and resolution, the downhole- reconfigurable tool string may even detect the first order features while moving toward the bottom of the borehole in preparation for a more comprehensive logging run.
• the first-level description of the reservoir a.k.a., the "background” is processed by the analyzer unit to identify zones of interests within the formation, i.e., "second-order features.”
• Second order features include variations within a given facies or lithology, fractures, sealing or open faults, variations in filtrate invasion, microstructural variations, i.e., the extent of intergranular and intrgranular porosities and vugs, etc..
• the background is detected and then filtered to remove data in order to facilitate reconfiguration and operation of the tool for purposes of enhancing the sensitivity of the focused measurements to higher-order features.
• Dynamic downhole configuration of the tool string and analyzer unit are executed in an enhancement step (206).
• the tool string and analyzer are configured based on data obtained from the detect step.
• the enhance step includes the following operations: hardware configuration (208) through adjustment of control parameters, and; software-focusing (210) for deliberately resolving any formation property within a specified zone, assuming that the implemented hardware has enough sensitivity to the formation property of interest.
• Downhole configuration can be utilized to configure the tool string for an entire logging run, or to configure the tool string multiple times during a single logging run.
• the tool string may be uniquely configured for each individual second order feature being logged during a logging run.
• each identified zone of interest can be regarded as a perturbation relative to the background, thereby permitting linearization of the system of equations representing the measurements.
• targets in that they target a certain specified parameter at a particular location in the reservoir space.
• CAw dr ⁇ . [ (r) ⁇ (r) and
• Any of the above two cost functions can be used as a measure of how well the hardware is synthesized to achieve the desired focusing on the particular parameter of interest. The smaller the value of these cost functions, the better the focusing of the measurement and maximization of its sensitivity to the particular reservoir parameter of interest. In view of the focusing scheme described above, it will be appreciated that for hardware reconfiguration it would be preferable to construct the hardware such that the kernel approximates a delta functional as closely as possible.
• control parameters may include: (1) number of sources/sinks and receivers/observers; (2) source/sink-receiver/observer spacing; (3) frequencies of operation or testing protocol; (4) vector components or polarizations; (5) data sampling; and (6) linear combinations thereof.
• the control parameters may include: (1) number of sources/sinks and receivers/observers; (2) source/sink-receiver/observer spacing; (3) frequencies of operation or testing protocol; (4) vector components or polarizations; (5) data sampling; and (6) linear combinations thereof.
• a tool string variant (100a) is equipped with slidably moving sensor components (300), e.g., transmitters and receivers, which are operative in response to signaling from the analyzer unit.
• the transmitters and receivers can be repositioned relative to one another downhole in order to achieve better placement of these sensors along the borehole for the purpose of enhancing the sensitivity of the measurements to the formation properties of interest.
• this will imply a flexible line with an internal elevator for probes, such as described in U.S. Patent 5195588, which is incorporated by reference.
• Packers could also be mounted across tubing, the open interval of which may be expanded or shrunk, e.g., with a screw driven inside of a shaft within the tubing and a flexible hose for inflating and deflating the packers.
• a tool string variant (100b) is equipped with redundant arrays (400a-400f) of fixed-position sensor components which are operative in response to signaling from the analyzer unit.
• individual transmitters and receivers in each array can be selectively activated and deactivated downhole in order to achieve better separation and placement of the active sensor components along the borehole for the purpose of enhancing the sensitivity of the measurements to the formation properties of interest.
• a sensor pair configured initially as transmitter (402) and receiver (404) could be reconfigured as transmitter (402) and receiver (406).
• combinations of arrays may be selectively activated to achieve a desired number of sources/sinks and receivers/observers.
• the number and layout of arrays, and the number and layout of components in individual arrays are implementation details which may depend on intended use, and the illustrated example is not intended to be limiting in those respects.
• the next step in obtaining targeted measurements is reconstruction (212).
• a nonlinear inversion (214) is executed to reconstruct the reservoir properties to achieve a greater degree of accuracy.
• the analyzer unit is operable to compare the measured data obtained by the downhole-reconfigurable tool string with data produced by simulation with a reservoir model. The analyzer unit then operates to reduce or minimize the difference between the measured data and simulation data. The match between the measured and simulated data can be accomplished by adjusting the reservoir model parameters associated with the simulation in order to arrive at an approximate match.
• Possible inversion methods include, but are not limited to, deterministic (least squares) and probabilistic (Bayesian).
• a final, optional, step is monitoring (216).
• the results of the detect, enhance and reconstruct steps provide a good description of the reservoir for both geometry (structure) and physical/chemical properties.
• a permanent monitoring sensor array e.g., resistivity, acoustic, pressure, temperature, gravity, etc.
• the permanent monitoring sensor array may be mounted as a part of the completion. Further, the permanent sensor array may be made partly reconfigurable as shown in step (218) in Figure 2. For example, although the sensor locations may be fixed if the array is mounted rigidly within cement, it may still be possible to change the excitation frequencies and sampling rates of the measurement, which is valuable if one is interested in maximizing information content of the data acquired during fluid movement.

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• Life Sciences & Earth Sciences (AREA)
• General Life Sciences & Earth Sciences (AREA)
• General Physics & Mathematics (AREA)
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• Geophysics And Detection Of Objects (AREA)
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• 2007
  • 2007-06-21 US US11/766,534 patent/US20080314582A1/en not_active Abandoned
• 2008
  • 2008-06-20 EP EP08771619A patent/EP2158502A2/de not_active Withdrawn
  • 2008-06-20 CA CA002676428A patent/CA2676428A1/en not_active Abandoned
  • 2008-06-20 WO PCT/US2008/067704 patent/WO2008157773A2/en not_active Ceased

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