Patent Grant
9771797
Formation testing tools can measure formation pressures along a wellbore and can obtain formation fluid samples as well. Information from the pressures and samples can then help characterize the wellbore and can predict performance of the surrounding reservoirs. Formation testing tools can be conveyed downhole in a variety of ways, including wireline, drill string, or the like. In fact, formation testing tools disposed on drill collars of a drilling assembly evaluate newly drilled formations.
When used, the formation testing tool obtains formation pressures and reservoir fluids from desired locations or zones of interest in the wellbore. Because drilling mud is used during drilling, the formation testing tool first tests the obtained fluid to determine if it is free of mud filtrates. To do this, fluid samples can be directly analyzed with a variety of sensors, including optic devices, spectrometers, temperature sensors, pressure sensors, etc. Stored fluids can also be analyzed at the surface.
Tools, such as formation testing tools, used during drilling have limited capability to communicate with the surface. For this reason, controlling the tool by operators or surface equipment is often hindered by the lack of “real time” or limited communication between the downhole instrument and the surface. In the end, data quality may be compromised because of the inability to interact with the tool operation in a timely manner.
During a test operation, for example, pressure data collected on a drilling tool may not be communicated to the surface for multiple reasons, such as communication errors, poor signal to noise ratio, or by test design. Operators at the surface may not be able to monitor pressures in the tool's flowline in real time, and information from the drawdown and buildup of the pressure test cannot be viewed in real time at the surface. Thus, operators are unable to evaluate the quality of test measurements as they occur, and operators cannot abort a test or adjust the test's parameters during a formation test if needed.
Historically, operators have preprogrammed a fixed series of steps for the tool to perform. Once the tool is deployed, operators expect the tool to perform these steps as instructed. However, this procedure is neither efficient nor optimal due to the varying reservoir or formation properties. As long as the tool has sufficient processing capabilities, the downhole tool can use mathematical models to predict tool response and can then adjust operating parameters appropriately. Hence, there is a need for intelligent decision making in a downhole tool that replicates some of the decision-making capabilities that occur when an operator monitors and controls a formation tester in real time.
The subject matter of the present disclosure is directed to overcoming, or at least reducing the effects of, one or more of the problems set forth above.
A formation tester or other downhole tool performs an autonomous pressure test (i.e., pre-test) operation using a local controller within the tool. The controller operates autonomously and uses automated decision-making to control the testing of formation pressures with a formation isolation device, such as a probe, straddle packer, or other known type of arrangement. To do this testing, the controller is preconfigured (programmed) to test each of one or more stations of a formation with the formation tester using at least two autonomous drawdowns and buildups.
During a first automated drawdown at a station of the formation, for example, the tool isolates a portion of the formation from the wellbore to obtain formation pressure and reservoir fluid therefrom. For example, the tool can dispose a probe against the formation to obtain formation pressure and reservoir fluid. The controller can determine that the probe is properly set by sensing a setting pressure of the hydraulic system used to set the probe.
With the isolation device set to obtain fluids from the formation, the controller measures the flowline pressure and the drawdown interval while the tool is performing the first autonomous drawdown with the flowline in fluid communication with the isolation device and the formation region of interest. The drawdown can be done using either a hydraulically activated or an electro-mechanical piston and pre-test chamber assembly, which is in fluid communication with the flowline.
If the flowline pressure response from the first drawdown fails to meet specified criterion, the controller then aborts this first autonomous drawdown and may attempt an entirely new operation or move on to another station.
Provided the first drawdown satisfies all the criteria, a buildup period commences in a first autonomous buildup. Thus, the focus of the disclosed tool is on obtaining a good steady state drawdown during testing, which is contrary to the exclusive focus on getting a good final buildup typically used by existing testing tools.
In the buildup period, the controller measures the flowline pressure and the elapsed time interval while allowing the buildup of pressure within the flowline. A buildup occurs when the drawdown piston has been stopped, and pressure in the flowline and pre-test chamber is allowed to increase, equilibrating with the formation pressure. During this first autonomous buildup, the controller permits the buildup to continue until a minimum set of criteria has been satisfied. For example, some possible criteria include, but are not limited to, the length of time and/or the rate of change in the buildup pressure. Thus, the controller can permit the buildup to continue until the buildup interval is longer than the drawdown interval and/or until the rate of pressure change falls below a predetermined threshold value. Otherwise, the controller aborts the first autonomous buildup if at least one of the specified buildup criteria has not been attained.
Finally, the controller determines if another buildup period is required and determines a new drawdown rate and a new drawdown volume for subsequent, autonomous drawdown and buildup operations. These second autonomous drawdowns and buildups are performed as before. At the end of the second autonomous buildup, the controller compares the first buildup pressure to a second buildup pressure measured in the second autonomous buildup. Based on the comparison, the controller decides how to proceed with operations of the formation tester. If the first and second buildup pressures are the same or close to one another, the controller can reset for new operations at another station of the formation. If the buildup pressures are different (at least within a threshold), then the controller can perform third drawdown and buildup to obtain more drawdown and build up pressures to clarify any discrepancies in data.
The foregoing summary is not intended to summarize each potential embodiment or every aspect of the present disclosure.
A. Formation Testing Tool
In
In use, the tool 10 obtains data at various depths in the borehole to determine various characteristics of interest, such as formation pressures in various zones. To do this, the tool 10 has an isolation device 20 and other components for in-situ sampling and analysis of formation fluids in the borehole. Details of the device 20 are schematically shown in
In the present example, the isolation device 20 has a probe 50, which can include an isolation piston 52 and snorkel 54. In alternative arrangements, the isolation device 20 can use a straddle packer or other suitable arrangement known in the art to isolate portion of the borehole wall to obtain formation fluids through a port or the like on the tool 10.
A flowline 22 of the tool 10 communicates with this isolation device's probe 50 and extends through various sections of the tool 10 as shown in
At the isolation device 20, a drawdown chamber 60 and piston 62 connect to the flowline 22, and an equalization valve 66 communicates between the flowline 22 and the surrounding borehole annulus. Various sensors 64 connect to the controller 70 for monitoring parameters of the sampled fluid, including pressure, temperature, flow rate, and the like. Suitable sensors 64 include crystal quartz gauges, strain gauges, resistivity cells, and other temperature and pressure transducers. Data from the sensors 64 can be recorded in a local memory unit 72.
During operation, the tool 10 disposes at a desired location in the borehole. When the equalization valve 66 of the tool 10 opens to equalize pressure in the tool's flowline 22 with the hydrostatic pressure of the fluid in the wellbore, one or more of the sensors 64, such as a pressure transducer or gauge, is able to measure the hydrostatic pressure of the fluid in the wellbore.
Commencing test operations, the area of the formation (i.e., a station in the wellbore) to be sampled is isolated from the borehole by straddle packers, an elastomeric pad, a metal pad, an isolation piston, or the like to make a seal against the formation and the mud cake. For example, the probe 50 can use its isolation element 52 and snorkel 54 that extend from the tool 10 to establish fluid communication with the formation. The equalization valve 66 then closes to isolate the tool 10 from the wellbore fluids. As the probe 50 then seals with the formation to establish fluid communication, pressure measured by the sensors 64 reach a point 42 depicted in the graph of
At this stage, the tool 10 draws formation fluid into the tool 10 by retracting the drawdown piston 62 in a chamber 60. This creates a pressure drop in the flowline 22, which most likely will be below the formation pressure. The volume expansion is referred to as “drawdown” and permits reservoir fluid to flow into the low-pressure region created by the retracting of the drawdown piston. The “drawdown” has characteristic shapes that those skilled in the art can use to infer reservoir properties. As shown in the graph of
Preferably, the drawdown is mechanically actuated, which generally allows the drawdown to have a more consistent rate of activation. However, other forms of actuation can be used for the drawdown. In fact, the drawdown can be hydraulically actuated. Although this may vary the drawdown rate, the processing and analysis disclosed herein can accommodate a varying rate for the drawdown.
Eventually, the piston 62 in
As shown in the graph of
Depending on the circumstances, collected data can be communicated or telemetered uphole by telemetry components 29 on the tool 10 for processing by surface equipment 30. Alternatively, the collected data can be processed locally by the downhole controller 70. Either of these scenarios is applicable to the disclosed tool 10. Although only schematically represented, it will be appreciated that the controller 70 and surface equipment 30 can employ any suitable processor, program instructions, memory, and the like for achieving the purposes disclosed herein.
Because the intention is to analyze formation fluids and formation pressures, obtaining uncontaminated fluids with the probe 50 is of prime importance. In some instances, the fluid can be contaminated by drilling fluids because the probe 50 has made a poor seal with the borehole wall or because of some other reason. Consequently, the drawn fluid can contain hydrocarbon components (solid, liquid, and/or gas) from the formation as well as drilling mud filtrate or other contaminants. For this reason, the drawn fluid can flow through the tool's flowline 22, and various instruments and sensors in the tool 10 can analyze the fluid to determine when the drawn fluid is primarily formation fluids.
For example, the isolation device 20 can uses its sensors 64 to measure various physical parameters (i.e., pressure, temperature, viscosity, density, etc.) of the fluid, and a measurement device, such as a spectrometer, a resistivity cell, a capacitance cell, or the like, in the fluid analysis section 24 can determine physical and chemical properties of oil, water, and gas constituents of the fluid. Eventually, fluid directed via the flowline 22 can either be purged to the wellbore or can be directed to the sample carrier section 26 where the samples can be retained for additional analysis at the surface. Eventually, the probe 50 can be disengaged, and the tool 10 can be positioned at a different depth (i.e., another station) to repeat the test cycle.
Overall, the tool 10 can test several stations of the borehole by repeating the testing operations and altering parameters in the process. The first test at the first station can use drawdown rates and other parameters based on known characteristics of the wellbore. Then, as testing continues at other stations, the various rates and other parameters from previous tests can be used, and new rates and parameters can be calculated as discussed below. Depending on communications, the tool 10 can receive parameters (e.g., drawdown rates, buildup times, buildup volumes, etc.) for use at a given station and can send data uphole to the surface.
Overall, the tool 10 can draw in about 3 cc to about 13 cc during each test. The pretest chamber 60 can hold up to 40-47 cc during the multiple tests at a test station downhole. Before being moved to a new station downhole, the entire chamber 60 of the tool 10 can be flushed and reset to accept an entirely new test volume. Of course, the chamber 60 can be flushed between any given pre-test at the same station if desired.
B. Pressure Test Process For Formation Pressures
1. Overview
When obtaining fluid samples and pressures of the formation with the tool 10 of
In the case of limited communication with the surface equipment 30, an operator has the ability to let the controller 70 operate in an autonomous mode where any decision about the next step in the operation of the tool 10 is determined by the controller 70. In this way, there is no need for instantaneous communication to the surface, which may not be possible or may be problematic or insufficient for testing purposes as noted previously. Operating in this “autonomous” mode allows the tool 10 to obtain high quality data and allows the tool 10 to operate without human intervention. The tool 10 only needs to communicate points of interest from the test and the current status of the tool 10 to the surface equipment 30 once the operation has been completed.
To operate the tool in the “autonomous” mode, the tool's controller 70 is programmed with a formation pressure test (“pre-test”) process for controlling drawdown and buildup operations. In the pre-test process, the programmed controller 70 can make decisions using direct measurements during downhole operations. As detailed later, these direct measurements include pressure, temperature, fluid flow rate, drawdown volume, time intervals, and the like and are made with the various sensors 64 and other components of the tool 10. Incorporating these direct measurements, the controller 70 can determine optimal operational parameters given current conditions encountered downhole.
In general, the pre-test process relies on the fundamental relationships between fluid flow and porous media to optimize the tool's operation as much as possible. In turn, the controller 70 controls the testing sequence of the formation testing tool's probe 50 by using the measured values and performing calculations as data is being acquired. Starting with some initial set conditions, the controller 70 then works to optimize pre-test operations by incorporating the primary measurements from the downhole tool 10 to make operational decisions and adjust operating parameters. In this way, problems associated with mathematical transforms and the like for process control can be avoided.
The decisions and controls of the pre-test process are intended to replicate as closely as possible the decisions typically made by a human operator if the human operator were able to operate the downhole tool 10 remotely with instantaneous communications. After starting the test with a set of preprogrammed values, the controller 70 measures the response. The controller 70 then makes a decision based on programmed logic and determines subsequent settings and actions. The process continues until the given time expires or some other occurrence terminates the process. Particular details of the pre-test workflow of the controller 70 are discussed below with reference to
2. Stages of the Pressure Test Process
Referring to
The stages (102 through 112) follow in succession of one another to complete the pre-test process 100. Typically, the process 100 repeats at the same location (station) in the borehole by making several drawdown and buildup sequences through the stages (104 through 112). During pressure acquisition, however, the process 100 will make at least two autonomous drawdowns and buildups, looping through stages (104 through 112) twice and terminating if the same result is produced both times. Being autonomous, the drawdowns and buildups with their associated logic stages are intended to operate in isolation of communication or instruction from surface equipment and users. Other implementations may use more or less drawdown and buildup sequences depending on the circumstances.
In the initial condition stage (102), the process 100 performs initial operating set up (Block 120) by configuring all of the required initial operating parameters for the tool 10 to perform a pre-test. These initial operating parameters can be configured prior to deployment downhole or can be communicated from the surface to the tool's downhole telemetry system during deployment.
Once initial setup is complete, the tool 10 commences the drawdown stage (104) in which the tool 10 performs its drawdown operations (Block 140). To do this, the tool 10 of
Once the probe 50 or other isolation device is properly set, the tool 10 performs the drawdown. During this procedure, the controller 70 is simultaneously executing the first logic stage (106) by performing measurement and monitoring (Block 160). The controller 70 analyzes the results to determine whether measurements made during the drawdown meet the predefined criteria that indicate a successful drawdown (Decision 161). In general, the pre-test process 100 aborts any operation that does not meet required criteria and may send a failure code to the surface. As discussed in more detail later, the basis for the decisions about whether a given drawdown meets the required criteria involve questions such as whether the drawdown volume is too small, whether the time interval for drawdown to occur is too long, whether the pressure difference created during drawdown is too small, whether the last recorded pressure after drawdown is above the fluid's expected bubble point pressure, and the like. If one or more of the required criterion is not met, the pre-test process 100 terminates as the tool 10 aborts the test and the human operator is informed of the test result or the decision is stored in the on-board memory 72 for surface retrieval (Block 162).
If the measurement and monitoring of the drawdown indicates success, the pre-test process 100 proceeds to the buildup stage (108) in which the tool 10 performs its buildup operations (Block 180). As noted previously, the tool 10 performs a buildup by stopping the motion of the drawdown piston 62 and allowing pressure to increase in the flowline 22 as outlined previously.
With the buildup, the controller 70 simultaneously executes the second logic stage (110) by performing measurement and monitoring (Block 200). Here, the controller 70 again analyzes the results to determine whether predefined required criteria are met that indicate a successful buildup (Decision 201). As discussed in more detail later, the basis for the decisions about whether a given buildup meets the required criteria involve questions such as whether the time interval for buildup to occur is long enough, whether the pressure difference created during buildup is too small, whether the last recorded pressure after buildup is below a minimum threshold, whether the buildup rate is too slow, whether too many buildup attempts have been made, and the like. If the criteria are not met, the pre-test process 100 terminates as the tool 10 aborts the test (Block 202). Otherwise, the pre-test process 100 results in a completed test (Block 203). The human operator is informed of the test result, or it is stored in the on-board memory 72 for surface retrieval.
With a completed drawdown and buildup sequence, the pre-test process 100 may also calculate new variables for the subsequent operation of the tool 10 (Block 250) in the rate determination stage (112), which is described in more detail later. If the required criteria are met, the successful test then ends (Block 251), and the calculations for the next operation can be stored for later retrieval by the controller 70 when executing the next drawdown operation.
Given the general overview of the stages of the pre-test process 100 in
a. Initial Condition and Drawdown Stages
These initial conditions 122/124/126 are stored locally in the controller (70) and fed into the drawdown stage (104) as drawdown parameters 142 during use of the tool (10). As the pre-test process 100 then initiates the drawdown operation of the tool 10 (Block 144), the initial drawdown parameters 142 are used to control the operation. As the drawdown occurs, the controller (70) stores a start time of the drawdown 146 for processing in the first logic stage (106) of
If the elapsed time during a drawdown is less than a predefined time T1 (Decision 150), the process 100 continues the drawdown and checks if the volume V of drawdown fluid from the formation is greater than or equal to a predefined volume set for operation (Decision 152). To check the drawdown volume, the controller (70) determines the volume of the drawdown chamber (60) based on the movement of the drawdown piston (62), for example, and techniques known in the art. (The predefined time T1 and volume V depend on the implementation and can vary.)
If either enough time has elapsed or enough volume has been achieved, the process 100 stops the drawdown piston (62) of the tool (10) for the pre-test (Block 154). Stopping of the drawdown piston (62) signals the end of the drawdown period and signals the start of the buildup period. The start 146 and end 147 of the drawdown interval are then stored for later processing in the first logic stage (106) of
Turning to
b. First Logic Stage
In addition to portions of the initial condition and drawdown stages (102 and 104),
More importantly, the first logic stage (106) also obtains the bubble point pressure 151 and initial hydrostatic pressure 128 from prior to the drawdown operation. Using these previously measured pressures, the first logic stage (106) analyzes whether the pre-test should be aborted. One possible reason for aborting the test is if a drawdown was “dry” (i.e., the drawdown had little or no fluid volume) (Block 168). In other words, the fluid in the flowline can no longer be treated as a single-phase solution, which compromises any analysis methodologies. Another reason for aborting the test is if the tool's seal failed during drawdown (Block 174). In other words, the probe (50) on the tool (10) may have allowed borehole fluids to enter the tool's flowline (22), compromising the test results.
A “dry” test as used herein may refer to a drawdown that results in little or no fluid volume. This can be different from a “tight” test, in which little or no build-up is measured after drawdown. To determine if the test was “dry,” the first logic stage (106) determines whether the last recorded drawdown pressure 156 via Link (B) is greater than the bubble point pressure 151 (Decision 166). If not, then the pre-test 100 is aborted because the test had a dry drawdown (Block 168). In other words, little or no formation fluid volume was obtained in the drawdown so that the results are not useful.
If the last recorded drawdown pressure 156 is greater than the bubble point pressure 151 (Decision 166), the first logic stage (106) calculates their pressure difference (Block 170) and determines whether the difference is greater than some predefined pressure differential P1 (Decision 172). (The actual predefined differential P1 used can depend on the particular implementation and expected values and may be configurable during operation either automatically or remotely.) If the pressure differential is not great enough, the first logic stage (106) determines that the seal of the probe (50) has failed and aborts the pre-test (Block 174). If there is enough pressure differential, then the first logic stage (106) stores a positive indication for the buildup stage (108) of
c. Buildup Stage
With the successful drawdown stage (104) completed (i.e., the pre-test process 100 has not aborted either due to mechanical failure (seal failure) or over stressing the formation (dry tests), the pre-test process 100 commences the buildup stage (108) as shown in
The buildup operation (Block 182) produces a number of variables for later processing. In particular, the process 100 determines an elapsed time 184 of the buildup, a measured buildup pressure 186, elapsed time 188 since the last pressure measurement, and a pressure change 190 since the last pressure sample by the appropriate sensor. Each of these variables can be obtained with the tool's controller (70), associated timers, and sensors (64) as discussed previously. Once obtained, these variables (184, 186, 188, and 190) are used for the second logic stage (110) of
d. Second Logic Stage
If enough time has elapsed at decision 210, then the second logic stage (110) calculates a pressure difference 212 between the last recorded drawdown pressure 156 (Link B) and the measured buildup pressure 186 (Link F). The second logic stage (110) also calculates the buildup rate 214 using the elapsed time 188 (Link G) since the last pressure and the pressure change 190 (Link H) since the last pressure sample, as obtained from the buildup stage (108) of
At this point, the second logic stage (110) of
If the difference 212 is not sufficient, then the second logic stage (110) aborts the pre-test for being “tight.” In other words, the pre-test operation in this instance would have a thin pressure differential, indicating that the buildup has produced an increase in pressure that is only slightly over the original drawdown pressure, which could occur due to any number of reasons.
If the difference 212 is sufficient, the second logic stage (110) determines whether the buildup rate 214 is less than a specified rate R (Decision 220). (The actual specified rate R can depend on the implementation and may be configurable during operation either automatically or remotely.) In general, it is desirable to end the buildup period when the rate of change of the pressure during the buildup period has decreased indicating that a stable sandface pressure has been reached.
Additionally, the second logic stage (110) determines whether the elapsed time 184 (Link AA) for the buildup has exceeded a specified time T2 (Decision 222). (The actual specified time T2 can depend on the implementation and may be configurable during operation either automatically or remotely.) Although not shown, the pre-test process 100 may allow additional time to elapse if the Decision at 222 indicates that the elapsed time is not long enough.
In the end, the second logic stage (110) terminates the buildup and obtains a final pressure measure (PSTOP) 226 and is stored (Block 227). As intended, this final buildup pressure (PSTOP) 226 corresponds to the sandface pressure (46) in
If this is the second drawdown and buildup with the tool 10 at the current location in the formation, then the process 100 may or may not repeat another drawdown and buildup sequence. In particular, if the current buildup pressure (PSTOP) 226 is the same (or at least within some acceptable error) as the previous buildup from storage (Decision 228), then the current pre-test terminates as successful (Block 232). If the two buildup pressures from the current and previous test are not the same, the second logic stage (110) determines if this current buildup is the last of the three allotted operations (Decision 230) and successfully terminates the test if so (Block 232). Otherwise, whether this is the first pre-test run or the second run not matching the pressure of the first, the pre-test process 100 continues onto the rate determination stage (112) of
As noted previously, the pre-test process 100 typically cycles no more than three times in its present configuration. After the first pre-test, a second pre-test may be needed with adjusted rate and volume. Yet, the process 100 stops short of doing a third pre-test if the second pre-test process 100 results in the same final buildup pressure (PSTOP) 226 as the first pre-test. Other implementations may involve more or less repetitions of the drawdown and buildup at the same borehole location. It is possible that the counter can be configured to contain as many iterations of drawdown and build up sequences as feasible.
e. Rate Determination Stage
Turning now to
As shown in
Here, the new flow rate is based on the previous flow rate scaled by a ratio of a specified pressure differential relative to the pressure difference between the final build up pressure and the final drawdown pressure. The intention is to create a flow rate with a preferred or useful pressure differential P3. This newly calculated flow rate Q may actually exceed the maximum flow rate of the tool 10 (Decision 254) so that the rate determination stage sets the new flow rate accordingly (Blocks 256, 258). By calculating a new rate, the testing sequence works to minimize the pressure drawdown thereby minimizing the amount of time required for a successful build up period within the time permitted.
Either way, a new drawdown volume is calculated from the remaining volume in the drawdown chamber (60) indicated by what the piston (62) had previously moved (Decision 260). In other words, a remaining volume is obtained from the piston volume moved 158 during the drawdown stage (104) via Link (C), and a new volume is calculated as at least half that remaining volume. Using this new volume, the stage (112) determines the new drawdown volume 262. For example, if the first pre-test run had a drawdown volume of 5-cc of the total available volume of 40-cc, then a volume of 35-cc remains. With the calculation, the new volume for the next drawdown would be half of that remaining volume or about 17.5-cc, provided the desired configuration consists of three drawdown and buildup sequences. In any event, during the second drawdown at this increased volume, the drawdown may still end before attaining that volume if the drawdown interval exceeds 30-seconds (i.e., the rate to fill this increased volume may not be enough to fill the entire increased volume within that time frame).
Additionally, the stage (112) increments the buildup count (Block 264) so that the process 100 will complete at most three runs (although more or less can be configured). In the end, the new flow rate 256 or 258, the new drawdown volume 262, and the incremented buildup count 264 are fed back as the drawdown parameters 142 of the drawdown stage (104) of
In addition, should communication be possible at some point, data of the pre-test could be telemetered uphole. By observing the data collected during a pre-test drawdown stage, an engineer may have the option to change the initial pre-test parameters, such as drawdown rate and drawdown volume, to better match them to the formation characteristics before attempting subsequent tests. Any reconfigured parameters 142 may even be used as initial conditions on another borehole location, or the pre-test process 100 may use a predefined set of initial conditions on the other borehole location with those initial conditions being either configured for the particular borehole location or not.
The subject matter of the present disclosure can be implemented in digital electronic circuitry, in computer hardware, firmware, software, or in combinations of these. For example, a computer program product tangibly embodied in a machine-readable or programmable storage device for execution by a programmable control device or processor can embody the disclosed subject matter, and method steps of the present disclosure can be performed by the programmable processor executing a program of instructions to perform functions disclosed herein. Any suitable processors can be used including general and special purpose microprocessors. Generally, a processor will receive instructions and data from a read-only memory and/or a random access memory. Generally, any memory or storage devices can include magnetic disks, such as internal hard disks and removable disks; magneto-optical disks; optical disks; non-volatile memory; and semiconductor memory devices (such as EPROM, EEPROM, and flash memory devices)—some of which may be better suited for downhole use. Any of the foregoing can be supplemented by, or incorporated in, ASICs (application-specific integrated circuits).
The foregoing description of preferred and other embodiments is not intended to limit or restrict the scope or applicability of the inventive concepts conceived of by the Applicants. In exchange for disclosing the inventive concepts contained herein, the Applicants desire all patent rights afforded by the appended claims. Therefore, it is intended that the appended claims include all modifications and alterations to the full extent that they come within the scope of the following claims or the equivalents thereof.
This is a divisional of U.S. application Ser. No. 13/188,947, filed 22 Jul. 2011, which is incorporated herein by reference in its entirety.
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