CA2290050A1 - Intelligent down hole testing system - Google Patents
Intelligent down hole testing system Download PDFInfo
- Publication number
- CA2290050A1 CA2290050A1 CA002290050A CA2290050A CA2290050A1 CA 2290050 A1 CA2290050 A1 CA 2290050A1 CA 002290050 A CA002290050 A CA 002290050A CA 2290050 A CA2290050 A CA 2290050A CA 2290050 A1 CA2290050 A1 CA 2290050A1
- Authority
- CA
- Canada
- Prior art keywords
- sensor
- control valve
- work string
- valve
- down hole
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
- 238000012360 testing method Methods 0.000 title claims abstract description 79
- 238000005070 sampling Methods 0.000 claims abstract description 20
- 239000012530 fluid Substances 0.000 claims abstract description 19
- 238000000034 method Methods 0.000 claims description 17
- 230000004044 response Effects 0.000 claims description 8
- 238000005259 measurement Methods 0.000 claims description 5
- 238000012544 monitoring process Methods 0.000 abstract description 3
- 239000000523 sample Substances 0.000 description 26
- 238000010586 diagram Methods 0.000 description 5
- 238000004519 manufacturing process Methods 0.000 description 5
- 230000008569 process Effects 0.000 description 4
- 230000015572 biosynthetic process Effects 0.000 description 3
- 230000008859 change Effects 0.000 description 3
- 230000035939 shock Effects 0.000 description 3
- 239000006096 absorbing agent Substances 0.000 description 2
- 238000000429 assembly Methods 0.000 description 2
- 230000000712 assembly Effects 0.000 description 2
- 238000005553 drilling Methods 0.000 description 2
- 238000011156 evaluation Methods 0.000 description 2
- 238000002955 isolation Methods 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 230000002285 radioactive effect Effects 0.000 description 2
- 230000008707 rearrangement Effects 0.000 description 2
- 238000006467 substitution reaction Methods 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 238000004458 analytical method Methods 0.000 description 1
- 230000006835 compression Effects 0.000 description 1
- 238000007906 compression Methods 0.000 description 1
- 238000013480 data collection Methods 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000010304 firing Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 239000012071 phase Substances 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 230000000717 retained effect Effects 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
- E21B2200/22—Fuzzy logic, artificial intelligence, neural networks or the like
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Measuring Fluid Pressure (AREA)
- Automatic Analysis And Handling Materials Therefor (AREA)
Abstract
An intelligent down hole testing system for conducting well testing has down hole flow and shut-in logic and sampling logic. The system allows for flow and shut-in testing and fluid sampling down hole without the need for surface monitoring or control.
Description
INTELLEGENT DOWN HOLE TESTING SYSTEM
BACKGROUND OF THE INVENTION
1. Technical Field of the invention:
The present invention relates to an intelligent down hole testing system used to obtain reservoir information during a well test without the need for surface control. Specifically, the present invention allows for the down hole intelligent automation of flow and shut-in testing and sampling.
BACKGROUND OF THE INVENTION
1. Technical Field of the invention:
The present invention relates to an intelligent down hole testing system used to obtain reservoir information during a well test without the need for surface control. Specifically, the present invention allows for the down hole intelligent automation of flow and shut-in testing and sampling.
2. Description of Related Art:
The expense of completing a petroleum producing well can quite frequently exceed the expense of actually drilling the well. As a result, it is critical that sufficient information be gathered on the well after drilling to accurately determine if it is economically feasible to complete the well. Testing can provide valuable information on the type of completion required to insure adequate production and proper reservoir maintenance procedures. Further, if a new formation is being explored, it is particularly critical that representative samples of the reservoir fluids be collected and analyzed from the first few wells drilled in order to evaluate the formation.
It is also important that any testing be accomplished as quickly as possible, since any testing performed will necessarily delay production during the test period. Development wells are drilled for their economic importance to production, and, therefore, the best testing strategies minimize time on the well site.
Important test data can be obtained by measuring the reservoir pressure and flow rate with the well in a stabilized flow condition and the pressure and temperature of the well down hole when the well is shut-in. A stabilized flow condition is reached when the well pressure remains unchanged over a period of time, resulting in steady-state flow, or the pressure changes linearly with respect to time while the well is being flowed at a constant rate. A common test regimen involves collecting flow rate, pressure, and temperature data while alternatively operating the well in stabilized flow and shut-in conditions. Typically, stabilized flow data is measured at the surface and interpolated to estimate the actual flow rate and pressure down hole. Calculating the flow rate and pressure at the surface, however, introduces two serious complications. First, the wellbore storage of production fluids introduces complications in the interpolation of the data to down hole rates and pressures due to the expansion or compression of wellbore fluids in response to changes in the wellbore pressure. Wellbore storage may also result in it taking several hours for a steady-state flow at the zone of interest to manifest itself at the surface. Consequently, the well has to be run at a steady-state for quite some time before data collection actually begins. When a limited amount of time has been set aside for testing, for example one day, it may be very difficult to run more than one or two stabilized flow and shut-in tests given the amount of time it takes to manifest stabilized flow conditions up hole.
Further, a failure to timely recognize problems in flow testing parameters could lead to permanent damage to the production capabilities of the well.
A second problem inherent in measuring pressures and flow rates at the surface is the fact that, with data thus collected, estimating true down hole conditions by interpolation techniques is difficult if the reservoir pressure drops below the bubble point. (The bubble point is the pressure below which gas evolves from an oil solution.) Further, fluid samples taken when the test well is below the bubble point can not be used to determine the hydrocarbon composition of the reservoir. Importantly, gas and liquid phases are typically not produced in a formation in the same proportion as they exist in a single phase above the bubble-point pressure.
While some prior art methods involve measuring pressures and temperatures down hole, the determination of whether the flow has reached steady-state is typically made at the surface, and fluid samples are often taken at the surface. Even a fluid sample taken down hole may not be of much use if the sample was taken below the bubble point, a fact that may not be determined until after the sample is painstakingly recovered.
Given the problems detailed above with these methods, a need exists for an intelligent down hole testing system that can flow and shut-in a well based on real time data taken down hole. Further, a need exists to collect samples of reservoir fluid at pressures above the bubble-point without the necessity of repeated sampling from the rig level and subsequent well flow manipulation.
Such intelligent down hole testing system would save considerable rig time while greatly increasing the reliability and accuracy of well testing.
SUMMARY OF THE INVENTION
The present invention relates to an intelligent down hole testing system that can be run into the well on a work string along with many of the prior art components presently used for well testing. The intelligent down hole testing system assures that adequate reservoir information is acquired during a well test without the need for surface read-out. The invention is programmed on the surface to flow, shut-in, and sample the well pursuant to the particular test parameters best suited for each application. The system is then run in the well in the same way a prior art drill and testing string is presently run.
Once the testing string has been run into the well and everything is prepared down hole and at the surface for well testing, the intelligent down hole testing system is activated using a signal that is conveyed by wire line, telemetry, or hydraulic pulses. During the testing job, the invention interprets collected data and samples so as to make decisions about how the well testing should be carried out. For example, these decisions can include when to open the well for flow, when to shut-in the well, and when to choke the well for sampling. These decisions are base on pre-programmed information. However, if a change in decision making parameters is necessary, the intelligent down hole testing system can be re-programmed by a wire line probe, telemetry, or hydraulic pulses. If the invention does not respond to these changes, a hydraulic override feature allows manual control of the intelligent down hole testing system. When the intelligent down hole testing system has completed its pre-programmed routine a multi-cycle safety circulating valve is activated to indicate that manual control of the system has been transferred. The operator on the surface then controls the system for well kill operations.
There are additionally two special logic features of the system that clearly distinguish the intelligent down hole testing system from prior art methods and apparatus. First, the invention's testing system has a flow and shut-in logic.
During the flow periods, an intelligent control valve monitors the pressure/temperature sensors to determine stability of the flow period. Once a pre-determined stability is achieved, a timer is activated. When the timer completes its cycle, a ball valve in the intelligent control valve closes.
When the intelligent control valve closes, the shut-in period commences and the intelligent control valve returns to monitoring the response from the pressure/temperature sensors. When pre-determined reservoir shut-in parameters are met, the timer is again activated. Once the timer completes this cycle the intelligent control valve opens, and the next flow period commences. The intelligent control valve continues to operate in this manner until programmed to change to a sampling mode (as described below) or to terminate the well test.
Second, the intelligent testing system comprises a sampling logic. If the intelligent control valve switches to the sampling mode, the ball valve is closed and a variable choke is opened for flow. Once a pre-determined stability is achieved, a timer in the intelligent sampling system is activated. When the timer completes its cycle, the intelligent sampling system captures a sample and checks the sample to determine if it was taken above or below the bubble-point.
If the sample was taken below the bubble-point, the sample is discharged and the variable choke in the intelligent control valve is choked back a pre-determined amount. The intelligent control valve then monitors the pressure/temperature sensors to determine stability of the flow. Once a pre-determined stability is achieved, another sample is taken and tested. This cycle continues until the sample pressure is measured at the pre-determined pressure above the bubble-point. Once a correct sample has been taken the intelligent control valve opens the ball valve and closes the variable choke. The intelligent control valve can resume further flow and shut-in periods or can end the test.
The present invention is a great improvement over prior art methods and assemblies by reducing the rig time required in running well tests and greatly increasing the reliability of such tests by taking measurements down hole.
Further, test parameters can be changed to meet unique down hole conditions, thereby efficiently gathering all necessary data while limiting the potential for well damage during testing.
BRIEF DESCRIPTION OF THE DRAWINGS
For a more complete understanding of the present invention, and for further details and advantages thereof, reference is now made to the following Detailed Description taken in conjunction with the accompanying drawings, in which:
Figure 1 is a schematic representation of an embodiment of the present invention.
Figure 2 is a flow diagram illustrating the overall functional sequence of an embodiment of the invention.
Figure 3a is a flow diagram illustrating the flow and shut-in logic of an embodiment of the invention.
Figure 3b is a flow diagram illustrating the sampling logic of an embodiment of the invention.
_7_ DETAILED DESCRIPTION OF THE DRAWINGS
Figure 1 shows an embodiment of the present invention attached to a work string 20 and placed inside a wellbore annulus 10. Figure 1 shows a single zone of interest 15 to be tested. Many of the components illustrated in Figure 1 are typical of testing apparatus run on a work strings and are optional equipment that can be substituted with other equipment or can be left out of various embodiments of the present invention. For example, Figure 1 shows a radioactive tag 22 attached below the work string 20 for locating the work string in a hole. Below the radioactive tag 22 is shown both a rupture disc safety circulation valve 24 and a multi-cycle safety circulation valve 26. An optional, off the shelf, telemetry system 28 is shown immediately below the multi-cycle safety circulation valve 26. Next, Figure 1 shows a jar sub 30 which can be used to mechanically shock the work string 20 in the event the work string 20 and/or the packer 34 becomes stuck. Below the jar 30 is shown a safety joint 32, which is a relax point if the jar sub 30 does not work to free the work string 20.
One essential component to the embodiment illustrated is an isolation packer 34. Such isolation packer 34, however, could be an off the shelf hydraulic packer typical of testing and completion assemblies. Other essential components to the embodiment illustrated, although also off the shelf technology, include down hole pressure/temperature sensors 36. Unlike prior art apparatuses, however, the down hole pressure/temperature sensors 36 are electronically or hydraulically connected to and monitored by an intelligent control valve 40.
The intelligent control valve illustrated in this embodiment comprises both a ball valve _$_ 43 and a variable choke 41. Also unique to the present invention is an intelligent sampling system 50, which is electronically integrated with the intelligence function of the invention.
Continuing down the work string, further optional equipment is shown such as a vertical shock absorber 60, a firing head 62, TCP guns 64, and radial shock absorbers 66, all of which are typical components of a perforation tool. The inclusion of these perforation tool components with the testing apparatus illustrates that the testing can be accomplished on the same work string, which performs the perforation of the zone of interest 15.
Figure 2 shows a flow diagram of the testing sequence of one embodiment of the invention. The process begins by programming 210 the intelligent down hole testing system at the surface. This programming 210 includes the flow, shut-in, and sample testing protocol, which will be described in reference to Figures 3a and 3b. After the system has been programmed 210, the invention is then run in 220 the well for testing. The run in step 220 can be accomplished exactly as prior art drill stem testing strings are presently run in wells. The intelligent down hole testing system ("IDHTS") is then activated 230 using a signal that is conveyed from the surface to the down hole components by wire line, telemetry, or hydraulic pulses. Once the invention is activated 230 the intelligent testing 240 takes place down hole. This testing includes collecting data (for example, pressure, temperature, and flow rates), during shut-in conditions, stabilized flow and testing and sampling the well fluids. The parameters of all these tests are performed pursuant to the programming initiated at the programming step 210. If during the _g_ test 240 it becomes necessary to change the programming parameters, the intelligent down hole testing system can be re-programmed 250 by a wire line probe, telemetry, or hydraulic pulses. If the invention does not respond to these programming changes, a hydraulic override feature 270 allows the surface operator to revert to manual control of the testing components. However, if the re-programming step 250 is successfully accepted by the intelligent down hole testing system, the testing step 240 is resumed. Once all of the intelligent down hole testing has been completed 260 a multi-cycle safety circulating valve, or other like component, can be activated to indicate manual control of the system has been transferred to the surface 280. The operator on the surface would control the intelligent down hole testing system for well kill operations.
Referring now to Figures 3a and 3b, these flow diagrams illustrate the flow and shut-in logic and the sampling logic, respectively. Consequently, Figures 3a and 3b provide greater detail of the intelligent testing step 240 illustrated in Figure 2.
The flow and shut-in logic begins with the step of opening the ball valve 300. This allows for the well to begin flowing back up the work string. While the well is flowing, the invention monitors down hole pressure and temperature sensors 305 in order to identify a stabilized flow. Once the invention has determined that a stabilized flow has been achieved 310, pursuant to the parameters programmed at step 210 of Figure 2, a timer is activated 315 in order to conduct stabilized flow testing during a predetermined time period.
Pressure and temperature data is collected during this timed stabilized flow. Once the stabilized flow time period expires, the next step involves closing the ball valve 320. The system again monitors the pressure and temperature 325 until the pre-programmed shut-in parameters for testing 330 are met. At this point, the timer is again activated 335 so that pressure and temperature data can be collected for the shut-in condition over a predetermined time period. After this shut-in test is complete, the system performs an iteration check 340, again pursuant to the previous programming, to determine if additional well flow and shut-in tests are required. If so, the process begins again with the step of opening the ball valve 300. Otherwise, the intelligent down hole testing system can revert to the sampling logic mode, as illustrated in Figure 3b, by first closing the ball valve 345.
With the ball valve closed 345, a variable choke is opened 350 a pre-determined amount. The initial choke can be based either on previous surface programming or can be influenced by the data collected during the previous flow and shut-in logic testing. Opening the variable choke 350 allows the well fluids to again flow up the work string, but at a pressure that can be regulated by increasing or decreasing the choke. The system again performs a pressure and temperature monitor step 355 until stabilized flow parameters are met 360. A
timer is then activated 365 to regulate the period of stabilized flow. The invention then captures a sample of the well fluid 370. This sample is captured 370 and evaluated 375 down hole in very close proximity to a reservoir. Consequently, the data obtained from this sample is extremely accurate.
The sample evaluation step 375 determines whether the sample was taken above or below the bubble point pressure. If the sample was taken below the bubble point pressure, the sample is discharged 380 and the choke on the variable choke valve is increased 385. The invention then again monitors the pressure and temperature 355 until stabilized flow parameters are met 360, thus starting the sampling process all over again. If, however, the sample evaluation 375 determines that the sample was taken at a pressure acceptably above the bubble point pressure, the sample is retained for further analysis and the choke valve is closed 390. The invention then returns to the beginning of the flow and shut-in logic illustrated in Figure 3a by opening the ball valve 300. If additional flow and shut-in testing is required or programmed, this process is again initiated by the pressure/temperature monitoring step 305. The entire system reverts to the manual mode 395, however, if no further testing is required.
While Figures 3a and 3b illustrate separate flow and shut-in logic and sampling logic, another embodiment of the invention initially combines the two logic functions so that they are accomplished simultaneously. This can be accomplished by performing the first sample capture 370 while a stabilized flow test is being timed 315. If the sample then evaluates 375 to be above the bubble point, no further sampling logic is required.
Although preferred embodiments of the present invention have been described in the foregoing description and illustrated in the accompanying drawings, it will be understood that the invention is not limited to the embodiments disclosed, but is capable of numerous rearrangements, modifications, and substitutions of steps without departing from the spirit of the invention.
Accordingly, the present invention is intended to encompass such rearrangements, modifications, and substitutions of steps as fall within the scope of the appended claims.
What is claimed is:
The expense of completing a petroleum producing well can quite frequently exceed the expense of actually drilling the well. As a result, it is critical that sufficient information be gathered on the well after drilling to accurately determine if it is economically feasible to complete the well. Testing can provide valuable information on the type of completion required to insure adequate production and proper reservoir maintenance procedures. Further, if a new formation is being explored, it is particularly critical that representative samples of the reservoir fluids be collected and analyzed from the first few wells drilled in order to evaluate the formation.
It is also important that any testing be accomplished as quickly as possible, since any testing performed will necessarily delay production during the test period. Development wells are drilled for their economic importance to production, and, therefore, the best testing strategies minimize time on the well site.
Important test data can be obtained by measuring the reservoir pressure and flow rate with the well in a stabilized flow condition and the pressure and temperature of the well down hole when the well is shut-in. A stabilized flow condition is reached when the well pressure remains unchanged over a period of time, resulting in steady-state flow, or the pressure changes linearly with respect to time while the well is being flowed at a constant rate. A common test regimen involves collecting flow rate, pressure, and temperature data while alternatively operating the well in stabilized flow and shut-in conditions. Typically, stabilized flow data is measured at the surface and interpolated to estimate the actual flow rate and pressure down hole. Calculating the flow rate and pressure at the surface, however, introduces two serious complications. First, the wellbore storage of production fluids introduces complications in the interpolation of the data to down hole rates and pressures due to the expansion or compression of wellbore fluids in response to changes in the wellbore pressure. Wellbore storage may also result in it taking several hours for a steady-state flow at the zone of interest to manifest itself at the surface. Consequently, the well has to be run at a steady-state for quite some time before data collection actually begins. When a limited amount of time has been set aside for testing, for example one day, it may be very difficult to run more than one or two stabilized flow and shut-in tests given the amount of time it takes to manifest stabilized flow conditions up hole.
Further, a failure to timely recognize problems in flow testing parameters could lead to permanent damage to the production capabilities of the well.
A second problem inherent in measuring pressures and flow rates at the surface is the fact that, with data thus collected, estimating true down hole conditions by interpolation techniques is difficult if the reservoir pressure drops below the bubble point. (The bubble point is the pressure below which gas evolves from an oil solution.) Further, fluid samples taken when the test well is below the bubble point can not be used to determine the hydrocarbon composition of the reservoir. Importantly, gas and liquid phases are typically not produced in a formation in the same proportion as they exist in a single phase above the bubble-point pressure.
While some prior art methods involve measuring pressures and temperatures down hole, the determination of whether the flow has reached steady-state is typically made at the surface, and fluid samples are often taken at the surface. Even a fluid sample taken down hole may not be of much use if the sample was taken below the bubble point, a fact that may not be determined until after the sample is painstakingly recovered.
Given the problems detailed above with these methods, a need exists for an intelligent down hole testing system that can flow and shut-in a well based on real time data taken down hole. Further, a need exists to collect samples of reservoir fluid at pressures above the bubble-point without the necessity of repeated sampling from the rig level and subsequent well flow manipulation.
Such intelligent down hole testing system would save considerable rig time while greatly increasing the reliability and accuracy of well testing.
SUMMARY OF THE INVENTION
The present invention relates to an intelligent down hole testing system that can be run into the well on a work string along with many of the prior art components presently used for well testing. The intelligent down hole testing system assures that adequate reservoir information is acquired during a well test without the need for surface read-out. The invention is programmed on the surface to flow, shut-in, and sample the well pursuant to the particular test parameters best suited for each application. The system is then run in the well in the same way a prior art drill and testing string is presently run.
Once the testing string has been run into the well and everything is prepared down hole and at the surface for well testing, the intelligent down hole testing system is activated using a signal that is conveyed by wire line, telemetry, or hydraulic pulses. During the testing job, the invention interprets collected data and samples so as to make decisions about how the well testing should be carried out. For example, these decisions can include when to open the well for flow, when to shut-in the well, and when to choke the well for sampling. These decisions are base on pre-programmed information. However, if a change in decision making parameters is necessary, the intelligent down hole testing system can be re-programmed by a wire line probe, telemetry, or hydraulic pulses. If the invention does not respond to these changes, a hydraulic override feature allows manual control of the intelligent down hole testing system. When the intelligent down hole testing system has completed its pre-programmed routine a multi-cycle safety circulating valve is activated to indicate that manual control of the system has been transferred. The operator on the surface then controls the system for well kill operations.
There are additionally two special logic features of the system that clearly distinguish the intelligent down hole testing system from prior art methods and apparatus. First, the invention's testing system has a flow and shut-in logic.
During the flow periods, an intelligent control valve monitors the pressure/temperature sensors to determine stability of the flow period. Once a pre-determined stability is achieved, a timer is activated. When the timer completes its cycle, a ball valve in the intelligent control valve closes.
When the intelligent control valve closes, the shut-in period commences and the intelligent control valve returns to monitoring the response from the pressure/temperature sensors. When pre-determined reservoir shut-in parameters are met, the timer is again activated. Once the timer completes this cycle the intelligent control valve opens, and the next flow period commences. The intelligent control valve continues to operate in this manner until programmed to change to a sampling mode (as described below) or to terminate the well test.
Second, the intelligent testing system comprises a sampling logic. If the intelligent control valve switches to the sampling mode, the ball valve is closed and a variable choke is opened for flow. Once a pre-determined stability is achieved, a timer in the intelligent sampling system is activated. When the timer completes its cycle, the intelligent sampling system captures a sample and checks the sample to determine if it was taken above or below the bubble-point.
If the sample was taken below the bubble-point, the sample is discharged and the variable choke in the intelligent control valve is choked back a pre-determined amount. The intelligent control valve then monitors the pressure/temperature sensors to determine stability of the flow. Once a pre-determined stability is achieved, another sample is taken and tested. This cycle continues until the sample pressure is measured at the pre-determined pressure above the bubble-point. Once a correct sample has been taken the intelligent control valve opens the ball valve and closes the variable choke. The intelligent control valve can resume further flow and shut-in periods or can end the test.
The present invention is a great improvement over prior art methods and assemblies by reducing the rig time required in running well tests and greatly increasing the reliability of such tests by taking measurements down hole.
Further, test parameters can be changed to meet unique down hole conditions, thereby efficiently gathering all necessary data while limiting the potential for well damage during testing.
BRIEF DESCRIPTION OF THE DRAWINGS
For a more complete understanding of the present invention, and for further details and advantages thereof, reference is now made to the following Detailed Description taken in conjunction with the accompanying drawings, in which:
Figure 1 is a schematic representation of an embodiment of the present invention.
Figure 2 is a flow diagram illustrating the overall functional sequence of an embodiment of the invention.
Figure 3a is a flow diagram illustrating the flow and shut-in logic of an embodiment of the invention.
Figure 3b is a flow diagram illustrating the sampling logic of an embodiment of the invention.
_7_ DETAILED DESCRIPTION OF THE DRAWINGS
Figure 1 shows an embodiment of the present invention attached to a work string 20 and placed inside a wellbore annulus 10. Figure 1 shows a single zone of interest 15 to be tested. Many of the components illustrated in Figure 1 are typical of testing apparatus run on a work strings and are optional equipment that can be substituted with other equipment or can be left out of various embodiments of the present invention. For example, Figure 1 shows a radioactive tag 22 attached below the work string 20 for locating the work string in a hole. Below the radioactive tag 22 is shown both a rupture disc safety circulation valve 24 and a multi-cycle safety circulation valve 26. An optional, off the shelf, telemetry system 28 is shown immediately below the multi-cycle safety circulation valve 26. Next, Figure 1 shows a jar sub 30 which can be used to mechanically shock the work string 20 in the event the work string 20 and/or the packer 34 becomes stuck. Below the jar 30 is shown a safety joint 32, which is a relax point if the jar sub 30 does not work to free the work string 20.
One essential component to the embodiment illustrated is an isolation packer 34. Such isolation packer 34, however, could be an off the shelf hydraulic packer typical of testing and completion assemblies. Other essential components to the embodiment illustrated, although also off the shelf technology, include down hole pressure/temperature sensors 36. Unlike prior art apparatuses, however, the down hole pressure/temperature sensors 36 are electronically or hydraulically connected to and monitored by an intelligent control valve 40.
The intelligent control valve illustrated in this embodiment comprises both a ball valve _$_ 43 and a variable choke 41. Also unique to the present invention is an intelligent sampling system 50, which is electronically integrated with the intelligence function of the invention.
Continuing down the work string, further optional equipment is shown such as a vertical shock absorber 60, a firing head 62, TCP guns 64, and radial shock absorbers 66, all of which are typical components of a perforation tool. The inclusion of these perforation tool components with the testing apparatus illustrates that the testing can be accomplished on the same work string, which performs the perforation of the zone of interest 15.
Figure 2 shows a flow diagram of the testing sequence of one embodiment of the invention. The process begins by programming 210 the intelligent down hole testing system at the surface. This programming 210 includes the flow, shut-in, and sample testing protocol, which will be described in reference to Figures 3a and 3b. After the system has been programmed 210, the invention is then run in 220 the well for testing. The run in step 220 can be accomplished exactly as prior art drill stem testing strings are presently run in wells. The intelligent down hole testing system ("IDHTS") is then activated 230 using a signal that is conveyed from the surface to the down hole components by wire line, telemetry, or hydraulic pulses. Once the invention is activated 230 the intelligent testing 240 takes place down hole. This testing includes collecting data (for example, pressure, temperature, and flow rates), during shut-in conditions, stabilized flow and testing and sampling the well fluids. The parameters of all these tests are performed pursuant to the programming initiated at the programming step 210. If during the _g_ test 240 it becomes necessary to change the programming parameters, the intelligent down hole testing system can be re-programmed 250 by a wire line probe, telemetry, or hydraulic pulses. If the invention does not respond to these programming changes, a hydraulic override feature 270 allows the surface operator to revert to manual control of the testing components. However, if the re-programming step 250 is successfully accepted by the intelligent down hole testing system, the testing step 240 is resumed. Once all of the intelligent down hole testing has been completed 260 a multi-cycle safety circulating valve, or other like component, can be activated to indicate manual control of the system has been transferred to the surface 280. The operator on the surface would control the intelligent down hole testing system for well kill operations.
Referring now to Figures 3a and 3b, these flow diagrams illustrate the flow and shut-in logic and the sampling logic, respectively. Consequently, Figures 3a and 3b provide greater detail of the intelligent testing step 240 illustrated in Figure 2.
The flow and shut-in logic begins with the step of opening the ball valve 300. This allows for the well to begin flowing back up the work string. While the well is flowing, the invention monitors down hole pressure and temperature sensors 305 in order to identify a stabilized flow. Once the invention has determined that a stabilized flow has been achieved 310, pursuant to the parameters programmed at step 210 of Figure 2, a timer is activated 315 in order to conduct stabilized flow testing during a predetermined time period.
Pressure and temperature data is collected during this timed stabilized flow. Once the stabilized flow time period expires, the next step involves closing the ball valve 320. The system again monitors the pressure and temperature 325 until the pre-programmed shut-in parameters for testing 330 are met. At this point, the timer is again activated 335 so that pressure and temperature data can be collected for the shut-in condition over a predetermined time period. After this shut-in test is complete, the system performs an iteration check 340, again pursuant to the previous programming, to determine if additional well flow and shut-in tests are required. If so, the process begins again with the step of opening the ball valve 300. Otherwise, the intelligent down hole testing system can revert to the sampling logic mode, as illustrated in Figure 3b, by first closing the ball valve 345.
With the ball valve closed 345, a variable choke is opened 350 a pre-determined amount. The initial choke can be based either on previous surface programming or can be influenced by the data collected during the previous flow and shut-in logic testing. Opening the variable choke 350 allows the well fluids to again flow up the work string, but at a pressure that can be regulated by increasing or decreasing the choke. The system again performs a pressure and temperature monitor step 355 until stabilized flow parameters are met 360. A
timer is then activated 365 to regulate the period of stabilized flow. The invention then captures a sample of the well fluid 370. This sample is captured 370 and evaluated 375 down hole in very close proximity to a reservoir. Consequently, the data obtained from this sample is extremely accurate.
The sample evaluation step 375 determines whether the sample was taken above or below the bubble point pressure. If the sample was taken below the bubble point pressure, the sample is discharged 380 and the choke on the variable choke valve is increased 385. The invention then again monitors the pressure and temperature 355 until stabilized flow parameters are met 360, thus starting the sampling process all over again. If, however, the sample evaluation 375 determines that the sample was taken at a pressure acceptably above the bubble point pressure, the sample is retained for further analysis and the choke valve is closed 390. The invention then returns to the beginning of the flow and shut-in logic illustrated in Figure 3a by opening the ball valve 300. If additional flow and shut-in testing is required or programmed, this process is again initiated by the pressure/temperature monitoring step 305. The entire system reverts to the manual mode 395, however, if no further testing is required.
While Figures 3a and 3b illustrate separate flow and shut-in logic and sampling logic, another embodiment of the invention initially combines the two logic functions so that they are accomplished simultaneously. This can be accomplished by performing the first sample capture 370 while a stabilized flow test is being timed 315. If the sample then evaluates 375 to be above the bubble point, no further sampling logic is required.
Although preferred embodiments of the present invention have been described in the foregoing description and illustrated in the accompanying drawings, it will be understood that the invention is not limited to the embodiments disclosed, but is capable of numerous rearrangements, modifications, and substitutions of steps without departing from the spirit of the invention.
Accordingly, the present invention is intended to encompass such rearrangements, modifications, and substitutions of steps as fall within the scope of the appended claims.
What is claimed is:
Claims (29)
1. A work string for use in well testing comprising:
a packer isolating a lower portion of the work string;
a control valve in said lower portion;
at least one sensor in said lower portion; and, wherein said control valve operates in response to said sensor.
a packer isolating a lower portion of the work string;
a control valve in said lower portion;
at least one sensor in said lower portion; and, wherein said control valve operates in response to said sensor.
2. The work string of claim 1 wherein said sensor is a pressure sensor.
3. The work string of claim 1 wherein said sensor is a temperature sensor.
4. The work string of claim 1 wherein said sensor determines whether a fluid sample is taken above the sampled fluid's bubble point.
5. The work string of claim 1 wherein the control valve is a variable choke valve.
6. The work string of claim 1 wherein said control valve is a ball valve.
7. The work string of claim 1 further comprising:
a fluid sampling component in said lower portion.
a fluid sampling component in said lower portion.
8. The work string of claim 1 wherein said control valve responses are programmed on the surface prior to well testing.
9. The work string of claim 1 wherein said control valve operating responses can be programmed from the surface by remote means while said work string is down hole.
10.A method of conducting a well test with a work string, said method comprising the steps of:
(a) detecting a reservoir condition with at least one sensor;
(b) operating a control valve in response to said detected condition; and (c) wherein said sensor and said control valve operate down hole.
(a) detecting a reservoir condition with at least one sensor;
(b) operating a control valve in response to said detected condition; and (c) wherein said sensor and said control valve operate down hole.
11. The method of claim 10 wherein said sensor is a pressure sensor.
12.The method of claim 10 wherein said sensor is a temperature sensor.
13. The method of claim 10 wherein said sensor determines whether a fluid sample is taken above the sampled fluid's bubble point.
14. The method of claim 10 wherein said control valve is a variable choke valve.
15. The method of claim 10 wherein said control valve is a ball valve.
16. An apparatus for use in a wellbore having an annulus, said apparatus comprising:
a work string placed in the annulus;
a sensor in said work string;
a control valve in said work string; and, wherein said control valve operates in response to reservoir measurements from said sensor.
a work string placed in the annulus;
a sensor in said work string;
a control valve in said work string; and, wherein said control valve operates in response to reservoir measurements from said sensor.
17. The apparatus of claim 16 wherein said reservoir measurements are down hole temperature data.
18. The apparatus of claim 16 wherein said reservoir measurements are down hole pressure data.
19. The apparatus of claim 16 wherein said reservoir measurements are fluid sample bubble point data.
20. The apparatus of claim 16 further comprising:
a fluid sampling component in said work string.
a fluid sampling component in said work string.
21. The apparatus of claim 16 further comprising:
a timer in said work string wherein said timer is electrically connected to said control valve and regulates the operation of said control valve.
a timer in said work string wherein said timer is electrically connected to said control valve and regulates the operation of said control valve.
22. An intelligent control valve for use in a well comprising:
a valve positionable between an open and closed position;
a sensor connected to said valve; and, wherein said valve operates in response to input from said sensor.
a valve positionable between an open and closed position;
a sensor connected to said valve; and, wherein said valve operates in response to input from said sensor.
23. The intelligent control valve of claim 22 wherein said valve is a variable choke valve.
24. The intelligent control valve of claim 22 wherein said valve is a ball valve.
25. The intelligent control valve of claim 22 wherein said sensor is a pressure sensor
26. The intelligent control valve of claim 22 wherein said sensor is a temperature sensor.
27. The intelligent control valve of claim 22 wherein said sensor determines if a fluid sample is taken above said sample's bubble point.
28. The intelligent control valve of Claim 22 wherein said sensor is hydraulically connected to said valve.
29. The intelligent control valve of Claim 22 wherein said sensor is electronically connected to said valve.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US19803798A | 1998-11-23 | 1998-11-23 | |
| US09/198,037 | 1998-11-23 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2290050A1 true CA2290050A1 (en) | 2000-05-23 |
Family
ID=22731753
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002290050A Abandoned CA2290050A1 (en) | 1998-11-23 | 1999-11-17 | Intelligent down hole testing system |
Country Status (3)
| Country | Link |
|---|---|
| EP (1) | EP1004747A2 (en) |
| CA (1) | CA2290050A1 (en) |
| NO (1) | NO995715L (en) |
Families Citing this family (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| BRPI0815539B8 (en) * | 2007-08-17 | 2019-08-20 | Shell Int Research | method for controlling the inflow of crude oil, natural gas and / or other effluents. |
| CN111101927A (en) * | 2018-10-26 | 2020-05-05 | 航天科工惯性技术有限公司 | Underground data acquisition device |
| CN110206540B (en) * | 2019-05-23 | 2024-04-02 | 广州海洋地质调查局 | Method and device for testing annular output profile of horizontal well |
-
1999
- 1999-11-17 CA CA002290050A patent/CA2290050A1/en not_active Abandoned
- 1999-11-18 EP EP99309215A patent/EP1004747A2/en not_active Withdrawn
- 1999-11-22 NO NO995715A patent/NO995715L/en not_active Application Discontinuation
Also Published As
| Publication number | Publication date |
|---|---|
| EP1004747A2 (en) | 2000-05-31 |
| NO995715D0 (en) | 1999-11-22 |
| NO995715L (en) | 2000-05-24 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| EP0610098B1 (en) | Downhole fluid property measurement | |
| US5687791A (en) | Method of well-testing by obtaining a non-flashing fluid sample | |
| US6058773A (en) | Apparatus and method for sampling formation fluids above the bubble point in a low permeability, high pressure formation | |
| US6216782B1 (en) | Apparatus and method for verification of monophasic samples | |
| CA2228439C (en) | Method and apparatus for testing and sampling open-hole oil and gas wells | |
| CA2556427C (en) | Smooth draw-down for formation pressure testing | |
| CA2193309C (en) | Early evaluation system with pump and method of servicing a well | |
| RU2502870C2 (en) | Methods and device for planning and dynamic update of sampling operations during drilling in underground formation | |
| US6347666B1 (en) | Method and apparatus for continuously testing a well | |
| US9771797B2 (en) | Autonomous formation pressure test process for formation evaluation tool | |
| US5579842A (en) | Bottomhole data acquisition system for fracture/packing mechanisms | |
| EP1623090A1 (en) | Formation testing apparatus and method for optimizing draw down | |
| US7086464B2 (en) | Well testing system | |
| WO2020256731A1 (en) | Contamination prediction of downhole pumpout and sampling | |
| CA2535054C (en) | Method of using a test tool to determine formation build-up in a wellbore penetrating a subterranean formation | |
| EP1004747A2 (en) | Intelligent downhole testing system | |
| US5887652A (en) | Method and apparatus for bottom-hole testing in open-hole wells | |
| US20110168389A1 (en) | Surface Controlled Downhole Shut-In Valve | |
| AU2003244534B2 (en) | Method for measuring formation properties with a time-limited formation test | |
| US10563505B2 (en) | Sample capture prioritization | |
| US20160177713A1 (en) | Realtime downhole sample volume collection | |
| EP1076156A2 (en) | Early evaluation system for a cased wellbore |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| FZDE | Dead |