Patent Grant
8636478
Subsurface wells for extracting and/or testing fluid (liquid or gas) samples on land and at sea have been used for many years. Many structures have been developed in an attempt to isolate the fluid from a particular depth in a well so that more accurate in situ or remote laboratory testing of the fluid at that depth “below ground surface” (bgs) can be performed. Unfortunately, attempts to accurately and cost-effectively accomplish this objective have been not altogether satisfactory.
For example, typical wells include riser pipes having relatively large diameters, i.e. 2-4 inches, or greater. Many such wells can have depths that extend hundreds or even thousands of feet bgs. In order to accurately remove a fluid sample for testing from a particular target zone within a well, such as a sample at 1,000 feet bgs, typical wells can require that the fluid above the target zone be removed at least once and more commonly 3 to 5 times this volume in order to obtain a more representative fluid sample from the desired level. From a volumetric standpoint, traditional wet casing volumes of 2-inch and 4-inch monitoring wells are 0.63 liters (630 ml) to 2.5 liters (2,500 ml) per foot, respectively. As an example, to obtain a sample at 1,000 feet bgs, approximately 630 liters to 2,500 liters of fluid must be purged from the well at least once and more commonly 3 to 5 times this volume. The time required and costs associated with extracting this fluid from the well can be rather significant.
One method of purging fluid from the well and/or obtaining a fluid sample includes using coaxial gas displacement within the riser pipe of the well. Unfortunately, this method can have several drawbacks. First, gas consumption during pressurization of these types of systems can be relatively substantial because of the relatively large diameter and length of riser pipe that must be pressurized. Second, introducing large volumes of gas into the riser pipe can potentially have adverse effects on the volatile organic compounds (VOC's) being measured in the fluid sample that is not collected properly. Third, a pressure sensor that may be present within the riser pipe of a typical well is subjected to repeated pressure changes from the coaxial gas displacement pressurization of the riser pipe. Over time, this artificially-created range of pressures in the riser pipe may have a negative impact on the accuracy of the pressure measurements from the sensor. Fourth, residual gas pressure can potentially damage one or more sensors and/or alter readings from the sensors once substantially all of the fluid has passed through the sample collection line past the sensors. Fifth, any leaks in the system can cause gas to be forcibly infused into the ground formation, which can influence the results of future sample collections.
Another method for purging fluid from these types of wells includes the use of a bladder pump. Bladder pumps include a bladder that alternatingly fills and empties with a gas to force movement of the fluid within a pump system. However, the bladders inside these pumps can be susceptible to leakage due to becoming fatigued or detached during pressurization. Further, the initial cost as well as maintenance and repair of bladder pumps can be relatively expensive. In addition, at certain depths, bladder pumps require an equilibration period during pressurization to decrease the likelihood of damage to or failure of the pump system. This equilibration period can result in a slower overall purging process, which decreases efficiency.
An additional method for purging fluid from a well includes using an electric submersible pump system having an electric motor. This type of system can be susceptible to electrical shorts and/or burning out of the electric motor. Additionally, this type of pump typically uses one or more impellers that can cause pressure differentials (e.g., drops), which can result in VOC loss from the sample being collected. Operation of these types of electric pumps can also raise the temperature of the groundwater, which can also impact VOC loss. Moreover, these pumps can be relatively costly and somewhat more difficult to repair and maintain.
Further, the means for physically isolating a particular zone of the well from the rest of the well can have several shortcomings. For instance, inflatable packers are commonly used to isolate the fluid from a particular zone either above or below the packer. However, these types of packers can be subject to leakage, and can be cumbersome and relatively expensive. In addition, these packers are susceptible to rupturing, which can potentially damage the well.
The present invention is directed toward a sensor assembly for sensing one or more fluid properties of a fluid in a subsurface well. One of the fluid properties can be selected from the group consisting of an electrical property, an optical property, an acoustical property, a chemical property and a hydraulic property. The subsurface well has a well fluid level, a surface region and a riser pipe that extends in a downwardly direction from the surface region. In certain embodiments, the sensor assembly includes a sensor apparatus and a pump assembly. The sensor apparatus is positioned within the subsurface well, and includes a sensor that senses one of the fluid properties of the fluid.
The pump assembly is coupled to the sensor apparatus. The pump assembly can be positioned within the subsurface well in an in-line manner relative to the sensor apparatus. In one embodiment, the pump assembly can pump fluid toward the sensor apparatus. In an alternative embodiment, the pump assembly can pump fluid in order to draw more fluid to the sensor apparatus so that the sensor can sense one or more of the fluid properties of the fluid. In various embodiments, the pump assembly is removable from the riser pipe of the subsurface well. Further, the pump assembly can include a two-line, two-valve pump.
In certain embodiments, the pump assembly is positioned substantially between the sensor apparatus and the surface region. In one such embodiment, at least a portion of the pump assembly is positioned below the well fluid level within the subsurface well. In alternative embodiments, the sensor apparatus can be positioned between the pump assembly and the surface region of the subsurface well. In these embodiments, the pump assembly is adapted to pump fluid to the sensor apparatus. In one such embodiment, the sensor apparatus can be positioned above the well fluid level within the subsurface well.
In another embodiment, the sensor assembly also includes a controller that receives data from the sensor regarding one of the fluid properties of the fluid. The data can be transmitted to the controller while the sensor is positioned within the subsurface well.
The present invention is also directed toward a method for sensing one or more fluid properties from a fluid within a subsurface well.
The novel features of this invention, as well as the invention itself, both as to its structure and its operation, will be best understood from the accompanying drawings, taken in conjunction with the accompanying description, in which similar reference characters refer to similar parts, and in which:
Monitoring the fluid in accordance with the present invention can be performed in situ or following removal of the fluid from its native or manmade environment 11. As used herein, the term “monitoring” or “sensing” can include a one-time measurement of a single parameter of the fluid, multiple or ongoing measurements of a single parameter of the fluid, a one-time measurement of multiple parameters of the fluid, or multiple or ongoing measurements of multiple parameters of the fluid. Further, it is recognized that subsurface fluid can be in the form of a liquid and/or a gas. In addition, the Figures provided herein are not to scale given the extreme heights of the fluid monitoring systems relative to their widths.
The fluid monitoring system 10 illustrated in
The subsurface well 12 can be installed using any one of a number of methods known to those skilled in the art. In non-exclusive, alternative examples, the well 12 can be installed with hollow stem auger, sonic, air rotary casing hammer, dual wall percussion, dual tube, rotary drilling, vibratory direct push, cone penetrometer, cryogenic, ultrasonic and laser methods, or any other suitable method known to those skilled in the art of drilling and/or well placement. The wells 12 described herein include a surface region 32 and a subsurface region 34. The surface region 32 is an area that includes the top of the well 12 which extends to a surface 36. Stated another way, the surface region 32 includes the portion of the well 12 that extends between the surface 36 and the top of the riser pipe 30, whether the top of the riser pipe 30 is positioned above or below the surface 36. The surface 36 can either be a ground surface or the surface of a body of water or other liquid, as non-exclusive examples. The subsurface region 34 is the portion of the well 12 that is below the surface region 32, e.g., at a greater depth than the surface region 34.
The annular materials 24A-C can include a first layer 24A (illustrated by dots) that is positioned at or near the first zone 26, and a second layer 24B (illustrated by dashes) that is positioned at or near the second zone 28. The annular materials are typically positioned in layers 24A-C during installation of the well 12. It is recognized that although three layers 24A-C are included in the embodiment illustrated in
In one embodiment, for example, the first layer 24A can be sand or any other suitably permeable material that allows fluid to move from the surrounding ground environment 11 to the fluid inlet structure 29 of the well 12. The second layer 24B is positioned above the first layer 24A. The second layer 24B can be formed from a relatively impermeable layer that inhibits migration of fluid from the environment 11 near the fluid inlet structure 29 and the first zone 26 to the riser pipe 30 and the second zone 28. For example, the second layer 24B can include a bentonite material or any other suitable material of relative impermeability. In this embodiment, the second layer 28 helps increase the likelihood that the fluid collected through the fluid inlet structure 29 of the well 12 is more representative of the fluid from the environment 11 adjacent to the fluid inlet structure 29. The third layer 24C is positioned above the second layer 24B and can be formed from any suitable material, such as backfilled grout, bentonite, volclay and/or native soil, as one non-exclusive example. The third layer 24C is positioned away from the first layer 24A to the extent that the likelihood of fluid migrating from the environment 11 near the third layer 24C down to the fluid inlet structure 29 is reduced or prevented.
As used herein, the first zone 26 is a target zone from which a particular fluid sample is desired to be taken and/or monitored. Further, the second zone 28 can include fluid that is desired to be excluded from the fluid sample to be removed from the well 12 and/or tested, and is adjacent to the first zone 26. In the embodiments provided herein, the first zone 26 is positioned either directly beneath or at an angle below the second zone 28 such that the first zone 26 is further from the surface 36 of the surface region 32 than the second zone 28.
In each well 12, the first zone 26 has a first volume and the second zone 28 has a second volume. In certain embodiments, the second volume is substantially greater than the first volume because the height of the second zone 28 can be substantially greater than a height of the first zone 26. For example, the height of the first zone 26 can be on the order of between several inches to approximately five or ten feet. In contrast, the height of the second zone 28 can be from several feet up to several hundreds or thousands of feet. Assuming somewhat similar inner dimensions of the first zone 26 and the second zone 28, the second volume can be from 100% to 100,000% greater than the first volume. As one non-exclusive example, in a 1-inch inner diameter well 12 having a depth of 1,000 feet, with the first zone 26 positioned at the bottom of the well 12, the first zone having a height of approximately five feet, the second zone 28 would have a height of approximately 995 feet. Thus, the first volume would be approximately 47 in3, while the second volume would be approximately 9,378 in3, or approximately 19,800% greater than the first volume.
For ease in understanding, the first zone 26 includes a first fluid 38 (illustrated with X's), and the second zone 28 includes a second fluid 40 (illustrated with O's). The first fluid 38 and the second fluid 40 migrate as a single fluid to the well 12 through the environment 11 outside of the fluid inlet structure 29. In this embodiment, a well fluid level 42W in the well 12 is the top of the second fluid 40, which, at equilibrium, is approximately equal to an environmental fluid level 42E in the environment 11, although it is acknowledged that some differences between the well fluid level 42W and the environmental fluid level 42E can occur. During equilibration of the fluid levels 42W, 42E, the fluid rises in the first zone 26 and the second zone 28 of the well 12. Due to gravitational forces and/or other influences, the fluid near an upper portion (e.g., in the second zone 28) of the well 12 will have a different composition from the fluid near a lower portion (e.g., in the first zone 26) of the well 12. Thus, although the first fluid 38 and the second fluid 40 can originate from a somewhat similar location within the environment 11, the first fluid 38 and the second fluid 40 can ultimately have different compositions at a point in time after entering the well 12, based on the relative positions of the fluids 38, 40 within the well 12.
The first fluid 38 is the liquid or gas that is desired for monitoring and/or testing. In this and other embodiments, it is desirable to inhibit mixing or otherwise commingling of the first fluid 38 and the second fluid 40 before monitoring and/or testing the first fluid 38. As described in greater detail below, the first fluid 38 and the second fluid 40 can be effectively isolated from one another utilizing the zone isolation assembly 22.
The fluid inlet structure 29 allows fluid from the first layer 24A outside the first zone 26 to migrate into the first zone 26. The design of the fluid inlet structure 29 can vary. For example, the fluid inlet structure 29 can have a substantially tubular configuration or another suitable geometry. Further, the fluid inlet structure 29 can be perforated, slotted, screened or can have some other alternative openings or pores (not shown) that allow fluid and/or various particulates to enter into the first zone 26. The fluid inlet structure 29 can include an end cap 31 at the lowermost end of the fluid inlet structure 29 that inhibits material from the first layer 24A from entering the first zone 26.
The fluid inlet structure 29 has a length 43 that can vary depending upon the design requirements of the well 12 and the subsurface monitoring system 10. For example, the length 43 of the fluid inlet structure 29 can be from a few inches to several feet or more.
The riser pipe 30 is a hollow, cylindrically-shaped structure. The riser pipe 30 can be formed from any suitable materials. In one non-exclusive embodiment, the riser pipe 30 can be formed from a polyvinylchloride (PVC) material and can be any desired thickness, such as Schedule 80, Schedule 40, etc. Alternatively, the riser pipe 30 can be formed from other plastics, fiberglass, ceramic, metal, etc. The length (oriented substantially vertically in
The inner diameter 44 of the riser pipe 30 can vary depending upon the design requirements of the well 12 and the fluid monitoring system 10. In one embodiment, the inner diameter 44 of the riser pipe 30 is less than approximately 2.0 inches. For example, the inner diameter 44 of the riser pipe 30 can be approximately 1.85 inches. In non-exclusive alternative embodiments, the inner diameter 44 of the riser pipe 30 can be approximately 1.40 inches, 0.90 inches, 0.68 inches, or any other suitable dimension. In still other embodiments, the inner diameter 44 of the riser pipe 30 can be greater than 2.0 inches.
The gas source 14 includes a gas 46 (illustrated with small triangles) that is used to move the first fluid 38 as provided in greater detail below. The gas 46 used can vary. For example, the gas 46 can include nitrogen, argon, oxygen, helium, air, hydrogen, or any other suitable gas. In one embodiment, the flow of the gas 46 can be regulated by the controller 17, which can be manually or automatically operated and controlled, as needed.
The gas inlet line 16 is a substantially tubular line that directs the gas 46 to the well 12 or to various structures and/or locations within the well 12, as described in greater detail below.
The controller 17 can control or regulate various processes related to fluid monitoring. For example, the controller 17 can adjust and/or control timing of the gas delivery to various structures within the well 12. Additionally, or alternatively, the controller 17 can adjust and/or regulate the volume of gas 46 that is delivered to the various structures within the well 12. In still other embodiments, the controller 17 can receive and/or analyze data that is transmitted to the controller 17 by other structures in the well 12, as described in greater detail below. For example, the controller can analyze data relating to the fluid properties of the fluid being analyzed and/or sampled in the well 12. In one embodiment, the controller 17 can include a computerized system. It is recognized that the positioning of the controller 17 within the fluid monitoring system 10 can be varied depending upon the specific processes being controlled by the controller 17. In other words, the positioning of the controller 17 illustrated in
The fluid receiver 18 receives the first fluid 38 from the first zone 26 of the well 12. Once received, the first fluid 38 can be monitored, sensed and/or tested by methods known by those skilled in the art. Alternatively, the first fluid 38 can be monitored, sensed and/or tested prior to being received by the fluid receiver 18. The first fluid 38 is transferred to the fluid receiver 18 via the fluid outlet line 20. Alternatively, the fluid receiver 18 can receive a different fluid from another portion of the well 12.
The zone isolation assembly 22 selectively isolates the first fluid 38 in the first zone 26 from the second fluid 40 in the second zone 28. The design of the zone isolation assembly 22 can vary to suit the design requirements of the well 12 and the fluid monitoring system 10. In the embodiment illustrated in
In the embodiment illustrated in
In certain embodiments, the docking receiver 48 is at least partially positioned at the uppermost portion of the first zone 26. In other words, a portion of the first zone 26 is at least partially bounded by the docking receiver 48. Further, the docking receiver 48 can also be positioned at the lowermost portion of the second zone 28. In this embodiment, a portion of the second zone 28 is at least partially bounded by the docking receiver 48.
The docking apparatus 50 selectively docks with the docking receiver 48 to form a substantially fluid-tight seal between the docking apparatus 50 and the docking receiver 48. The design and configuration of the docking apparatus 50 as provided herein can be varied to suit the design requirements of the docking receiver 48. In various embodiments, the docking apparatus 50 moves from a disengaged position wherein the docking apparatus 50 is not docked with the docking receiver 48, to an engaged position wherein the docking apparatus 50 is docked with the docking receiver 48.
In the disengaged position, the first fluid 38 and the second fluid 40 are not isolated from one another. In other words, the first zone 26 and the second zone 28 are in fluid communication with one another. In the engaged position (illustrated in
The docking apparatus 50 includes a docking weight 56, a resilient seal 58 and a fluid channel 60. In various embodiments, the docking weight 56 has a specific gravity that is greater than water. In non-exclusive alternative embodiments, the docking weight 56 can be formed from materials so that the docking apparatus has an overall specific gravity that is at least approximately 1.50, 2.00, 2.50, 3.00, or 3.50. In certain embodiments, the docking weight 56 can be formed from materials such as metal, ceramic, epoxy resin, rubber, Viton, Nylon, Nitrile, Teflon, glass, plastic or other suitable materials having the desired specific gravity characteristics.
In various embodiments, the resilient seal 58 is positioned around a circumference of the docking weight 56. The resilient seal 58 can be formed from any resilient material such as rubber, urethane or other plastics, certain epoxies, or any other material that can form a substantially fluid-tight seal with the docking receiver 48. In one non-exclusive embodiment, for example, the resilient seal 58 is a rubberized O-ring. In this embodiment, because the resilient seal 58 is in the form of an O-ring, a relatively small surface area of contact between the resilient seal 58 and the docking receiver 48 occurs. As a result, a higher force in pounds per square inch (psi) is achieved. For example, a fluid-tight seal between the docking receiver 48 and the resilient seal 58 can be achieved with a force that is less than approximately 1.00 psi. In non-exclusive alternative embodiments, the force can be less than approximately 0.75, 0.50, 0.40 or 0.33 psi. Alternatively, the force can be greater than 1.00 psi or less than 0.33 psi.
The fluid channel 60 can be a channel or other type of conduit for the first fluid 38 to move through the docking weight 56, in a direction from the first zone 26 toward the surface region 32. In one embodiment, the fluid channel 60 can be tubular and can have a substantially circular cross-section. Alternatively, the fluid channel 60 can have another suitable configuration. The positioning of the fluid channel 60 within the docking weight 56 can vary. In one embodiment, the fluid channel 60 can be generally centrally positioned within the docking weight 56 so that the first fluid 38 flows substantially centrally through the docking weight 56. Alternatively, the fluid channel 60 can be positioned in an off-center manner.
The docking apparatus 50 can be lowered into the well 12 from the surface region 32. In certain embodiments, the docking apparatus 50 utilizes the force of gravity to move down the riser pipe 30, through any fluid present in the riser pipe 30 and into the engaged position with the docking receiver 48. Alternatively, the docking apparatus 50 can be forced down the riser pipe 30 and into the engaged position by another suitable means.
The docking apparatus 50 is moved from the engaged position to the disengaged position by exerting a force on the docking apparatus 50 against the force of gravity, such as by pulling in a substantially upward manner, e.g., in a direction from the docking receiver 48 toward the surface region 32, on a tether or other suitable line coupled to the docking apparatus 50 to break or otherwise disrupt the seal between the resilient seal 58 and the docking receiver 48.
The sensor assembly 51 senses one or more fluid properties in the first fluid 38 or any other fluid in certain portions of the well 12. The sensing of fluid properties by the sensor assembly 51 can be performed in situ, which can save time and/or the expense normally required for the fluid purging process. Further, the sensor assembly 51 can transport or otherwise move the first fluid 38 or another fluid between points within the well 12 and/or from the well 12 to outside of the well 12, such as to the controller 17, the fluid receiver 18, or other suitable locations. The design of the sensor assembly 51 can vary to suit the design requirements of the fluid monitoring system 10.
In certain embodiments, the sensor assembly 51 includes a sensor apparatus 52 and a pump assembly 54. In the embodiment illustrated in
Once the relevant fluid properties have been sensed by the sensor apparatus 52, the pump assembly 54 can pump the first fluid 38 to the controller 17, the fluid receiver 18 or to another region of the fluid monitoring system 10, as required. In the embodiment illustrated in
The sensor apparatus 52 has a length 62 that can be varied to suit the design requirements of the first zone 26 and the fluid monitoring system 10. In certain embodiments, the sensor apparatus 52 extends substantially the entire length 43 of the fluid inlet structure 29. Alternatively, the length 62 of the sensor apparatus 52 can be any suitable percentage of the length 43 of the fluid inlet structure 29.
The pump assembly 54 pumps the first fluid 38 that enters the pump assembly 54 to the fluid receiver 18 via the fluid outlet line 20. The design and positioning of the pump assembly 54 can vary. In one embodiment, the pump assembly 54 is a highly robust, miniaturized low flow pump that can easily fit into a relatively small diameter wells 12, such as a 1-inch or ¾-inch riser pipe 30, although the pump assembly 54 is also adaptable to be used in larger diameter wells 12. Further, in various embodiments, the pump assembly 54, including all of its components, is completely removable from within the riser pipe 30 of the well 12, as necessary.
In the embodiment illustrated in
As explained in greater detail below, gas 46 from the gas source 14 is delivered down the gas inlet line 16 to the pump assembly 54 to force the first fluid 38 that has migrated to the pump assembly 54 during equilibration upward through the fluid outlet line 20 to the fluid receiver 18. With this design, the gas 46 does not cause any pressurization of the riser pipe 30, nor does the gas 46 utilize the riser pipe 30 during the pumping process. Stated another way, in this and other embodiments, the riser pipe 30 does not form any portion of the pump assembly 54. With this design, the need for high-pressure riser pipe 30 is reduced or eliminated. Further, gas consumption is greatly reduced because the riser pipe 30, which has a relatively large volume, need not be pressurized.
The pump assembly 54 can be coupled to the docking apparatus 50 so that removal of the docking apparatus 50 from the well 12 likewise results in simultaneous removal of the pump assembly 54 and/or the sensor apparatus 52 from the well 12. In the embodiment illustrated in
In operation, following installation of the well 12, fluid from the environment 11 enters the first zone 26 through the fluid inlet structure 29. Before the docking apparatus 50 is in the engaged position, the first zone 26 and the second zone 28 are in fluid communication with one another, thereby allowing the fluid to flow upwards and mix into the second zone while the fluid level is equilibrating within the well 12.
During a monitoring, sampling or testing process, the docking apparatus 50 is lowered into the well 12 down the riser pipe 30 until the docking apparatus 50 engages with the docking receiver 48. The resilient seal 58 forms a fluid-tight seal with the docking receiver 48 so that the first zone 26 and the second zone 28 are no longer in fluid communication with one another. At this point the fluid within the well becomes separated into the first fluid 38 and the second fluid 40.
In the embodiment illustrated in
As the first fluid 38 continues to rise toward the pump assembly 54, the first fluid 38 remains isolated from the second fluid 40 because the pump assembly 54 is self-contained and does not rely on the riser pipe 30 as part of the structure of the pump assembly 54. In other words, the first fluid 38 within the pump assembly 54 does not contact the second fluid 40.
In certain embodiments, the controller 17 (or an operator of the system) can commence the flow of gas 46 from the gas source 14 to the pump assembly 54 to begin pumping the first fluid 38 through the fluid outlet line 20 to the fluid receiver 18, as described in greater detail below. Once a suitable volume of the first fluid 38 has been pumped to the fluid receiver 18, the controller 17 can stop the flow of gas 46, which effectively stops the pumping process. The pump assembly 54 can then refill with more fluid from the environment 11 (via the first zone 26), which can then be monitored, analyzed and/or removed for further testing as needed. Alternatively, the first fluid 38 can be analyzed by the sensor apparatus 52 in situ in the first zone 26, without the need for transporting the first fluid 38 through the fluid outlet line 20 to the fluid receiver 18. Alternatively, the process of purging the fluid can be immediately followed by sampling and/or testing the fluid with the controller 17, for example.
Because the volume of the first zone 26 is relatively small in comparison with the volume of the second zone 28, purging of the first fluid 38 from the first zone 26 can occur relatively rapidly. Further, because the first zone 26 is the sampling zone from which the first fluid 38 is collected, there is no need to purge or otherwise remove any of the second fluid 40 from the second zone 28. As long as the docking apparatus 50 remains in the engaged position, any fluid entering the first zone 26 will not be substantially influenced by or diluted with the second fluid 40.
The fluid inlet structure 229 has an outer diameter 264, the riser pipe 230 has an outer diameter 266, and the docking receiver 248 has an outer diameter 268. In this embodiment, the outer diameters 264, 266, 268 are substantially similar so that the outer casing of the well 212 has a standard form factor and is relatively uniform for easier installation. Alternatively, the outer diameters 264, 266, 268 can be different from one another.
The specific design of the pump assembly 454 can vary. In this embodiment, the pump assembly 454 is a two-valve, two-line assembly. The pump assembly 454 includes a pump chamber 484, a first valve 482F, a second valve 482S, a portion of the gas inlet line 416 and a portion of the fluid outlet line 420. The pump chamber 484 can encircle one or more of the valves 482F, 482S and/or portions of the lines 416, 420.
The first valve 482F is a one-way valve that allows the first fluid (represented by arrow 438) to migrate or otherwise be transported from the first zone 26 into the pump housing 484. For example, the first valve 482F can be a check valve or any other suitable type of one-way valve that is open as the well fluid level 42W (illustrated in
The second valve 482S can also be a one-way valve that operates by opening to allow the first fluid 438 into the fluid outlet line 420 as the level of the first fluid 438 rises within the pump chamber 484 due to the equilibration process described previously. However, any back pressure in the fluid outlet line 420 causes the second valve 482S to close, thereby inhibiting the first fluid 438 from receding from the fluid outlet line 420 back into the pump chamber 484.
In certain embodiments, the first fluid 438 within the fluid outlet line 420 is systematically moved toward and into the fluid receiver 18 (illustrated in
The gas source 414 is then turned off to allow the level of the first fluid 438 in the gas inlet line 416 to equilibrate with the environmental fluid level 42E. The second valve 482S closes, inhibiting any change in the level of the first fluid 438 in the fluid outlet line 420. Once the first fluid 438 in the gas inlet line 416 has equilibrated with the environmental fluid level 42E, the process of opening the gas source 414 to move the gas 446 downward in the gas inlet line 416 is repeated. Each such cycle raises the level of the first fluid 438 in the fluid outlet line 420 until a desired amount of the first fluid 438 reaches the fluid receiver 18. The gas cycling in this embodiment can be utilized regardless of the time required for the first fluid 438 to equilibrate, but this embodiment is particularly suited toward a relatively slow equilibration process.
In the second embodiment illustrated in
With these designs, because the gas 446 is cycled up and down within the gas inlet line 416 and or pump chamber 484, and no pressurization of the riser pipe 30 (illustrated in
The sensor assembly 551 includes a sensor apparatus 552 and a pump assembly 554 coupled to the sensor apparatus 552 in an in-line manner. Stated another way, in this embodiment, the pump assembly 554 is positioned substantially directly between the sensor apparatus 552 and the surface region 532 of the well 512 in a direction that moves between the sensor apparatus 552 and the surface region 532 of the well 512. In one such embodiment, the sensor apparatus 552, the pump assembly 554 and the surface region 532 of the well 512 are arranged in a substantially collinear manner. It is recognized, however, that not all wells 512 are absolutely linear in configuration. For instance, some wells 512 can include riser pipes 530 that curve or bend. It is to be understood that as used herein, the term “in-line” is intended to be construed as consecutive or in series with one another. With this in-line design, the sensor assembly 551 can be positioned in wells 512 having relatively small inner diameters 544, i.e. less than approximately 1.50 inches, less than approximately 1.00 inches, or less than approximately 0.75 inches, as non-exclusive examples.
In one embodiment, the sensor assembly 551 is positioned at or below the well fluid level 542W. However, in alternative embodiments, only a portion of the sensor assembly 551 is positioned at or below the well fluid level 542W. For example, in one embodiment, the entire sensor apparatus 552 and only a portion of the pump assembly 554 are positioned below the well fluid level 542W. In still other embodiments, one of the sensor assembly 552 and the pump assembly 554 are positioned below the well fluid level 542W, while the other of the sensor assembly 552 and the pump assembly 554 is positioned entirely above the well fluid level 542W. In yet another embodiment, only a portion of one of the sensor apparatus 552 and the pump assembly 554 is positioned below the well fluid level 542W, while the other of the sensor apparatus 552 and the pump assembly 554 is positioned entirely above the well fluid level 542W.
In various embodiments, the activation of the pump assembly 554 draws fluid through the sensor apparatus 552 for determining one or more fluid properties of the fluid. In other embodiments, the pump assembly 554 can pump fluid through the sensor apparatus 552 for determining one or more fluid properties of the fluid, as described in greater detail below. The pump assembly 554 can pump the fluid only to the extent of moving at least partially through the sensor apparatus 552, or the pump assembly 554 can pump the fluid through the sensor apparatus 552 and further to the fluid receiver 518. Alternatively, the pump assembly 554 can pump the fluid through the sensor apparatus 552 and further to another structure of the fluid monitoring system 510.
In one embodiment, the sensor apparatus 552 has an apparatus housing 570 having one or more housing inlets 572 (only one housing inlet 572 is illustrated in
Further, in this embodiment, the sensor assembly 551 can include a first conduit 576 and/or a second conduit 578. The first conduit 576 extends directly between the sensor apparatus 552 and the pump assembly 554. The first conduit 576 guides movement of the fluid between the sensor apparatus 552 and the pump assembly 554.
In the embodiment illustrated in
In an alternative embodiment, only the first conduit 576 is used. In this embodiment, the fluid and the one or more signal transmitters can move, can be positioned, or can otherwise cohabitate within the first conduit 576, at least between the sensor apparatus 552 and the pump assembly 554. In still another embodiment, no conduit is used to guide positioning of the signal transmitter(s) between the sensor apparatus 552 and the pump assembly 554.
The pump assembly 554 can include any suitable type of pump. In the embodiment illustrated in
The sensor apparatus 552 includes one or more sensors 682 that sense or otherwise determine one or more fluid properties of the fluid and/or collect data relative to one or more fluid properties of the fluid, which can then be sent, relayed or otherwise transmitted to the controller 517 (illustrated in
In one embodiment, because the fluid properties are sensed in situ, the sensor assembly 551 can be dynamically raised or lowered within the well 512 (illustrated in
In this embodiment, rather than the fluid being drawn into the sensor apparatus 852, activation of the pump assembly 854 pushes or pumps fluid through the sensor apparatus 852. The pump assembly 854 can pump the fluid only to the extent of moving at least partially through the sensor apparatus 852, or the pump assembly 854 can pump the fluid through the sensor apparatus 852 and further to the fluid receiver 818. Alternatively, the pump assembly 854 can pump the fluid through the sensor apparatus 882 and further to another structure of the fluid monitoring system 810, as required by the system 810.
Further, in this embodiment, fluid monitoring system 810 includes a gas inlet line 816 similar to that described previously herein. However, in this embodiment, the gas inlet line 816 can either be positioned to travel through the sensor apparatus 852, or to bypass or detour around the sensor apparatus 852.
In one embodiment, the entire sensor assembly 851 is positioned at or below the well fluid level 842W. However, in the embodiment illustrated in
It is recognized that the various embodiments illustrated and described herein are representative of various combinations of features that can be included in the fluid monitoring system 10 and/or the zone isolation assemblies 22 and/or the sensor assemblies 51. However, numerous other, embodiments have not been illustrated and described as it would be impractical to provide all such possible embodiments herein. It is to be understood that an embodiment of the sensor assembly 51, for example, can combine the sensor apparatus 52 and the pump assembly 54 within a single housing structure, as opposed to separate housing structures for each of the sensor apparatus 52 and the pump assembly 54 within the well 12. No limitations are intended by not specifically illustrating and describing any particular embodiment.
While the particular fluid monitoring systems 10 and sensor assemblies 51 as herein shown and disclosed in detail are fully capable of obtaining the objects and providing the advantages herein before stated, it is to be understood that they are merely illustrative of various embodiments of the invention. No limitations are intended to the details of construction or design herein shown other than as described in the appended claims.
This Application claims the benefit on U.S. Provisional Application Ser. No. 60/758,030 filed on Jan. 11, 2006, and on U.S. Provisional Application Ser. No. 60/765,249 filed on Feb. 3, 2006. The contents of U.S. Provisional Application Ser. Nos. 60/758,030 and 60/765,249 are incorporated herein by reference.
| Number | Name | Date | Kind |
|---|---|---|---|
| 2128253 | Johnson | Aug 1937 | A |
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| Number | Date | Country | |
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| 20070169933 A1 | Jul 2007 | US |
| Number | Date | Country | |
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| 60758030 | Jan 2006 | US | |
| 60765249 | Feb 2006 | US |
