Well fluid isolation and sample apparatus and method

Abstract

The present invention specifically permits purging and/or sampling of a well but only removing, at most, about 25% of the fluid volume compared to conventional methods and, at a minimum, removing none of the fluid volume from the well.The invention is an isolation assembly that is inserted into the well. The isolation assembly is designed so that only a volume of fluid between the outside diameter of the isolation assembly and the inside diameter of the well over a fluid column height from the bottom of the well to the top of the active portion (lower annulus) is removed. A seal may be positioned above the active portion thereby sealing the well and preventing any mixing or contamination of inlet fluid with fluid above the packer. Purged well fluid is stored in a riser above the packer. Ports in the wall of the isolation assembly permit purging and sampling of the lower annulus along the height of the active portion.

Description

FIELD OF THE INVENTION

The present invention relates generally to an apparatus and method for obtaining well fluid from a well. More specifically, the invention is a method and apparatus for purging and/or sampling well fluid wherein the apparatus is an isolation assembly that minimizes the amount of fluid discharged for purging and/or sampling.

BACKGROUND OF THE INVENTION

Sampling the contents of a well is commonly done for purposes ranging from bacterial analysis of potable water wells to chemical analysis of oil and gas supply wells. With increased environmental protection regulations, more sampling wells, particularly water wells, have been drilled.

Prior to sampling a well, the standing fluid must be removed or purged so that what is sampled is fresh fluid influx to the well rather than stagnant fluid. Because fluid extracted from a well may become contaminated, it is preferred to avoid re-injecting the fluid into the well. Moreover, if the fluid is already contaminated (hence the reason for taking the samples) it is preferred to contain the contamination and not spread it by dumping it on the ground. In the United States, extracted well fluid is prohibited by regulation from being re-injected into the well or dumped onto the ground. Hence, handling the volume of purged fluid adds significant expense to the sampling procedure and as more sampling is done, the cost rises proportionately.

Present methods of purging involve removing two to four well volumes into a container. If sampling must be done more than once, with extended period of time between sampling, the well must be purged prior to each sampling. Thus, there is a need in the well sampling industry for a means and method of purging and sampling that would reduce the amount of water taken from wells for purposes of sampling.

SUMMARY OF THE INVENTION

The present invention specifically permits purging and/or sampling of a well but only removing, at most, about 25% of the fluid volume compared to conventional methods and, at a minimum, removing none of the fluid volume from the well.

The invention is an isolation assembly that is inserted into the well. The isolation assembly is designed so that a volume of fluid between the outside diameter of the isolation assembly and the inside diameter of the well over a fluid column height from the bottom of the well to the top of the active portion (lower annulus) is removed. In embodiments having a packer, pump means and exhaust direction means, the packer is positioned above the active portion thereby sealing the well and preventing any mixing or contamination of inlet fluid with fluid above the packer. Because the top of the isolation assembly may be open and well fluid may enter therein but is prevented from entering the lower annulus, and although well fluid within the isolation assembly may literally be below the packer, the phrase "above the packer" or "above the sealing means" as used herein is defined to mean the same as "excluded from the lower annulus". In its broadest sense, that definition can include well fluid in an isolation chamber. Where an internal seal exists between the isolation chamber and the packer unit, the phrase "above the packer" does not include the isolation chamber.

Ports in the wall of the isolation assembly permit purging and sampling of the lower annulus along the height of the active portion.

The subject matter of the present invention is particularly pointed out and distinctly claimed in the concluding portion of this specification. However, both the organization and method of operation, together with further advantages and objects thereof, may best be understood by reference to the following description taken in connection with accompanying drawings wherein like reference characters refer to like elements.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a section view of a well showing deployment of the isolation assembly.

FIG. 2 is a section view of the isolation assembly.

FIG. 3 is a section view of the valve means.

FIG. 4 is a schematic of an embodiment of the exhaust direction means illustrating the second operational function or the first directional function.

FIG. 5 is a schematic of an embodiment of the exhaust direction means illustrating the third operational function.

FIG. 6 is a schematic of an embodiment of the exhaust direction means illustrating the first direction function.

FIG. 7 is a schematic of an embodiment of the exhaust direction means illustrating the fifth operational function.

FIG. 8 is a sectional view of a retrofit isolation assembly.

FIG. 9 is a sectional view of a simplified isolation chamber.

DESCRIPTION OF THE PREFERRED EMBODIMENT(S)

Referring to FIG. 1, illustrated therein is a well 1 having a top opening 2, a bottom 3, an inner surface 4, and an active portion 5. The inner surface 4 may be earth, for example host rock or soil, or a casing of metal or plastic, and the active portion may be earth or a screened interval.

For purposes of purging and sampling, an isolation assembly 6 that is hollow and having a first end 7 and a second end 8 is inserted into the well 1 wherein the first end 7 is positionable near or in contact with the bottom 3 of the well 1 and the second end 8 is extendable above the active portion 5.

The isolation assembly 6 has an isolation chamber 9 with a valve 10 mounted at or near the first end 7 for admitting well fluid into the isolation chamber 9, a seal 12 for sealing between the inner surface 4 and the isolation assembly 6, and at least one port 14 for admitting additional well fluid into the isolation assembly 6.

During insertion of the isolation assembly 6, the valve 10 may permit well fluid to enter the isolation chamber 9. Upon locating the isolation assembly 6 in a final position in the well 1, the valve 10 is closed and sealed thereby isolating the well fluid within the isolation chamber 9 thereby preventing mixing of fluid within the isolation chamber 9 with fluid in an annular space 15 between the isolation chamber 9 and the inner surface 4 of the well 1.

After insertion to the final position, the seal 12 is activated for sealing the annular space 15. The seal is mounted near the second end 8 and positioned above the active portion 5 thereby isolating well fluid in a lower annulus 16 from below the seal 12 to the bottom 3 of the well 1 from well fluid above the seal 12. (The lower annulus 16 includes volume between the first end 7 of the isolation assembly 6 and the bottom 3 of the well 1.) With the isolation assembly 6 in place, the volume of well fluid within the isolation chamber 9 need not be removed from the well 1 for purposes of purging. The volume of well fluid to be purged is that within the lower annulus 16.

In a well 1 having an inside diameter of 4.0 inches which would be the case for a nominal 4-inch schedule 40 casing, an isolation assembly 6 having an outside diameter of 3.5 inches results in a well fluid volume to be purged of about 23% of the total well volume assuming that the well fluid level is below the seal 12. If instead, the nominal 4-inch well has a schedule 80 casing, then the inside diameter is 3.826 inches and the 3.5 inch diameter isolation assembly 6 results in a well fluid volume to be purged of about 9% of the total well volume. If the well fluid level is above the seal 12, then there is further reduction in purge volume.

During purging or sampling at least one port 14 takes well fluid from the lower annulus 16. The purged or sampled well fluid may be discharged to the surface and handled accordingly. Alternatively, regulations permitting, purged or sampled well fluid may be discharged into the volume above the seal 12. In wells wherein the screened interval of the well has low permeability or that are located in an area regulations do not permit leaving the purged or sampled well fluid in the well, the purged or sampled well fluid may be discharged into a riser 17, preferably an expandable riser. Expandable risers are disposed of more easily and for less cost than the cost of disposal and decontamination of rigid risers. If a riser is not used, and well fluid removal is needed, well fluid above the seal 12 can be removed at a convenient time for disposal. In wells not needing or requiring removal of purged or sampled well fluid, the purged or sampled well fluid may simply flow back toward the bottom 3 of the well 1 upon release of the seal 12.

After purging and/or sampling, the isolation assembly 6 may be removed from the well 1. Removal is facilitated by a pressure equalization port 18 that permits the valve 10 to open and permit well fluid to drain from the isolation chamber 9.

Isolation Assembly

In FIG. 2, further detail of the isolation assembly 6 is provided. The isolation assembly 6 generally has four subsections, packer unit 20, spacer unit 30, operational unit 40, and isolation unit 71. Units are connected with a coupler 60, wherein the coupler 60 is preferably a threaded coupling.

The packer unit 20 has a packer housing 21. The packer housing 21 may be made of any hollow material but is preferably schedule 80 polyvinyl-chloride (PVC) pipe. The packer housing 21 has an open end 22 and a coupling end 23. The coupling end 23 may be of any suitable geometry permitting connection with the spacer unit 30, but preferably has a thread machined on the external surface of the coupling end 23. Mounted on the exterior of the packer housing 21 is a packer 24. The packer 24 may be any type of packer including but not limited to mechanical packers, fluid inflated packer, disposable packer or compression packer. Preferably, the packer 24 is a fluid inflated packer made of an elastomeric material. Such packers may be obtained from Aardvark Corporation, Puyallup, Wash. A packer inflation line 25 is provided.

The spacer unit 30 has a housing 31 with a first end 32 and a second end 34. The first end 32 connects with the coupling end 23. Thus, the first end 32 preferably has internal threads connectably compatible with the external threads on the coupling end 23. The second end 32 preferably has an external thread. While FIG. 2 shows a single spacer length, it will be appreciated by those skilled in the art that the spacer 30 may be of any length or may contain several lengths of housing 31 with connectable ends. The purpose of the spacer 30 is to place the packer 24 above the active portion 5 while the first end 7 of the isolation assembly 6 rests near or on the bottom 3 of the well 1.

The operational unit 41 has a housing 41 connectable to the spacer unit 30 preferably in the same manner as the spacer unit 30 connects to the packer unit 20. Within the operational unit 40, is a pump 42 and exhaust director 44. Further, a top bulkhead 46, center bulkhead 47, and bottom bulkhead 48 are optionally used to seal a pump chamber 49, and a exhaust chamber 50. One or more inlet lines 51 direct well fluid from the lower annulus 16 to the exhaust director 44 and thence to the pump inlet 52. The pump 42 exhausts back through the exhaust director 44 and thence either to a first exhaust port 54 or a second port 55. The first exhaust port 54 directs well fluid through the interior of the spacer and packer units 30 and 20 respectively and to the well volume above the packer 24. The second port 55 is a transport tube that directs well fluid to the top of the well 1.

The isolation unit 70 has a housing 71 with at least one end connectable with other units. It will be apparent to those of skill in the art that the isolation unit 70 may be of any length or have one or more isolation units 70 with both ends connectable thereby permitting locating one or more ports 74 at predetermined height(s) above the bottom 3 of the well 1. The isolation unit 70 resting near or on the bottom 3 of the well 1, has an end 7 with the valve 10. The isolation chamber 9 is defined by the interior space from below the bottom bulkhead 48 to above the valve 10.

When an internal bulkhead is present, pressure equalizer port 18 is provided in the isolation unit 70 near connection with the operational unit 40 so that upon release of the packer 24, the well fluid within the isolation chamber 9 would be able to drain through the valve upon the pressure equalizer port 18 breaching the water level within the well 1. Pressure equalization may be achieved by any means, but is preferably a float valve that opens when the float is in air above a well fluid level.

Sensors 80 for measuring well fluid characteristics could be mounted in any location within or without the isolation assembly 6. For example, they could be located on either the inlet side or exhaust side of the pump 42 or within the isolation unit 70. Sensors 80 are however preferably mounted within the operational unit 40 in a manner permitting contact with well fluid prior to well fluid entry into the pump 42. Placement of sensors within the operational unit 40 permits keeping all electrical wiring within a particular unit which simplifies manufacture, assembly, and operation. Placement of sensors prior to pump inlet 52 avoids any sample interaction with the pump 42.

An electrical bundle 82 is provided for providing electricity to the pump 42, exhaust director 44, and the sensors 80.

The valve 10 can be any type of valve including but not limited to electrically actuated, pneumatically actuated, and mechanically actuated valves. It is preferred to use a mechanically actuated valve to eliminate the need to run a line, either electrical or fluidic, to the valve 10 location.

Valve Detail

Further detail of a preferred embodiment of the valve 10 is provided in FIG. 3. In this embodiment, valve 10 has a sealable bulkhead 310 and a slidable stem 320. The sealable bulkhead 310 is connectable to the valve end 73 of housing 71 preferably threadably connectable with the valve end 73 with internal threads on the housing 71 valve end 73 and external threads on a bulkhead disk 311. The bulkhead disk 311 has at least one hole 312 for flow of well fluid. In addition, a center hole 313 has a guide tube 314 mounted therein.

The slidable stem 320 has a first end 321 with a cap 322 mounted thereon. An elongate section 323 extends from the first tube end 321 through the guide tube 314 and below the bulkhead disk 311. Below the bulkhead disk 311 a sealing disk 324 is attached to the elongate section 323. An elastomeric ring 325 is mounted on the sealing disk 324 wherein the elastomeric ring 325 contacts the bulkhead disk 311 forming a seal and preventing flow of well fluid through hole(s) 312. The elongate section 323 further extends to a second tube end 326 having a closure disk 327 mounted thereon. The closure disk 327 prevent well fluid from entering the elongate section 323 and bears on the bottom 3 of the well 1. The cap 322 also prevents well fluid from entering the elongate section 323 and bears on the guide tube 314 thereby preventing the slidable 1stem 320 from falling through the sealable bulkhead 310.

It will be apparent to those skilled in the art that the valve 10 can be made in many ways other than depicted in FIG. 3. For example, a hinge valve could be used instead of a slidable valve. Alternatively the sealable bulkhead 310 could be made to slide within the housing 71 past holes in the side of the housing 71. Further, a sealing disk 324 may be rigidly mounted within housing 71 with the elastomeric ring 325 on the downward facing side of the sealing disk 324. Holes would be added to the sealing disk 324 to permit flow of well fluid.

Exhaust Director

It will be understood by those skilled in the art that the exhaust director 44 may be any combination of one-way and/or multi-way valves having any type of remote actuation. In the following description, an operative preferred embodiment is described in terms of solenoid actuated one-way valves connected by tubes. This operative preferred embodiment fits within the operation unit 40 using readily available solenoid valves and tubing. As a practical expedient, check valves 410 are included to prevent closed solenoid valves from being forced open by pump pressure.

However, exhaust director 44 may be constructed from a solid piece of material wherein flow passages are machined therein and threaded holes are provided for installation of solenoid valves. Yet further, the exhaust director 44 could be constructed as a large rotary valve or series of rotary valves wherein simply rotating a valve control stem to a particular location would provide the proper valve and flow passage arrangement for a particular direction function. Moreover, check valves are not necessary if valves are used having sufficient resistance to system pump pressure. It will be recognized that many modifications to the operative preferred embodiment are possible that perform essentially the same function of selectively drawing well fluid in essentially the same way of directing well fluid through tubing, valve(s), and pump, to achieve essentially the same result of purging and/or sampling.

The exhaust director 44 needs a minimum capability as defined by four one-way valves for a pump having a tubular inlet and for a single inlet line. Valve capability corresponding to five one-way valves is needed for pump having a flooded inlet. With valve capability defined by four or five one-way valves, five basic operational functions are provided with a single inlet line 51. Additional valve capability as defined by a one-way valve is needed for each additional inlet line 51. FIG. 4 is a schematic of one-way solenoid valves with two inlet lines 51. Inlet valve 401 is for one of the inlet lines, and inlet valve 402 is for the other inlet line. Exhaust valve 403 is used in combination with purge valve 405 for purging exhaust port 55 by emptying the well fluid contents therein into the first exhaust port 54. Sample valve 404 for collecting well fluid samples from the lower annulus 16 and directing them to the second exhaust port 55. Purge valve 405 is for purging the lower annulus by removing well fluid to the first exhaust port Extraction valve 406 is used only with sample valve 404 for removing well fluid from above the packer 24 to the second exhaust port 55 that may terminate above the top of the well.

The first operational function is no flow for storage or installation of the isolation assembly 6.

The second operational function is removal of well fluid from the lower annulus 16 through inlet line(s) 51 via pump 42 and thence to the first exhaust port 54. This direction function is referred to as purge or purging. Again, with reference to FIG. 4, the valves are arranged to accomplish a purge of the lower annulus 16. Sample valves 401 and 402 are open while valves 403, 404, and 406 are closed. Well fluid is drawn through samples valves 401 and 402 to the pump inlet 52. The pump exhausts the well fluid through open purge valve 405 to the first exhaust port 54.

The third operational function, sample collection is shown in FIG. 5. While mixed samples from multiple sample lines 51 is permissible, a single sample line sampling is illustrated. Sample valve 401 is open to receive a sample of well fluid from the lower annulus 16. The sample is drawn past sensor(s) 80 upstream of the pump inlet 52. The pump discharges through sample valve 404 to the second exhaust port 55. The purpose of discharging to the second exhaust port 55 is so that additional analyses may be done either for confirmation of sensor(s) 80 or complimentarily to information provided by sensor(s) 80. Valves 402, 403, 405, and 406 remain closed during sample collection.

The fourth operational function, sample tube purge, requires two direction functions. The purpose of this operational function is to remove well fluid remaining in the second exhaust port 55 and in the inlet line(s) 51 from previous sampling activity in preparation for obtaining new fresh sample(s). The first direction function is illustrated in FIG. 6 wherein well fluid is drawn from the second exhaust port 55 through exhaust valve 403 to the pump inlet 52. The second direction function is a purge of the inlet line(s) 51 according to the second operational function as described above. The reason that separate purging of the second exhaust port 55 and of the inlet line(s) 51 is provided is for pump 42 that have an open or flooded inlet. Pump 42 having a closed or tubular inlet would permit a single purge of inlet and exhaust lines.

The fifth operational function is removal of well fluid from above the packer 24 to above the well, or purged well fluid extraction. If purged well fluid is stored within a riser, then the option exists for simply closing the riser and removing it from the well, or removing riser and isolation assembly 6 then closing the riser and separating it from the isolation assembly 6. If, on the other hand, purged well fluid is stored in the well above the packer 24, then purged well fluid may be removed as illustrated in FIG. 7. Well fluid is drawn from the first exhaust port 54 through extraction valve 406 to the pump inlet 52. The pump exhausts through sample valve 404 to the second exhaust port 55 and thence to the top of the well.

Retrofit Isolation Assembly

For applications in which it is desirable to utilize a pump that may already be present in the well 1, the isolation assembly 6 may be simplified as depicted in FIG. 8. In these applications, the isolation assembly 6 is made up of existing pump 800 and an assembly kit 802.

The existing pump 800 may be any type of pump, but is preferably a centrifugal pump so that well fluid may drain through the pump 800 when it is not operating. If existing pump 800 is a type of pump that does not so drain, an additional valve in the exhaust director 44 may be needed.

The assembly kit 802 has a packer unit 21 and an exhaust director 44. The packer unit may be of any type, but is preferably an inflatable packer 24 as shown in FIG. 8. The inflatable packer 24 is mounted on packer housing 21. The exhaust director 44 has the equivalent of two one-way valves, preferably a three-way valve, plus directional plumbing through which well fluid is received from pump exhaust 804, then directed either to the first exhaust port 54 emptying either into a riser or directly into the well space above the packer, or to the second exhaust port 55 emptying to the top of the well 1.

The packer housing 21 has an open end 22 and a coupling end 23. Coupling may be to the pump 800 as shown in FIG. 8 or to the discharge pipe 805. It will be appreciated by those skilled in the art of well sampling that many sealable couplings are useable for this purpose.

The three-way valve may be any type of three-way valve, but is preferably an electrically actuated three-way valve. In combustible environments, the three-way valve may be pneumatically or hydraulically actuated.

In certain wells, the bottom 3 may be much below an active portion 5 from which samples are desired. In these wells, the isolation assembly 6 may have a second packer 24 mounted on the isolation unit 70, or in the case of a retrofit, a second packer assembly 20 would be added below the pump 800. A valve 10 would be needed at the bottom of either the isolation unit 70 or the second packer assembly 20. In this case, the valve 10 would be actuated by means other than by contact with the bottom of the well.

The isolation assembly has two basic operational functions. The first operational function is purging wherein well fluid is taken from the lower annulus 16 and discharged through the first exhaust port 54. The second operational function is sampling wherein well fluid from the lower annulus 1 is discharged through the second exhaust port 55. As an option, sensor(s) 80 may be placed on or below the packer housing 21.

A yet further embodiment is an isolation assembly 6 having simply a packer unit 20 sealably attached to the pump 800 or a pump discharge pipe 805. In this embodiment, the second exhaust port 55 would go to the top of the well and terminate with a flexible pipe or hose, while the first exhaust port 54 is absent. In this case, the flexible pipe or hose is the exhaust director 44 but has no valves per se. Flexible pipe includes but is not limited to jointed hard pipe, or bendable plastic, or composite material pipe or hose. For purging, the flexible pipe or hose is placed in the well bore, and well fluid is collected above the packer 24. For sampling, the flexible pipe or hose is directed to a sample collection container. This embodiment is not preferred because additional purge volume is required to ensure purging of the exhaust port 55 volume.

Simplified Isolation Assembly

An isolation assembly having no packer is referred to as a simplified isolation assembly and is shown in FIG. 9. The simplified isolation assembly is an isolation assembly 6 having a first end 6 and a second end 7 enclosing an isolation chamber 9. A bottom hole 901 is provided in the second end 7. The first end 8 is provided with an closure 902 having a top hole 904.

The closure 902, in cooperation with the hole 901 permits entry of water into the isolation chamber 9 as the isolation assembly 6 is lowered into the well 1. Air in the isolation chamber 9 escapes through the top hole 904 as water enters through the bottom hole 901.

The diameter of the bottom hole can range from a size barely permitting water to enter the isolation chamber up to the inside diameter of the isolation chamber. However, for bottom holes less than about 3/8 inch in diameter, the mass flow of water through the hole is limited so that the amount of time for the isolation chamber 9 to fill and empty is excessive. For bottom holes greater than about 1 inch or a plurality of bottom holes, it is difficult to "seal" the hole(s) on the bottom 3 of the well 1. Thus, it is preferred that the bottom hole be located near the center of the first end 7 and range in size from about 3/8 inch to about 1 inch.

The diameter of the top hole 904 can be quite small, but should be of a size corresponding to the volume flow of air escaping therethrough as the volume flow of water entering the bottom hole 901. In other words, the volume flow capacity of the top hole 904 for air is preferably equal to or greater than the volume flow capacity of the bottom hole 901 for water. Moreover, the top hole 904 preferably retards any flow of water from within the isolation chamber 9 to the water exterior to the isolation assembly 6 after the isolation assembly 6 is in place and full of water. Thus, although the top hole 904 can range in size from the minimum possible to permit passage of air molecules to the inside diameter of the isolation chamber 9, it is preferred that the top hole 904 be from about 1/16 in. to about 1/2 in. and more preferably about 1/4 in.

Once emplaced in the well 1, the isolation assembly 6 permits purging of well water from the lower annulus 16 while leaving substantially undisturbed the water within the isolation chamber 9. A small amount of water from the isolation chamber 9 may diffuse through the top hole 9 into the well 1. However, because the purging step is accomplished in less than about 1/2 hour and very often within about 10 minutes, the amount of diffusion is negligible. In wells wherein it is not possible to seal the bottom hole 901 at the bottom 3 of the well 1, the foot valve 10 may be used in place of an open bottom hole 901.

To facilitate emplacement and removal of the isolation assembly, a T-bar 906 may be used having a `T` or tee 908 attached to a cable 910 passing through the top hole 904. The cable 910 may be attached to the pump 912 or run up to the surface of the ground.

Operation of the simplified isolation chamber is shown in FIG. 10. The arrows 1001 show the direction of water flow toward the pump 912 during purging and sampling. The closure 902 preferably has a shape permitting active flow throughout the region 1002 between the top 8 of the isolation assembly and the pump 912 and avoiding creation of stagnant zones within the region 1002. A preferred shape is a cone, but it will be apparent to those skilled in the art that a spherical segment, elliptical segment, hyperbolic, quadratic, cubic, logarithmic or other curved segment either concave or convex may be applied to permit active flow. A closure 902 having a substantially horizontally flat surface could be used, but is less preferred because of the potential stagnant zone created near the center of the flat surface.

As a means to prevent diffusion or other flow from within the isolation chamber 9 to the region 1002, a foot valve 10 may be used in place of the bottom hole 901 as previously mentioned, or a check valve may be used at the top hole 904. If a check valve is used, then the T-bar 906 is replaced by another lifting handle. The check valve would be closed upon buoyant contact with water and opened upon lifting the isolation assembly and permitting water to escape.

An example of a check valve is shown in FIG. 11. In this embodiment, a float 1101 is used in cooperation with a float seat 1102 to seal the closure 902. A float container 1103 is provided to retain the float in proximity to the closure 902. A bail 1104 replaces the T-bar 906 to avoid interference with the float 1001. The top hole 904 is sized to be larger than the float 1101. Instead of a float 1101, a flap valve such as used in toilet flush apparatus or on SCUBA diving breathing apparatus may be mounted on the closure 902.

In order to facilitate handling in a well, spacers 1105 may be placed on the exterior of the isolation assembly. The spacers may be hemispherical buttons, half moon shaped pieces or any variety of intermittent spacer.

Closure

While a preferred embodiment of the present invention has been shown and described, it will be apparent to those skilled in the art that many changes and modifications may be made without departing from the invention in its broader aspects. The appended claims are therefore intended to cover all such changes and modifications as fall within the true spirit and scope of the invention.

Claims

1. An isolation assembly for obtaining well fluid from a well having a top opening, a bottom, an inner surface, and an active portion, wherein the isolation assembly comprises:

(a) an isolation chamber that is hollow having a wall, and insertable into the sampling well, the isolation chamber further having a first end positionable within the active portion of the well and a second end extendable above the active portion of the well;

(b) a valve for admitting a portion of the well fluid into the isolation chamber, said valve mounted on or near the first end, said valve also for sealing the portion of the well fluid within the isolation chamber thereby preventing mixing of well fluid within the isolation chamber with well fluid in an annular space between the isolation chamber and an inner surface of the well;

(c) a seal for sealing the annular space, said seal mounted near the second end and positioned above the active portion thereby isolating well fluid in a lower annulus from below said seal to the bottom of the well from well fluid above said seal;

(d) a port for admitting well fluid from the lower annulus into an inlet;

(e) a pump for pumping admitted well fluid from the inlet to an exhaust port; and

(f) a riser connected to a first exhaust port for collecting purged well fluid.

2. The isolation assembly as recited in claim 1, wherein obtaining well fluid is purging or sampling the well fluid.

3. The isolation assembly as recited in claim 1, further comprising:

(g) a sensor for characterizing the admitted well fluid.

4. The isolation assembly as recited in claim 1, further comprising:

(g) an exhaust director permitting selection of an operational function with selected flow paths.

5. The isolation assembly as recited in claim 4, wherein said pump and said exhaust director are mounted in a housing forming an operational unit.

6. The isolation assembly as recited in claim 1, wherein said seal comprises:

(h) a packer unit.

7. The isolation assembly as recited in claim 6, wherein said packer unit comprises:

(i) a housing with an open end and a coupling end;

(j) a packer mounted on the housing; and

(k) a packer inflation tube for pressurizing the packer.

8. The isolation assembly as recited in claim 1, further comprising:

(l) an exhaust director permitting selection of an operational function with selected flow paths;

(m) an operational unit having a housing wherein are mounted said pump and said exhaust director; and

(n) said seal comprising a packer unit having a packer housing with an open end and a coupling end, with a packer mounted on the packer housing.

9. The isolation assembly as recited in claim 8, further comprising:

(o) a spacer unit placed between and connected to the packer unit and the operational unit; and

(p) an isolation unit with a port for admitting well fluid mounted therein, and having said valve.

10. A method for obtaining well fluid from a well having a top opening, a bottom, an inner surface, and an active portion, wherein the method comprises the steps of:

(a) inserting an isolation chamber that is hollow and further having a first end and a second end, and positioning the first end within the active portion of the well and extending the second end above the active portion of the well;

(b) admitting a portion of the well fluid into the isolation chamber and sealing the portion of the well fluid within the isolation chamber thereby preventing mixing of well fluid within the isolation chamber with well fluid in an annular space between the isolation chamber and an inner surface of the well;

(c) sealing the annular space with a seal near the second end and above the active portion thereby isolating well fluid in a lower annulus from below the seal to the bottom of the well from well fluid above said seal;

(d) admitting well fluid from the lower annulus into an inlet through at least one port mounted on the isolation chamber;

(e) pumping admitted well fluid from the inlet to an exhaust port; and

(f) storing purged well fluid in a riser.

11. The method as recited in claim 10, wherein obtaining well fluid is purging or sampling the well fluid.

12. The method as recited in claim 10, further comprising:

(g) sensing at least one characteristic of the admitted well fluid.

13. The method as recited in claim 10, further comprising:

(h) selecting an operational function with an exhaust director permitting selection of flow paths.

14. An isolation assembly for obtaining well fluid from a well having a top opening, a bottom, an inner surface, and an active portion, wherein the isolation assembly comprises:

(a) an isolation unit that is hollow having a wall defining an isolation chamber, and insertable into the sampling well, the isolation unit further having a first end positionable within the active portion of the well and a second end extendable above the active portion of the well;

(b) a bottom hole for admitting water into said isolation unit of the first end, said bottom hole sealed by contact with the bottom of the well, thereby retarding mixing of well fluid within the isolation unit with well fluid from an annular space between the isolation unit and an inner surface of the well; and

(c) a closure on said second end, and a hole or pressure equalization port through said wall or said closure permitting escape of air from the isolation chamber.

15. The isolation assembly as recited in claim 14, further comprising:

a foot valve in the bottom hole on said first end.

16. The isolation assembly as recited in claim 14, further comprising:

a check valve on said closure.

17. The isolation assembly as recited in claim 14, wherein the closure has a shape permitting active flow.

18. The isolation assembly as recited in claim 14, further comprising:

a T-bar for emplacing and removing the isolation assembly within and from the well.

19. A method for obtaining well fluid from a well having a top opening, a bottom, an inner surface, and an active portion, wherein the method comprises the steps of:

(a) inserting an isolation unit that is hollow and further having a first end and a second end, and positioning the first end within the active portion of the well and extending the second end above the active portion of the well;

(b) admitting a portion of the well fluid into the isolation unit and containing the portion of the well fluid within the isolation chamber, thereby retarding mixing of the portion of the well fluid within the isolation chamber unit with well fluid from an annular space between the isolation unit and an inner surface of the well; and

(c) pumping well fluid from the annular space to an exhaust port.

20. The method as recited in claim 19, further comprising:

(d) sensing at least one characteristic of the admitted well fluid.