US20070113638A1 - Single phase sampling apparatus and method - Google Patents
Single phase sampling apparatus and method Download PDFInfo
- Publication number
- US20070113638A1 US20070113638A1 US11/643,924 US64392406A US2007113638A1 US 20070113638 A1 US20070113638 A1 US 20070113638A1 US 64392406 A US64392406 A US 64392406A US 2007113638 A1 US2007113638 A1 US 2007113638A1
- Authority
- US
- United States
- Prior art keywords
- piston
- sample
- pressurized gas
- pressure
- formation
- 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
Images
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N1/00—Sampling; Preparing specimens for investigation
- G01N1/02—Devices for withdrawing samples
- G01N1/10—Devices for withdrawing samples in the liquid or fluent state
- G01N1/14—Suction devices, e.g. pumps; Ejector devices
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
- G01N33/26—Oils; viscous liquids; paints; inks
- G01N33/28—Oils, i.e. hydrocarbon liquids
- G01N33/2823—Oils, i.e. hydrocarbon liquids raw oil, drilling fluid or polyphasic mixtures
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N7/00—Analysing materials by measuring the pressure or volume of a gas or vapour
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N1/00—Sampling; Preparing specimens for investigation
- G01N1/02—Devices for withdrawing samples
- G01N1/10—Devices for withdrawing samples in the liquid or fluent state
- G01N2001/1031—Sampling from special places
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N1/00—Sampling; Preparing specimens for investigation
- G01N1/02—Devices for withdrawing samples
- G01N1/10—Devices for withdrawing samples in the liquid or fluent state
- G01N2001/1062—Sampling under constant temperature, pressure, or the like
Definitions
- This invention relates generally to formation fluid testing and collection apparatus and more particularly to a single phase collection apparatus for a formation evaluation tool that collects formation fluids at a predetermined pressure and maintains the collected fluid pressure at such pressure throughout the sampling operation.
- a drilling fluid (“mud”) is used during drilling of a wellbore to facilitate the drilling process and to maintain a hydrostatic pressure in the wellbore greater than the pressure in the formations surrounding the wellbore.
- This drilling fluid penetrates into or invades the formations for varying radial depths (referred to generally as the invaded zones) depending upon the types of the formation and drilling fluid used.
- Wireline formation testing tools lowered into the mud of the wellbore are used to monitor formation pressures, collect formation fluid samples from the wellbore and to predict performance of reservoirs around the wellbore.
- These formation evaluation tools typically contain an elongated body having an elastomeric packer that is sealingly urged against the zone of interest in the wellbore.
- Fluid is collected and brought to the surface for analysis to determine the properties of the fluids and the conditions of the zones or formations from where the fluids have been collected. During this process, it is critical that only uncontaminated fluids are collected, and in the same condition in which they exist in the formation.
- Formation evaluation tools typically collect formation fluid by transferring such fluids from a probe into a sample chamber.
- Prior art formation evaluation tools such as sequential formation testers and repeat formation testers used large collection chambers that varied in size from one to five gallons to collect samples. Samples were not pumped into the chamber, but were forced into the chamber by the hydrostatic pressure of the formation acting against the atmospheric pressure in the chamber. The problem with these chambers was that once opened at the formation zone, they would ingest not only the sample, but also surrounding mud, rocks and other contaminates.
- Current formation testing tools overcome this problem by first testing fluids from the desired formations or zones of interest to ensure that the fluid is substantially free of mud filtrates, and then collecting fluids by pumping formation fluid into one or more sample bottles associated with the tool.
- the temperature difference between the surface elevation and the formation elevation can exceed several hundred degrees Fahrenheit.
- the chamber temperature drops, causing the pressure in the chamber to drop. This substantial pressure drop in the chamber can result in the pressure of the formation sample dropping below the bubble point, resulting in a multi-phase sample.
- the present invention addresses the above noted problems and provides a single phase collection apparatus in which collected formation fluid is maintained at a predetermined pressure above the bubble point to maintain the sample in a single phase. No water cushions are required to uniformly fill the chambers.
- the tool also automatically maintains the chamber pressure above the bubble point pressure during the entire sampling operation regardless of the change in the temperature surrounding the chamber.
- the single phase collection apparatus of the present invention is therefore designed to maintain wellbore formation samples at a pressure above the bubble point as the sample is removed from the wellbore and is transported to a laboratory for analysis.
- a nitrogen gas charge that acts against a sample piston
- the sample is maintained at a pressure above the bubble point of the sample, thereby preventing the sample from separating into two phases.
- the nitrogen pressure utilized in this collection apparatus is significantly lower than the pressure used in existing single phase collection designs, and is therefore safer and easier to use.
- the amount of pressure present in a commercial nitrogen bottle generally will be sufficient to pre-charge the apparatus, without the need for nitrogen gas boosters to achieve the high pressures required.
- the present invention modifies an existing Department of Transportation (“DOT”) exempt sample bottle, simplifying DOT approval.
- DOT Department of Transportation
- Utilization of sample bottles that can be shipped as freight improves sample quality because the sample does not need to be transferred for transport.
- the use of these currently available sample bottles also allows in-the-field modification of existing DOT sample bottles. No additional leak paths for the sample are introduced by the modification, unlike older Drill Stem Test single phase samplers that created multiple leak paths with sliding seals and port crossing seals that affected the reliability of the devices.
- the simplified new design allows for the acquisition of larger sample sizes that may be more than twice that of existing designs.
- the new design does not have any valves to shift, fluid to port or any other items to complicate and use up formation sample space.
- the size of the sample can be changed as desired because the nitrogen pressure can be adjusted for each sampling operation. A higher initial pressure is used to retrieve a smaller sample.
- FIG. 1 illustrates a standard sample bottle.
- FIG. 2 illustrates the lower portion of a standard sample bottle modified according to the present disclosure.
- FIG. 3 illustrates the sample piston and nitrogen charging piston being forced to the bottom of the bottle.
- FIG. 4 illustrates pressurized nitrogen gas being forced into the nitrogen gas chamber.
- FIG. 5 illustrates a sample bottle prepared for use.
- FIG. 6 illustrates hydrostatic pressure forcing the nitrogen charging piston upwards.
- FIG. 7 illustrates formation fluid being pumped into the sample chamber.
- the Single Phase Sample Collection Apparatus utilizes an existing sample bottle modified to allow for the introduction of pressurized nitrogen gas that acts against a sample piston of the device to maintain the sample at or above the bubble point of the sample.
- the collection apparatus utilizes the hydrostatic pressure present at the depth of the desired formation sample to compress the nitrogen gas “pre-charge” to the pressure of the formation sample, then maintains that pressure as the collection apparatus is removed from the wellbore.
- FIG. 1 illustrates an existing formation evaluation tool sample bottle 10 designed to contain a formation sample located in a collection chamber 2 .
- the formation sample is pumped into the collection chamber 2 , pushing the sample piston 1 downwards until it comes into contact with an end cap located at the bottom of the sample bottle 10 .
- the present invention single phase collection apparatus 20 utilizes a current version sample bottle 10 , but it is equipped with a nitrogen charging piston 3 inserted into the bore of the sample bottle 10 .
- the sample bottle 10 is preferably a standard sample bottle that can be shipped as freight. The use of a sample bottle that can be shipped as freight improves sample quality because the sample does not need to be transferred to a separate shipping bottle for transport.
- the nitrogen charging piston 3 is positioned between the sample piston 1 and an end cap 4 . The addition of the nitrogen charging piston 3 into the sample bottle 10 creates a variable size nitrogen gas chamber 6 between the nitrogen charging piston 3 and the sample piston 1 .
- the sample piston 1 is preferably made of an alloy steel, but can also be constructed from stainless steel, corrosion resistant alloy metals or other material with the appropriate properties to withstand the temperatures, pressures and corrosive conditions associated with such a device.
- the nitrogen charging piston 3 is preferably made of an alloy steel, but can also be constructed from stainless steel, corrosion resistant alloy metals or other material with the appropriate properties to withstand the temperatures, pressures and corrosive conditions associated with such a device.
- the nitrogen charging piston 3 is sized to fit precisely within the bore of sample bottle 10 . Gases are prevented from escaping around the nitrogen charging piston 3 by the use of one or more O-ring seals fitted into grooves inscribed into the outside diameter of the piston. An anti-extrusion backup seal may be placed on the low pressure side of the seal to help improve the seal.
- the nitrogen charging piston 3 has an open axial bore 9 allowing for the communication of gas through the piston.
- a check valve 5 is located within the axial bore 9 of the nitrogen charging piston and controls gas communication through the piston, into and out of the nitrogen gas chamber 6 .
- Check valve 5 could also be a different type of valve such as a manually operated open/closed valve.
- a plunger 7 with a narrowed diameter section, fits into nitrogen charging piston 3 .
- the plunger 7 is preferably threaded to allow engagement with matching threads on the inside diameter of the axial bore 9 .
- the narrowed diameter section of the plunger 7 functions to open check valve 5 .
- the plunger 7 has an axial bore running through it with a removable release plug 8 to close off the end of the axial bore. O-ring seals at the outside diameter of the plunger 7 prevent gases from escaping around the plunger.
- a case adaptor 11 with anti-rotation lugs 12 fits into and locks into the end of the sample bottle 10 , and engages nitrogen charging piston 3 when the piston is pushed up to the end of its stroke.
- the anti-rotation lugs 12 prevent the nitrogen charging piston 3 from rotating with respect to the lower case adaptor 11 so that the plunger 7 may be rotated for insertion/removal.
- the end cap 4 is inserted into and engages the case adaptor 11 .
- the end cap 4 comprises a port 15 that is open to hydrostatic pressure when the collector apparatus is inserted into a wellbore, thereby exposing the nitrogen charging piston 3 to hydrostatic pressure.
- the single phase collection apparatus 20 is assembled as shown in FIG. 2 .
- the end cap 4 is removed and an air pressure source is connected to the sub 13 .
- Air pressure at approximately 100 psi is then introduced into the collection apparatus, forcing the sample piston 1 and the nitrogen charging piston 3 down towards the case adaptor 11 .
- the nitrogen charging piston 3 stops when it reaches the case adaptor 11 , and the anti-rotation lugs 12 engage the nitrogen charging piston 3 thereby preventing rotation with respect to the case adaptor 11 .
- Release plug 8 is then removed to allow any trapped gases between the sample piston 1 and the nitrogen charging piston 3 to escape, thereby minimizing the volume between sample piston 1 and the nitrogen charging piston 3 .
- the plunger 7 is then removed from the nitrogen charging piston 3 and a purge adapter 14 , connected to a pressurized nitrogen supply, is inserted into the nitrogen charging piston 3 , opening the check valve 5 , as shown in FIG. 4 .
- the air pressure source attached to the sub 13 is removed and nitrogen gas is forced through the purge adaptor 14 , through the check valve 5 , and into the nitrogen gas chamber 6 .
- the sample piston 1 is forced upwards until nitrogen gas fills nearly the entire volume of the sampler.
- nitrogen gas is the preferred pressurizing medium, it is conceivable that other pressurizing gases could be utilized to achieve the same function. However, nitrogen has the advantages of easy availability and has well known physical properties.
- the purge adapter 14 is removed, thereby closing off check valve 5 .
- the release plug 8 is then reinstalled in the plunger 7 , and then the plunger 7 is reinstalled into the nitrogen charging piston 3 .
- the narrowed diameter section of the plunger 7 opens check valve 5 , allowing nitrogen gas to act against the O-rings of the plunger 7 . This prevents the formation of any regions in the apparatus with only atmospheric pressure, which would increase the differential pressure acting on the seal.
- the end cap 4 is then replaced, as shown in FIG. 5 .
- one or more of the single phase collection apparatus 20 is inserted into the multi-chamber section (“MCS”) of a formation evaluation tool to collect formation samples.
- MCS multi-chamber section
- the open port 15 of the end cap 4 is exposed to mud at hydrostatic pressure and the nitrogen charging piston 3 is forced upwards once hydrostatic pressure is greater than the initial nitrogen gas pressure, compressing the nitrogen gas within the nitrogen gas chamber 6 so that the pressure of the nitrogen gas equals the hydrostatic pressure, as in FIG. 6 .
- the appropriate valve of the MCS is opened and the desired formation fluid is pumped into the collection chamber 2 , thereby forcing both the sample piston 1 and the nitrogen charging piston 3 downward towards the case adaptor 11 as shown in FIG. 7 . Mud is forced out of the open port 15 of the end cap 4 as both the sample piston 1 and the nitrogen charging piston 3 move downwards. Once the nitrogen charging piston 3 engages the case adaptor 11 , the pressure of both the sample and the nitrogen gas increases as pumping continues. Once the desired overpressure has been attained, the MCS valve is closed trapping the sample and the nitrogen gas at a pressure above hydrostatic.
- the formation sample shrinks as the sample cools.
- the highly compressible nitrogen gas acting against the sample piston 1 maintains the pressure of the sample above the bubble point.
- a shipping end cap replaces the end cap 4 for transportation and storage. If cool temperatures are expected during shipping, additional fluid can be pumped in through the shipping end cap to compress the nitrogen further, thereby helping to maintain the sample at a high pressure.
- the removal of the sample from the collection apparatus 20 is accomplished using conventional techniques to remove formation samples from a sample bottle. Thus, fluid is pumped in to the collection apparatus 20 to force the sample out of the collection chamber 2 .
Abstract
A single phase sampling apparatus and method for retrieving a formation fluid sample at or above the bubble point of the sample. The apparatus utilizes a gas charge contained between a sample piston and a charging piston to maintain a formation sample at the desired pressure. The charging piston utilizes the hydrostatic pressure present at the depth of the desired formation sample to compress and therefore increase the gas charge to the appropriate pressure necessary to maintain the formation sample at the desired pressure. The utilization of hydrostatic pressure to increase the pressure of the gas charge allows the use of a low pressure gas charging system to prepare the apparatus prior to sampling, thereby increasing the safety and ease of use of the device.
Description
- This application is a continuation of U.S. application Ser. No. 10/648,977 filed Aug. 27, 2003, which claims the benefit of U.S. Provisional Application No. 60/406,619, filed Aug. 27, 2002.
- This invention relates generally to formation fluid testing and collection apparatus and more particularly to a single phase collection apparatus for a formation evaluation tool that collects formation fluids at a predetermined pressure and maintains the collected fluid pressure at such pressure throughout the sampling operation.
- In the oil and gas industry, a drilling fluid (“mud”) is used during drilling of a wellbore to facilitate the drilling process and to maintain a hydrostatic pressure in the wellbore greater than the pressure in the formations surrounding the wellbore. This drilling fluid penetrates into or invades the formations for varying radial depths (referred to generally as the invaded zones) depending upon the types of the formation and drilling fluid used. Wireline formation testing tools lowered into the mud of the wellbore are used to monitor formation pressures, collect formation fluid samples from the wellbore and to predict performance of reservoirs around the wellbore. These formation evaluation tools typically contain an elongated body having an elastomeric packer that is sealingly urged against the zone of interest in the wellbore. Fluid is collected and brought to the surface for analysis to determine the properties of the fluids and the conditions of the zones or formations from where the fluids have been collected. During this process, it is critical that only uncontaminated fluids are collected, and in the same condition in which they exist in the formation.
- Formation evaluation tools typically collect formation fluid by transferring such fluids from a probe into a sample chamber. Prior art formation evaluation tools such as sequential formation testers and repeat formation testers used large collection chambers that varied in size from one to five gallons to collect samples. Samples were not pumped into the chamber, but were forced into the chamber by the hydrostatic pressure of the formation acting against the atmospheric pressure in the chamber. The problem with these chambers was that once opened at the formation zone, they would ingest not only the sample, but also surrounding mud, rocks and other contaminates. Current formation testing tools overcome this problem by first testing fluids from the desired formations or zones of interest to ensure that the fluid is substantially free of mud filtrates, and then collecting fluids by pumping formation fluid into one or more sample bottles associated with the tool.
- Because of the great difference in pressure between the formation (hydrostatic) and the interior of the sample bottle (atmospheric), there is a possibility that the formation fluid pumped into the chamber will vaporize, or “flash,” due to a great decrease in pressure. In order to prevent or reduce the chances of the liquid vaporizing from a decrease in pressure, formation fluid is pumped into the chamber at a relatively slow rate. In addition, the tools are often equipped with restrictions to slow down the fluid flow rate into the chamber. Water cushions are also utilized to fill the chambers more uniformly. However, it is common for the collected single phase fluid to separate into a two phase sample containing vaporized gas. If the sample fluid pressure is reduced prior to arrival in the analysis lab, a lengthy procedure is required to recombine the sample back into a single phase as it was in situ. Additionally, asphaltenes are commonly present in the hydrocarbons and if the pressure in the chamber remains at a relatively low pressure, such asphaltenes tend to flocculate to form gel-type masses in the fluid. The flocculation process is substantially irreversible. Thus, it is desirable to withdraw and maintain the sample fluid at a pressure above the bubble point to maintain it in a single phase.
- Additionally, the temperature difference between the surface elevation and the formation elevation can exceed several hundred degrees Fahrenheit. As the tool is retrieved, the chamber temperature drops, causing the pressure in the chamber to drop. This substantial pressure drop in the chamber can result in the pressure of the formation sample dropping below the bubble point, resulting in a multi-phase sample.
- Attempts have been made to maintain the fluid sample in a single phase by applying a pressurized nitrogen charge against a sample piston located in the chamber. This forces the sample piston against the fluid sample to maintain its pressure at a sufficient level to prevent a phase change upon retrieval. However, this system is complex and requires the use of nitrogen at a pressure of over 20,000 psi. The danger and inconvenience of working with nitrogen at this extremely high pressure discourages its use.
- The present invention addresses the above noted problems and provides a single phase collection apparatus in which collected formation fluid is maintained at a predetermined pressure above the bubble point to maintain the sample in a single phase. No water cushions are required to uniformly fill the chambers. The tool also automatically maintains the chamber pressure above the bubble point pressure during the entire sampling operation regardless of the change in the temperature surrounding the chamber.
- The single phase collection apparatus of the present invention is therefore designed to maintain wellbore formation samples at a pressure above the bubble point as the sample is removed from the wellbore and is transported to a laboratory for analysis. By utilizing a nitrogen gas charge that acts against a sample piston, the sample is maintained at a pressure above the bubble point of the sample, thereby preventing the sample from separating into two phases. However, the nitrogen pressure utilized in this collection apparatus is significantly lower than the pressure used in existing single phase collection designs, and is therefore safer and easier to use. The amount of pressure present in a commercial nitrogen bottle generally will be sufficient to pre-charge the apparatus, without the need for nitrogen gas boosters to achieve the high pressures required.
- The present invention modifies an existing Department of Transportation (“DOT”) exempt sample bottle, simplifying DOT approval. Utilization of sample bottles that can be shipped as freight improves sample quality because the sample does not need to be transferred for transport. The use of these currently available sample bottles also allows in-the-field modification of existing DOT sample bottles. No additional leak paths for the sample are introduced by the modification, unlike older Drill Stem Test single phase samplers that created multiple leak paths with sliding seals and port crossing seals that affected the reliability of the devices. In addition, unlike the older designs which were limited to sample sizes of around 400 to 500 cubic centimeters due to the complexity of the mechanism, the simplified new design allows for the acquisition of larger sample sizes that may be more than twice that of existing designs. This is because the new design does not have any valves to shift, fluid to port or any other items to complicate and use up formation sample space. In addition, the size of the sample can be changed as desired because the nitrogen pressure can be adjusted for each sampling operation. A higher initial pressure is used to retrieve a smaller sample.
-
FIG. 1 illustrates a standard sample bottle. -
FIG. 2 illustrates the lower portion of a standard sample bottle modified according to the present disclosure. -
FIG. 3 illustrates the sample piston and nitrogen charging piston being forced to the bottom of the bottle. -
FIG. 4 illustrates pressurized nitrogen gas being forced into the nitrogen gas chamber. -
FIG. 5 illustrates a sample bottle prepared for use. -
FIG. 6 illustrates hydrostatic pressure forcing the nitrogen charging piston upwards. -
FIG. 7 illustrates formation fluid being pumped into the sample chamber. - The Single Phase Sample Collection Apparatus utilizes an existing sample bottle modified to allow for the introduction of pressurized nitrogen gas that acts against a sample piston of the device to maintain the sample at or above the bubble point of the sample. The collection apparatus utilizes the hydrostatic pressure present at the depth of the desired formation sample to compress the nitrogen gas “pre-charge” to the pressure of the formation sample, then maintains that pressure as the collection apparatus is removed from the wellbore.
-
FIG. 1 illustrates an existing formation evaluationtool sample bottle 10 designed to contain a formation sample located in acollection chamber 2. When at the desired formation depth, the formation sample is pumped into thecollection chamber 2, pushing thesample piston 1 downwards until it comes into contact with an end cap located at the bottom of thesample bottle 10. - The present invention single
phase collection apparatus 20, as shown inFIG. 2 , utilizes a currentversion sample bottle 10, but it is equipped with anitrogen charging piston 3 inserted into the bore of thesample bottle 10. Thesample bottle 10 is preferably a standard sample bottle that can be shipped as freight. The use of a sample bottle that can be shipped as freight improves sample quality because the sample does not need to be transferred to a separate shipping bottle for transport. Thenitrogen charging piston 3 is positioned between thesample piston 1 and anend cap 4. The addition of thenitrogen charging piston 3 into thesample bottle 10 creates a variable sizenitrogen gas chamber 6 between thenitrogen charging piston 3 and thesample piston 1. - The
sample piston 1 is preferably made of an alloy steel, but can also be constructed from stainless steel, corrosion resistant alloy metals or other material with the appropriate properties to withstand the temperatures, pressures and corrosive conditions associated with such a device. - The
nitrogen charging piston 3 is preferably made of an alloy steel, but can also be constructed from stainless steel, corrosion resistant alloy metals or other material with the appropriate properties to withstand the temperatures, pressures and corrosive conditions associated with such a device. Thenitrogen charging piston 3 is sized to fit precisely within the bore ofsample bottle 10. Gases are prevented from escaping around thenitrogen charging piston 3 by the use of one or more O-ring seals fitted into grooves inscribed into the outside diameter of the piston. An anti-extrusion backup seal may be placed on the low pressure side of the seal to help improve the seal. Thenitrogen charging piston 3 has an openaxial bore 9 allowing for the communication of gas through the piston. Acheck valve 5 is located within theaxial bore 9 of the nitrogen charging piston and controls gas communication through the piston, into and out of thenitrogen gas chamber 6. Checkvalve 5 could also be a different type of valve such as a manually operated open/closed valve. A plunger 7, with a narrowed diameter section, fits intonitrogen charging piston 3. The plunger 7 is preferably threaded to allow engagement with matching threads on the inside diameter of theaxial bore 9. When the plunger 7 is fully inserted into thepiston 3, the narrowed diameter section of the plunger 7 functions to opencheck valve 5. The plunger 7 has an axial bore running through it with aremovable release plug 8 to close off the end of the axial bore. O-ring seals at the outside diameter of the plunger 7 prevent gases from escaping around the plunger. - A
case adaptor 11 with anti-rotation lugs 12, fits into and locks into the end of thesample bottle 10, and engagesnitrogen charging piston 3 when the piston is pushed up to the end of its stroke. When engaged, the anti-rotation lugs 12 prevent thenitrogen charging piston 3 from rotating with respect to thelower case adaptor 11 so that the plunger 7 may be rotated for insertion/removal. Theend cap 4 is inserted into and engages thecase adaptor 11. Theend cap 4 comprises aport 15 that is open to hydrostatic pressure when the collector apparatus is inserted into a wellbore, thereby exposing thenitrogen charging piston 3 to hydrostatic pressure. - In order to collect a formation sample, the single
phase collection apparatus 20 is assembled as shown inFIG. 2 . As shown inFIG. 3 , theend cap 4 is removed and an air pressure source is connected to thesub 13. Air pressure at approximately 100 psi is then introduced into the collection apparatus, forcing thesample piston 1 and thenitrogen charging piston 3 down towards thecase adaptor 11. Thenitrogen charging piston 3 stops when it reaches thecase adaptor 11, and the anti-rotation lugs 12 engage thenitrogen charging piston 3 thereby preventing rotation with respect to thecase adaptor 11.Release plug 8 is then removed to allow any trapped gases between thesample piston 1 and thenitrogen charging piston 3 to escape, thereby minimizing the volume betweensample piston 1 and thenitrogen charging piston 3. - The plunger 7 is then removed from the
nitrogen charging piston 3 and apurge adapter 14, connected to a pressurized nitrogen supply, is inserted into thenitrogen charging piston 3, opening thecheck valve 5, as shown inFIG. 4 . The air pressure source attached to thesub 13 is removed and nitrogen gas is forced through thepurge adaptor 14, through thecheck valve 5, and into thenitrogen gas chamber 6. As nitrogen gas fills thenitrogen gas chamber 6, thesample piston 1 is forced upwards until nitrogen gas fills nearly the entire volume of the sampler. Although nitrogen gas is the preferred pressurizing medium, it is conceivable that other pressurizing gases could be utilized to achieve the same function. However, nitrogen has the advantages of easy availability and has well known physical properties. Once this pre-charging pressure reaches the proper level, preferably around 3,000 psi, thepurge adapter 14 is removed, thereby closing offcheck valve 5. Therelease plug 8 is then reinstalled in the plunger 7, and then the plunger 7 is reinstalled into thenitrogen charging piston 3. The narrowed diameter section of the plunger 7 openscheck valve 5, allowing nitrogen gas to act against the O-rings of the plunger 7. This prevents the formation of any regions in the apparatus with only atmospheric pressure, which would increase the differential pressure acting on the seal. Theend cap 4 is then replaced, as shown inFIG. 5 . - Once assembled and pre-charged, one or more of the single
phase collection apparatus 20 is inserted into the multi-chamber section (“MCS”) of a formation evaluation tool to collect formation samples. As the tool is lowered down into the wellbore, theopen port 15 of theend cap 4 is exposed to mud at hydrostatic pressure and thenitrogen charging piston 3 is forced upwards once hydrostatic pressure is greater than the initial nitrogen gas pressure, compressing the nitrogen gas within thenitrogen gas chamber 6 so that the pressure of the nitrogen gas equals the hydrostatic pressure, as inFIG. 6 . - When a sample is to be taken, the appropriate valve of the MCS is opened and the desired formation fluid is pumped into the
collection chamber 2, thereby forcing both thesample piston 1 and thenitrogen charging piston 3 downward towards thecase adaptor 11 as shown inFIG. 7 . Mud is forced out of theopen port 15 of theend cap 4 as both thesample piston 1 and thenitrogen charging piston 3 move downwards. Once thenitrogen charging piston 3 engages thecase adaptor 11, the pressure of both the sample and the nitrogen gas increases as pumping continues. Once the desired overpressure has been attained, the MCS valve is closed trapping the sample and the nitrogen gas at a pressure above hydrostatic. - As the
collection apparatus 20 is retrieved from the wellbore, the formation sample shrinks as the sample cools. However, the highly compressible nitrogen gas acting against thesample piston 1 maintains the pressure of the sample above the bubble point. - At the surface, a shipping end cap replaces the
end cap 4 for transportation and storage. If cool temperatures are expected during shipping, additional fluid can be pumped in through the shipping end cap to compress the nitrogen further, thereby helping to maintain the sample at a high pressure. - The removal of the sample from the
collection apparatus 20 is accomplished using conventional techniques to remove formation samples from a sample bottle. Thus, fluid is pumped in to thecollection apparatus 20 to force the sample out of thecollection chamber 2.
Claims (10)
1. A method for downhole fluid sample collection comprising:
inserting pressurized gas in a space between a first piston and a second piston of a tube having a first end and a second end, and the first piston and the second piston located within said tube;
collecting a formation fluid sample in the space between the first end of the tube and said first piston, whereby the pressure exerted on the formation fluid through said first piston by the pressurized gas is equal to or greater than the hydrostatic pressure in the borehole.
2. The method of claim 1 , wherein the step of inserting pressurized gas in the space between said first and second pistons, comprises (i) attaching a pressurized gas source to the second piston and (ii) forcing pressurized gas through said second piston into the space between said first and second pistons.
3. The method of claim 1 , wherein the step of inserting pressurized gas in the space between said first and second piston is preceded by forcing said first and second pistons together to purge any existing gas from the space between said first and second pistons.
4. The method of claim 3 , therein the step of forcing said first and second pistons together comprises filling the space between the second piston and the second end of the tube with a borehole mud at hydrostatic pressure.
5. A method for downhole fluid sample collection comprising:
inserting pressurized gas in a space between a first piston and a second piston of a tube having a first end and a second end, and the first piston and the second piston located within said tube;
collecting a formation fluid sample in the space between the first end of the tube and said first piston, at pressure substantially higher than the hydrostatic pressure in the borehole.
6. The method of claim 5 , wherein the step of inserting pressurized gas in the space between said first and second pistons, comprises (i) attaching a pressurized gas source to the second piston and (ii) forcing pressurized gas through said second piston into the space between said first and second pistons.
7. The method of claim 5 , wherein the step of inserting pressurized gas in the space between said first and second piston is preceded by forcing said first and second pistons together to purge any existing gas from the space between said first and second pistons.
8. The method of claim 7 , therein the step of forcing said first and second pistons together comprises filling the space between the second piston and the second end of the tube with a borehole mud at hydrostatic pressure.
9. A method for extracting a single phase fluid sample from a wellbore formation and maintaining the sample in a single phase, comprising:
forcing a sample piston and a charging piston together within a formation fluid sample bottle to purge any existing gas from a pressurized gas chamber;
attaching a pressurized gas source to said charging piston;
forcing pressurized gas through said charging piston into said pressurized gas chamber;
removing said pressurized gas source from said charging piston;
inserting said formation fluid sample bottle into a formation evaluation tool;
lowering said formation evaluation tool into a wellbore;
exposing said charging piston to the wellbore mud at hydrostatic pressure;
pumping formation fluid into said single phase collection apparatus, wherein the pressure excreted on the formation fluid through said sample piston by the pressurized gas and the wellbore mud is greater than the hydrostatic pressure in the wellbore;
raising said formation evaluation tool; and
removing said single phase collection apparatus from said formation evaluation tool.
10. The method of claim 8 , further comprising increasing pressure of the formation fluid sample in the single phase collection apparatus by increasing pressure exerted by the charging piston on the pressurized gas.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US11/643,924 US20070113638A1 (en) | 2002-08-27 | 2006-12-20 | Single phase sampling apparatus and method |
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US40661902P | 2002-08-27 | 2002-08-27 | |
US10/648,977 US7191672B2 (en) | 2002-08-27 | 2003-08-27 | Single phase sampling apparatus and method |
US11/643,924 US20070113638A1 (en) | 2002-08-27 | 2006-12-20 | Single phase sampling apparatus and method |
Related Parent Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US10/648,977 Continuation US7191672B2 (en) | 2002-08-27 | 2003-08-27 | Single phase sampling apparatus and method |
Publications (1)
Publication Number | Publication Date |
---|---|
US20070113638A1 true US20070113638A1 (en) | 2007-05-24 |
Family
ID=31978324
Family Applications (2)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US10/648,977 Expired - Lifetime US7191672B2 (en) | 2002-08-27 | 2003-08-27 | Single phase sampling apparatus and method |
US11/643,924 Abandoned US20070113638A1 (en) | 2002-08-27 | 2006-12-20 | Single phase sampling apparatus and method |
Family Applications Before (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US10/648,977 Expired - Lifetime US7191672B2 (en) | 2002-08-27 | 2003-08-27 | Single phase sampling apparatus and method |
Country Status (8)
Country | Link |
---|---|
US (2) | US7191672B2 (en) |
EP (1) | EP1540299B1 (en) |
AU (1) | AU2003260108B2 (en) |
BR (1) | BR0313826A (en) |
CA (1) | CA2497295C (en) |
GB (1) | GB2408334B (en) |
NO (1) | NO20051397L (en) |
WO (1) | WO2004020982A1 (en) |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20140262347A1 (en) * | 2013-03-15 | 2014-09-18 | Carl E. Keller | Method for sealing of a borehole liner in an artesian well |
WO2016153522A1 (en) * | 2015-03-26 | 2016-09-29 | Halliburton Energy Services, Inc. | Corrosion tester tool for use during drill stem test |
Families Citing this family (41)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8555968B2 (en) | 2002-06-28 | 2013-10-15 | Schlumberger Technology Corporation | Formation evaluation system and method |
US8899323B2 (en) | 2002-06-28 | 2014-12-02 | Schlumberger Technology Corporation | Modular pumpouts and flowline architecture |
US8210260B2 (en) | 2002-06-28 | 2012-07-03 | Schlumberger Technology Corporation | Single pump focused sampling |
US7178591B2 (en) | 2004-08-31 | 2007-02-20 | Schlumberger Technology Corporation | Apparatus and method for formation evaluation |
US7463027B2 (en) * | 2003-05-02 | 2008-12-09 | Halliburton Energy Services, Inc. | Systems and methods for deep-looking NMR logging |
WO2005036208A2 (en) * | 2003-10-03 | 2005-04-21 | Halliburton Energy Services, Inc. | System and methods for t1-based logging |
WO2005067569A2 (en) * | 2004-01-04 | 2005-07-28 | Halliburton Energy Services, Inc. | Method and apparatus for detecting hydrocarbons with nmr logs in wells drilled with oil-based muds |
US7114385B2 (en) | 2004-10-07 | 2006-10-03 | Schlumberger Technology Corporation | Apparatus and method for drawing fluid into a downhole tool |
US7458419B2 (en) | 2004-10-07 | 2008-12-02 | Schlumberger Technology Corporation | Apparatus and method for formation evaluation |
US7258167B2 (en) * | 2004-10-13 | 2007-08-21 | Baker Hughes Incorporated | Method and apparatus for storing energy and multiplying force to pressurize a downhole fluid sample |
US7565835B2 (en) | 2004-11-17 | 2009-07-28 | Schlumberger Technology Corporation | Method and apparatus for balanced pressure sampling |
US7546885B2 (en) * | 2005-05-19 | 2009-06-16 | Schlumberger Technology Corporation | Apparatus and method for obtaining downhole samples |
US7596995B2 (en) * | 2005-11-07 | 2009-10-06 | Halliburton Energy Services, Inc. | Single phase fluid sampling apparatus and method for use of same |
US7874206B2 (en) * | 2005-11-07 | 2011-01-25 | Halliburton Energy Services, Inc. | Single phase fluid sampling apparatus and method for use of same |
US7472589B2 (en) * | 2005-11-07 | 2009-01-06 | Halliburton Energy Services, Inc. | Single phase fluid sampling apparatus and method for use of same |
GB2471048B (en) * | 2008-04-09 | 2012-05-30 | Halliburton Energy Serv Inc | Apparatus and method for analysis of a fluid sample |
US7926575B2 (en) * | 2009-02-09 | 2011-04-19 | Halliburton Energy Services, Inc. | Hydraulic lockout device for pressure controlled well tools |
GB2481731B (en) * | 2009-03-06 | 2013-07-24 | Baker Hughes Inc | Apparatus and method for formation testing |
US8839871B2 (en) | 2010-01-15 | 2014-09-23 | Halliburton Energy Services, Inc. | Well tools operable via thermal expansion resulting from reactive materials |
US8474533B2 (en) | 2010-12-07 | 2013-07-02 | Halliburton Energy Services, Inc. | Gas generator for pressurizing downhole samples |
DE102011018207A1 (en) * | 2011-04-20 | 2012-10-25 | Parker Hannifin Gmbh | Pressure vessel with defined leakage path |
US9010442B2 (en) | 2011-08-29 | 2015-04-21 | Halliburton Energy Services, Inc. | Method of completing a multi-zone fracture stimulation treatment of a wellbore |
US9151138B2 (en) | 2011-08-29 | 2015-10-06 | Halliburton Energy Services, Inc. | Injection of fluid into selected ones of multiple zones with well tools selectively responsive to magnetic patterns |
US9133686B2 (en) | 2011-10-06 | 2015-09-15 | Halliburton Energy Services, Inc. | Downhole tester valve having rapid charging capabilities and method for use thereof |
AU2011378455B2 (en) | 2011-10-06 | 2015-08-06 | Halliburton Energy Services, Inc. | Downhole tester valve having rapid charging capabilities and method for use thereof |
US9506324B2 (en) | 2012-04-05 | 2016-11-29 | Halliburton Energy Services, Inc. | Well tools selectively responsive to magnetic patterns |
US9169705B2 (en) | 2012-10-25 | 2015-10-27 | Halliburton Energy Services, Inc. | Pressure relief-assisted packer |
US9587486B2 (en) | 2013-02-28 | 2017-03-07 | Halliburton Energy Services, Inc. | Method and apparatus for magnetic pulse signature actuation |
US9982530B2 (en) | 2013-03-12 | 2018-05-29 | Halliburton Energy Services, Inc. | Wellbore servicing tools, systems and methods utilizing near-field communication |
US9284817B2 (en) | 2013-03-14 | 2016-03-15 | Halliburton Energy Services, Inc. | Dual magnetic sensor actuation assembly |
US9752414B2 (en) | 2013-05-31 | 2017-09-05 | Halliburton Energy Services, Inc. | Wellbore servicing tools, systems and methods utilizing downhole wireless switches |
US20150075770A1 (en) | 2013-05-31 | 2015-03-19 | Michael Linley Fripp | Wireless activation of wellbore tools |
US9482072B2 (en) | 2013-07-23 | 2016-11-01 | Halliburton Energy Services, Inc. | Selective electrical activation of downhole tools |
US9739120B2 (en) | 2013-07-23 | 2017-08-22 | Halliburton Energy Services, Inc. | Electrical power storage for downhole tools |
US9920620B2 (en) | 2014-03-24 | 2018-03-20 | Halliburton Energy Services, Inc. | Well tools having magnetic shielding for magnetic sensor |
DE102014114041A1 (en) * | 2014-09-26 | 2016-03-31 | Friedrich Leutert GmbH & Co. KG | Device for receiving a sample |
WO2016085465A1 (en) | 2014-11-25 | 2016-06-02 | Halliburton Energy Services, Inc. | Wireless activation of wellbore tools |
US9771798B2 (en) | 2014-12-15 | 2017-09-26 | Schlumberger Technology Corporation | Single phase capture and conveyance while drilling |
US10677053B2 (en) | 2016-08-30 | 2020-06-09 | Schlumberger Technology Corporation | Fluid compensation system for downhole sampling bottle |
CN106404465A (en) * | 2016-11-19 | 2017-02-15 | 浙江大学 | Deep-sea integrated energy-accumulator pressure-maintaining sampler mechanism |
WO2019237095A2 (en) * | 2018-06-09 | 2019-12-12 | Todd Coleman | Apparatus and methods for gas sampling containers |
Citations (26)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2262655A (en) * | 1940-01-19 | 1941-11-11 | Roy Q Seale | Formation tester |
US3011554A (en) * | 1956-01-23 | 1961-12-05 | Schlumberger Well Surv Corp | Apparatus for investigating earth formations |
US3209588A (en) * | 1961-03-03 | 1965-10-05 | Exxon Production Research Co | Apparatus and method for logging boreholes with formation testing fluids |
US3577782A (en) * | 1969-01-10 | 1971-05-04 | Schlumberger Technology Corp | Well logging tool for making multiple pressure tests and for bottom hole sampling |
US4210018A (en) * | 1978-05-22 | 1980-07-01 | Gearhart-Owen Industries, Inc. | Formation testers |
US4339948A (en) * | 1980-04-25 | 1982-07-20 | Gearhart Industries, Inc. | Well formation test-treat-test apparatus and method |
US4470456A (en) * | 1983-02-22 | 1984-09-11 | Moutray Iii Waldo W | Borehole sampling tool |
US4860581A (en) * | 1988-09-23 | 1989-08-29 | Schlumberger Technology Corporation | Down hole tool for determination of formation properties |
US4936139A (en) * | 1988-09-23 | 1990-06-26 | Schlumberger Technology Corporation | Down hole method for determination of formation properties |
US4951749A (en) * | 1989-05-23 | 1990-08-28 | Schlumberger Technology Corporation | Earth formation sampling and testing method and apparatus with improved filter means |
US5233866A (en) * | 1991-04-22 | 1993-08-10 | Gulf Research Institute | Apparatus and method for accurately measuring formation pressures |
US5279153A (en) * | 1991-08-30 | 1994-01-18 | Schlumberger Technology Corporation | Apparatus for determining horizontal and/or vertical permeability of an earth formation |
US5337822A (en) * | 1990-02-15 | 1994-08-16 | Massie Keith J | Well fluid sampling tool |
US5672819A (en) * | 1996-03-13 | 1997-09-30 | Halliburton Energy Services, Inc. | Formation evaluation using phase shift periodic pressure pulse testing |
US5741962A (en) * | 1996-04-05 | 1998-04-21 | Halliburton Energy Services, Inc. | Apparatus and method for analyzing a retrieving formation fluid utilizing acoustic measurements |
US5826662A (en) * | 1997-02-03 | 1998-10-27 | Halliburton Energy Services, Inc. | Apparatus for testing and sampling open-hole oil and gas wells |
US5934374A (en) * | 1996-08-01 | 1999-08-10 | Halliburton Energy Services, Inc. | Formation tester with improved sample collection system |
US6065355A (en) * | 1997-09-23 | 2000-05-23 | Halliburton Energy Services, Inc. | Non-flashing downhole fluid sampler and method |
US6173793B1 (en) * | 1998-12-18 | 2001-01-16 | Baker Hughes Incorporated | Measurement-while-drilling devices with pad mounted sensors |
US6212574B1 (en) * | 1997-04-04 | 2001-04-03 | Microsoft Corporation | User mode proxy of kernel mode operations in a computer operating system |
US6301959B1 (en) * | 1999-01-26 | 2001-10-16 | Halliburton Energy Services, Inc. | Focused formation fluid sampling probe |
US6452592B2 (en) * | 1998-11-13 | 2002-09-17 | Smartasic, Inc. | Clock generation for sampling analog video |
US20030066646A1 (en) * | 2001-09-19 | 2003-04-10 | Baker Hughes, Inc. | Dual piston, single phase sampling mechanism and procedure |
US6688390B2 (en) * | 1999-03-25 | 2004-02-10 | Schlumberger Technology Corporation | Formation fluid sampling apparatus and method |
US6729399B2 (en) * | 2001-11-26 | 2004-05-04 | Schlumberger Technology Corporation | Method and apparatus for determining reservoir characteristics |
US7128144B2 (en) * | 2003-03-07 | 2006-10-31 | Halliburton Energy Services, Inc. | Formation testing and sampling apparatus and methods |
Family Cites Families (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3065355A (en) * | 1959-12-24 | 1962-11-20 | Burroughs Corp | Marker sensing device |
DE19648688B4 (en) * | 1996-11-25 | 2006-11-09 | Robert Bosch Gmbh | Method for recording the fill level of a tank system |
US6216782B1 (en) * | 1999-05-18 | 2001-04-17 | Halliburton Energy Services, Inc. | Apparatus and method for verification of monophasic samples |
-
2003
- 2003-08-27 EP EP03791853A patent/EP1540299B1/en not_active Expired - Fee Related
- 2003-08-27 GB GB0504935A patent/GB2408334B/en not_active Expired - Fee Related
- 2003-08-27 AU AU2003260108A patent/AU2003260108B2/en not_active Ceased
- 2003-08-27 WO PCT/US2003/026846 patent/WO2004020982A1/en not_active Application Discontinuation
- 2003-08-27 CA CA002497295A patent/CA2497295C/en not_active Expired - Fee Related
- 2003-08-27 US US10/648,977 patent/US7191672B2/en not_active Expired - Lifetime
- 2003-08-27 BR BR0313826-7A patent/BR0313826A/en active IP Right Grant
-
2005
- 2005-03-17 NO NO20051397A patent/NO20051397L/en not_active Application Discontinuation
-
2006
- 2006-12-20 US US11/643,924 patent/US20070113638A1/en not_active Abandoned
Patent Citations (26)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2262655A (en) * | 1940-01-19 | 1941-11-11 | Roy Q Seale | Formation tester |
US3011554A (en) * | 1956-01-23 | 1961-12-05 | Schlumberger Well Surv Corp | Apparatus for investigating earth formations |
US3209588A (en) * | 1961-03-03 | 1965-10-05 | Exxon Production Research Co | Apparatus and method for logging boreholes with formation testing fluids |
US3577782A (en) * | 1969-01-10 | 1971-05-04 | Schlumberger Technology Corp | Well logging tool for making multiple pressure tests and for bottom hole sampling |
US4210018A (en) * | 1978-05-22 | 1980-07-01 | Gearhart-Owen Industries, Inc. | Formation testers |
US4339948A (en) * | 1980-04-25 | 1982-07-20 | Gearhart Industries, Inc. | Well formation test-treat-test apparatus and method |
US4470456A (en) * | 1983-02-22 | 1984-09-11 | Moutray Iii Waldo W | Borehole sampling tool |
US4860581A (en) * | 1988-09-23 | 1989-08-29 | Schlumberger Technology Corporation | Down hole tool for determination of formation properties |
US4936139A (en) * | 1988-09-23 | 1990-06-26 | Schlumberger Technology Corporation | Down hole method for determination of formation properties |
US4951749A (en) * | 1989-05-23 | 1990-08-28 | Schlumberger Technology Corporation | Earth formation sampling and testing method and apparatus with improved filter means |
US5337822A (en) * | 1990-02-15 | 1994-08-16 | Massie Keith J | Well fluid sampling tool |
US5233866A (en) * | 1991-04-22 | 1993-08-10 | Gulf Research Institute | Apparatus and method for accurately measuring formation pressures |
US5279153A (en) * | 1991-08-30 | 1994-01-18 | Schlumberger Technology Corporation | Apparatus for determining horizontal and/or vertical permeability of an earth formation |
US5672819A (en) * | 1996-03-13 | 1997-09-30 | Halliburton Energy Services, Inc. | Formation evaluation using phase shift periodic pressure pulse testing |
US5741962A (en) * | 1996-04-05 | 1998-04-21 | Halliburton Energy Services, Inc. | Apparatus and method for analyzing a retrieving formation fluid utilizing acoustic measurements |
US5934374A (en) * | 1996-08-01 | 1999-08-10 | Halliburton Energy Services, Inc. | Formation tester with improved sample collection system |
US5826662A (en) * | 1997-02-03 | 1998-10-27 | Halliburton Energy Services, Inc. | Apparatus for testing and sampling open-hole oil and gas wells |
US6212574B1 (en) * | 1997-04-04 | 2001-04-03 | Microsoft Corporation | User mode proxy of kernel mode operations in a computer operating system |
US6065355A (en) * | 1997-09-23 | 2000-05-23 | Halliburton Energy Services, Inc. | Non-flashing downhole fluid sampler and method |
US6452592B2 (en) * | 1998-11-13 | 2002-09-17 | Smartasic, Inc. | Clock generation for sampling analog video |
US6173793B1 (en) * | 1998-12-18 | 2001-01-16 | Baker Hughes Incorporated | Measurement-while-drilling devices with pad mounted sensors |
US6301959B1 (en) * | 1999-01-26 | 2001-10-16 | Halliburton Energy Services, Inc. | Focused formation fluid sampling probe |
US6688390B2 (en) * | 1999-03-25 | 2004-02-10 | Schlumberger Technology Corporation | Formation fluid sampling apparatus and method |
US20030066646A1 (en) * | 2001-09-19 | 2003-04-10 | Baker Hughes, Inc. | Dual piston, single phase sampling mechanism and procedure |
US6729399B2 (en) * | 2001-11-26 | 2004-05-04 | Schlumberger Technology Corporation | Method and apparatus for determining reservoir characteristics |
US7128144B2 (en) * | 2003-03-07 | 2006-10-31 | Halliburton Energy Services, Inc. | Formation testing and sampling apparatus and methods |
Cited By (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20140262347A1 (en) * | 2013-03-15 | 2014-09-18 | Carl E. Keller | Method for sealing of a borehole liner in an artesian well |
US9797227B2 (en) * | 2013-03-15 | 2017-10-24 | Carl E. Keller | Method for sealing of a borehole liner in an artesian well |
WO2016153522A1 (en) * | 2015-03-26 | 2016-09-29 | Halliburton Energy Services, Inc. | Corrosion tester tool for use during drill stem test |
Also Published As
Publication number | Publication date |
---|---|
NO20051397L (en) | 2005-04-19 |
US20040055400A1 (en) | 2004-03-25 |
CA2497295C (en) | 2009-12-15 |
GB0504935D0 (en) | 2005-04-20 |
US7191672B2 (en) | 2007-03-20 |
BR0313826A (en) | 2005-07-05 |
NO20051397D0 (en) | 2005-03-17 |
GB2408334B (en) | 2006-07-12 |
AU2003260108B2 (en) | 2009-02-12 |
EP1540299A1 (en) | 2005-06-15 |
EP1540299B1 (en) | 2013-02-20 |
CA2497295A1 (en) | 2004-03-11 |
AU2003260108A1 (en) | 2004-03-19 |
WO2004020982A1 (en) | 2004-03-11 |
EP1540299A4 (en) | 2009-11-11 |
GB2408334A (en) | 2005-05-25 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US7191672B2 (en) | Single phase sampling apparatus and method | |
NO313716B1 (en) | Method and test instrument for obtaining a sample of an intact phase pore fluid | |
US7845405B2 (en) | Formation evaluation while drilling | |
US6688390B2 (en) | Formation fluid sampling apparatus and method | |
NO312785B1 (en) | Method and instrument for obtaining specimens of formation fluid | |
US6557632B2 (en) | Method and apparatus to provide miniature formation fluid sample | |
AU739721B2 (en) | Non-flashing downhole fluid sampler and method | |
EP1623091B1 (en) | A method and apparatus for a downhole micro-sampler | |
US4950844A (en) | Method and apparatus for obtaining a core sample at ambient pressure | |
US9644479B2 (en) | Device for sampling fluid under pressure for geological site development monitoring | |
NO176150B (en) | Brönnverktöy for taking well fluid samples | |
US3437138A (en) | Drill stem fluid sampler | |
US9534987B2 (en) | Apparatus, system and method for reducing dead volume in a sample container | |
US20200182750A1 (en) | Apparatus and methods for fluid transportation vessels | |
US11384615B2 (en) | Core retrieving tool | |
US3957117A (en) | Method and apparatus for bottom hole testing in wells | |
BRPI0313826B1 (en) | TRAINING FLUID SAMPLE BOTTOM, MONOPHASIC TRAINING ASSESSMENT TOOL, PRESSURIZATION PISTON, METHOD FOR SPECIMEN COLLECTION OF FLUID HOLE BELOW |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |