Pump Drain Arrangements For Packer Systems And Methods For Sampling Underground Formations Using Same

Abstract

An apparatus, system and method of sampling a reservoir fluid is disclosed. An inflatable packer is deployed into a wellbore having one or more fluid ports for receiving the reservoir fluid. The fluid ports are positionable at different longitudinal and/or radial positions. One or more pumps are connected to the fluid ports and are within the packer. A fluid exit may optionally be provided in the packer to expel the reservoir fluid received from one of the fluid ports back into the wellbore.

Description

BACKGROUND OF THE DISCLOSURE

Underground formation testing is beneficial and is performed during drilling and geotechnical investigation of underground formations. As time passes, testing of such underground formations becomes more important as the results of such examinations may determine, for example, if a driller is to proceed or stop. As drilling operations can be extremely expensive on a per day basis, excessive drilling impacts the overall economic viability of drilling projects. There is a need, therefore, to minimize the amount of drilling and to obtain accurate information from the underground formations.

Different types of information may be obtained from the underground formations. One of the primary forms of information that is desired to be obtained is actual samples of fluid from underneath the ground surface. Such samples, when they are obtained, can be quickly analyzed by professionals to determine the constituents of the underground formation.

Determination of the underground fluid constituents is extremely important in the exploration for trapped hydrocarbon reserves. Determination of oil, gas or mixtures of oil and gas are of primary importance in many areas of the world and correct determination of the presence of these constituents is valuable.

Difficulty often arises, however, in sampling of the oil and gas from these formations. First, many formations may be under tremendous underground pressures that hamper the recovery efforts. To limit the amount of pressure from traveling uphole, operators may use specific engineering control methods, such as installing a device called a “packer” that limits the flow of fluid to the uphole environment. These packers are conveyed down inside the formation by various methods and then expanded/inflated at a point of interest including, but not limited to wireline methods. The expansion limits the fluid, or in some instances, eliminates fluid penetration to the uphole environment from the packer installation through the obstruction caused by the packer.

There is a need to provide a system that will allow for more accurate sampling of underground fluids without the clogging problems experienced by conventional systems.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a side view of a drill rig system in one aspect described, wherein the drill rig system prepares a wellbore in a geotechnical subsurface environment.

FIG. 2 is a side view of a packer system with guard drains and a single central sampling drain in another aspect described to be used in the geotechnical substrate environment.

FIG. 3 is a flow diagram of a fluid entering the packer system of FIG. 2, wherein flow from guard drains exits the system in a predefined location(s) and sampled fluid is withdrawn for analysis.

FIG. 4 is a flow pattern diagram of the packer system of FIG. 2, wherein cleaning of the sampling drain and guard drains is illustrated.

FIG. 5 is a flow pattern diagram of the packer system of FIG. 2, wherein sampling is performed through the single central sampling drain.

FIG. 6 is a method of performing sampling through a packer system in the example embodiment provided in FIG. 2.

FIG. 7 is an alternative method for performing sampling through the example embodiment packer system provided in FIG. 2.

DETAILED DESCRIPTION

It will be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments. Specific examples of components and arrangements are described below to simplify the present disclosure. These are, of course, merely examples and are not intended to be limiting.

This disclosure may repeat reference numerals and/or letters in the various examples. This repetition is for the purpose of simplicity and clarity and does not itself dictate a relationship between the various embodiments and/or configurations discussed. Moreover, the subterranean formation of a first feature over or on a second feature in the description that may include embodiments in which the first and second features are formed in direct contact, and may also include embodiments in which additional features may be formed interposing the first and second features, such that the first and second features may not be in direct contact.

The present disclosure illustrates a system and method for collecting formation fluid through a port or drain in the body of an inflatable or expandable packer. The collected formation fluid may be conveyed along an outer layer of the packer to a tool flow line and then directed to a desired collection location. Use of the packer to collect a sample enables the use of larger expansion ratios and higher drawdown pressure differentials. Additionally, because the packer uses a single expandable sealing element, the packer is better able to support the formation in a produced zone at which formation fluids are collected. This quality facilitates relatively large amplitude draw-downs even in weak, unconsolidated formations.

The packer is expandable across an expansion zone to collect formation fluids from a position along the expansion zone, i.e. between axial ends of the outer sealing layer. Formation fluid can be collected through one or more ports or drains comprising fluid openings in the packer for receiving formation fluid into an interior of the packer. The ports may be positioned at different radial and longitudinal distances. For example, separate ports can be disposed along the length of the packer to establish collection intervals or zones that enable focused sampling at a plurality of collecting intervals, e.g. two or three collecting intervals. The formation fluid collected may be directed along flow lines, e.g. along flow tubes, having sufficient inner diameter to transport the formation fluid. Separate flowlines can be connected to different drains to enable the collection of unique formation fluid samples. In other applications, sampling can be conducted by using a single drain placed between axial ends of the packer sealing element.

In accordance with the present disclosure, a wellsite with associated wellbore/well 110 and apparatus is described in order to describe a typical, but not limiting, environment in which an embodiment of the application is to be installed. To that end, apparatus at the wellsite may be altered, as necessary, due to field considerations encountered. The apparatus disclosed may be installed using various techniques, hereinafter described.

Referring generally to FIG. 1, one embodiment of a well system 101 is illustrated as deployed in a wellbore 110. The well system 101 comprises a conveyance 105 employed to deliver at least one packer 160 into the wellbore 110. In many applications, the packer 160 is used on a modular dynamics formation tester (MDT) tool deployed by the conveyance 105 in the form of a wireline. However, the conveyance 105 may have other forms, including tubing strings, such a coiled tubing, drill strings, production tubing, casing or other types of conveyance depending on the required application. In the embodiment illustrated, the packer 160 is an inflatable or extendable packer used to collect formation fluids from a surrounding formation 115. The packer 160 is selectively expanded in a radially outward direction to seal across an expansion zone. For example, the packer 160 may be inflated by fluid, such as wellbore fluid, hydraulic fluid or other fluid. When the packer 160 is expanded to seal against the wellbore 110, formation fluids can flow into the packer 160. The formation fluids may then directed to a tool flow line and produced to a collection location, such as a location at a well site surface.

As shown in FIG. 1, the conveyance 105 may extend from a rig 101 into a zone of the formation 115. In an embodiment, the packer 160 may be part of a plurality of tools 125, such as a plurality of tools forming a modular dynamics formation tester. The tools 125 may collect the formation fluid, test properties of the formation fluid, obtain measurements of the wellbore, formation about the wellbore or the conveyance 105, or perform other operations as will be appreciated by those having ordinary skill in the art. The tools 125 may be measurement while drilling or logging while drilling tools, for example such as shown by numerals 6a and 6b. In an embodiment, the downhole tools 6a and 6b may be a formation pressure while drilling tool.

In an embodiment, the tools 125 may include logging while drilling (“LWD”) tools having a thick walled housing, commonly referred to as a drill collar, and may include one or more of a number of logging devices. The logging while drilling tool may be capable of measuring, processing, and/or storing information therein, as well as communicating with equipment disposed at the surface of the well site. As another example, the tools 125 include measurement while drilling (“MWD”) tools may include one or more of the following measuring tools a modulator, a weight on bit measuring device, a torque measuring device, a vibration measuring device, a shock measuring device, a stick slip measuring device, a direction measuring device, and inclination measuring device, and\or any other device. As yet another example, the tools 125 may include a formation capture device 170, a gamma ray measurement device 175 and a formation fluid sampling tool 610, 710, 810 which may include a formation pressure measurement device 6a and/or 6b. The signals may be transmitted toward the surface of the earth along the conveyance 105.

Measurements obtained or collected may be transmitted via a telemetry system to a computing system 185 for analysis. The telemetry system may include wireline telemetry, wired drill pipe telemetry, mud pulse telemetry, fiber optic telemetry, acoustic telemetry, electromagnetic telemetry or any other form of telemetering data from a first location to a second location. The computing system 185 is configurable to store or access a plurality of models, such as a reservoir model, a fluid analysis model, a fluid analysis mapping function.

The rig 101 or similar looking/functioning device may be used to move the conveyance 105. Several of the components disposed proximate to the rig 101 may be used to operate components of the overall system. For example, a drill bit 116 may be used to increase the length (depth) of the wellbore. In an embodiment where the conveyance 105 is a wireline, the drill bit 116 may not be present or may be replaced by another tool. A pump 130 may be used to lifts drilling fluid (mud) 135 from a tank 140 or pits and discharges the mud 135 under pressure through a standpipe 145 and flexible conduit 150 or hose, through a top drive 155 and into an interior passage inside the conveyance 105. The mud 135 which can be water or oil-based, exits the conveyance 105 through courses or nozzles (not shown separately) in the drill bit 116, wherein it cools and lubricates the drill bit 116 and lifts drill cuttings generated by the drill bit 116 to the surface of the earth through an annular arrangement.

When the well 110 has been drilled to a selected depth, the tools 125 may be positioned at the lower end of the conveyance 105 if not previously installed. The tools 125 may be coupled to an adapter sub 160 at the end of the conveyance 105 and may be moved through, for example in the illustrated embodiment, a highly inclined portion 165 of the well 110.

During well logging operations, the pump 130 may be operated to provide fluid flow to operate one or more turbines in the tools 125 to provide power to operate certain devices in the tools 125. When tripping in or out of the well 110, (turning on and off the mud pumps 130) it may be in feasible to provide fluid flow. As a result, power may be provided to the tools 125 in other ways. For example, batteries may be used to provide power to the tools 125. In one embodiment, the batteries may be rechargeable batteries and may be recharged by turbines during fluid flow. The batteries may be positioned within the housing of one or more of the tools 125. Other manners of powering the tools 125 may be used including, but not limited to, one-time power use batteries.

An apparatus and system for communicating from the conveyance 105 to the surface computer 185 or other component configured to receive, analyze, and/or transmit data may include a second adapter sub 190 that may be coupled between an end of the conveyance 105 and the top drive 155 that may be used to provide a communication channel with a receiving unit 195 for signals received from the tools 125. The receiving unit 195 may be coupled to the surface computer 185 to provide a data path therebetween that may be a bidirectional data path.

Though not shown, the conveyance 105 may alternatively be connected to a rotary table, via a Kelly, and may suspend from a traveling block or hook, and additionally a rotary swivel. The rotary swivel may be suspended from the drilling rig 101 through the hook, and the Kelly may be connected to the rotary swivel such that the Kelly may rotate with respect to the rotary swivel. The Kelly may be any mast that has a set of polygonal connections or splines on the outer surface type that mate to a Kelly bushing such that actuation of the rotary table may rotate the Kelly. An upper end of the conveyance 105 may be connected to the Kelly, such as by threadingly reconnecting the drill string 105 to the Kelly, and the rotary table may rotate the Kelly, thereby rotating the drill string 105 connected thereto.

FIG. 2 illustrates an embodiment of a packer system 200. For example, the packer system 200 may be the packer 160 as shown in FIG. 1 or may be deployed into a wellbore for other uses. The packer system 200 may be described as a “packer” for brevity in some circumstances. The packer system 200 may be used to fluidly isolate one portion of a wellbore from another portion of a wellbore. The packer system 200 is conveyed to a desired downhole location and, in the non-limiting embodiment provided, inflated or expanded to provide a seal between the packer system 200 and the well 110. For example, the packer system may prevent fluid communication from two portions of a wellbore by expanding or inflating circumferentially to abut the wellbore.

The packer system 200 may have one or more ports or sampling drains 204, 206 (the terms drains or ports are used herein interchangeably and no inference should be drawn from use of one term without the other) for receiving fluid from the formation or the wellbore into the packer system 200. In an embodiment, the packer system 200 has one or more guard ports 204 located longitudinally from one or more sample ports 206. In the illustrated embodiment, the guard ports 204 are illustrated a closer longitudinal distance from ends of the packer system than a longitudinal distance of the one or more sample ports 206 to the ends of the packer system 200. The ports 204, 206 may be located at distinct radial positions about the packer system 200 such that the ports 204, 206 contact different radial positions of the wellbore. The ports 204, 206 may be embedded radially into a sealing element of an outer layer of the packer system 200. By way of example, sealing element may be cylindrical and formed of an elastomeric material selected for hydrocarbon based applications, such as nitrile rubber (NBR), hydrogenated nitrile butadiene rubber (HNBR), and fluorocarbon rubber (FKM). The packer system 200 may be expanded or inflated, such as by the use of wellbore fluid, hydraulic fluid, mechanical means or otherwise positioned such that the one or more sample ports 206 and the one or more guard ports 204 may abut the walls of the formation 115 to be sampled. The packer system 200 may be expanded or inflated from a first position to a second position such that the outer diameter of the packer system 200 is greater at the second position than the first position. In an embodiment, the second position may be the position in which the ports 204, 206 abut the formation and the first position may be an unexpanded or deflated position. The packer system 200 may move to a plurality of positions between the first position and the second position. The packer system 200 may expand in the relative areas around the one or more guard ports 204 and the one or more sample ports 206 such that a tight seal is achieved between the exterior of the packer system 200 and wellbore, casing pipe or other substance external to the packer system 200.

Operationally, the packer system 200 is positioned within the wellbore 110 to a sampling location. The packer system 200 is inflated or expanded to the formation through the expansion of the body 202 of the packer system 200 expanding with the internal diameter of the pipe or within the formation 115. A pump may be utilized to draw fluid from the ports 204, 206 and/or to transport fluid within or out of the packer system 200. The pump may be incorporated into the packer system 200 or may be external to the packer system 200. The fluid removed through the sample drain 206 and/or guard drains 204 may then be transported through the packer system 200 to a downhole tool, such as the tools 125 for example. In an alternative configuration, the packer system 200 may retain the fluid in an interior system for later analysis when the packer system 200 is deflated or unexpanded and retrieved. An outer seal layer 212 is provided around the periphery of the remainder of the packer system 200 to allow for mechanical wear of the unit as well as sealing capability to the formation 115 or inner wall of the wellbore. The packer system 200 may have an inner, inflatable bladder disposed within an interior of outer seal layer 212.

Referring to FIG. 3, the packer system 200 may be used to draw reservoir fluid from the formation 115. For example, the reservoir fluid may be drawn into the sample drains or ports 206 and/or the guard drains or ports 204. As shown, larger based arrows indicate flow through the sample drains 206, and smaller arrows based arrows indicate flow through guard drains 204 and expelled from the body 202 of the packer system 200. To this end, the packer system 200 may have ports at 210 through which fluid originating in the guard drains 204 is expelled. Flow from each of the guard drains 204 is combined inside the packer system 200 to form a central flow 208 that is ejected as illustrated. The central flow 208 is taken from the individual guard drains 204 to the bottom of the system through a conveyance, which in the illustrated embodiment is shown as a flow line, such as a stainless steel tube. The body 202 in one non-limiting embodiment, may be made of rubber and compatible with oil and/or water based muds. The body 202 may include an outer seal layer 212 as shown in FIG. 2 and/or an inflatable bladder interior of the outer seal layer 212.

Flow from the sample drain 206 is transported through the packer system 200 and may pass into a connected downhole tool. In the illustrated embodiment, the flow from the packer system 200 sample drain 206 is not combined with the flow from the guard drains 204. The flow from the sample drain 206 may also be stored in another downhole tool or may be stored within the packer system 200 for retrieval and analysis. In other embodiments, flow from the sample drain 206 may be combined with that of the guard drains 204.

In the illustrated embodiment provided in FIG. 4, a flow pattern for activation of all of the guard drains 204 and the sample drain 206 is illustrated when the sample drain 206 is not being used for sampling. As illustrated, the guard drains 204 obtain fluid from the formation and combine the flow to form a central flow 208, as previously illustrated. Conversely, FIG. 5 is a flow pattern diagram of the packer system 200 of FIG. 2, wherein sampling is performed through the single central sampling drain 206.

Flow from the sample drain 206 is transported up the packer system 200 and exits at the upper section of the system 200 through a conveyance, in this illustrated embodiment, stainless steel tubing. Each of the conveyances discussed may prevent backflow into the packer system 200 through a check valve system, as a non-limiting embodiment. This methodology of using all of the guard drains 204 and the sample drain 206 allows the fluid flow from the formation to be drained more quickly than using only the guard drains 204. The packer system 200 may also have at least one top drain exit with a conveyance pathway between the at least one top drain exit and the at least one sample drain. This at least one top drain exit may be selectively closed during formation sampling for storage.

The packer system 200 may include one or more pumps in fluid communication with the guard drains 204 and/or the sample drains 206. In an embodiment, the packer system 200 may include a first pump for the guard drains 204 and a second pump for the sample drains 206. In another embodiment, the packer system 200 may include a pump for each one of the drains 204, 206. The one or more pumps may be positioned within the body of the packer system 200, such as between ends of the packer system 200 defining the length of the packer system 200. In an embodiment, the one or more pumps may be positioned within or at the drains 204, 206. The one or more pumps may be used not only to draw fluid into the port but also to transport fluid within or through the packer system 200. Different pump configurations may be used in conjunction with the embodiments provided above. The one or more pumps may comprise a hydraulically actuated pump, a pump activated by an electrical motor, a positive displacement pump, a progressive cavity pump, and a piston pump.

The system 200 described provides many advantages over conventional packer systems. The system 200 described allows for more uniform flow during analysis of the underground formation as the ports and constituent parts of the systems are not prone to clogging as in conventional systems.

The system 200 is also superior to conventional systems as the system 200 may be accurately cleaned by operators if a problem arises during sampling. This ability to accurately clean the system 200 allows for continued and long term use of the system 200 in the downhole environment.

The system 200 is also relatively easy to manufacture and will fit into conventional wellbores for intended service. The system 200 is also able to work in a variety of environmental conditions such that it may be used in differing underground formations.

Each of the pumps placed in the system 200 may be operated through associated electronics such that actuation of the electronics operates each of the pumps. In the illustrated embodiment provided, operators in the uphole environment may issue instructions to the downhole electronics such that the downhole electronics in the system 200 operate the pumps and the associated functions of the system 200 to the desired operational characteristics of the system 200. As the electronics are placed in a downhole environment, the electronics are insulated to protect from harsh temperatures, pressure and fluid entry.

The system 200 used may be used with existing systems and downhole conditions such that it may be retrofitted into many wellbores. To that end, pumps within the drains may be partially powered through movement of downhole hydraulic fluid. In the instance of pump activation through hydraulic fluid movement, a dedicated power provision from the downhole tool, for example, directly to the packer may be provided.

In another example embodiment, pumps within the system 200 may be activated by electrical motors, instead of the above described hydraulic fluid movement. The pumps used in these configurations may be configured to withstand hydraulic pressures exerted in the downhole environment. In another alternative configuration a solenoid may be used to actuate a piston within the pump.

Referring to FIG. 6, a method 300 for using the system 200 is illustrated. A driller may lower the system 200 into a geotechnical formation such that the system reaches a specified level 302. The packer system 200 is abutted to the edge of the downhole formation through, for example, expanding/inflating the packer system 200 inside the borehole 304. Such expansion is accomplished through gas or fluid injection into the packer system 200.

After placement of the system 200 within the borehole, the operator sends an electrical signal to the guard pumps placed within the guard drains 204 to begin pumping 306. Fluid from the guard drains are conveyed to the bottom of the system 200 and exit the system 200 back to the wellbore. Conveyance may be through wireline, tractor, drill string as non-limiting embodiments.

After a time decided by the operator, the sample drain pump is activated 310 in the sample drain 206 such that fluid is withdrawn from the formation/reservoir. The fluid then may be stored in a downhole location or may be conveyed to the surface, as needed by the operator 312. The method may stop at 314.

In an alternative configuration, as illustrated in FIG. 7, a driller/operator may lower the system 200 into a geotechnical formation such that the system reaches a specified level 402. The packer system 200 is abutted to the edge of the downhole formation through, for example, expanding/inflating the packer system 200 inside the borehole 404. Alternatively, the packer system 200 may be expanded/inflated within the borehole to bear on the inner walls, as appropriate, providing a seal. Such expansion is accomplished through gas or fluid injection into the packer system 200, as non-limiting embodiments. The gas or fluid injected into the packer system 200 may be provided from an uphole environment or may be carried down to the downhole environment inside the packer system 200.

After placement of the system 200 within the borehole, the operator sends an electrical signal to the guard pumps placed within the guard drains 204 and the sample drains 206 to begin pumping 406. Fluid from the guard drains are conveyed to the bottom of the system 200 and exit the system 200 back to the wellbore 408. Fluid from the sample drains are conveyed to the top of the system 200 for sampling 410 or may be stored. The method may end at step 412. Although not shown, the packer may be deflated prior to step 412 prior to removal.

As will be apparent, the steps in the two methods described above may be altered, as necessary, to achieve desired results. Sample drains 206 may be started first, before guard drains. All drains may be started at the same time. Sampling from the sample drains 206 may occur immediately or fluid may be pulled from the geotechnical foundation 115 and ejected for a period of time through a flow path through, for example, the top of the packer system that may have an exit port/passage. In addition to the above, the arrangement and methods may allow for individual drains to be selectively started, at the discretion of the operator. The pumps, in another embodiment, may be actuated based upon a preset pattern or time sequence through computer actuation. Such actuation may be from surface commands or may be from a downhole processor in charge of such functions. In an alternative method, the flow from the guard drains 204 and the sample drain 206 may be initiated initially, with flow from the sample drain 206 automatically being retained or conveyed for analysis, as needed. In an alternative embodiment, the method may include cleaning each of the sampling drains 206 and the guard drains 204 prior to withdrawing the fluid from the underground formation. Such cleaning may entail backwashing fluid through the drains, or varying suction pressure during removal of fluids to dislodge potential materials. In one non-limiting embodiment, a minimum of two sampling drains and four guard drains are used. Different conveyance may be used for the packer, including slickline, conventional wireline, logging while fishing systems, coiled tubing and tractor systems.

The packer system 200 may be an inflatable packer positioned within the wellbore. The packer system 200 may inflate from a first diameter to a second diameter greater than the first diameter to fluidly connect the sample drain 206 and the guard drain 204 with reservoir fluid. The guard drain 204 is positioned at a longitudinal distance closer to an end of the packer system 200 than a longitudinal distance from the sample drain 206 to the end of the packer system 200. The reservoir fluid from the wellbore may be pumped through the guard drain 204 or the sample drain 206 with a pump positioned within the packer system 200, such as within the body of the packer, within the guard drain 204 or within the sample drain 206. Further, the reservoir fluid may be pumped through the guard drain at a first rate and may be pumped through the sample drain at a second rate different than the first rate. The sample drain and the guard drain can be radially separated a distance along the packer.

The packer system 200 may be utilized to clean at least one of the sample drain 206 and the guard drain 204 prior to withdrawing the reservoir fluid. At least a portion of the reservoir fluid may be expelled from the packer into the wellbore. For example, the reservoir fluid may be expelled until the fluid passing through is free of debris, the drain 204, 206 is free of debris, or the fluid passing through the drain 204, 206 has below a predetermined amount of contaminants. For example, cleaning may comprise receiving fluid through the sample drain 206 or the guard drain 204 and ejecting the fluid from the packer into the wellbore without passing the fluid out of the packer. Pumping of the reservoir fluid from the sample drain and the guard drain can be accomplished with different pumps. For example, the reservoir fluid may be pumped through the guard drain 204 at a first rate and through the sample drain 206 at a second rate, and further wherein the first rate is different than the second rate.

The packer system 200 may include a body having a guard drain 204 and a sample drain 204 providing fluid access from an external of the body to an internal of the body. The body is inflatable from a first diameter to a second diameter greater than the first diameter. The body may include an elastomeric seal layer configured to seal against a wall of a wellbore. The guard drain 204 is located a longitudinal distance from the sample drain 206. A fluid exit is positioned within the body to expel fluid received from the guard drain or the sample drain out of the body. At least one pump within the body is fluidly connected to the guard drain 204 or the sample drain 206. The pump is positionable at the guard drain or the sample drain. The at least one pump may be a hydraulically actuated pump, a pump activated by an electrical motor, a positive displacement pump, a progressive cavity pump, and a piston pump. The at least one pump is configured to draw fluid into the guard drain or the sample drain and pump the fluid through the fluid exit. The at least one pump may include a first pump in fluid communication with the guard drain 204 and a second pump in fluid communication with the sample drain 206. The first pump and the second pump operate at different rates and are individually controllable. The first pump or the second pump is positionable in the guard drain 204 or the sample drain 206. The at least one pump moves fluid from the guard drain 204 into the body and expels the fluid out of the body. The at least one pump moves fluid from the sample drain 206 into the body and expels the fluid out of the body.

The arrangements illustrated may be configured, in specific embodiments, to provide interface with formation testing capability. Such formation testing capabilities may use internal or externally powered systems and may have temperature operational capabilities up to 200 degrees Centigrade. The interface provided with the arrangements may be scalable and may interface with sensors, tools or combinations of both, as applicable, to enable access and control to desired information.

The arrangements illustrated may have electrical modules for modular testing which may comprise a master board and any number of slave boards feeding information to and from the slave boards to the master board. Such slave boards may be configured to interface with devices or sensors. In the arrangements illustrated, different gateways may be coupled with application specific software to exchange data from devices, such as formation testing devices and/or sensors to an internal bus for data transfer and processing. Fluid analysis capabilities supported may be, in non-limiting embodiments, gamma-ray or X-ray testing, resistivity, fluorescence, ultra-sonic testing, and spectrometer analysis.

In specific embodiments, common communication interfaces may be developed to facilitate information transfer from data point/data origination to processing centers and ultimately user interface. Such communication interfaces may be dynamic configurations allowing users to expand and contract features and program components connected to the data transfer networks. Protocols may be developed and used in connection with the data transfer networks, in layered programming as a non-limiting example embodiment, to allow addition and subtraction of communication capability. In embodiments, network management may include network initialization, configuration, synchronization and monitoring capability. Device access and control may be performed through control of subprograms or objects, as applicable. Such device access and control may be, in specific embodiments, through open computer architecture.

In one non-limiting embodiment, a method of sampling is disclosed. The method comprises positioning a packer in a wellbore, activating the packer to form a seal between at least one guard drain and at least one sample drain and withdrawing a fluid from an underground formation through the at least one guard drain and the at least one sample drain, wherein at least one individual pump is used for each guard drain and each sampling drain.

In another example embodiment, a method is provided wherein the at least one guard drain is four guard drains. In a further example embodiment, the method is provided wherein the four guard drains are positioned in a rectangular configuration around the sampling drain.

In another example, the method may be accomplished wherein during the withdrawing the fluid from the underground formation from the at least one guard drain and the at least one sample drain, the fluid from the at least one guard drain is rejected back into the wellbore. In another example, the method is accomplished wherein the withdrawing the fluid from the underground formation from the at least one sample drain is conveyed back to a surface environment.

In another example, the method is accomplished wherein the withdrawing the fluid from the underground formation from the at least one sample drain is conveyed back to a tool and stored. The method may also be accomplished to further comprise analyzing the fluid that is stored in the tool when the tool is in the wellbore.

In another example, an apparatus is provided. The apparatus may comprise a body with at least one guard drain port and at least one sample drain port, the body further having at least one bottom drain exit with a conveyance pathway between the bottom drain exit and the at least one guard drain port and at least one pump within each the at least one guard drain port and the at least one sample drain.

In another example embodiment, the apparatus may further comprise at least one top drain exit with a conveyance pathway between the at least one top drain exit and the at least one sample drain.

In another example embodiment, the apparatus may include a body that is made of stainless steel. The apparatus may also be accomplished wherein the at least one pump is a fluid actuated pump. The apparatus may also further comprise a power supply and wherein the at least one pump is an electric pump driven by the power supply. The at least one pump may be a piston pump or a progressive cavity pump. The at least one pump may be solenoid actuated.

The foregoing outlines feature of several embodiments so that those skilled in the art may better understand the aspects of the disclosure. Those skilled in the art should appreciate that they may readily use the present disclosure as a basis for designing or modifying other processes and structure for carrying out the sample purposes and/or achieving the same advantages of the embodiments introduced herein. Those skilled in the art should also realize that such equivalent constructions do not depart from the spirit and scope of the present disclosure, and that they may make various changes, substitutions and alterations herein without departing from the spirit and scope of the present disclosure.

Claims

1. A method comprising:

positioning an inflatable packer in a wellbore;

inflating the packer from a first diameter to a second diameter greater than the first diameter to fluidly connect a sample drain and a guard drain with reservoir fluid wherein the guard drain is positioned at a longitudinal distance closer to an end of the packer than a longitudinal distance from the sample drain to the end of the packer; and

pumping the reservoir fluid from the wellbore through the guard drain or the sample drain with a pump positioned within the packer.

2. The method according to claim 1 wherein the pumping comprises pumping the reservoir fluid through the guard drain at a first rate and pumping the reservoir fluid through the sample drain at a second rate different than the first rate.

3. The method according to claim 1 wherein the sample drain and the guard drain are radially separated a distance along the packer.

4. The method according to claim 1 further comprising:

cleaning at least one of the sample drain and the guard drain prior to withdrawing the reservoir fluid.

5. The method according to claim 1 further comprising:

expelling at least a portion of the reservoir fluid from the packer into the wellbore.

6. The method according to claim 4 wherein the cleaning comprises receiving fluid through the sample drain or the guard drain and ejecting the fluid from the packer into the wellbore without passing the fluid out of the packer.

7. The method according to claim 1 further comprising pumping the reservoir fluid from the sample drain and the guard drain with different pumps.

8. The method according to claim 7 wherein the pumping comprises pumping fluid through the guard drain at a first rate and pumping fluid through the sample drain at a second rate, and further wherein the first rate is different than the second rate.

9. An apparatus, comprising:

a body having a guard drain and a sample drain providing fluid access from an external of the body to an internal of the body, the body inflatable from a first diameter to a second diameter greater than the first diameter, the guard drain located a longitudinal distance from the sample drain;

a fluid exit positioned within the body to expel fluid received from the guard drain or the sample drain out of the body; and

at least one pump within the body and fluidly connected to the guard drain or the sample drain.

10. The apparatus of claim 9 wherein the body includes an elastomeric seal layer configured to seal against a wall of a wellbore.

11. The apparatus of claim 9 wherein the at least one pump is positioned at the guard drain or the sample drain.

12. The apparatus according to claim 9, wherein the at least one pump is one of a hydraulically actuated pump, a pump activated by an electrical motor, a positive displacement pump, a progressive cavity pump, and a piston pump.

13. The apparatus according to claim 9 wherein the at least one pump is configured to draw fluid into the guard drain or the sample drain and pump the fluid through the fluid exit.

14. The apparatus of claim 9 wherein the at least one pump includes a first pump in fluid communication with the guard drain and a second pump in fluid communication with the sample drain.

15. The apparatus of claim 9 wherein the at least one pump moves fluid from the guard drain into the body and expels the fluid out of the body.

16. The apparatus of claim 9 wherein the at least one pump moves fluid from the sample drain into the body and expels the fluid out of the body.

17. The apparatus of claim 14 wherein the first pump and the second pump operate at different rates and are individually controllable.

18. The apparatus of claim 14 wherein the first pump or the second pump is positioned in the guard drain or the sample drain.