Abstract: A method and apparatus are shown for burning crude oil or natural gas extracted from an underground reservoir, or for burning both crude oil and natural gas extracted from an underground reservoir, for providing thermal energy. The method and apparatus are also shown transferring the thermal energy to brine separated from the extracted oil, gas or both, for providing heated brine, or for converting the thermal energy to mechanical work, or for both transferring the thermal energy to the separated brine and converting the thermal energy to mechanical work. The method and apparatus are also shown heating the underground reservoir with the heated brine injected into the underground reservoir, or heating the underground reservoir with a resistive cable energized by electricity generated by converting the mechanical work to electric energy, or heating the underground reservoir with both the heated brine and the energized resistive cable.

Abstract: The present disclosure relates to a downhole packer assembly that includes an outer skin, an inner packer disposed within the outer skin such that inflation of the inner packer is configured to expand the outer skin, a pair of mechanical fittings engaged with axial ends of the outer skin, and a ring assembly disposed within at least one of the pair of mechanical fittings. The ring assembly includes a shear pin configured to shear upon application of a tensile force to the downhole packer assembly.

Abstract: An off bottom flow diverter subassembly. A fronthead and shank each includes a central bore. One of the shank and the fronthead has an outer diameter configured to fit within the central bore of another of the fronthead and shank. The shank and fronthead are arranged to slide longitudinally with respect to each other and are limited from sliding out of contact with each other. At least one diverting flow passage is between adjacent sliding surfaces of the shank and fronthead. Sliding the fronthead and shank with respect to each other opens and closes the diverting flow passage. Application of a force, sufficient to open the diverting flow passage, to a drill string to which the subassembly is attached in a direction toward an opening of a hole being drilled causes the diverting flow passage to open and drilling fluid to flow out of the subassembly away from the bit.

Abstract: An apparatus for supporting tubing in casing includes a setting tool and a liner top packer, which can be used for tieback. A setting slip is disposed uphole of a packing assembly on the packer and is movable from a retracted to an extended state engaging the casing. The setting tool has a temporary connection to the packer and has a pack-off that seals the tool in the packer but allows for movement. After running downhole, the temporary connection of the setting tool to the packer is disconnected, and the setting slip is set in the casing by moving the setting tool in an uphole direction. To set the packing assembly, the packer is moved in the uphole direction by engaging the setting tool with the pack-off and compressing the packing element (e.g., packing element and opposing cones and slips) against the set setting slip. Eventually, the setting tool is disconnected from the packer by disengaging the pack-off.

Abstract: A method for cementing an annular space outside of an inner casing of a subterranean well includes running and setting a cement packer assembly into a bore of the inner casing. The cement packer assembly includes a plurality of nails spaced around a circumference of the cement packer assembly. Slips are set and a lower end of each of the nails is pushed through the inner casing with a setting tool to form holes. A middle portion of the nails having a smaller outer dimension than the lower end of the nails is positioned within the holes. Cement is pumped through the inner casing, through the holes and into the annular space. A force is applied to the nails to move the nails through the holes and position a seal plate of each nail against an inside surface of the bore surrounding one of the holes.

Abstract: A hydraulic fracture diagnostic system for reservoir evaluation of a high angle wellbore includes coiled tubing that extends from the surface to a wellbore location. The system includes a sensor and a pump connected to the coiled tubing and a pump and sensor connected to an annulus between the coiled tubing and the wellbore casing. A tool having at least two packing elements and a port positioned between the packing elements is connected to the coiled tubing and is positioned adjacent a fracture. The packing elements isolate the fracture and the port is configured to provide communication with the isolated portion of the wellbore. A diagnostic method includes pumping a volume of fluid into the isolated portion of a wellbore and monitoring the pressure within the annulus via the coiled tubing. The tool may also be used in an openhole portion of a wellbore to diagnose the formation.

Abstract: A disclosed reverse-out valve includes an upper mandrel, a lower mandrel movable with respect to the upper mandrel, and a reverse activated plug device arranged on the upper mandrel and including a piston arranged within a piston chamber of the upper mandrel and a prop extending longitudinally from the piston, wherein the piston chamber includes a first end and a second end, the reverse activated plug device further including a closure device movable between an open position where the piston is arranged at the first end and the prop holds the closure device open such that a reverse-circulation fluid is able to bypass the reverse activated plug device, and a closed position, where the piston is arranged at the second end and the prop is moved to allow the closure device to close and thereby prevent the reverse-circulation fluid from bypassing the reverse activated plug device.

Abstract: A downhole tool having a first packing element and a second packing element configured to synchronically set to selectively hydraulically isolate a portion of the wellbore. The lower packing element may be first set against the well with the upper packing element next being set against the well. A slip joint permits a change in distance between the packing elements during the setting of the packing elements. The slip joint may be energized to apply a force to the lower packing element to prevent the unsetting of the lower packing element during the setting of the upper packing element. A resilient member may be used to energize the slip joint or the slip joint could be hydraulically or pneumatically energized. Once both packing elements are set, the wellbore may then be treated by flowing fluid out of a ported sub positioned between the packing elements.

Abstract: Flow control mechanism (100) for a downhole tool includes a housing (102), an inner liner (104), and a rotatable sleeve (106). The inner liner (104) is provided in and remains stationary relative the housing (102). The rotatable sleeve (106) can be arranged to rotate about the inner liner (104) to provide a closed configuration (900), a first open configuration (1400), and a second open configuration (1900). The closed configuration (900) can enable through-flow of fluid through the flow control mechanism (100) to a distal tool (50). The first open configuration (1400) can enable partial through-flow of fluid through the flow control mechanism (100) to the distal tool (50) and partial through-flow of fluid in a substantially radial direction. The second open configuration (1900) can prevent through-flow of fluid through the flow control mechanism to the distal tool (50) and to enable through-flow of fluid in a substantially radial direction.

Abstract: A downhole tool and concomitant methodology for selectively opening and closing multiple frac stages and multiple production zones in the absence of an intervention step. A sliding frac valve is disposed between a fixed open sleeve and a fixed mandrel. Under the influence of an open flow port or a closed flow port, the sliding frac valve is caused to slide in a predetermined direction to trigger emplacement of a locking rib cage within a corresponding recess, thereby locking the tool in an open or closed position. An option is provided for selectively filtering sand and other particulate impurities using a similarly slidable sliding screen valve.

Abstract: The system and method for setting a completion tool within a wellbore includes assembling a mandrel, inner sleeve, piston, outer sleeve, and dog member. In a first locked position, the dog member abuts against the indentation of the mandrel and the locking surface of the piston. The dog member is friction fit between the piston and mandrel so that movement of the completion tool corresponds to movement of the mandrel. The mechanical link, such as shear pins, of the completion tool is protected by the dog member holding steady on the mandrel. When the completion tool reaches the desired location, a pressure pulse opens a chamber between the sleeves to transition to a second released position. The dog member releases from the mandrel to be housed in the chamber, when movement of the mandrel sets the completion tool by the mechanical link, such as shear pins.

Abstract: A sealing arrangement and method for dynamic sealing around a drill stem (50) in water-carrying, drilling fluid-carrying or hydrocarbon-carrying wells, comprising at least one dynamic sealing (35a) which is arranged to envelop the drill stem (50), and a receiver unit (30) arranged to receive the at least one sealing (35a), with the dynamic sealing being arranged to be driven into the receiver unit (30) with the help of the drill stem, and to be securely locked in the receiver unit, and also that internal pressure support in the sealing arrangement is provided corresponding to at least the surrounding pressure.

Abstract: An example downhole completion system includes a first sealing structure arranged within an open hole section of a wellbore and being movable between a contracted configuration and an expanded configuration, a second sealing structure arranged axially adjacent the first sealing structure and also being movable between a contracted configuration and an expanded configuration, and a flow control device arranged between the first and second sealing structures and configured to provide a flow path for fluids to communicate between a surrounding subterranean formation and an interior of the downhole completion system.

Abstract: Disclosed is a downhole completion assembly for sealing and supporting an open hole section of a wellbore and providing flow control through the downhole completion assembly. One downhole completion system includes a first sealing structure arranged within an open hole section of a wellbore and being movable between a contracted configuration and an expanded configuration, a second sealing structure arranged axially adjacent the first sealing structure and also being movable between a contracted configuration and an expanded configuration, and a flow control device arranged between the first and second sealing structures and configured to provide a flow path for fluids to communicate between a surrounding subterranean formation and an interior of the downhole completion system.

Abstract: A downhole tool for use in a well. The tool has a packer assembly and a pumpable plug associated with the packer assembly. The pumpable plug has a diameter greater than the maximum outer diameter of the packer assembly. The pumpable plug may be pumped through a casing having a diameter larger than that for which the packer assembly is designed and will urge the packer assembly through the large diameter casing into a smaller diameter casing for which the packer assembly is designed.

Abstract: Moveable and split packer cups for use above a conventional coiled tubing fracturing or stimulation tool are described as well as methods for running these tools into a wellbore. These devices can be used for extended stimulation intervals with coiled tubing, as well as for a secondary pressure containment to avoid pressure communication with uphole formations or perforations.

Abstract: System, devices, and methods are described relating to the treatment (e.g., perforating, fracturing, foam stimulation, acid treatment, cement treatment, etc.) of well-bores (e.g., cased oil and/or gas wells). In at least one example, a method is provided for treatment of a region in a well, the method comprising: positioning, in a well-bore, a packer above the region of the well-bore, fixing, below the region, an expansion packer, treating the region, the treatment fixing the packer, moving the expansion packer, and moving the packer after the moving of the expansion packer.

Abstract: A tool assembly and method for completing a well are provided. The tool is deployed on tubing string and includes a fluid treatment assembly with cup seals above and below the treatment ports. An equalization valve beneath the fracturing assembly can be opened or closed to control fluid passage between the coiled tubing and treatment zone to the wellbore below.

Abstract: A device for establishing an environment of a required fluid inside a length of pipe, comprising two pipe-engaging members adapted to engage the interior surface of the pipe at respective positions spaced therealong, and means for introducing said fluid into the interior of the pipe between said engaging members, each pipe-engaging member comprising a casing for contacting the pipe interior surface and containing an inflatable element; wherein the casing of each engaging member includes at least a portion of stretchable material for enabling expansion and contraction of the casing in a direction radially of the pipe, for engaging a range of internal pipe sizes.

Abstract: A tool assembly and method for completing a well are provided. The tool is deployed on tubing string and includes a fluid treatment assembly with cup seals above and below the treatment ports. An equalization valve beneath the fracturing assembly can be opened or closed to control fluid passage between the coiled tubing and treatment zone to the wellbore below.

Abstract: An apparatus for controlling fluid flow in a borehole in an earth formation includes: a carrier configured to be deployed in the borehole; and a sealing device including at least one deformable element disposed at the carrier, the deformable element configured to have a first position and a second position, the first position forming a void in the sealing device configured to retain a flowable sealing material therein, the second position causing the void to be in flowable communication with leak paths formed in at least one of the sealing device and the borehole.

Abstract: A cementing sub for wellbore annulus cementing that allows certain regions of the wellbore annulus to be cemented while other regions are left open for perforating, activation or controllable ported access. The cementing sub may include a tubular body including a first end, an opposite end and a wall defined between an inner bore extending from the first end to the opposite end and an outer surface; a port through the wall of the tubular body providing communication between the inner bore and the outer surface, the port including an openable closure; a conduit along the wall of the tubular extending from an inlet adjacent the first end and an outlet adjacent the opposite end, the inlet and outlet opening to the outer surface and being isolated from communication with the inner bore; a first annular packer encircling the tubular body and positioned between the port and the inlet; and a second annular packer encircling the tubular body and positioned between the port and the outlet.

Abstract: A subsurface discrete interval system for water and soil vapor, providing verifiable interval isolation, media evaluation and monitoring, field modifiability, extraction, and injection capabilities. The system comprises an outer structure (01) and inner core (02), each comprised of one or more seal sections (03) and one or more port sections (04). A user of the system can monitor, sample, and evaluate the characteristics of the media of interest at verifiable isolated discrete intervals. A user of the system can extract or inject fluid, vapor, or multiphase substances in the media of interest. During installation or anytime afterwards the user can modify or remove the system to meet the dynamic conditions and needs frequently encountered during subsurface investigation and/or remediation.

Abstract: The present disclosure relates to a device and a method for isolating a section of a wellbore, the device including a straddle packer (1) and associated systems (100, 10) for selectively setting of at least one upper packer element (2), at least one lower packer element (3) and at least one anchoring device (4) of the straddle packer (1), wherein at least one setting element (10) of the straddle packer (1) is operated independent from other setting elements (100).

Abstract: A tool for use in the treatment of a formation penetrated by a well bore. The tool comprises a tubular core having at least one opening therein for the discharge of pressurized fluid from within the core, first and second axially spaced apart seals disposed on the core for seals between the core and the well bore, the opening in the core being located between the first and second seals, and a third seal disposed downhole relative to the first and second seals for sealing between the tool and the well bore, the third seal protecting the first and second seals from pressure in the well bore below the tool.

Abstract: A downhole plug is provided. In one or more embodiments, the plug includes a body and an element system disposed about the body. The plug further includes a first and second back-up ring member having two or more tapered wedges. The tapered wedges are at least partially separated by two or more converging grooves. First and second cones are disposed adjacent the first and second back-up ring members.

Abstract: A stirrer includes a vessel for holding a liquid to be stirred; and a sound wave generator that irradiates the liquid with a sound wave to stir the liquid by the sound wave. The sound wave generator includes a piezoelectric substrate, and a sound generating element provided on the piezoelectric substrate and arranged outside the vessel so as to be adjacent to the liquid across the vessel and the piezoelectric substrate to generate a sound wave for stirring the liquid.

Abstract: A well packer assembly with an annular fluid bypass and a check valve. The well packer assembly has an upper packer apparatus and a lower packer apparatus with a stimulation port therebetween. An annular fluid bypass in the upper packer apparatus communicates the well annulus from above packer elements on the upper packer apparatus to below the packer elements. The well fluid circulated through the fluid bypass is discharged into the well annulus below the packer elements on the upper packer apparatus to circulate stimulation fluid through the stimulation port and upwardly through the upper packer apparatus and the tubing used to lower the upper packer apparatus into the well.

Abstract: System, devices, and methods are described relating to the treatment (e.g., perforating, fracturing, foam stimulation, acid treatment, cement treatment, etc.) of well-bores (e.g., cased oil and/or gas wells). In at least one example, a method is provided for treatment of a region in a well, the method comprising: positioning, in a well-bore, a packer above the region of the well-bore, fixing, below the region, an expansion packer, treating the region, the treatment fixing the packer, moving the expansion packer, and moving the packer after the moving of the expansion packer.

Abstract: Methods are provided in which reliance is placed on a first and second barrier respectively positioned in a well 10 to provide well control during well suspension, completion and/or workover operations. Each of the barriers is below the depth of the lowermost end of a completion string when that string is installed in the well. By not placing either barrier higher up in the well-bore, both of the barriers can remain in place during suspension and completion and workover operations, thus obviating the need to use a BOP stack to supplement well control. This results in a considerable saving in drill rig time and thus significantly reduces the cost of constructing a well.

Abstract: A packing element, which is a composite structure, contains the sealing portion to minimize extrusion. The element is retained in tension when running in to minimize damage. In the preferred embodiment, a collapsing sleeve transfers setting force applied at one end, to the opposite end to avoid the problem of bunching up the element adjacent to where it is being compressed which could, if not addressed, result in insufficiently low sealing contact pressure in regions remote from where the pushing force is applied.

Abstract: A device and a method are provided for the hydraulic fracturing of multiple zones in a well bore. A stinger carries a plurality of packers into a well bore. Each packer is separably connected to each adjacent packer. As each packer is sequentially secured in the well bore, the stinger is withdrawn from the secured packer and the process is repeated as the remaining packers are sequentially secured and separated.

Abstract: An isolation string having: an upper packer; and an isolation pipe in mechanical communication with the upper packer, wherein the isolation pipe comprises a pressure activated valve and an object activated valve. A method having: running-in an isolation string on a service tool, wherein the isolation string comprises a pressure activated valve and a object activated valve; setting the isolation string in the casing adjacent perforations in the casing; releasing an object from the service tool, whereby the object travels to the object activated valve; closing the object activated valve with the released object; and withdrawing the service tool from the well.

Abstract: A packer with an equalizing valve for automatically equalizing the pressure above and below the packer element. The packer comprises a housing having an equalizing valve disposed therein. A packer element is disposed about the housing for sealingly engaging the wellbore. An equalizing valve is disposed in the housing and seals the housing to prevent flow therethrough when the packer element is actuated to engage the wellbore. The valve is movable in the closed position wherein communication through the housing is prevented to an open position so that the portion of the wellbore above the packer element may be communicated with a portion of the wellbore below the packer element while the element is in the set position so that pressure above and below the element may be equalized. Once the pressure is equalized, the packer can be unset and retrieved from the wellbore.

Abstract: A pack-off system for packing off an area of interest in a wellbore, the pack-off system comprising a body, two spaced-apart selectively settable packing elements on the body for sealing off the area of interest, selectively actuatable setting apparatus connected to the body for selectively setting the two spaced-apart selectively settable packing elements, the selectively actuatable setting apparatus actuatable by fluid under pressure introduced into the pack-off system. A method for packing off an area of interest in a wellbore, the method including installing a pack-off system as described herein in the wellbore to pack-off the area of interest. Such a method may also include flowing treatment fluid from the pack-off system to an area of interest in an earth formation and/or adjacent a wellbore in the earth.

Abstract: A system for relieving pressurized fluid entrapped in a annular space between a casing (12) and the surrounding wall (11) of a well bore hole (10) during deployment of a packer exterior (14) of the casing (12) for sealing engagement with the wall (11). When packer (14) is inflated in a zone (17) where fluid is entrapped, such as an intermediate packer between two previously inflated packers (13, 14), the squeeze pressure developed by the inflating packer (14) has been found to be sufficient to prevent effective and lasting sealing of the intermediate packer (14). The present system includes a valve mechanism (35) which is activated by the pressurized fluid providing for inflating the packer (14) to open a passageway (90, 94, 91) to bleed the entrapped fluid into the casing (12) and to then close the passageway (90, 94, 91) as inflation of the intermediate packer (14) is completed.

Abstract: Apparatus for completing a subterranean well and associated methods provide economical and efficient well completions. In one described embodiment, a well completion apparatus includes a packer which is settable by application of a compressive axial force thereto. The packer sealingly engages a wellbore of the well when set therein, but does not anchor to the wellbore. The apparatus further includes a screen and an attachment device. The attachment device permits the apparatus to be attached to another packer previously set and anchored within the wellbore.

Abstract: An inflatable packer having a sealing section, with noncontinuous ribs, is provided in combination with a ribbed element, which provides anchoring capabilities in tandem with the partially ribbed element which provides sealing capabilities in downhole applications.

Abstract: Apparatus for completing a subterranean well and associated methods provide economical and efficient well completions. In one described embodiment, a well completion apparatus includes a packer which is settable by application of a compressive axial force thereto. The packer sealingly engages a wellbore of the well when set therein, but does not anchor to the wellbore. The apparatus further includes a screen and an attachment device. The attachment device permits the apparatus to be attached to another packer previously set and anchored within the wellbore.

Abstract: A straddle tool is disclosed which ensures sequential setting of the packing elements through the use of lost motion mechanisms. Once the lower pack-off has been set, the upper one is set and an internal valve is opened to allow flow through the tool to actuate a downhole tool, such as an inflatable packer. An anchor prevents actuation of the pack-off tool unless it is extended into a profile for support of the tool. Inadvertent settings of the pack-off tool are prevented, such as in oversized casing where the anchors are already fully extended, by virtue of a distance-sensing mechanism on the tool. When a large distance is sensed by one or more sensors, the mandrel is locked to the setting collars, preventing relative movement which could set the pack-off elements.

Abstract: A method and apparatus for repairing or isolating holes, ruptures, splits or old perforations in marginal oil and gas wells from producing perforations. The apparatus includes two packer assemblies, a tube assembly and a slip assembly. The packer assemblies further include expandable packer elements and a vent cone mounted on a mandrel. The mandrels of the packer assemblies are connected to opposite ends of the tube assembly. The slip assembly is housed on the mandrel of one packer assembly and is used to create a positive mechanical set of the repair apparatus when positioned over the damaged area. Once the packer apparatus is positioned and the packer elements expanded, gas from producing formations flow to the wellhead through the tube assembly without interfering with the operation of down-hole pumps. The length of the gas vent packer apparatus can be varied between the packer elements depending upon the depth of damaged casing requiring repair or isolation.

Abstract: A well tool having an anchor device, straddle packers above and below a port and an internal valve which are operated by longitudinal motion in an inflatable packer device. The well tool anchor is armed by a hydraulic operated plug and set upon downward motion in a locating profile groove in a well bore. The tool when attached to a string of tubing can be filled with cement slurry and downward motion used to anchor the well tool in a profile groove in an inflatable packer; to set the straddle packers above and below an access port on an inflatable packer; and then to open a valve to admit cement slurry to the inflatable packer. After filling the inflatable packer with cement slurry, an upward motion is used to close the valve, unset the straddle packers and release the anchor to move to another location where the operation can be repeated. At the conclusion of operations, a circulation valve is opened by pressure to reverse out cement slurry from the tubing string.

Abstract: A method and apparatus for performing a block squeeze cementing job. The invention provides for perforating the wellbore above and below the desired well formation on a single wireline trip and setting a lower packer on a wireline above the lower perforations. A stinger is positioned in the lower packer, and secondary packer elements on an upper packer are set above the upper perforations. Cementing of the lower perforations is carried out through the lower packer. The secondary packer elements are unset, and the stinger is repositioned adjacent to the upper perforations. Primary packer elements on the upper packer are then set, and the cementing of the upper perforations is carried out through the upper packer and stinger. Setting of the secondary packer elements requires only vertical movement of the tubing string and no rotation. Both cementing steps are carried out on a single tubing trip. The upper packer is retrievable, and the lower packer is of a drillable type.

Abstract: A fluid flow control system, assembly and method for wells in which a sliding sleeve valve is connected in a string of well tubing in a wellbore casing. The sliding sleeve valve functions to selectively control the lateral flow of fluid through the assembly into the annulus between the assembly and the wellbore casing. A straddle assembly is locked within the sleeve valve assembly for isolating a lateral flow path. A stinger assembly is provided which receives reeled tubing and is insertable to lock within the straddle assembly to create a flow path between the reeled tubing and exterior of the sleeve valve.

Abstract: A straddle packer apparatus includes a housing having a central opening. The housing has inflation passages, treating fluid passages, and equalizing passages defined therein. Upper and lower longitudinally spaced packers are mounted on the housing on opposite sides of an outlet of the treating fluid passage. An inner mandrel is slidably received in the central opening of the housing. The mandrel has a mandrel bore and has upper and lower inflation ports, upper and lower equalizing ports, and a treating port, all of which communicate with the mandrel bore. A lug and endless J-slot is operably associated with the housing and mandrel for controlling a telescoping position of the mandrel relative to the housing in response to telescoping reciprocation without rotation of the mandrel relative to the housing.

Abstract: A retrievable tension-set packer, by itself, and in conjunction with retrievable tension-set bridge plug for use in field testing of oil well casings is disclosed. The retrievable tension-set packer is constructed to be set and sealed above an area of the oil well casing to be tested, while the retrievable tension-set bridge plug is constructed to be set and sealed in an area below the area of the casing to be tested. When used in conjunction with a retrievable tension-set bridge plug, the retrievable tension-set packer has a portion thereof which allows limited rotational movement for setting the bridge plug below the area to be tested, while the tension-set packer requires greater predetermined rotational movement to set the packer above the area to be tested.

Abstract: Treating apparatus arranged to be positioned in well bores that includes a packer that is retrievable and resettable and that provides a spaced pair of sealing elements to isolate a zone in the well bore. A valve operable within the packer is moveable among positions wherein fluid can be circulated through the operations, an open position wherein the treating fluids can be injected into the zone to be treated, and a closed position wherein the selected zone can be sealed off.

Abstract: A unitary assembly (10); is disclosed for isolating a leak in a side pocket mandrel (12) between the tubing annulus (16) about a tubing string (14) and the interior (20) of the tubing string. The unitary assembly includes an upper packer (22), and a lower packer (24) interconnected by a tailpipe (26). The upper packer (22) is preferably set by a wireline tool and the lower packer is preferably set hydraulically. This eliminates the need for a drilling or workover rig to be setup over the well when patching a leak.

Abstract: A multi-channel pipe for monitoring groundwater in aquifers at multiple levels below a single site. Pipe sections each comprise an outer wall, an interior element dividing the pipe into multiple channels, a monitoring port opening into one of the channels, coupling means for joining pipe sections lengthwise to each other, and a plug for plugging the channel immediately below the monitoring ports. The interior element is preferably star-shaped, having a hollow cylindrical central core and eight radial segments affixed between the core and the outer wall. Each channel is defined in part by the outer wall and in part by two adjacent segments of the interior element. Corresponding channels of adjacent pipe sections are joined by couplings each channel receiving one end of a coupling. A capped plug is inserted into the upper end of the coupling below immediately above the monitoring ports of a channel. An inflatable packer encircling the pipe seals the drill hole between groups of monitoring ports.

Abstract: There is disclosed apparatus for use in completing oil or gas wells having two or more perforated production zones which includes packers and assemblies for closing off the annular space between the tubing string and the well bore intermediate adjacent zones to isolate one from the other in order to produce from each individually.