Abstract: Subterranean gas capture wellbores are used to capture lost produced gas. Produced gas can be injected into a subterranean for gas enhanced hydrocarbon recovery and rise in the subterranean formation toward a production wellbore. A first portion is effective for enhanced hydrocarbon recovery and a second portion rises past the production wellbore to become the lost produced gas that is converted to captured produced gas in the subterranean gas capture wellbore. The captured produced gas can then flow in the subterranean gas capture wellbore to the surface for recovery.

Abstract: An inflow control nozzle is provided for use with a tubing. The nozzle includes a one-piece, 3D printed body, the body including a fluid inlet in communication with an outside of the tubing said inlet having an oval cross section; a fluid outlet in communication with an inside of the tubing; and an inner bore connecting the fluid inlet to the fluid outlet, said inner bore including a venturi restriction. The inner bore comprises a flared profile from the fluid inlet to the venturi restriction, and a flared and curved profile from the venturi restriction to the fluid outlet, said curved profile being free of angular bends or sharp direction change. An outflow control nozzle is also provided for use with a tubing and an inflow-outflow control nozzle is further provided for use with a casing.

Abstract: A measuring device for pore throat pressure of Jamin effect based on mechanochromic materials is provided and includes: a bubble pressurization part, configured to inject bubbles into a microscopic visualization test part; the microscopic visualization test part including a mechanochromic material and a pore throat structure, configured to characterize changes of pore throat pressure during bubble injection; a waste liquid recycling part, configured to recycle bubble waste liquid passing through the microscopic visualization test part; a data acquisition and analysis part, configured to acquire changing data of the pore throat pressure in the microscopic visualization test part and analyze the changing data to obtain the pore throat pressure. The device is simple in structure and easy to operate, and provides a method for measuring an internal surface pressure of an object. The method can realize a real time measurement of the pore throat pressure of Jamin effect.

Abstract: Acoustic characterization and mapping of flow from a perforation zone of a well. As a wireline probe containing acoustic sensors moves through the well, the acoustic sensors record acoustic pressure measurements of flow for each perforation in the well casing. The acoustic data is recorded and compiled into a three-dimensional flow model showing flow of hydrocarbons within and/or out of perforation tunnels. The three-dimensional flow models generated can be combined with historical data to form four-dimensional models illustrating flow over time, and both the three and four-dimensional models can be used to determine effectiveness of perforation charges as well as future flow from the well.

Abstract: System, methods, and devices for simultaneously fracturing a target formation and an adjacent secondary formation are disclosed. The simultaneous fracturing operations interfere with each other to form in-situ dynamic barriers. The in-situ barriers prevent acid from the fracturing treatment in the target formation from invading the secondary formation and, in some instances, sealing formation rock at the location of the in-situ barrier to prevent or reduce water movement from the secondary formation into the primary formation.

Abstract: Thermal recovery of oils is improved by capturing waste heat from a depleted steam chamber using steam plus foam and an optional gas to carry low quality steam deep into the chamber where the waste heat converts water to steam in situ. Thus, overall steam generation needs and thus costs are reduced.

Abstract: A fluid injection process includes removing a core sample from a low permeability reservoir. The process also includes performing an imbibition test on a plurality of stage one surfactants, each stage one surfactant mixed with a first treatment fluid, using a portion of the core sample to obtain a wettability index or measurement of capillary pressure for each stage one surfactant. In addition, the process includes selecting a stage one surfactant by determining which of the plurality of stage one surfactants has the highest wettability index or lowest capillary pressure and performing an oil recovery test on a plurality of stage two surfactants, each stage two surfactant mixed with a second treatment fluid. Further, the process includes selecting a stage two surfactant by determining which of the plurality of stage two surfactants has the highest oil recovery test result and injecting the selected stage one surfactant into a matrix of the low permeability reservoir.

Abstract: There is provided a method of producing hydrocarbon material. A first hydrocarbon material is produced from the formation, the first hydrocarbon material including a gaseous hydrocarbon material originally in place in the formation. At least a portion of the produced gaseous hydrocarbon material is injected into the formation to increase the formation pressure. A second hydrocarbon material is produced from the formation.

Abstract: Methods of plugging a hydrocarbon well by a through-tubing technique wherein the tubing is left in place, and only very short (<5 m) sections are cut, milled, perforated, ruptured and expanded, or combinations thereof. A blocking device is sent downhole if needed to block a bottom of the plug section, and resin dropped onto the blocking device to make a first plug, then cement is deployed onto said first plug to form a second plug. Therefore, the final interval is plugged with a two material binary plug. Once completed, and both primary and secondary barriers are in place, the well can be closed and the Christmas tree removed. A rock-to-rock plug can be set by removing or partially removing the tubular and the outer casing, or just inner casing/tubulars can be removed if the exterior cement and casing are of sufficient quality.

Abstract: A method relates to improving production rate and recovery of heavy oil or bitumen and reducing heat loss to over and under burden in a steam-assisted production process. The method includes strategically injecting recycled carbon dioxide into the reservoir between production wells. The heat insulation and solvent effects provided by carbon dioxide dissolved in the oil phase facilitate the desired improvement on oil recovery, and simultaneously sequester the CO2 back into the reservoir.

Abstract: A method of enhanced oil recovery from an unconventional resource reservoir comprises injecting an enhanced recovery fluid into the unconventional resource reservoir via an injection well and producing hydrocarbons from the unconventional resource reservoir via the injection well or a production well offset from the injection well.

Abstract: A system for Water-Alternating-Gas (WAG) injection for Enhanced Oil Recovery (EOR) includes a mechanical well configured to enable multi-point selective injection for water and gas. The system further includes an optimization engine configured to calculate reservoir flow dynamics and selectively inject water and gas via the mechanical well according to reservoir flow dynamics.

Abstract: Systems and methods for determining an optimal acid placement design for a production well near an aquifer are provided. An optimal acid placement that is determined accounts for the drawdown from heel to toe of the production well and reservoir heterogeneity to thereby address the issue of water breakthrough from the nearby aquifer and improve hydrocarbon recovery.

Abstract: A fluid injection system includes a choke valve having at least one inlet. The system also includes a water injection line extending between a water supply and the choke valve, and the water injection line is configured to flow water from the water supply into a first inlet of the at least one inlet of the choke valve. The system also includes a polymer injection line extending from a polymer supply toward the choke valve, and the polymer injection line is configured to flow a polymer in a substantially non-inverted state from the polymer supply toward the choke valve. The choke valve is configured to receive the water and the polymer and to facilitate inversion of the polymer as the water and the polymer flow through the choke valve.

Abstract: Recovering oil from a subterranean formation is disclosed, comprising processing a source water to produce a processed water stream and a reject water stream; injecting a first fluid into an injection well toward a first downhole exhaust, wherein the first fluid comprises the processed water stream; and injecting a second fluid into the injection well toward a second downhole exhaust, wherein the second fluid comprises the reject water stream or a produced water stream, wherein the first fluid is separated from the second fluid within the injection well; and producing oil via a production well.

Abstract: Aspects of the invention relate to compositions and methods that are used for the remediation of near-wellbore damage in regions of formations near injection wells in communication with subterranean reservoirs. The damage is caused by previous injection of a polymer emulsion into the injection well. A specific aspect is a method of injecting into the subterranean reservoir a composition containing an olefin sulfonate, a sulfosuccinate, and a chemical selected from an alcohol alkoxylated sulfate, an alcohol alkoxylated carboxylate, or a combination thereof. The polymer emulsion is thereby dissolved, cleaned and/or flushed away from the region near the injection well.

Abstract: A method and a sealing fluid for setting a packer in an annulus between a well bore and a well tubular is provided, which by adjusting i.a. the density, viscosity and setting time of the sealing fluid is able to provide among other things a full radial seal with an acceptable axial dispersion, in particular in highly deviated wells and/or in wells having eccentric annuli.

Abstract: A method of determining the in situ pressure of a light hydrocarbon in a shale source rock formation comprising: providing an inclusion comprising the light hydrocarbon trapped within the inclusion; using Raman spectroscopy to determine the density and composition of the light hydrocarbon trapped within the inclusion; and calculating a pressure of the light hydrocarbon in the shale source rock formation based upon the density and composition of the light hydrocarbon trapped within the inclusion.

Abstract: This invention is a solvent based gravity drainage process whereby the vertical growth rate of the chamber is restricted by placing, monitoring and managing a buoyant gas blanket at the top of the vapor chamber. This invention reduces the heat loss to the overburden as well as providing a means to preserve a barrier layer of bitumen saturated reservoir sand at the top of the pay zone in reservoirs where there is limited or no confining layer present.

Abstract: There is herein described the prevention of hydrates and the provision of a Relief Well in an oil and gas Well. More particularly, there is described the prevention of hydrates in an oil and gas Well by utilizing the latent heat in the sub-soil and providing Subterranean Channels to facilitate the provision of Relief Well access.

Abstract: A method for producing oil from a fractured oil bearing formation is provided in which an oil recovery formulation comprising water and dimethyl ether is introduced into a fracture in the formation to mobilize oil, the mobilized oil is contacted with water or brine, and the mobilized oil is produced from the formation at a location positioned upwards from the fracture.

Abstract: An in situ extraction process for heavy oil reservoirs using solvent comprises removing liquids and gases from areas contacting with the heavy oils to increase an interfacial area of unextracted heavy oil contactable by the solvent. Solvent vapor is injected into the areas to raise the reservoir pressure until sufficient liquid solvent is present to contact the increased interfacial area. The reservoir is shut in for a sufficient time for the solvent to diffuse into the unextracted oil across the interfacial area in a ripening step to create a reduced viscosity blend of solvent and oil. One or more reservoir characteristics is measured to confirm the extent of solvent dilution that has occurred of the unextracted oil in the reservoir. Gravity drainage based production is commenced from the reservoir upon the blend having a viscosity low enough to permit the blend to drain through the reservoir to a production well.

Abstract: Casing valves for selective well stimulation and control. A well system includes at least one valve interconnected in a casing string operable via at least one line external to the casing string to selectively control fluid flow between an exterior and interior of the casing string, and the casing string, valve and line being cemented in a wellbore. A method of selectively stimulating a subterranean formation includes: positioning a casing string in a wellbore, the casing string including spaced apart valves operable via a line to selectively control fluid flow between an interior and exterior of the casing string; and for each of multiple intervals of the formation in sequence, stimulating the interval by opening a corresponding one of the valves, closing the remainder of the valves, and flowing a stimulation fluid from the casing string into the interval.

Abstract: A system monitors and controls the injection of additives into formation fluids recovered through a well may include a plurality of nozzles that receive the injection fluid from an umbilical disposed in a well. Each nozzle may have an associated flow control element that is configured to affect a flow of the injection fluid ejected through the associated nozzle. The umbilical may include one or more filters positioned in a first of two parallel conduits formed along the umbilical. An occlusion member restricts in a second of the two conduits. The occlusion member permits flow in the second conduit after a predetermined pressure differential exists in the second conduit. The system may include a plurality of pressure sensors disposed along the umbilical, and an injector unit that dispenses fluid into the umbilical. A controller operatively coupled to the injector unit operates the injector in response to measurements from the pressure sensors.

Abstract: Methods and apparatus for running a completion string with sand screen assemblies through multiple zones are presented allowing sequential stimulation of zones, and production without multiple trips. An exemplary method includes running a completion string and isolating target zones. If desired, the formation can be produced prior to stimulation. To stimulate the zones, a first tubing valve is closed, for example by ball-drop, forcing fluid through the first screen assembly. After stimulating the zone is complete, a first screen valve is closed by increased tubing pressure. The first work string valve is re-opened by further increasing tubing pressure. A subsequent tubing valve is then closed, for example, by flowing the ball to the next ball seat. The process is repeated until all zones are stimulated. Valves are then opened at each screen assembly to allow production flow through the screen assemblies.

Abstract: Produced natural gas containing carbon dioxide is dehydrated and chilled to liquefy the carbon dioxide and then fractionated to produce a waste stream of liquid carbon dioxide and hydrogen sulfide. Natural gas liquids may be first separated and removed before fractionation. After fractionation, the waste stream is pressurized and transmitted to a remote injection well for injection either for disposal of the waste stream and preferably to urge hydrocarbons toward the producing well. A hydrocarbon stream proceeds from fractionation to a methanol absorber system which removes carbon dioxide gas. The hydrocarbon stream is thereafter separated into at least hydrocarbon gas, nitrogen and helium. Some of the nitrogen is reintroduced into a fractionation tower to enhance the recovery of hydrocarbons. A methanol recovery system is provided to recover and reuse the methanol. The hydrocarbons are sold as natural gas and the helium is recovered and sold. Excess nitrogen is vented.

Abstract: In a method for controlling interface level between a liquid inventory and an overlying steam chamber in a subterranean petroleum-bearing formation, an inflow relationship is developed to predict the vertical position in a gravity field of the interface between the two fluids (liquid and steam) with a density contrast relative to a horizontal producer well. The inflow relationship is applied to producer well completions by designing the completion to raise or lower sand face pressures according to mobility variations over the horizontal length of the well. This pressure distribution will affect liquid levels according to the inflow relationship. The completion can include tubing-conveyed or liner-conveyed flow control devices to create flow network that provides a customized sand face pressure distribution. Axial flow relationships between adjacent locations along the producer well may be modeled in order to develop an axial flow network to facilitate estimation of liquid levels at selected locations.

Abstract: A method for producing oil and/or gas comprising injecting a miscible enhanced oil recovery formulation into fractures, karsts, and/or vugs of a formation for a first time period from a first well; producing oil and/or gas from the fractures, karsts, and/or vugs from a second well for the first time period; injecting a miscible enhanced oil recovery formulation into the fractures, karsts, and/or vugs for a second time period from the second well; and producing oil and/or gas from the fractures, karsts, and/or vugs from the first well for the second time period.

Abstract: Systems and methods are provided for producing hydrocarbons from reservoirs. A provided method includes drilling a first horizontal well substantially proximate to a base of a reservoir and drilling a second horizontal well at a horizontal offset from the first horizontal well. Fluid communication is established between the first horizontal well and the second horizontal well through cyclic production processes. A mobilizing fluid is injected through the second horizontal well and fluids are produced from the first horizontal well.

Abstract: A method for producing oil and/or gas from an underground formation comprising locating a suitable reservoir in a subsurface formation; creating a model of the reservoir; populating the model with laboratory data; modeling the reservoir to determine fluid displacements based on fluids injected and fluids produced; determining an optimum fluid mixture for the fluids to be injected based on a series of sensitivity analyses performed with the model; drilling a first well in the formation; injecting the optimum fluid mixture into the first well; drilling a second well in the formation; and producing oil and/or gas from the second well.

Abstract: A method and apparatus for the management of injection and production of well fluids in a subterranean well is described to optimize the use of stimulation fluids to enhance their compatibility with subterranean reservoirs and the surface environment and thereby reducing the damage said fluids induce in subterranean reservoirs and upon flow back to the surface reduce their damage to the environment is described. More specifically, this method is directed to the subterranean treatment of injection fluids.

Abstract: A system for and method of supplying an injection fluid to a well assembly so that the injection fluid flows at a substantially constant flow rate. The fluid can be injected at a single site in the well assembly or multiple sites. A flow control regulator is included that attaches to the well assembly and provides a self adjusting flow control for the fluid being injected. The regulator includes a slidable floating sleeve having an orifice through which the fluid flows. The sleeve includes an inlet port that can register with a fluid supply port to allow the injection fluid to make its way into the sleeve. The fluid exits the sleeve through the orifice to generate a pressure differential across the orifice that in turn exerts a sliding force onto the sleeve. Moving the sleeve misaligns the inlet port and fluid supply port thereby throttling flow through the regulator to a predetermined flow rate.

Abstract: A completion system delivers lifting gas supplied from the surface via a casing annulus through the packer for injecting to the wellbore at bottom hole. So, lifting gas maximizes hydrocarbon producing from a subterranean well while maintaining integrity and serviceability as a typical gas lift well. More specifically, a single completion system uses the same tubing string for both producing the well and delivering lifting gas to the wellbore at downhole. The top section of the tubing is used for producing the well, while the bottom section of the tubing is used for delivering lifting gas for injecting at bottom hole. The lifting gas will be injected to the wellbore proximately at perforation intervals for helping unloading liquid and producing the well. The use of modified equipment named “TK Bypass Mandrel” and “JP Bypass Nipple Sub” allows delivering and controlling of the lifting gas for injecting at bottom hole via a single tubing string.

Abstract: A modified process for recovering oil from an underground reservoir using the an in situ combustion process. A diluent, namely a hydrocarbon condensate, is injected within a separate wellbore, or alternatively within said separate wellbore and via tubing in a horizontal wellbore portion, preferably proximate the toe, of a vertical-horizontal well pair, to increase mobility of oil.

Abstract: A modified process for recovering oil from an underground reservoir using the toe-to-heel in situ combustion process. A diluent, namely a hydrocarbon condensate, is injected within a horizontal wellbore portion, preferably proximate the toe, of a vertical-horizontal well pair, or alternatively into an adjacent injection well, or both, to increase mobility of oil.

Abstract: A method of producing hydrocarbons from a layer of oil sand located in a formation comprises creating a plurality of boreholes in the formation, including a first borehole and a second borehole spaced from the first borehole in a selected direction along which the layer of oil sand extends, and creating a cavity in the layer, the cavity being in fluid communication with the first borehole; extending the cavity in the selected direction by operating fluid jetting means via the first borehole to jet a stream of fluid against the cavity wall; when the cavity is in fluid communication with the second borehole, operating the fluid jetting means via the second borehole to jet a stream of fluid against the cavity wall so as to further extend the cavity; and transporting a slurry of fluid and oil sand from the cavity to a processing facility.

Abstract: A method for ensuring the integrity of a well comprises selecting a thermally insulating fluid as a packer fluid, pumping the thermally insulating packer fluid into an annulus of the well and insulating the well by controlling the heat transfer from the production tubing to the outer annuli. Controlling the heat transfer may also mitigate annular pressure buildup and thereby reduce the incidence of casing failure. In one embodiment of the invention, the thermally insulating fluid comprises a silicone-based fluid.

Abstract: Methods and apparatuses for releasing a chemical in a well bore are disclosed. One apparatus includes a curved member configured for coupling to a casing, and a hollow member is connected to the curved member. A chemical container is disposed, at least in part, within the hollow space, and the hollow member extends at least partially around a hollow space.

Abstract: A process to increase the area of microbial stimulation in a process of methane gas recovery in a multi seamed coal bed/methane dewatering and depressurizing production system by first utilizing an underbalanced multilateral drilling technique. At this point in the process one could introduce the microorganisms into the horizontal well bore to achieve a greater area of stimulation of the coal bed than would a vertical well. An even more preferred method would to first drill a series of lateral wells off of the horizontally drilled well bore, so as to increase or maximize the area of coal bed which is being covered. At that point, one would take the steps of what is known in the art of introducing a particular type of microorganism, such as the type disclosed in the '535 patent, which would then be injected via the plurality of lateral bores into the coal bed formation, to maximize the area of penetration, which would include, most, if not all, of the area of the coal bed through the series of lateral wells.

Abstract: A system for and method of supplying an injection fluid to a well assembly so that the injection fluid flows at a substantially constant flow rate. The fluid can be injected at a single site in the well assembly or multiple sites. A flow control regulator is included that attaches to the well assembly and provides a self adjusting flow control for the fluid being injected. The regulator includes a slidable floating sleeve having an orifice through which the fluid flows. The sleeve includes an inlet port that can register with a fluid supply port to allow the injection fluid to make its way into the sleeve. The fluid exits the sleeve through the orifice to generate a pressure differential across the orifice that in turn exerts a sliding force onto the sleeve. Moving the sleeve misaligns the inlet port and fluid supply port thereby throttling flow through the regulator to a predetermined flow rate.

Abstract: Processes for effecting biocidal activity in subterranean oil and gas wells being drilled, completed, worked over or produced are described. In general the process comprises blending with aqueous well fluid a biocidally-effective amount of a sulfamate stabilized, bromine-based biocide. Compositions comprised of aqueous well fluid blended with such aqueous biocides are also described.

Abstract: An equalizing injection wash tool includes a plurality of interconnectable wash tool segments. Each of the segments provides a flow applicator nozzle for transmitting fluid/and or solid from the interior flowbore of the wash tool and into the surrounding formation. Each segment preferably features a plurality of nozzle pipes and nozzles which are oriented about the cross-sectional circumference of the segment in an angularly spaced orientation to provide for a flow pattern that is substantially equalized in an angular manner. In a preferred embodiment, the nozzle pipes have a length that extends into the flowbore of a neighboring wash tool segment.

Abstract: A process for improved safety and productivity when undertaking oil recovery from an underground reservoir by the toe-to-heel in situ combustion process employing a horizontal production well. Water, steam, and/or a non-oxidizing gas, which in the preferred embodiment substantially comprises carbon dioxide which acts as a gaseous solvent, is injected into the reservoir for improving recovery in an in situ combustion recovery process, via either an injection well, a horizontal well, or both.

Abstract: A process for improved safety and productivity when undertaking oil recovery from an underground reservoir by the toe-to-heel in situ combustion process employing a horizontal production well. Water, steam, and/or a non-oxidizing gas, which in the preferred embodiment substantially comprises carbon dioxide which acts as a gaseous solvent, is injected into the reservoir for improving recovery in an in situ combustion recovery process, via either an injection well, a horizontal well, or both.

Abstract: Systems and methods for drainage of a heavy oil reservoir via a horizontal wellbore. A method of improving production of fluid from a subterranean formation includes the step of propagating a generally vertical inclusion into the formation from a generally horizontal wellbore intersecting the formation. The inclusion is propagated into a portion of the formation having a bulk modulus of less than approximately 750,000 psi. A well system includes a generally vertical inclusion propagated into a subterranean formation from a generally horizontal wellbore which intersects the formation. The formation comprises weakly cemented sediment.

Abstract: A method for well construction and completion is disclosed. Generally the method comprises the steps of 1) drilling through an injection zone, 2) positioning an extendable permeable element on the casing capable of stopping formation material from entering the well bore, 3) positioning the casing such that the extendable elements are aligned with the injection zone, 4) extending the member such that they come into direct contact with the injection zone formation, 5) running tubing/completion equipment, and 6) begin injecting the desired fluids into the well. Thus eliminating the need to perforate and gravel pack the well while improving reliability of the injection well completion.

Abstract: An expandable reamer apparatus and methods for reaming a borehole, wherein a laterally movable blade carried by a tubular body may be selectively positioned at an inward position and an expanded position. The laterally movable blade, held inwardly by blade-biasing elements, may be forced outwardly by drilling fluid selectively allowed to communicate therewith by way of an actuation sleeve disposed within the tubular body. Alternatively, a separation element may transmit force or pressure from the drilling fluid to the movable blade. Further, a chamber in communication with the movable blade may be pressurized by way of a downhole turbine or pump. A ridged seal wiper, compensator, movable bearing pad, fixed bearing pad preceding the movable blade, or adjustable spacer element to alter expanded blade position may be included within the expandable reamer. In addition, a drilling fluid pressure response indicating an operational characteristic of the expandable reamer may be generated.

Abstract: In a WAG flood oil is displaced from a subterranean formation by injecting water alternately with gas into a single injection completion per pattern. The ratio of water to gas injected is the WAG ratio. In this invention, two separate injection completions are used in each pattern, with one placed directly above the other. A very low WAG ratio is used for injection into the bottom extremity of the formation. A very high WAG ratio is injected into the upper interval, at as high a rate as can safely be used without fracturing the formation. In the preferred embodiment, two horizontal well bores serve as the two completion intervals. Proper design of this method gives a vertical sweep efficiency of the gas that is several-fold greater than the best of previous WAG flood designs, especially in thin formations.

Abstract: Provided is a bore hole underreamer, intended in particular for oil drilling. The underreamer has a hollow body and at least two cylindrical bores. The bores are distributed over the circumference of the hollow body and each bore contains a cylindrical widening arm. Each arm has a bladed cutting end disposed on the outside of the body that slides between active and inactive positions. Another end of each arm is disposed inside the body and receives fluid pressure for pushing the arm into the active position. The underreamer includes a locking member for locking the arms in their inactive position when the locking member is immobilized in the body in a releasable fashion in a locking position. When released, the locking member leaves the locking position under a thrust from at least one of the arms subjected to the pressure capable of pushing the arm into its active position.

Abstract: The present invention generally provides a method and apparatus for injecting a compressible fluid at a controlled flow rate into a geological formation at multiple zones of interest. In one aspect, the invention provides a tubing string with a pocket and a nozzle at each isolated zone. The nozzle permits a predetermined, controlled flow rate to be maintained at higher annulus to tubing pressure ratios. The nozzle includes a diffuser portion to recover lost steam pressure associated with critical flow as the steam exits the nozzle and enters a formation via perforations in wellbore casing. In another aspect, the invention ensures steam is injected into a formation in a predetermined proportion of water and vapor by providing a plurality of apertures between a tubing wall and a pocket. The apertures provide distribution of steam that maintains a relative mixture of water and vapor.