US20120073820A1 - Chemical Injector for Wells - Google Patents
Chemical Injector for Wells Download PDFInfo
- Publication number
- US20120073820A1 US20120073820A1 US13/246,500 US201113246500A US2012073820A1 US 20120073820 A1 US20120073820 A1 US 20120073820A1 US 201113246500 A US201113246500 A US 201113246500A US 2012073820 A1 US2012073820 A1 US 2012073820A1
- Authority
- US
- United States
- Prior art keywords
- fluid
- tubing
- mixing chamber
- intake
- well
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
- 239000000126 substance Substances 0.000 title description 12
- 239000012530 fluid Substances 0.000 claims abstract description 140
- 238000002347 injection Methods 0.000 claims abstract description 50
- 239000007924 injection Substances 0.000 claims abstract description 50
- 238000007599 discharging Methods 0.000 claims abstract description 7
- 239000007788 liquid Substances 0.000 claims description 33
- 239000004088 foaming agent Substances 0.000 claims description 19
- 238000004891 communication Methods 0.000 claims description 13
- 238000000034 method Methods 0.000 claims description 7
- 239000006260 foam Substances 0.000 claims description 5
- 230000002706 hydrostatic effect Effects 0.000 claims description 2
- 230000001939 inductive effect Effects 0.000 claims description 2
- 239000000203 mixture Substances 0.000 claims description 2
- 238000005086 pumping Methods 0.000 claims description 2
- 238000007789 sealing Methods 0.000 claims description 2
- 238000004519 manufacturing process Methods 0.000 description 11
- 230000015572 biosynthetic process Effects 0.000 description 5
- 238000005755 formation reaction Methods 0.000 description 5
- 229930195733 hydrocarbon Natural products 0.000 description 3
- 150000002430 hydrocarbons Chemical class 0.000 description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 3
- 238000005260 corrosion Methods 0.000 description 2
- 230000007797 corrosion Effects 0.000 description 2
- 230000001186 cumulative effect Effects 0.000 description 2
- 239000012188 paraffin wax Substances 0.000 description 2
- 150000003839 salts Chemical class 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 230000035508 accumulation Effects 0.000 description 1
- 238000009825 accumulation Methods 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 238000005187 foaming Methods 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 230000000977 initiatory effect Effects 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 229910001220 stainless steel Inorganic materials 0.000 description 1
- 239000010935 stainless steel Substances 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
- E21B43/121—Lifting well fluids
- E21B43/13—Lifting well fluids specially adapted to dewatering of wells of gas producing reservoirs, e.g. methane producing coal beds
Landscapes
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Chemical & Material Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
Abstract
A fluid injection sub for a well creates eduction to draw well fluid into a mixing chamber and discharge the well fluid mixed with an injection fluid pumped down a string of tubing to the sub. The injection sub has a well fluid intake passage leading from an exterior of the housing to the mixing chamber. The injection sub also has a mixed fluid discharge passage extending from the mixing chamber to the exterior of the housing for discharging the mixed fluid exterior of the housing. A nozzle at the lower end of the mixing chamber discharges the injection fluid into the mixing chamber.
Description
- This application claims priority to
provisional application 61/387,876 filed Sep. 29, 2010. - This disclosure relates in general to an injector to inject chemicals into a well and in particular to facilitate the removal of water from gas wells by injecting a foaming agent.
- Many gas wells are drilled in gas bearing shale formations. Often the gas well has an upper vertical portion leading to a horizontal portion. In one technique for completing these wells, the operator perforates the shale formation through the casing and employs hydraulic fracturing to create cracks and fissures in the shale formations. During hydraulic fracturing, a fracturing fluid is pumped down the casing at high pressure. After the fracturing process has been completed, the well will be loaded with fracturing fluid that must be removed. The formation pressure of the gas may be inadequate to blow the fracturing fluid from the well. Swabbing can be employed to remove the fracturing fluid from the vertical portion of the well, enabling the gas to begin producing.
- Also, after the well begins producing, often liquids, both water and hydrocarbons, will be produced along with the gas. These liquids tend to accumulate in the well, impeding the flow of gas. Various techniques are employed to remove the liquids, including installing a submersible pump.
- Hydrocarbon producing wells also have many other problems that develop overtime. Salt can accumulate which builds up in the production tubing and impedes well fluid flow. Paraffin can build up within the production tubing. Corrosion and scale occur in some wells. Operators have deployed chemicals for these various problems by pumping or gravity feeding the chemicals into the well. One type of chemical is a foaming agent that creates foam when mixed with the well fluid.
- A fluid injection apparatus for a well has a housing with a tubing mounting mechanism for securing the housing to a string of tubing to lower the housing into a well. A tubing intake in the housing is in fluid communication with an interior of the tubing. A mixing chamber is located in the housing. An injection fluid inlet passage extends from the tubing intake to a lower end of the mixing chamber for discharging an injection fluid pumped down the tubing into the mixing chamber. A well fluid intake passage leads from an exterior of the housing to the mixing chamber. The well fluid intake passage has an entrance selected to be below a liquid level in the well, so that well fluid is induced to flow into the mixing chamber where it mixes with the injection fluid being pumped down the tubing, creating a mixed fluid. A mixed fluid passage extends from the mixing chamber to the exterior of the housing for discharging the mixed fluid exterior of the housing.
- A nozzle may be at an end of the injection fluid inlet passage opposite the tubing intake and joining the mixing chamber. The nozzle has a flow area smaller than a flow area of the mixing chamber.
- A check valve may be located in the injection fluid inlet passage between the tubing intake and the mixing chamber. The check valve is biased to a closed position that prevents flow from the tubing intake to the mixing chamber unless a selected pressure of the injection fluid is reached.
- The entrance of the well fluid intake passage is at an elevation below the mixing chamber. The mixed fluid passage has an outlet at an elevation above the mixing chamber.
- A seal carried within an upper portion of the housing seals around the tubing. Gripping members carried by the housing grip an outer diameter of the tubing.
- The injection fluid intake passage may include a plenum located below and in fluid communication with the mixing chamber. An upper injection fluid intake passage portion joins the tubing intake and extends within the housing alongside the mixing chamber to the plenum.
- The tubing intake may include an intake chamber for receiving fluid discharged by the tubing. The tubing intake may also include a throat passage of smaller diameter than the intake chamber and extending downward from the intake chamber. In addition, optionally, a diverging passage extends downward from the throat passage and is in fluid communication with the injection fluid passage.
-
FIG. 1 is a schematic view illustrating a well having an injection system in accordance with this disclosure. -
FIG. 2 is a cross-sectional view of the injector sub of the system ofFIG. 1 . -
FIG. 3 is a cross-sectional view of the injector sub ofFIG. 2 , showing a chemical being injected into the injector sub and well fluid being drawn into the sub. - Referring to
FIG. 1 , aninjection system 11 is employed in this example to facilitate the production of gas in a well. The well includes acasing 13 that optionally may have avertical portion 13 a and an inclined orhorizontal portion 13 b.Horizontal portion 13 b hasperforations 15 into which wellfluid 17 flows.Well fluid 17 includesgas 19 as well asliquid 21; principally water, but possibly condensate or liquid hydrocarbons. Depending upon the formation pressure of the well,liquid 21 will flow partially up thevertical portion 13 a ofcasing 13, reaching alevel 22.Gas 19 will flow fromperforations 15 intohorizontal portion 13 b and up casingvertical portion 13 a to the surface. Theliquid 21 flowing throughperforations 15 begins to build up within casinghorizontal portion 13 b.Gas 19 may still continue to flow as it will bubble throughliquid 21 and upcasing 13. However, the buildup ofliquid 21 impedes the amount of gas that can be produced. A significant level ofliquid 21 in casingvertical portion 13 a could stop the flow of gas fromperforations 15. - Casing 13 is supported at the surface by a
casing hanger 23 and seal. Hanger andseal 23 engage awellhead member 25 located at the surface. Wellheadmember 25 serves as a production tree and has a lateral flow port with awing valve 27 for flowing gas to production facilities. - A
chemical injector 29 is suspended in casingvertical portion 13 a.Injector 29 is a tubular sub that preferably has a lower portion submerged withinliquid 21 and an upper portion abovelevel 22.Injector 29 may have aweight bar 30 connected to its lower end to provide additional weight for lowering it intocasing 13. In this example,injector 29 is much smaller in diameter than the inner diameter ofcasing 13. For example, it may be only about 1.8 inches in outer diameter while the inner diameter ofcasing 13 would typically be greater than five inches. There is no packer or seal utilized in this example for sealing the annular space betweeninjector 29 andcasing 13. - The weight of
injector 29 is supported by a smallcapillary tube 31 that extends upward towellhead 25.Tube 31 is employed tolower injector 29 intocasing 13 as well as pump a chemical down.Tube 31 is preferably a metal tube, such as stainless steel, of dimensions that may be in a range from 0.25 to 0.375 inches in outer diameter. Atubing hanger 33, shown schematically, supportstube 31 andinjector 29.Tubing hanger 33 mounts to or withinwellhead member 25 and may be of a type for supporting a string of tubing in the well. In this example, production tubing is not employed; rathergas 19 flows upcasing 13. Alternately, production tubing could be installed, in whichcase injector 29 would be lowered through the production tubing to a point within casing 13 below the production tubing.Gas 19 would flow up the production tubing in that instance. -
Tube 31 extends throughtubing hanger 33 and over to apump 35, which may be a conventional type, such as a positive displacement pump.Pump 35 has its intake within a reservoir oraccumulator 37 that contains aninjection fluid chemical 36, which in this example comprises a liquid foaming agent. The foaming agent may be a conventional type utilized to provide foam within wells, such as a surfactant. Acontroller 39 controls the operation ofpump 35.Pump 35 has the capability of applying a significant amount of pressure, such as 5000 psi greater than the pressure of the well whereinjector 29 is located. - Referring to
FIG. 2 ,injector 29 includes ahousing 41, which may be formed of several components secured together.Housing 41 has ahead member 43 with avertical tube passage 45 extending through it.Tube 31 extends throughtube passage 45 and is sealed by atube seal 47. Aseal nut 49, when tightened, energizestube seal 47 to seal aroundtube 31. A set of tube slips 51 is mounted belowtube seal 47. Tube slips 51 comprise gripping members with teeth on the inner sides thatgrip tube 31 to support the weight ofinjector 29. A slipsnut 53 when tightened causes tube slips 51 to tightly grip the outer diameter oftube 31. - An
intermediate housing member 55 is secured by threads to headmember 43.Intermediate housing member 55 has atube intake chamber 57 in fluid communication with the interior oftube 31 for receiving injection fluid. A smaller diameter orthroat portion 59 joins a lower end oftube intake chamber 55. Avalve seat 60 joins thethroat portion 59.Valve seat 60 is conical and diverges outward in this example. Pump downtube 31 passes intotube intake chamber 57 and terminates abovethroat portion 59. Acheck valve 61 mounts belowthroat portion 59 for engagingvalve seat 60. Checkvalve 61 is upwardly spring biased to a closed position and can be set to open at a selected pressure fromtube 31. When the pressure of the fluid flowing downtube 31 is below the selected pressure,check valve 61 will be closed. - A
lower housing member 63 secures by threads tointermediate housing member 55.Lower housing member 63 has acylindrical cavity 64 with a closed base or bottom 66. A cylindrical mixingmember 65 is located withincavity 64.Lower housing member 63 has one or more well fluid intake ports 67 (two shown) that are preferably angled upward and inward. Wellfluid intake ports 67 are intended to be belowliquid level 22.Lower housing member 63 also has one or more mixed fluid outlet ports 69 (two shown). Mixedfluid outlet ports 69 may angle upward and outward and are preferably located aboveliquid level 22. - Mixing
member 65 has at least one injection fluid passage 71 (two shown) extending from its upper end to its lower end.Injection fluid passages 71 are parallel to the axis ofinjector 29 and spaced circumferentially apart from each other around the axis ofinjector 29. The upper ends of injectionfluid passages 71 are open whencheck valve 61 is open and closed whencheck valve 61 is closed. The lower ends of injectionfluid passages 71 lead to aplenum 73 located betweenlower housing bottom 66 and the bottom of mixingmember 65. - A
nozzle 75 mounts to the bottom of mixingmember 65 and points upward.Nozzle 75 is shown as a two-piece member secured by aretainer ring 76. Other configurations fornozzle 75 are feasible.Nozzle 75 has apassage 77 extending through it that is in communication withplenum 73. - Mixing
member 65 has at least one and preferably more than one wellfluid intake passages 79. Wellfluid intake passages 79 register with agallery 80, which is an annular groove surrounding mixingmember 65.Gallery 80 is in communication with wellfluid intake ports 67 inlower housing 63. Wellfluid intake passages 79 extend inward and upward. Mixingmember 65 also has at least one mixedfluid discharge passage 81, and two are shown. Mixedfluid discharge passages 81 also extend to a gallery surrounding mixingmember 65 so that they will register with mixedfluid outlet ports 69. The inclination of mixedfluid outlet ports 69 and mixedfluid discharge passages 81 are the same in this example. Mixedfluid discharge passages 81 extend upward and outward from an upper portion of a central throat or mixing chamber 83 within mixingmember 65. Mixing chamber 83 is simply a cylindrical passage without any elements within in it. The inclinations of wellfluid intake passages 79 are also the same as inclinations of wellfluid intake ports 67 in this example. Wellfluid intake passages 79 extend to a lower portion of mixing chamber 83 below injectionfluid discharge passages 81. The outlet ofnozzle 75 is located within a lower portion of mixing chamber 83, thus is in communication with fluid flowing into wellfluid intake passages 79.Annular seals 85 extend around mixingmember 65 and are positioned to seal to the inner diameter oflower housing member 63 above and below eachgallery 80. - The cumulative flow area of the well
fluid intake passages 79 is preferably greater than the flow area of mixing chamber 83. Also, preferably the cumulative flow area of the mixed fluid discharge passages is greater than the flow area of mixing chamber 83. The flow area ofnozzle 75 is less than the flow area of mixing chamber 83. - In operation, the operator will lower
injector 29 ontube 31 andsecure tube 31 withtubing hanger 33. If wellhead pressure exists, the operator may need to employ a lubricator and other pressure control equipment. The operator will positioninjector 29 with itsoutlet ports 69 aboveliquid level 22 andintake ports 67 belowliquid level 22. -
Controller 39 will be set to periodically turn onpump 35 to inject a chemical 36, which in this example, comprises a foaming agent. The intermittent initiation ofpump 35 and the shutting off ofpump 35 may be based on a timer or on a sensing mechanism to sense thelevel 22 of liquid. Oncepump 35 is turned on, it will pumpliquid foaming agent 36 downtube 31. When the pressure frompump 31 reaches a preset amount, such as 1500 psi, it will cause check valve 61 (FIG. 2 ) to open. The preset amount is selected to be above the well pressure at wellfluid inlet ports 67 ofinjector 29. Then, as illustrated inFIG. 3 , liquid foaming agent will pass down injectionfluid passages 71 intoplenum 73 and upnozzle 75. Preferably controller 39 (FIG. 1 ) will continue to causepump 35 to operate until the pressure at the lower end oftube 31 increases significantly above the well pressure atinjector 29, such as to 6500 psi. - The high pressure foaming agent being injected out of
nozzle 75 flows through mixing chamber 83 and outoutlet passages 81 andoutlet ports 69. The discharge ofnozzle 75 causes a dynamic pressure drop. This flow operates on a venturi principle, inducing the flow of well fluid 17 into mixing chamber 83 throughinlet ports 67 andintake passages 79. The well fluid 17 and foamingagent 36 mix within mixing chamber 83 and discharge out mixedfluid outlet ports 69 aboveliquid level 22. The mixing of foamingagent 36 with well fluid 17 creates a foaming action as illustrated inFIG. 3 . The foam facilitates the production of gas by loweringliquid level 22 and reducing the hydrostatic head incasing 13 by lightening the column of fluid incasing 13. Some of thegas 19 will flow up casing 13 without enteringinjector 29, and some gas will flow intoinjector 29 along withliquid 21.Foaming agent 36 mixed withliquid 21 and propelled by the upward flow ofgas 19 flows up casing 13 towellhead 25. At the surface, separation equipment, not shown, removes foamingagent 36 and liquid 21 fromgas 19, which is then further processed. Becauseliquid 21 becomes a foam that flows up casing 13, the process removes liquid from casing 13. -
Controller 39 may be preset to turn off thepump 35 and the injection of foamingagent 36 for a selected time. During this off duty time,liquid level 22 will gradually build back up.Controller 39 will then turn onpump 35 for another cycle. -
Injector 29 could also be utilized in wells to inject chemicals other than foaming agents.Injector 29 could be employed in wells that produce oil rather than significant amounts of gas. The various chemicals could be employed not only to remove fluid from the well, but also treat salt accumulations, paraffin build-up and corrosion and scale. - While the disclosure has been shown in only one of its forms, it should be apparent to those skilled in the art that it is not so limited but is susceptible to various changes without departing from the scope of the disclosure.
Claims (20)
1. A fluid injection apparatus for a well, comprising:
a housing;
a tubing mounting mechanism associated with the housing for securing the housing to a string of tubing to lower the housing into a well;
a tubing intake in the housing in fluid communication with an interior of the tubing;
a mixing chamber located in the housing;
an injection fluid inlet passage extending from the tubing intake to a lower end of the mixing chamber for discharging an injection fluid pumped down the tubing into the mixing chamber;
a well fluid intake passage leading from an exterior of the housing to the mixing chamber, the well fluid intake passage having an entrance selected to be below a liquid level in the well, so that well fluid is induced to flow into the mixing chamber where it mixes with the injection fluid being pumped down the tubing, creating a mixed fluid; and
a mixed fluid passage extending from the mixing chamber to the exterior of the housing for discharging the mixed fluid exterior of the housing.
2. The apparatus according to claim 1 , further comprising:
a nozzle at an end of the injection fluid inlet passage opposite the tubing intake and joining the mixing chamber, the nozzle having a flow area smaller than a flow area of the mixing chamber.
3. The apparatus according to claim 1 , further comprising:
a check valve in the injection fluid inlet passage between the tubing intake and the mixing chamber, the check valve being biased to a closed position that prevents flow from the tubing intake to the mixing chamber unless a selected pressure of the injection fluid is reached.
4. The apparatus according to claim 1 , wherein the entrance of the well fluid intake passage is at an elevation below the mixing chamber.
5. The apparatus according to claim 1 , wherein the mixed fluid passage has an outlet at an elevation above the mixing chamber.
6. The apparatus according to claim 1 , wherein the tubing mounting mechanism comprises:
a seal carried within an upper portion of the housing for sealing around the tubing; and
a plurality of gripping members carried by the housing to grip an outer diameter of the tubing.
7. The apparatus according to claim 1 , wherein the injection fluid intake passage comprises:
a plenum located below and in fluid communication with the mixing chamber; and
an upper injection fluid intake passage portion joining the tubing intake and extending within the housing alongside the mixing chamber to the plenum.
8. The apparatus according to claim 1 , wherein the tubing intake comprises:
an intake chamber for receiving fluid discharged by the tubing;
a throat passage of smaller diameter than the intake chamber and extending downward from the intake chamber;
a diverging passage extending downward from the throat passage; and
wherein an upper end of the injection fluid passage is in fluid communication with the diverging passage.
9. A fluid injection apparatus for a well, comprising:
a string of tubing adapted to be suspended in a well;
a housing having an upper portion and a lower portion;
a tubing mounting mechanism associated with the upper portion of the housing for securing the housing to the string of tubing;
a tubing intake in the upper portion of the housing in fluid communication with an interior of the tubing;
a mixing member having a cylindrical exterior and located within a cylindrical interior of the lower portion of the housing;
a mixing chamber located in the mixing member;
an injection fluid inlet passage extending from the tubing intake through the mixing member alongside the mixing chamber to a lower end of the mixing chamber for discharging an injection fluid pumped down the tubing into the mixing chamber;
at least one well fluid intake passage leading through the lower portion of the housing and through the mixing member to the mixing chamber, the well fluid intake passage having an entrance below the mixing chamber and selected to be below a liquid level in the well, so that well fluid is induced to flow into the mixing chamber where it mixes with the injection fluid being pumped down the tubing, creating a mixed fluid; and
at least one mixed fluid passage extending upward and outward from the mixing chamber through the mixing member and through the lower portion of the housing for discharging the mixed fluid exterior of the housing and above the entrance of the well fluid passage.
10. The apparatus according to claim 9 , wherein an outer diameter of the tubing is in a range from 0.25 to 0.375 inches.
11. The apparatus according to claim 9 , further comprising:
a nozzle at an end of the injection fluid inlet passage opposite the tubing intake and joining the mixing chamber, the nozzle having a flow area smaller than a flow area of the mixing chamber.
12. The apparatus according to claim 9 , further comprising:
a check valve in the injection fluid inlet passage between the tubing intake and the mixing chamber, the check valve being biased to a closed position that prevents flow from the tubing intake to the mixing chamber unless a selected pressure of the injection fluid is reached.
13. The apparatus according to claim 9 , wherein the tubing mounting mechanism comprises:
a seal carried within the upper portion of the housing that seals around the tubing; and
a plurality of gripping members carried by the housing that grip an outer diameter of the tubing.
14. The apparatus according to claim 9 , wherein the injection fluid inlet passage comprises:
a plenum located between a base of the lower portion of the housing and a bottom of the mixing member in fluid communication with the mixing chamber; and
an upper injection fluid inlet passage portion joining the tubing intake and extending within the housing alongside the mixing chamber to the plenum.
15. The apparatus according to claim 9 , wherein the tubing intake comprises:
an intake chamber for receiving fluid discharged by the tubing;
a throat passage of smaller diameter than the intake chamber and extending downward from the intake chamber;
a diverging passage extending downward from the throat passage; and
wherein an upper end of the injection fluid inlet passage is in fluid communication with the diverging passage.
16. The apparatus according to claim 9 , wherein:
said at least one well fluid intake passage comprises a plurality of the well fluid intake passages; and
said at least one mixed fluid discharge passages comprises a plurality of the mixed fluid discharge passages.
17. The apparatus according to claim 16 , wherein:
a total flow area of the well fluid intake passages exceeds a flow area of the mixing chamber; and
a total flow area of the mixed fluid discharge passages exceeds the flow area of the mixing chamber.
18. A method of removing liquid from a gas producing well, comprising:
providing an injection sub having a mixing chamber, an injection passage leading to a lower end of the mixing chamber, a well fluid intake passage leading from an exterior of the sub to the mixing chamber and a mixed fluid discharge passage leading from the mixing chamber to an exterior of the sub;
connecting the injection sub to a string of tubing and lowering the sub into the well to a point wherein an entrance of the well fluid intake passage is below a liquid level in the well;
pumping a foaming agent down the tubing and through the injection fluid intake passage into and through the mixing chamber and out the mixed fluid discharge passage into the well;
in response to the flow of foaming agent into the mixing chamber, inducing well fluid to flow into the well fluid intake passage and mix with the foaming agent in the mixing chamber as the foaming agent flows out the mixed fluid discharge passage; and
wherein the mixing of the foaming agent with the well fluid creates a foam that migrates up the well in an annulus surrounding the tubing.
19. The method according to claim 18 , wherein the well fluid is induced to flow into the well fluid intake passage by creating a lower dynamic pressure within the mixing chamber than a hydrostatic pressure of the well bore fluid at an entrance of the well fluid intake passage.
20. The method according to claim 18 , wherein the sub is lowered to a level that positions an outlet of the mixed fluid discharge passage above the liquid level.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/246,500 US20120073820A1 (en) | 2010-09-29 | 2011-09-27 | Chemical Injector for Wells |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US38787610P | 2010-09-29 | 2010-09-29 | |
US13/246,500 US20120073820A1 (en) | 2010-09-29 | 2011-09-27 | Chemical Injector for Wells |
Publications (1)
Publication Number | Publication Date |
---|---|
US20120073820A1 true US20120073820A1 (en) | 2012-03-29 |
Family
ID=45869458
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US13/246,500 Abandoned US20120073820A1 (en) | 2010-09-29 | 2011-09-27 | Chemical Injector for Wells |
Country Status (1)
Country | Link |
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US (1) | US20120073820A1 (en) |
Cited By (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP3109398A1 (en) * | 2015-06-26 | 2016-12-28 | Welltec A/S | Liquid unloading method and system |
US11008848B1 (en) | 2019-11-08 | 2021-05-18 | Forum Us, Inc. | Apparatus and methods for regulating flow from a geological formation |
US11421518B2 (en) * | 2017-07-21 | 2022-08-23 | Forum Us, Inc. | Apparatuses and systems for regulating flow from a geological formation, and related methods |
Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3884299A (en) * | 1972-12-11 | 1975-05-20 | Blount R E | Well pump for fluids and vapors |
US4988389A (en) * | 1987-10-02 | 1991-01-29 | Adamache Ion Ionel | Exploitation method for reservoirs containing hydrogen sulphide |
US5211242A (en) * | 1991-10-21 | 1993-05-18 | Amoco Corporation | Apparatus and method for unloading production-inhibiting liquid from a well |
US7455105B1 (en) * | 2005-08-08 | 2008-11-25 | Mckee Jim D | Apparatus and method for installing coiled tubing in a well |
US20090008101A1 (en) * | 2007-07-06 | 2009-01-08 | Coady Patrick T | Method of Producing a Low Pressure Well |
US20090145608A1 (en) * | 2007-11-09 | 2009-06-11 | Bjc Consulting Ltd. | Apparatus and method for deliquifying a well |
-
2011
- 2011-09-27 US US13/246,500 patent/US20120073820A1/en not_active Abandoned
Patent Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3884299A (en) * | 1972-12-11 | 1975-05-20 | Blount R E | Well pump for fluids and vapors |
US4988389A (en) * | 1987-10-02 | 1991-01-29 | Adamache Ion Ionel | Exploitation method for reservoirs containing hydrogen sulphide |
US5211242A (en) * | 1991-10-21 | 1993-05-18 | Amoco Corporation | Apparatus and method for unloading production-inhibiting liquid from a well |
US7455105B1 (en) * | 2005-08-08 | 2008-11-25 | Mckee Jim D | Apparatus and method for installing coiled tubing in a well |
US20090008101A1 (en) * | 2007-07-06 | 2009-01-08 | Coady Patrick T | Method of Producing a Low Pressure Well |
US20090145608A1 (en) * | 2007-11-09 | 2009-06-11 | Bjc Consulting Ltd. | Apparatus and method for deliquifying a well |
Cited By (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP3109398A1 (en) * | 2015-06-26 | 2016-12-28 | Welltec A/S | Liquid unloading method and system |
US11421518B2 (en) * | 2017-07-21 | 2022-08-23 | Forum Us, Inc. | Apparatuses and systems for regulating flow from a geological formation, and related methods |
US11008848B1 (en) | 2019-11-08 | 2021-05-18 | Forum Us, Inc. | Apparatus and methods for regulating flow from a geological formation |
US11686189B2 (en) | 2019-11-08 | 2023-06-27 | Forum Us, Inc. | Apparatus and methods for regulating flow from a geological formation |
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