US20060076145A1 - Gas lift using a gas/oil mixer - Google Patents
Gas lift using a gas/oil mixer Download PDFInfo
- Publication number
- US20060076145A1 US20060076145A1 US10/963,977 US96397704A US2006076145A1 US 20060076145 A1 US20060076145 A1 US 20060076145A1 US 96397704 A US96397704 A US 96397704A US 2006076145 A1 US2006076145 A1 US 2006076145A1
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- Prior art keywords
- gas
- tubular
- hydrocarbon
- bubbles
- wellbore
- Prior art date
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- Abandoned
Links
- 238000000034 method Methods 0.000 claims abstract description 39
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 33
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 33
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 20
- 230000002706 hydrostatic effect Effects 0.000 claims abstract description 4
- 238000004519 manufacturing process Methods 0.000 claims description 82
- 239000012530 fluid Substances 0.000 claims description 59
- 239000000654 additive Substances 0.000 claims description 30
- 239000003784 tall oil Substances 0.000 claims description 21
- 235000014113 dietary fatty acids Nutrition 0.000 claims description 14
- 229930195729 fatty acid Natural products 0.000 claims description 14
- 239000000194 fatty acid Substances 0.000 claims description 14
- 150000004665 fatty acids Chemical class 0.000 claims description 13
- 230000000996 additive effect Effects 0.000 claims description 11
- 150000001408 amides Chemical class 0.000 claims description 10
- 238000006243 chemical reaction Methods 0.000 claims description 4
- 230000001804 emulsifying effect Effects 0.000 claims description 4
- 150000004702 methyl esters Chemical class 0.000 claims description 4
- AKEJUJNQAAGONA-UHFFFAOYSA-N sulfur trioxide Chemical compound O=S(=O)=O AKEJUJNQAAGONA-UHFFFAOYSA-N 0.000 claims description 4
- 238000004945 emulsification Methods 0.000 claims description 3
- 125000004432 carbon atom Chemical group C* 0.000 claims description 2
- 239000004094 surface-active agent Substances 0.000 claims description 2
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims 1
- 239000007789 gas Substances 0.000 description 94
- 239000003921 oil Substances 0.000 description 16
- 235000019198 oils Nutrition 0.000 description 15
- 239000007795 chemical reaction product Substances 0.000 description 11
- 230000015572 biosynthetic process Effects 0.000 description 9
- 239000000203 mixture Substances 0.000 description 8
- ZBCBWPMODOFKDW-UHFFFAOYSA-N diethanolamine Chemical compound OCCNCCO ZBCBWPMODOFKDW-UHFFFAOYSA-N 0.000 description 7
- RSWGJHLUYNHPMX-UHFFFAOYSA-N Abietic-Saeure Natural products C12CCC(C(C)C)=CC2=CCC2C1(C)CCCC2(C)C(O)=O RSWGJHLUYNHPMX-UHFFFAOYSA-N 0.000 description 4
- KHPCPRHQVVSZAH-HUOMCSJISA-N Rosin Natural products O(C/C=C/c1ccccc1)[C@H]1[C@H](O)[C@@H](O)[C@@H](O)[C@@H](CO)O1 KHPCPRHQVVSZAH-HUOMCSJISA-N 0.000 description 4
- IMUDHTPIFIBORV-UHFFFAOYSA-N aminoethylpiperazine Chemical compound NCCN1CCNCC1 IMUDHTPIFIBORV-UHFFFAOYSA-N 0.000 description 4
- 238000002347 injection Methods 0.000 description 4
- 239000007924 injection Substances 0.000 description 4
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
- KHPCPRHQVVSZAH-UHFFFAOYSA-N trans-cinnamyl beta-D-glucopyranoside Natural products OC1C(O)C(O)C(CO)OC1OCC=CC1=CC=CC=C1 KHPCPRHQVVSZAH-UHFFFAOYSA-N 0.000 description 4
- 235000015112 vegetable and seed oil Nutrition 0.000 description 4
- 239000008158 vegetable oil Substances 0.000 description 4
- HZAXFHJVJLSVMW-UHFFFAOYSA-N 2-Aminoethan-1-ol Chemical compound NCCO HZAXFHJVJLSVMW-UHFFFAOYSA-N 0.000 description 3
- 239000004165 Methyl ester of fatty acids Substances 0.000 description 3
- 229920002873 Polyethylenimine Polymers 0.000 description 3
- 239000004568 cement Substances 0.000 description 3
- 238000006073 displacement reaction Methods 0.000 description 3
- 238000004821 distillation Methods 0.000 description 3
- 239000003995 emulsifying agent Substances 0.000 description 3
- 150000002148 esters Chemical class 0.000 description 3
- 235000019387 fatty acid methyl ester Nutrition 0.000 description 3
- 238000005086 pumping Methods 0.000 description 3
- 230000001105 regulatory effect Effects 0.000 description 3
- 238000013517 stratification Methods 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- GAWIXWVDTYZWAW-UHFFFAOYSA-N C[CH]O Chemical group C[CH]O GAWIXWVDTYZWAW-UHFFFAOYSA-N 0.000 description 2
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- VZCYOOQTPOCHFL-OWOJBTEDSA-N Fumaric acid Chemical compound OC(=O)\C=C\C(O)=O VZCYOOQTPOCHFL-OWOJBTEDSA-N 0.000 description 2
- 239000002253 acid Substances 0.000 description 2
- 150000007513 acids Chemical class 0.000 description 2
- 235000019864 coconut oil Nutrition 0.000 description 2
- 239000003240 coconut oil Substances 0.000 description 2
- 239000000839 emulsion Substances 0.000 description 2
- 238000012544 monitoring process Methods 0.000 description 2
- 239000003345 natural gas Substances 0.000 description 2
- 230000000750 progressive effect Effects 0.000 description 2
- 239000000376 reactant Substances 0.000 description 2
- 229920006395 saturated elastomer Polymers 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- -1 C20 fatty acids Chemical class 0.000 description 1
- 239000004952 Polyamide Substances 0.000 description 1
- NIXOWILDQLNWCW-UHFFFAOYSA-N acrylic acid group Chemical group C(C=C)(=O)O NIXOWILDQLNWCW-UHFFFAOYSA-N 0.000 description 1
- 235000020661 alpha-linolenic acid Nutrition 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000006227 byproduct Substances 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- 229910002092 carbon dioxide Inorganic materials 0.000 description 1
- 230000005465 channeling Effects 0.000 description 1
- 230000006835 compression Effects 0.000 description 1
- 238000007906 compression Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000032050 esterification Effects 0.000 description 1
- 238000005886 esterification reaction Methods 0.000 description 1
- 150000002193 fatty amides Chemical class 0.000 description 1
- 239000010685 fatty oil Substances 0.000 description 1
- 239000006260 foam Substances 0.000 description 1
- 239000001530 fumaric acid Substances 0.000 description 1
- 239000007792 gaseous phase Substances 0.000 description 1
- 150000002462 imidazolines Chemical class 0.000 description 1
- 235000020778 linoleic acid Nutrition 0.000 description 1
- OYHQOLUKZRVURQ-HZJYTTRNSA-N linoleic acid group Chemical group C(CCCCCCC\C=C/C\C=C/CCCCC)(=O)O OYHQOLUKZRVURQ-HZJYTTRNSA-N 0.000 description 1
- 125000005481 linolenic acid group Chemical group 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- FPYJFEHAWHCUMM-UHFFFAOYSA-N maleic anhydride Chemical compound O=C1OC(=O)C=C1 FPYJFEHAWHCUMM-UHFFFAOYSA-N 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 229920002647 polyamide Polymers 0.000 description 1
- 239000011347 resin Substances 0.000 description 1
- 229920005989 resin Polymers 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 125000001424 substituent group Chemical group 0.000 description 1
- 150000003871 sulfonates Chemical class 0.000 description 1
- VZCYOOQTPOCHFL-UHFFFAOYSA-N trans-butenedioic acid Natural products OC(=O)C=CC(O)=O VZCYOOQTPOCHFL-UHFFFAOYSA-N 0.000 description 1
- 235000021122 unsaturated fatty acids Nutrition 0.000 description 1
- 150000004670 unsaturated fatty acids Chemical class 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/0078—Nozzles used in boreholes
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/122—Gas lift
Definitions
- Embodiments of the present invention generally relate to artificially lifting fluid from a wellbore. More particularly, embodiments of the present invention relate to artificially lifting fluid from a wellbore using a gas lift system.
- a wellbore is drilled into the earth to intersect an area of interest within a formation.
- the wellbore may then be “completed” by inserting casing within the wellbore and setting the casing therein using cement.
- the wellbore may remain uncased (an “open hole wellbore”), or may become only partially cased.
- production tubing is typically run into the wellbore primarily to convey production fluid (e.g., hydrocarbon fluid, which may also include water) from the area of interest within the wellbore to the surface of the wellbore.
- Sucker rod lifting systems generally include a surface drive mechanism, a sucker rod string, and a downhole positive displacement pump. Fluid is brought to the surface of the wellbore by pumping action of the downhole pump, as dictated by the drive mechanism attached to the rod string.
- PCP progressive cavity pump
- sucker rod lifting system is a rod lift system, with which fluid is brought to the surface of the wellbore by reciprocating pumping action of the drive mechanism attached to the rod string. Reciprocating pumping action moves a traveling valve on the positive displacement pump, loading it on the down-stroke of the rod string and lifting fluid to the surface on the up-stroke of the rod string.
- Sucker rod lifting systems include several moving mechanical components. Specifically, the rod strings of sucker rod lifting systems must be reciprocated or rotated to operate the lifting systems. In some applications, the moving parts are disadvantageous. When a subsurface safety valve is employed within the wellbore, such as within an offshore well, a sucker rod string cannot be placed through the subsurface safety valve. Additionally, moving parts are susceptible to failure or damage, potentially causing the sucker rod lifting systems to become inoperable.
- An alternative lift system is a gas lift system.
- compressed gas G is injected into an annulus 15 between the outer diameter of production tubing 20 and the inner diameter of casing 25 within the wellbore 30 .
- a valve system 35 supplies injection gas G and allows produced fluid to exit the gas lift system 10 .
- the production tubing 20 typically has gas lift mandrels 40 thereon having gas lift valves 45 therein.
- the gas lift valves 45 are used to allow or disallow gas flow from the annulus 15 into the production tubing 20 .
- a production packer 50 located at a lower end of the production tubing 20 forces the flow of production fluid P from a reservoir or zone of interest in a formation 55 up through the production tubing 20 instead of up through the annulus 15 .
- production fluid P flows from the formation 55 into the wellbore 30 through perforations 60 through the casing 25 and the formation 55 .
- the production fluid P flows into the production tubing 20 .
- compressed gas G is introduced into the annulus 15 .
- Any of the gas lift valves 45 which are in the open position allow the gas G to flow into the production tubing 20 through an opening in the gas lift mandrel 40 to lift the production fluid P to the surface of the wellbore 30 .
- the injected gas G lowers the hydrostatic pressure in the production tubing 20 to re-establish the required pressure differential between the reservoir and the wellbore 30 , thereby causing the production fluid P to flow to the surface of the wellbore 30 .
- Gas lift systems are often the preferred artificial lifting systems because fewer moving parts exist during the operation of the gas lift systems than during the operation of sucker rod lift systems. Moreover, gas lift systems are sometimes preferred over sucker rod lift systems because no sucker rod is required in the operation of gas lift systems. Because a sucker rod is not used in operating the gas lift system, the gas lift system is usable in offshore wells having subsurface safety valves.
- gas lift systems are advantageous in most applications, wells which contain heavier production fluid P (such as heavier oil) are often not effectively served using typical gas lift systems.
- heavier production fluid P such as heavier oil
- typical gas lift systems When heaver oil is present in the well, the gas G tends to channel up the inner diameter of the production tubing 20 .
- the channeling of the gas G causes a stratified flow of fluid up the production tubing 20 , as the heavier oil sticks against the wall of the production tubing 20 and the gas G flows rapidly up the center portion of the production tubing 20 through the stuck oil.
- Embodiments of the present invention provide methods of producing hydrocarbon.
- the method includes introducing the hydrocarbons into a tubular for transport to a surface and introducing a gas into the tubular, wherein the gas is introduced as miniature bubbles for mixing with the hydrocarbon.
- the method also includes mixing the bubbles with the hydrocarbons, thereby reducing a hydrostatic pressure in the tubular and flowing the hydrocarbons toward the surface.
- the gas is introduced at one or more gas lift entry points along the tubular.
- the gas is introduced to the tubular using a mixing device.
- the mixing device is adapted to form the miniature bubbles.
- the gas comprises one or more additives for creating smaller or miniaturized bubbles.
- the gas comprises one or more additives for emulsifying the gas and the hydrocarbon.
- a method of producing hydrocarbon comprises flowing hydrocarbon through a tubular for transport to a surface; introducing gas into the tubular; and generating small bubbles for mixing with the hydrocarbon.
- the method also includes increasing a pressure differential between an exterior of the tubular and the interior of the tubular and moving the hydrocarbon toward the surface.
- the method also includes increasing a concentration of the gas adjacent a wall of the tubular.
- the gas is introduced using a device selected from the group consisting of venturi nozzle and a vortex nozzle.
- FIG. 1 shows a typical gas lifting system
- FIG. 2 shows an embodiment of a gas lift system of the present invention.
- FIG. 3 is a sectional view of the gas lift system of FIG. 2 .
- FIG. 3A is a cross-sectional view of the mixing device of the gas lift system of FIG. 2 .
- Embodiments of the present invention include methods and apparatuses for lifting production fluid using a gas lift system.
- Embodiments of the present invention are capable of lifting the production fluid by preventing the stratification of the gas and the production fluid while flowing up through production tubing.
- embodiments of the present invention are especially useful to lift heavier oil production fluid without stratification of the flow.
- FIG. 2 shows a first embodiment of a gas lift system 110 for artificially lifting production fluid P using a compressed gas G.
- the compressed gas G is injected into an annulus 115 between the outer diameter of production tubing 120 and the inner diameter of casing 125 (or the inner diameter of the wellbore 130 , in the case of an open hole wellbore) by a valve system 135 disposed at a surface of the wellbore 130 .
- the valve system 135 includes a gas injection inlet 114 regulated by a valve 117 which controls gas G flow into the annulus 115 .
- valve system 135 Also included in the valve system 135 is a production fluid outlet 113 through which production fluid P exits the gas lift system 110 , regulated by a valve 116 which controls production fluid P flow exiting the gas lift system 110 .
- valves 116 and 117 may include an in-line orifice choke, which is a calibrated, adjustable choke for regulating injection gas or production fluid flow.
- either or both of the valves 116 , 117 may include pneumatic motor valves.
- a pressure gauge 112 may be included with the valve system 135 to indicate the pressure within the gas lift system 110 .
- a wellbore 130 formed in an earth formation 155 by a drilling device such as a drill bit.
- the wellbore 130 shown in FIG. 2 is a cased wellbore, as casing 125 is located within the wellbore 130 and set by cement 184 .
- One or more perforations 160 extend through the casing 125 , cement 184 , and wellbore 130 to allow production fluid P to flow from the formation 155 into the wellbore 130 .
- a cased wellbore is shown in FIG. 2 , it is contemplated that the wellbore may be an open hole wellbore.
- Production tubing 120 is disposed within the inner diameter of the casing 125 .
- One or more sealing elements 150 are disposed at a portion of the production tubing 120 to seal the annulus 115 so that production fluid P flows from the wellbore 130 up into the inner diameter of the production tubing 120 , rather than flowing up through the annulus 115 .
- one or more mixing devices 180 are disposed at one or more locations of the production tubing 120 .
- the mixing devices 180 are adapted to cause the compressed gas G and the production fluid P to form a mixture M.
- the mixing device 180 is adapted to introduce small or “miniaturized” bubbles into the production tubing 120 to mix with the production fluid P. It is believed that these miniature bubbles provide several advantages for increasing the efficiency of the gas lift system 110 . For example, because smaller bubbles have a larger surface area to volume ratio, smaller bubbles offer more surface area for contacting the production fluid. Another advantage is that smaller bubbles require a longer time period to coalesce into larger bubbles, thus allowing more bubbles to mix with the production fluid.
- FIG. 3 shows an exemplary mixing device 180 suitable for supplying small bubbles to the production tubing 120 to provide a better gas and production fluid mixture.
- the mixing devices 180 may be housed within one or more side pocket mandrels 122 .
- the mixing device 180 is preferably generally concentric around the production tubing 120 .
- Each mixing device 180 includes a gas inlet passage 181 therethrough to allow the gas G to enter from the annulus 115 into the mixing device 180 .
- a one way valve 183 or check valve may be used to prevent production fluid P from flowing into the annulus 115 .
- the production tubing 120 has a gas inlet passage 182 therethrough to allow the gas to enter the production tubing 120 and mix with the production fluid P within the production tubing 120 .
- the mixing device 180 comprises a nozzle 186 adapted to form the small bubbles in the production tubing 120 .
- FIG. 3A is a cross-sectional view of the mixing device 180 . Although four nozzles 186 are shown arranged around the tubing 120 , one or more nozzles 186 may be used. Suitable mixing devices include a venturi nozzle, a vortex venturi, or any other mixing devices capable of creating small bubbles into the production tubing. In another aspect, the mixing device 186 may inject the gas into the production tubing 120 with sufficient velocity or energy such that a turbulent flow is created in the adjacent areas. The turbulent flow acts like an agitator to bring more gas into contact with the oil, thereby increasing gas saturation.
- the turbulent flow alone or in combination with the smaller bubbles, promotes the formation of a more homogeneous gas and oil mixture.
- the gas may be injected with sufficient energy to form an emulsion with the oil. As a result, more oil will be lifted toward the surface.
- compressed gas G is injected through the gas injection inlet 114 into the annulus 115 by manipulating the valve 117 into the open position.
- the valve system 135 may be controlled electronically or optically by a surface monitoring and control unit (not shown) to control and monitor the amount of gas G supplied into the annulus 115 and the amount of gas needed to lift the production fluid P.
- the surface monitoring and control unit may operate at the well site or by remote telemetry and may be used to control an individual well or multiple gas lift wells.
- the compressed gas G may be natural gas obtained from the well into which it is injected or from another well, and may be obtained as high pressure natural gas from the well or from a compression source. Other suitable gases such as nitrogen, carbon dioxide, and other compressed gases known to a person of ordinary skill in the art may be used to lighten the oil.
- the compressed gas G enters the mixing device 180 through the one way valve 183 .
- the mixing device 180 injects the gas into the production fluid such that small bubbles are formed to increase mixing of the gas and the production fluid.
- the increased saturation of the gas in the production fluid will resist the stratification of the production fluid flow, thereby causing more production fluid to be lifted toward the surface.
- additional mixing devices may be disposed at one or more gas lift entry points along the production tubing 120 to optimally lift the production fluids to the surface.
- additives may be employed to facilitate the formation of small bubbles.
- the additives may also promote a better mixing of the gas and the production fluid.
- additives such as surfactants may be added to the gas at the surface.
- Exemplary additives such as sulfur trioxide or sulfonates may be added to the gas to help wet the gas for mixing. It is contemplated any additive suitable for causing the gas to form smaller bubbles as is known to a person of ordinary skill in the art may be used.
- the additives When the additives are injected into the tubing 120 along with the gas, the additives may cause emulsification of the gas with the oil, thereby preventing the oil from separating from the gas and sticking to the walls of the tubing.
- the emulsion generated from the gas bubbles dispersed in the oil creates a foam.
- the additives may be utilized separately from or in combination with mechanically generated small bubbles to increase the efficiency of the gas lift system. Also, the additives may be added in the gaseous phase, liquid phase, or combinations thereof.
- Additives may also include emulsifiers that may be classified as amido-esters or esterified amides.
- exemplary emulsifiers include oxidized mixtures of vegetable oils, saponified tall oils, crude tall oil oils, distilled tall oil oils, and polyacids thermally produced from the vegetable oils or tall oil fatty acids of linolenic or linoleic acids. They may also be non-oxidized.
- the additives may be modified. Exemplary modified additives include acrylic adducts or maleic adducts and the like. They may be combinations of the above.
- the additives may further include mixed amido-esters and distilled talls.
- additives include fumaric acid, maleic anhydride modified bis amides or polyamides, the fumaric or maleic adducts of imidazolines, and combinations thereof.
- the additive is formed by the sequential reaction and subsequent distillation of a tall oil fatty acid having a moderately low rosin content with a fatty alkanolamide, preferably in the presence of methyl ester of fatty acids, and most preferably when further reacted with an emulsifier such as coconut oil diethanolamide or an amide of aminoethylpiperazine (AEP) under distillation conditions facilitating the removal of water and lighter reaction byproducts.
- an emulsifier such as coconut oil diethanolamide or an amide of aminoethylpiperazine (AEP)
- Fatty acids suitable for use in the compositions of the additive include, for example, disproportionated tall oil fatty acids; distilled tall oil; disproportionated tall oil; resin acids and rosin acids; rosin tall oil; and combinations thereof.
- Tall oil fatty acids having from 8 to 24 carbon atoms are preferred, with tall oil fatty acids having C 12 , C 14 , C 16 , C 18 , and C 20 fatty acids being most preferred.
- Amide/esters that are suitable for use in the compositions of the additive include, for example, N,N-bis (hydroxyethyl) tall oil fatty amides; reaction products of rosin with diethanolamine; and reaction products of tall oil fatty acids with diethanolamine.
- the preferred amides for use are most preferably made using diethanolamine (DEA), monoethanolamine (MEA), and other hydroxyethylamines that can undergo low temperature esterification and then interchange during the distillation.
- Amides suitable for use as additives include the reaction product of vegetable oil and an alkanolamine, the reaction product of vegetable oil with a polyethylene amine, the reaction product fo distilled tall oil with AEP, and the reaction product of distilled tall oil with a polyethylene amine, for example, N,N-bis (hydroxyethyl) saturated and unsaturated C 8-18 and C 18 amides; reaction products of coconut oil with diethanolamine; and reaction products of these substituents with AEP and other polyethylene amine homologues.
- Methyl esters suitable for use in the compositions of the additive include, for example, methyl esters of C 16-18 saturated and C 18 unsaturated fatty acids, and methyl esters of tall oil fatty acids.
- the additive comprises from about 45 to about 90 weight percent of the reaction product of tall oil fatty acid and a fatty alkanolamide, reacted in the presence of from about 5 to about 25 weight percent methyl ester of fatty acids, then further reacted and distilled in the presence of from about 5 to about 30 weight percent of the reaction product of a fatty oil with an alkanolamine.
- the combined weight of the fatty acid and amide/ester components preferably ranges from about 55 to about 90 weight percent of the total reactants, and the ratio of fatty acid to amide/ester desirably ranges from about 2:1 to about 3:2.
- the fatty alkanolamide is the reaction product of distilled tall oil and diethanolamine
- the distilled tall oil and diethanolamine are preferably reacted in a ratio of about 3:1 by weight.
- from about 5 to about 25 weight percent of methyl ester of fatty acids is also added to the initial reactants.
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- Geology (AREA)
- Mining & Mineral Resources (AREA)
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- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
A method of producing hydrocarbon includes introducing the hydrocarbons into a tubular for transport to a surface and introducing a gas into the tubular, wherein the gas is introduced as miniature bubbles for mixing with the hydrocarbon. The method also includes mixing the bubbles with the hydrocarbons, thereby reducing a hydrostatic pressure in the tubular and flowing the hydrocarbons toward the surface. In one embodiment, the gas is introduced at one or more gas lift entry points along the tubular.
Description
- 1. Field of the Invention
- Embodiments of the present invention generally relate to artificially lifting fluid from a wellbore. More particularly, embodiments of the present invention relate to artificially lifting fluid from a wellbore using a gas lift system.
- 2. Description of the Related Art
- To obtain hydrocarbon fluids from an earth formation, a wellbore is drilled into the earth to intersect an area of interest within a formation. The wellbore may then be “completed” by inserting casing within the wellbore and setting the casing therein using cement. In the alternative, the wellbore may remain uncased (an “open hole wellbore”), or may become only partially cased. Regardless of the form of the wellbore, production tubing is typically run into the wellbore primarily to convey production fluid (e.g., hydrocarbon fluid, which may also include water) from the area of interest within the wellbore to the surface of the wellbore.
- Often, pressure within the wellbore is insufficient to cause the production fluid to naturally rise through the production tubing to the surface of the wellbore. Thus, to carry the production fluid from the area of interest within the wellbore to the surface of the wellbore, artificial lift means is sometimes necessary.
- Some artificially-lifted wells are equipped with sucker rod lifting systems. Sucker rod lifting systems generally include a surface drive mechanism, a sucker rod string, and a downhole positive displacement pump. Fluid is brought to the surface of the wellbore by pumping action of the downhole pump, as dictated by the drive mechanism attached to the rod string.
- One type of sucker rod lifting system is a rotary positive displacement pump, typically termed a progressive cavity pump (“PCP”). The progressive cavity pump lifts production fluid by a rotor disposed within a stator. The rotor rotates relative to the stator by use of a sucker rod string.
- An additional type of sucker rod lifting system is a rod lift system, with which fluid is brought to the surface of the wellbore by reciprocating pumping action of the drive mechanism attached to the rod string. Reciprocating pumping action moves a traveling valve on the positive displacement pump, loading it on the down-stroke of the rod string and lifting fluid to the surface on the up-stroke of the rod string.
- Sucker rod lifting systems include several moving mechanical components. Specifically, the rod strings of sucker rod lifting systems must be reciprocated or rotated to operate the lifting systems. In some applications, the moving parts are disadvantageous. When a subsurface safety valve is employed within the wellbore, such as within an offshore well, a sucker rod string cannot be placed through the subsurface safety valve. Additionally, moving parts are susceptible to failure or damage, potentially causing the sucker rod lifting systems to become inoperable.
- An alternative lift system is a gas lift system. In a typical
gas lift system 10 shown inFIG. 1 , compressed gas G is injected into anannulus 15 between the outer diameter ofproduction tubing 20 and the inner diameter ofcasing 25 within thewellbore 30. Avalve system 35 supplies injection gas G and allows produced fluid to exit thegas lift system 10. - The
production tubing 20 typically hasgas lift mandrels 40 thereon havinggas lift valves 45 therein. Thegas lift valves 45 are used to allow or disallow gas flow from theannulus 15 into theproduction tubing 20. Aproduction packer 50 located at a lower end of theproduction tubing 20 forces the flow of production fluid P from a reservoir or zone of interest in a formation 55 up through theproduction tubing 20 instead of up through theannulus 15. - In operation, production fluid P flows from the formation 55 into the
wellbore 30 throughperforations 60 through thecasing 25 and the formation 55. The production fluid P flows into theproduction tubing 20. When it is desired to lift the production fluid P with gas G, compressed gas G is introduced into theannulus 15. Any of thegas lift valves 45 which are in the open position allow the gas G to flow into theproduction tubing 20 through an opening in thegas lift mandrel 40 to lift the production fluid P to the surface of thewellbore 30. The injected gas G lowers the hydrostatic pressure in theproduction tubing 20 to re-establish the required pressure differential between the reservoir and thewellbore 30, thereby causing the production fluid P to flow to the surface of thewellbore 30. - Gas lift systems are often the preferred artificial lifting systems because fewer moving parts exist during the operation of the gas lift systems than during the operation of sucker rod lift systems. Moreover, gas lift systems are sometimes preferred over sucker rod lift systems because no sucker rod is required in the operation of gas lift systems. Because a sucker rod is not used in operating the gas lift system, the gas lift system is usable in offshore wells having subsurface safety valves.
- Although gas lift systems are advantageous in most applications, wells which contain heavier production fluid P (such as heavier oil) are often not effectively served using typical gas lift systems. When heaver oil is present in the well, the gas G tends to channel up the inner diameter of the
production tubing 20. The channeling of the gas G causes a stratified flow of fluid up theproduction tubing 20, as the heavier oil sticks against the wall of theproduction tubing 20 and the gas G flows rapidly up the center portion of theproduction tubing 20 through the stuck oil. - Because of these difficulties with using a
gas lift system 10 to lift heavier oil up theproduction tubing 20 for production, gas lift systems are often not utilized when a well contains heavier production fluid P. Therefore, historically, sucker rod lifting systems commonly are resorted to, despite the problems inherent with these sucker rod systems described above, when it is desired to lift heavier production fluid P from a well. - Therefore, it would be advantageous to provide a gas lift system capable of effectively lifting heavier production fluid from a well. It would be further beneficial to provide a gas lift system capable of lifting production fluid from a well without a stratified flow of gas and production fluid ensuing, regardless of the weight of the production fluid.
- Embodiments of the present invention provide methods of producing hydrocarbon. In one embodiment, the method includes introducing the hydrocarbons into a tubular for transport to a surface and introducing a gas into the tubular, wherein the gas is introduced as miniature bubbles for mixing with the hydrocarbon. The method also includes mixing the bubbles with the hydrocarbons, thereby reducing a hydrostatic pressure in the tubular and flowing the hydrocarbons toward the surface. In another embodiment, the gas is introduced at one or more gas lift entry points along the tubular.
- In another embodiment, the gas is introduced to the tubular using a mixing device. Preferably, the mixing device is adapted to form the miniature bubbles.
- In yet another embodiment, the gas comprises one or more additives for creating smaller or miniaturized bubbles.
- In yet another embodiment, the gas comprises one or more additives for emulsifying the gas and the hydrocarbon.
- In another embodiment, a method of producing hydrocarbon comprises flowing hydrocarbon through a tubular for transport to a surface; introducing gas into the tubular; and generating small bubbles for mixing with the hydrocarbon. The method also includes increasing a pressure differential between an exterior of the tubular and the interior of the tubular and moving the hydrocarbon toward the surface.
- In yet another embodiment, the method also includes increasing a concentration of the gas adjacent a wall of the tubular.
- In yet another embodiment, the gas is introduced using a device selected from the group consisting of venturi nozzle and a vortex nozzle.
- So that the manner in which the above recited features of the present invention can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments of this invention and are therefore not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments.
-
FIG. 1 shows a typical gas lifting system. -
FIG. 2 shows an embodiment of a gas lift system of the present invention. -
FIG. 3 is a sectional view of the gas lift system ofFIG. 2 . -
FIG. 3A is a cross-sectional view of the mixing device of the gas lift system ofFIG. 2 . - Embodiments of the present invention include methods and apparatuses for lifting production fluid using a gas lift system. Embodiments of the present invention are capable of lifting the production fluid by preventing the stratification of the gas and the production fluid while flowing up through production tubing. In particular, embodiments of the present invention are especially useful to lift heavier oil production fluid without stratification of the flow.
-
FIG. 2 shows a first embodiment of agas lift system 110 for artificially lifting production fluid P using a compressed gas G. The compressed gas G is injected into anannulus 115 between the outer diameter ofproduction tubing 120 and the inner diameter of casing 125 (or the inner diameter of thewellbore 130, in the case of an open hole wellbore) by avalve system 135 disposed at a surface of thewellbore 130. Thevalve system 135 includes agas injection inlet 114 regulated by avalve 117 which controls gas G flow into theannulus 115. Also included in thevalve system 135 is aproduction fluid outlet 113 through which production fluid P exits thegas lift system 110, regulated by avalve 116 which controls production fluid P flow exiting thegas lift system 110. Either or both of thevalves valves pressure gauge 112 may be included with thevalve system 135 to indicate the pressure within thegas lift system 110. - Extending below the
valve system 135 is awellbore 130 formed in anearth formation 155 by a drilling device such as a drill bit. Thewellbore 130 shown inFIG. 2 is a cased wellbore, as casing 125 is located within thewellbore 130 and set by cement 184. One ormore perforations 160 extend through thecasing 125, cement 184, and wellbore 130 to allow production fluid P to flow from theformation 155 into thewellbore 130. Although a cased wellbore is shown inFIG. 2 , it is contemplated that the wellbore may be an open hole wellbore. -
Production tubing 120 is disposed within the inner diameter of thecasing 125. One ormore sealing elements 150, preferably production packers, are disposed at a portion of theproduction tubing 120 to seal theannulus 115 so that production fluid P flows from thewellbore 130 up into the inner diameter of theproduction tubing 120, rather than flowing up through theannulus 115. - In one aspect, one or
more mixing devices 180 are disposed at one or more locations of theproduction tubing 120. The mixingdevices 180 are adapted to cause the compressed gas G and the production fluid P to form a mixture M. In one embodiment, themixing device 180 is adapted to introduce small or “miniaturized” bubbles into theproduction tubing 120 to mix with the production fluid P. It is believed that these miniature bubbles provide several advantages for increasing the efficiency of thegas lift system 110. For example, because smaller bubbles have a larger surface area to volume ratio, smaller bubbles offer more surface area for contacting the production fluid. Another advantage is that smaller bubbles require a longer time period to coalesce into larger bubbles, thus allowing more bubbles to mix with the production fluid. It is also believed that smaller bubbles tend to accumulate near the wall of thetubing 120 while larger bubbles migrate toward the center. Therefore, the smaller bubbles are more adapted to mix with the production fluid near the wall, thereby preventing the stratified flow of gas and production fluid. It must be noted that realization of one or more of these advantages are not prerequisites for the operation of various embodiments of the present invention, and therefore do not limit embodiments of the present invention. -
FIG. 3 shows anexemplary mixing device 180 suitable for supplying small bubbles to theproduction tubing 120 to provide a better gas and production fluid mixture. As shown, the mixingdevices 180 may be housed within one or moreside pocket mandrels 122. Themixing device 180 is preferably generally concentric around theproduction tubing 120. Eachmixing device 180 includes agas inlet passage 181 therethrough to allow the gas G to enter from theannulus 115 into themixing device 180. A oneway valve 183 or check valve may be used to prevent production fluid P from flowing into theannulus 115. Additionally, theproduction tubing 120 has agas inlet passage 182 therethrough to allow the gas to enter theproduction tubing 120 and mix with the production fluid P within theproduction tubing 120. In one embodiment, themixing device 180 comprises anozzle 186 adapted to form the small bubbles in theproduction tubing 120.FIG. 3A is a cross-sectional view of themixing device 180. Although fournozzles 186 are shown arranged around thetubing 120, one ormore nozzles 186 may be used. Suitable mixing devices include a venturi nozzle, a vortex venturi, or any other mixing devices capable of creating small bubbles into the production tubing. In another aspect, themixing device 186 may inject the gas into theproduction tubing 120 with sufficient velocity or energy such that a turbulent flow is created in the adjacent areas. The turbulent flow acts like an agitator to bring more gas into contact with the oil, thereby increasing gas saturation. In this respect, the turbulent flow, alone or in combination with the smaller bubbles, promotes the formation of a more homogeneous gas and oil mixture. In yet another embodiment, the gas may be injected with sufficient energy to form an emulsion with the oil. As a result, more oil will be lifted toward the surface. - In operation, referring to both
FIGS. 1 and 2 , compressed gas G is injected through thegas injection inlet 114 into theannulus 115 by manipulating thevalve 117 into the open position. Thevalve system 135 may be controlled electronically or optically by a surface monitoring and control unit (not shown) to control and monitor the amount of gas G supplied into theannulus 115 and the amount of gas needed to lift the production fluid P. The surface monitoring and control unit may operate at the well site or by remote telemetry and may be used to control an individual well or multiple gas lift wells. - The compressed gas G may be natural gas obtained from the well into which it is injected or from another well, and may be obtained as high pressure natural gas from the well or from a compression source. Other suitable gases such as nitrogen, carbon dioxide, and other compressed gases known to a person of ordinary skill in the art may be used to lighten the oil. The compressed gas G enters the
mixing device 180 through the oneway valve 183. In turn, themixing device 180 injects the gas into the production fluid such that small bubbles are formed to increase mixing of the gas and the production fluid. In this respect, the increased saturation of the gas in the production fluid will resist the stratification of the production fluid flow, thereby causing more production fluid to be lifted toward the surface. In some instances, additional mixing devices may be disposed at one or more gas lift entry points along theproduction tubing 120 to optimally lift the production fluids to the surface. - In another embodiment, additives may be employed to facilitate the formation of small bubbles. The additives may also promote a better mixing of the gas and the production fluid. For example, additives such as surfactants may be added to the gas at the surface. Exemplary additives such as sulfur trioxide or sulfonates may be added to the gas to help wet the gas for mixing. It is contemplated any additive suitable for causing the gas to form smaller bubbles as is known to a person of ordinary skill in the art may be used. When the additives are injected into the
tubing 120 along with the gas, the additives may cause emulsification of the gas with the oil, thereby preventing the oil from separating from the gas and sticking to the walls of the tubing. In some cases, the emulsion generated from the gas bubbles dispersed in the oil creates a foam. It must be noted that the additives may be utilized separately from or in combination with mechanically generated small bubbles to increase the efficiency of the gas lift system. Also, the additives may be added in the gaseous phase, liquid phase, or combinations thereof. - Additives may also include emulsifiers that may be classified as amido-esters or esterified amides. Exemplary emulsifiers include oxidized mixtures of vegetable oils, saponified tall oils, crude tall oil oils, distilled tall oil oils, and polyacids thermally produced from the vegetable oils or tall oil fatty acids of linolenic or linoleic acids. They may also be non-oxidized. Further, the additives may be modified. Exemplary modified additives include acrylic adducts or maleic adducts and the like. They may be combinations of the above. The additives may further include mixed amido-esters and distilled talls.
- Other examples of additives include fumaric acid, maleic anhydride modified bis amides or polyamides, the fumaric or maleic adducts of imidazolines, and combinations thereof.
- Other suitable additives are disclosed in U.S. Pat. No. 6,194,361; U.S. Pat. No. 6,489,272; and U.S. patent application Publication No. 2003/0092580, which patents and/or application have been assigned to the assignee of the present application and are herein incorporated by reference in their entirety.
- In one embodiment, the additive is formed by the sequential reaction and subsequent distillation of a tall oil fatty acid having a moderately low rosin content with a fatty alkanolamide, preferably in the presence of methyl ester of fatty acids, and most preferably when further reacted with an emulsifier such as coconut oil diethanolamide or an amide of aminoethylpiperazine (AEP) under distillation conditions facilitating the removal of water and lighter reaction byproducts.
- Fatty acids suitable for use in the compositions of the additive include, for example, disproportionated tall oil fatty acids; distilled tall oil; disproportionated tall oil; resin acids and rosin acids; rosin tall oil; and combinations thereof. Tall oil fatty acids having from 8 to 24 carbon atoms are preferred, with tall oil fatty acids having C12, C14, C16, C18, and C20 fatty acids being most preferred.
- Amide/esters that are suitable for use in the compositions of the additive include, for example, N,N-bis (hydroxyethyl) tall oil fatty amides; reaction products of rosin with diethanolamine; and reaction products of tall oil fatty acids with diethanolamine. The preferred amides for use are most preferably made using diethanolamine (DEA), monoethanolamine (MEA), and other hydroxyethylamines that can undergo low temperature esterification and then interchange during the distillation.
- Amides suitable for use as additives include the reaction product of vegetable oil and an alkanolamine, the reaction product of vegetable oil with a polyethylene amine, the reaction product fo distilled tall oil with AEP, and the reaction product of distilled tall oil with a polyethylene amine, for example, N,N-bis (hydroxyethyl) saturated and unsaturated C8-18 and C18 amides; reaction products of coconut oil with diethanolamine; and reaction products of these substituents with AEP and other polyethylene amine homologues.
- Methyl esters suitable for use in the compositions of the additive include, for example, methyl esters of C16-18 saturated and C18 unsaturated fatty acids, and methyl esters of tall oil fatty acids.
- In another embodiment, the additive comprises from about 45 to about 90 weight percent of the reaction product of tall oil fatty acid and a fatty alkanolamide, reacted in the presence of from about 5 to about 25 weight percent methyl ester of fatty acids, then further reacted and distilled in the presence of from about 5 to about 30 weight percent of the reaction product of a fatty oil with an alkanolamine. The combined weight of the fatty acid and amide/ester components preferably ranges from about 55 to about 90 weight percent of the total reactants, and the ratio of fatty acid to amide/ester desirably ranges from about 2:1 to about 3:2. Where the fatty alkanolamide is the reaction product of distilled tall oil and diethanolamine, the distilled tall oil and diethanolamine are preferably reacted in a ratio of about 3:1 by weight. According to a preferred embodiment of the invention, from about 5 to about 25 weight percent of methyl ester of fatty acids is also added to the initial reactants.
- While the foregoing is directed to embodiments of the present invention, other and further embodiments of the invention may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.
Claims (30)
1. A method of producing hydrocarbons, comprising:
introducing the hydrocarbons into a tubular for transport to a surface;
injecting a gas around the outer diameter of the tubular;
introducing the gas into the inner diameter of the tubular, wherein the gas is introduced as miniature bubbles for mixing with the hydrocarbon;
mixing the bubbles with the hydrocarbons, thereby reducing a hydrostatic pressure in the tubular; and
flowing the hydrocarbons toward the surface.
2. The method of claim 1 , wherein the gas is introduced through a mixing device.
3. The method of claim 2 , wherein the mixing device is adapted to form the miniature bubbles.
4. The method of claim 3 , wherein the miniature bubbles increase the saturation of the gas in the hydrocarbon.
5. The method of claim 1 , wherein the gas comprises one or more additives.
6. The method of claim 1 , further comprising emulsifying the gas and the hydrocarbon.
7. The method of claim 6 , further comprising adding an additive to facilitate the emulsification process.
8. The method of claim 1 , further comprising generating a turbulent flow in the tubular.
9. The method of claim 1 , wherein the gas is introducing at multiple entry points along the tubular.
10. The method of claim 1 , wherein the tubular comprises production tubing.
11. The method of claim 1 , wherein the hydrocarbon is a component of a production fluid.
12. The method of claim 11 , further comprising emulsifying the gas and the production fluid.
13. A method of producing hydrocarbon, comprising:
flowing hydrocarbon through a tubular for transport to a surface;
introducing gas into an annular space around the outer diameter of the tubular;
generating miniature bubbles in a mixer located in the wall of the tubular for mixing with the hydrocarbon;
increasing a pressure differential between an exterior of the tubular and the interior of the tubular; and
moving the hydrocarbon toward the surface.
14. The method of claim 13 , further comprising increasing a concentration of the gas adjacent a wall of the tubular.
15. The method of claim 13 , further comprising increasing a concentration of the gas away from a well center.
16. The method of claim 13 , further comprising emulsifying the gas and the hydrocarbon.
17. The method of claim 16 , further comprising adding an additive to facilitate the emulsification process.
18. The method of claim 17 , wherein the additive is selected from the group consisting of a sulfur trioxide, a sulfonate, a surfactant, and combinations thereof.
19. The method of claim 17 , wherein the additive comprises an amido-ester or esterified amide.
20. The method of claim 17 , wherein the additive comprises a product from a reaction of a tall oil fatty acid and a fatty alkanolamide.
21. The method of claim 20 , wherein the reaction further includes a methyl ester.
22. The method of claim 20 , wherein the tall oil fatty acids has between 8 and 24 carbon atoms.
23. The method of claim 13 , further comprising generating a turbulent flow in the tubular.
24. The method of claim 13 , wherein the gas is introducing at multiple entry points along the tubular.
25. The method of claim 13 , wherein the gas is introduced using a device selected from the group consisting of venturi nozzle and a vortex nozzle.
26. The method of claim 13 , wherein the gas comprises one or more additives.
27-29. (canceled)
30. The method of producing hydrocarbons described in claim 2 , wherein the mixing device is in fluid communication with an annulus between the outer diameter of the tubular and the inner diameter of a casing.
31. The method of producing hydrocarbons described in claim 13 , wherein the mixing device is in fluid communication with the annulus.
32. An apparatus for producing hydrocarbons comprising:
a tubular for use in a wellbore;
a mixing device for generating miniature bubbles, the mixing device in fluid communication with an annulus between the outer diameter of the tubular and the inner diameter of the wellbore.
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
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US10/963,977 US20060076145A1 (en) | 2004-10-13 | 2004-10-13 | Gas lift using a gas/oil mixer |
CA002522416A CA2522416A1 (en) | 2004-10-13 | 2005-10-06 | Gas lift using a gas/oil mixer |
BRPI0504602-5A BRPI0504602A (en) | 2004-10-13 | 2005-10-11 | gas lift using a gas / oil mixture |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
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US10/963,977 US20060076145A1 (en) | 2004-10-13 | 2004-10-13 | Gas lift using a gas/oil mixer |
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US20060076145A1 true US20060076145A1 (en) | 2006-04-13 |
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US10/963,977 Abandoned US20060076145A1 (en) | 2004-10-13 | 2004-10-13 | Gas lift using a gas/oil mixer |
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US (1) | US20060076145A1 (en) |
BR (1) | BRPI0504602A (en) |
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CN113304664A (en) * | 2021-05-31 | 2021-08-27 | 广州蓝涛水处理有限公司 | Emulsification device optimized through high-frequency ultrasonic action and laminar flow sedimentation |
US11242733B2 (en) * | 2019-08-23 | 2022-02-08 | Baker Hughes Oilfield Operations Llc | Method and apparatus for producing well with backup gas lift and an electrical submersible well pump |
US11939848B1 (en) * | 2022-12-20 | 2024-03-26 | Saudi Arabian Oil Company | Nitrogen lift in wells |
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US11242733B2 (en) * | 2019-08-23 | 2022-02-08 | Baker Hughes Oilfield Operations Llc | Method and apparatus for producing well with backup gas lift and an electrical submersible well pump |
CN111322040A (en) * | 2020-03-16 | 2020-06-23 | 西安诚科石油工程技术服务有限公司 | Water-producing gas well full-life-cycle drainage gas production method and system |
CN113304664A (en) * | 2021-05-31 | 2021-08-27 | 广州蓝涛水处理有限公司 | Emulsification device optimized through high-frequency ultrasonic action and laminar flow sedimentation |
US11939848B1 (en) * | 2022-12-20 | 2024-03-26 | Saudi Arabian Oil Company | Nitrogen lift in wells |
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CA2522416A1 (en) | 2006-04-13 |
BRPI0504602A (en) | 2006-05-23 |
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