CA2731037A1 - Coiled tubing deployed esp - Google Patents
Coiled tubing deployed esp Download PDFInfo
- Publication number
- CA2731037A1 CA2731037A1 CA2731037A CA2731037A CA2731037A1 CA 2731037 A1 CA2731037 A1 CA 2731037A1 CA 2731037 A CA2731037 A CA 2731037A CA 2731037 A CA2731037 A CA 2731037A CA 2731037 A1 CA2731037 A1 CA 2731037A1
- Authority
- CA
- Canada
- Prior art keywords
- well
- coiled tubing
- sealing means
- tubing
- esp
- 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
- 239000012530 fluid Substances 0.000 claims abstract description 28
- 238000007789 sealing Methods 0.000 claims abstract description 17
- 238000004891 communication Methods 0.000 claims abstract description 8
- 238000005086 pumping Methods 0.000 claims abstract description 7
- 238000009434 installation Methods 0.000 description 4
- 241000191291 Abies alba Species 0.000 description 2
- 229910000831 Steel Inorganic materials 0.000 description 1
- 230000004888 barrier function Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 230000002706 hydrostatic effect Effects 0.000 description 1
- 239000000314 lubricant Substances 0.000 description 1
- 238000000034 method Methods 0.000 description 1
- 238000012856 packing Methods 0.000 description 1
- 230000001012 protector Effects 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
- 238000011282 treatment Methods 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
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
- E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
- E21B23/14—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
-
- 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
- E21B43/128—Adaptation of pump systems with down-hole electric drives
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Structures Of Non-Positive Displacement Pumps (AREA)
Abstract
A well pumping system is provided comprising a length of coiled tubing extending to the surface of the well, a first electric pump and a first electric motor, and a sealing means that seals against the side of the well. The sealing means include a first fluid path through which coiled tubing is in fluid communication with the well beneath the sealing means, and a second fluid path through which first electric pump is in fluid communication with the well beneath the sealing means.
Description
Coiled Tubing Deployed ESP
This invention relates to Electric Submersible Pumps that can be deployed on a length of coiled tubing.
Electrical submersible pumps are commonly used in oil and gas wells for producing large volumes of production fluid. An electrical submersible pump (hereinafter referred to "ESP") normally has a centrifugal pump with a large number of stages of impellers and diffusers. The pump is driven by a downhole motor, which is a large three-phase motor. A seal section separates the motor from the pump to equalise the internal pressure of lubricant within the motor to the pressure of the well bore. Often, additional components will be included, such as a gas separator, a sand separator and a pressure and temperature measuring module.
An ESP is normally installed by securing it to a string of production tubing and lowering the ESP assembly into the well. Production tubing is made up of sections of pipe, each being about 30 feet in length. The well will be `dead', that is not be capable of flowing under its own pressure, while the pump and tubing are lowered into the well. To prevent the possibility of a blowout, a kill fluid may be loaded in the well, the kill fluid having a weight that provides a hydrostatic pressure significantly greater than that of the formation pressure.
In normal operations it is desirable to access the reservoir below the ESP to perform a production log to determine where the different fluids are flowing from and perform treatments using coiled tubing to either stimulate a section of reservoir or seal a section of the reservoir producing too much water.
Coiled tubing has been used for a number of years for deploying various tools in wells, including wells that are live. A pressure controller, often referred to as a stripper and blowout preventer, is mounted at the upper end of the well to seal around the coiled tubing while the coiled tubing is moving into or out of the well. The coiled tubing comprises steel tubing that wraps around a large reel. An injector grips the coiled tubing and forces it from the reel into the well.
It is an objective of this invention to be able to provide an electric submersible pump banded to the coiled tubing and lowered into a well.
Another objective is to be able to access the well below the ESP via the bore of the coiled tubing while the ESP is running.
Another objective is to have a conventional sub surface safety valve in the ESP
discharge flow path Another objective is to have multi barriers in the coiled tubing to ensure it does not provide a leak path to surface.
Another objective is to install two pumps in parallel to either double the production capability of the well or provide redundancy.
This invention relates to Electric Submersible Pumps that can be deployed on a length of coiled tubing.
Electrical submersible pumps are commonly used in oil and gas wells for producing large volumes of production fluid. An electrical submersible pump (hereinafter referred to "ESP") normally has a centrifugal pump with a large number of stages of impellers and diffusers. The pump is driven by a downhole motor, which is a large three-phase motor. A seal section separates the motor from the pump to equalise the internal pressure of lubricant within the motor to the pressure of the well bore. Often, additional components will be included, such as a gas separator, a sand separator and a pressure and temperature measuring module.
An ESP is normally installed by securing it to a string of production tubing and lowering the ESP assembly into the well. Production tubing is made up of sections of pipe, each being about 30 feet in length. The well will be `dead', that is not be capable of flowing under its own pressure, while the pump and tubing are lowered into the well. To prevent the possibility of a blowout, a kill fluid may be loaded in the well, the kill fluid having a weight that provides a hydrostatic pressure significantly greater than that of the formation pressure.
In normal operations it is desirable to access the reservoir below the ESP to perform a production log to determine where the different fluids are flowing from and perform treatments using coiled tubing to either stimulate a section of reservoir or seal a section of the reservoir producing too much water.
Coiled tubing has been used for a number of years for deploying various tools in wells, including wells that are live. A pressure controller, often referred to as a stripper and blowout preventer, is mounted at the upper end of the well to seal around the coiled tubing while the coiled tubing is moving into or out of the well. The coiled tubing comprises steel tubing that wraps around a large reel. An injector grips the coiled tubing and forces it from the reel into the well.
It is an objective of this invention to be able to provide an electric submersible pump banded to the coiled tubing and lowered into a well.
Another objective is to be able to access the well below the ESP via the bore of the coiled tubing while the ESP is running.
Another objective is to have a conventional sub surface safety valve in the ESP
discharge flow path Another objective is to have multi barriers in the coiled tubing to ensure it does not provide a leak path to surface.
Another objective is to install two pumps in parallel to either double the production capability of the well or provide redundancy.
According to the present invention, there is provided a well pumping system comprising a length of coiled tubing extending to the surface of the well a first electric pump and a first electric motor a sealing means that seals against the side of the well the sealing means wherein the sealing means include a first fluid path through which coiled tubing is in fluid communication with the well beneath the sealing means, and a second fluid path through which first electric pump is in fluid communication with the well beneath the sealing means.
The following figures will be used to describe embodiments of the invention.
Figure 1 is a side view of the well from surface to total depth, showing the ESP
relative to the coiled tubing, well tubing, wellhead and wiring.
Figure 2 is a side view of the well from surface to total depth, showing the ESP
relative to the coiled tubing, well tubing, wellhead and wiring, and in addition the inclusion of a sub surface safety valve in the downstream path from the ESP.
Figure 3 is a similar view to Fig 2 with the reservoir being accessed below the ESP by a wireline logging tool via the inside of the coiled tubing.
Figure 4 is a similar view to Fig 2 with the reservoir being accessed below the ESP by a coiled tubing work string via the inside of the coiled tubing.
The following figures will be used to describe embodiments of the invention.
Figure 1 is a side view of the well from surface to total depth, showing the ESP
relative to the coiled tubing, well tubing, wellhead and wiring.
Figure 2 is a side view of the well from surface to total depth, showing the ESP
relative to the coiled tubing, well tubing, wellhead and wiring, and in addition the inclusion of a sub surface safety valve in the downstream path from the ESP.
Figure 3 is a similar view to Fig 2 with the reservoir being accessed below the ESP by a wireline logging tool via the inside of the coiled tubing.
Figure 4 is a similar view to Fig 2 with the reservoir being accessed below the ESP by a coiled tubing work string via the inside of the coiled tubing.
Figure 5 is a side view of the ESP banded to the coiled tubing.
Figure 6 is a side view of a two ESP installation, one stacked on top of the other each having individual inlets from the reservoir and a common discharge into the production tubing surrounding the ESP's and external to the coiled tubing.
Figure 7 is a plan view of the single ESP installation.
Figure 8 is a plan view of the tandem ESP installation.
Figure 9 is a side view of the coiled tubing and sub surface safety valve arrangement situated at a suitable depth below surface.
Referring to figure 1, the ESP system comprises an electric motor 22 and electric pump 24 suspended on a length of coiled tubing 20 which extends down a well tubing 30, hanging from a well head 25. The end of the coiled tubing 20 and the electric pump 24 terminate in a stinger 26.
In order to install the ESP system, electric motor 22, electric pump 24 are secured to the coiled tubing 20, and stinger 26 is secured to the ends of the electric pump 24 and coiled tubing 20, and the whole system is lowered down the well tubing 30 on the coiled tubing until the stinger 26 abuts against a locating profile 45. As the system is lowered, a power cable 32 supplying the motor is banded to the coiled tubing and is terminated in a wellhead in a conventional manor. When the stinger 26 has located in the well tubing, the When the stinger 26 has located in the well tubing, the top of the coiled tubing is secured on a tubing hanger in tubing portthe Christmas tree upper flange 37.
The stinger 26 includes a sealing means 72 which seals against the well tubing 30. The stinger also features a double bore through which the coiled tubing 20 and the inlet 27 of the pump 24 extend through into the reservoir beneath the stinger. The coiled tubing includes upper and lower seals 41, 42 which block its inner bore. As will be described in more detail later, these seals may be removable.
Once the stinger 26 has engaged with the locating profile 45, the electric motor 22 and electric pump 24 may be activated to pump well bore fluids from the reservoir beneath the stinger up through the inside of the well tubing 30 above the stinger and the outside of the coiled tubing 20 to the wellhead to exit through a side port 39 of the Christmas tree.
Referring to figure 2, the ESP system may also include a sub-surface safety valve (SSSV). In this embodiment, an SSSV 41 is attached to the coiled tubing 20 (ideally before the ESP system is deployed down the well) at an intermediate region of the ESP system, by a packer 36. In a similar manner to the stinger 26, the packer 36 seals against the well tubing 30, and has two bores, one of which the coiled tubing 20 extends through, and one of which the SSSV extends through. The packer 36 also has an electrical feedthrough for the power cable 32. The SSSV 41 is controlled via a SSSV control line 52 which exits the wellhead, for example through the power cable portits own bulkhead. An additional seal 44 is provided in the coiled tubing 20 in the region of the SSSV. In a similar way as previously described, production fluid may be pumped through the pump inlet 27 from beneath the stringer 26, through the pump 24, up the well bore to the packer, through the SSSV 41, and out through the side port 39. Where an emergency where the well has to be closed off, for example where the surface production facilities fail, the SSSV
may be activated so that the well bore is closed off.
The SSSV 41 is shown in more detail in figure 9. The SSSV 41 has a packer portion 64 has a first bore 68 which constrains fluid communication in the well casing tubing 30 (not including the separate fluid path of the coiled tubing 20) through the safety valve means 65, and a second bore 69 through which the fluid path of the coiled tubing 20 passes. O-ringsrubber packing elements 63 seal the packer 64 against the side of the well casingtubing 30. When the valve means 65 is activated, the fluid path through the well casing tubing by the flapper valve 70 (not including the coiled tubing) is blocked. This figure also shows a profile 67 into which the seal 44 is located; the other seals 42, 43, may be located in similar profiles.
Referring to figure 3, tools such as a logging tool 47 may be run down the well through the coiled tubing 20. To insert the tool 47, a lubricator 50 is attached to the coiled tubing port, and the tool 47 pumped lowered through the coiled tubing whilst attached to a wireline paid out from reels reel (not shown) over pulleys 21. The seals 42, 43, 44 in the coiled tubing are removed in some manner, for example by retrieval through the coiled tubing 20 from the surface using a GS fishing tool. The tool is then lowered past the end of the coiled tubing 20 as far as desired. The tool may be winched up and removed from the well simply by reversing the operation. The seals 42, 43 44 (or replacement seals) are then lowered or dropped down the coiled tubing 20 to their original position. Production fluid may still be pumped through the ESP system during the installation of the tool 47 in the well.
Referring to figure 4, a second length of coiled tubing 60, having a smaller bore diameter than the bore of the coiled tubing 20, may be introduced into the coiled tubing 20 through the coiled tubing port 37 using a coiled tubing injector 31. As for the previous example, the seals 42, 43, 44 are removed before or during the introduction of the second coiled tubing 54 60 through the first coiled tubing 20. The second length of coiled tubing may extended down through the end of the coiled tubing 20 to a lower part of the well. The coiled tubing 54 60 may for example be used to inject fluid or gas at a lower part of the well. The coiled tubing 54 60 may of course be removed from the well simply by reversing the operation. As for the previous example, the seals 42, 43, 44 in coiled tubing 20 may be replaced by various known methods.
Referring now to figure 6, a second electric motor 55, motor protector 53 and electric pump 54 may be included in the ESP system. In this embodiment, the inlet 57 of the pump 54 ports onto the side of the coiled tubing 20 through a Y-tool 59. An additional retrievable seal 46 is included in the coiled tubing 20, immediately above where the second pump 54 ports onto the coiled tubing 20.
The electric motor 55, and electric pump 54 are powered by a second power cable 58. If an SSSV is included, the power cable 58 extends through an electrical feedthrough together with power cable 32.
Figure 6 is a side view of a two ESP installation, one stacked on top of the other each having individual inlets from the reservoir and a common discharge into the production tubing surrounding the ESP's and external to the coiled tubing.
Figure 7 is a plan view of the single ESP installation.
Figure 8 is a plan view of the tandem ESP installation.
Figure 9 is a side view of the coiled tubing and sub surface safety valve arrangement situated at a suitable depth below surface.
Referring to figure 1, the ESP system comprises an electric motor 22 and electric pump 24 suspended on a length of coiled tubing 20 which extends down a well tubing 30, hanging from a well head 25. The end of the coiled tubing 20 and the electric pump 24 terminate in a stinger 26.
In order to install the ESP system, electric motor 22, electric pump 24 are secured to the coiled tubing 20, and stinger 26 is secured to the ends of the electric pump 24 and coiled tubing 20, and the whole system is lowered down the well tubing 30 on the coiled tubing until the stinger 26 abuts against a locating profile 45. As the system is lowered, a power cable 32 supplying the motor is banded to the coiled tubing and is terminated in a wellhead in a conventional manor. When the stinger 26 has located in the well tubing, the When the stinger 26 has located in the well tubing, the top of the coiled tubing is secured on a tubing hanger in tubing portthe Christmas tree upper flange 37.
The stinger 26 includes a sealing means 72 which seals against the well tubing 30. The stinger also features a double bore through which the coiled tubing 20 and the inlet 27 of the pump 24 extend through into the reservoir beneath the stinger. The coiled tubing includes upper and lower seals 41, 42 which block its inner bore. As will be described in more detail later, these seals may be removable.
Once the stinger 26 has engaged with the locating profile 45, the electric motor 22 and electric pump 24 may be activated to pump well bore fluids from the reservoir beneath the stinger up through the inside of the well tubing 30 above the stinger and the outside of the coiled tubing 20 to the wellhead to exit through a side port 39 of the Christmas tree.
Referring to figure 2, the ESP system may also include a sub-surface safety valve (SSSV). In this embodiment, an SSSV 41 is attached to the coiled tubing 20 (ideally before the ESP system is deployed down the well) at an intermediate region of the ESP system, by a packer 36. In a similar manner to the stinger 26, the packer 36 seals against the well tubing 30, and has two bores, one of which the coiled tubing 20 extends through, and one of which the SSSV extends through. The packer 36 also has an electrical feedthrough for the power cable 32. The SSSV 41 is controlled via a SSSV control line 52 which exits the wellhead, for example through the power cable portits own bulkhead. An additional seal 44 is provided in the coiled tubing 20 in the region of the SSSV. In a similar way as previously described, production fluid may be pumped through the pump inlet 27 from beneath the stringer 26, through the pump 24, up the well bore to the packer, through the SSSV 41, and out through the side port 39. Where an emergency where the well has to be closed off, for example where the surface production facilities fail, the SSSV
may be activated so that the well bore is closed off.
The SSSV 41 is shown in more detail in figure 9. The SSSV 41 has a packer portion 64 has a first bore 68 which constrains fluid communication in the well casing tubing 30 (not including the separate fluid path of the coiled tubing 20) through the safety valve means 65, and a second bore 69 through which the fluid path of the coiled tubing 20 passes. O-ringsrubber packing elements 63 seal the packer 64 against the side of the well casingtubing 30. When the valve means 65 is activated, the fluid path through the well casing tubing by the flapper valve 70 (not including the coiled tubing) is blocked. This figure also shows a profile 67 into which the seal 44 is located; the other seals 42, 43, may be located in similar profiles.
Referring to figure 3, tools such as a logging tool 47 may be run down the well through the coiled tubing 20. To insert the tool 47, a lubricator 50 is attached to the coiled tubing port, and the tool 47 pumped lowered through the coiled tubing whilst attached to a wireline paid out from reels reel (not shown) over pulleys 21. The seals 42, 43, 44 in the coiled tubing are removed in some manner, for example by retrieval through the coiled tubing 20 from the surface using a GS fishing tool. The tool is then lowered past the end of the coiled tubing 20 as far as desired. The tool may be winched up and removed from the well simply by reversing the operation. The seals 42, 43 44 (or replacement seals) are then lowered or dropped down the coiled tubing 20 to their original position. Production fluid may still be pumped through the ESP system during the installation of the tool 47 in the well.
Referring to figure 4, a second length of coiled tubing 60, having a smaller bore diameter than the bore of the coiled tubing 20, may be introduced into the coiled tubing 20 through the coiled tubing port 37 using a coiled tubing injector 31. As for the previous example, the seals 42, 43, 44 are removed before or during the introduction of the second coiled tubing 54 60 through the first coiled tubing 20. The second length of coiled tubing may extended down through the end of the coiled tubing 20 to a lower part of the well. The coiled tubing 54 60 may for example be used to inject fluid or gas at a lower part of the well. The coiled tubing 54 60 may of course be removed from the well simply by reversing the operation. As for the previous example, the seals 42, 43, 44 in coiled tubing 20 may be replaced by various known methods.
Referring now to figure 6, a second electric motor 55, motor protector 53 and electric pump 54 may be included in the ESP system. In this embodiment, the inlet 57 of the pump 54 ports onto the side of the coiled tubing 20 through a Y-tool 59. An additional retrievable seal 46 is included in the coiled tubing 20, immediately above where the second pump 54 ports onto the coiled tubing 20.
The electric motor 55, and electric pump 54 are powered by a second power cable 58. If an SSSV is included, the power cable 58 extends through an electrical feedthrough together with power cable 32.
In normal use, this embodiment may be operated as for the previously described embodiments, with well fluid being drawn through the pump 24, and up through the well to the surface, whilst the coiled tubing 20 may have its seals 42, 43, 44, 46 removed so that tools 47 or narrow-boresmaller diameter coiled tubing 60 may be run down the coiled tubing 20. However, should a fault develop with the pump 24 or motor 22 which prevents the pump 24 from drawing well fluid, the seal 42 may be removed from the coiled tubing (which may involve removal and replacement of seals 43, 44, and 46) and second motor 55 activated so that the pump 54 draws well fluid through the end of the coiled tubing 20, past the stinger 26, into the pump 54 via the Y-tool 59, out of the pump outlet 58 71 and up through the well and out of the side port 39.
Claims (5)
1. A well pumping system comprising a length of coiled tubing extending to the surface of the well a first electric pump and a first electric motor a sealing means that seals against the side of the well the sealing means wherein the sealing means include a first fluid path through which coiled tubing is in fluid communication with the well beneath the sealing means, and a second fluid path through which first electric pump is in fluid communication with the well beneath the sealing means.
2. A well pumping system according to the previous claim wherein first electric pump and/or first electric motor are secured to the coiled tubing prior to deployment down the well.
3. A well pumping system according to either previous claim wherein the sealing means is secured to the first electric pump and coiled tubing prior to deployment down the well.
4. A well pumping system according to any previous claim wherein there is included a valve means above the sealing means and the electric motor and electric pump but beneath the surface of the well on the other, which can be activated to provide a seal against the side of the well and the outer surface of the coiled tube.
5. A well pumping system according to any previous claim wherein there is included a second electric pump and a second electric motor, the second electric pump being in fluid communication with the coiled tubing.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2731037A CA2731037A1 (en) | 2011-02-04 | 2011-02-04 | Coiled tubing deployed esp |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2731037A CA2731037A1 (en) | 2011-02-04 | 2011-02-04 | Coiled tubing deployed esp |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2731037A1 true CA2731037A1 (en) | 2012-08-04 |
Family
ID=46599575
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2731037A Abandoned CA2731037A1 (en) | 2011-02-04 | 2011-02-04 | Coiled tubing deployed esp |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA2731037A1 (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN111119836A (en) * | 2018-10-29 | 2020-05-08 | 中国石油化工股份有限公司 | Production fluid profile testing pipe column and method |
-
2011
- 2011-02-04 CA CA2731037A patent/CA2731037A1/en not_active Abandoned
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN111119836A (en) * | 2018-10-29 | 2020-05-08 | 中国石油化工股份有限公司 | Production fluid profile testing pipe column and method |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| US8950476B2 (en) | Coiled tubing deployed ESP | |
| US7677320B2 (en) | Subsea well with electrical submersible pump above downhole safety valve | |
| GB2477909A (en) | Coiled Tubing Deployed ESP | |
| US7753129B2 (en) | Wireline or coiled tubing deployed electric submersible pump | |
| AU2004203372B2 (en) | ROV retrievable sea floor pump | |
| US7717181B2 (en) | Artificial lift system | |
| US10428630B2 (en) | Apparatus, system and method for live well artificial lift completion | |
| US8261838B2 (en) | Artificial lift system | |
| EP2281999A2 (en) | BOP and separator combination | |
| NO20161876A1 (en) | Downhole equipment suspension and lateral power system | |
| US9874065B2 (en) | Dual stripper apparatus | |
| US10605056B2 (en) | System for installing an electrically submersible pump on a well | |
| CA2961469C (en) | Sea floor boost pump and gas lift system and method for producing a subsea well | |
| US12012824B2 (en) | Through-tubing electrical submersible pump for live wells and method of deployment | |
| CA2731037A1 (en) | Coiled tubing deployed esp | |
| CA2739109C (en) | Artificial lift system | |
| CA2573189C (en) | Artificial lift system |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| FZDE | Discontinued |
Effective date: 20160204 |