WO2017112506A2 - Integration of in-well wetmate esp motor connector with high pressure hydraulic line - Google Patents
Integration of in-well wetmate esp motor connector with high pressure hydraulic line Download PDFInfo
- Publication number
- WO2017112506A2 WO2017112506A2 PCT/US2016/066796 US2016066796W WO2017112506A2 WO 2017112506 A2 WO2017112506 A2 WO 2017112506A2 US 2016066796 W US2016066796 W US 2016066796W WO 2017112506 A2 WO2017112506 A2 WO 2017112506A2
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- hydraulic fluid
- pressure
- motor
- pump
- intensifier
- Prior art date
Links
- 230000010354 integration Effects 0.000 title description 2
- 239000012530 fluid Substances 0.000 claims abstract description 116
- 238000004519 manufacturing process Methods 0.000 claims abstract description 30
- 238000000034 method Methods 0.000 claims abstract description 19
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 9
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 9
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 8
- 230000013011 mating Effects 0.000 claims abstract description 8
- 230000015572 biosynthetic process Effects 0.000 description 3
- 238000011109 contamination Methods 0.000 description 3
- 230000002939 deleterious effect Effects 0.000 description 3
- 238000009434 installation Methods 0.000 description 3
- 238000005461 lubrication Methods 0.000 description 3
- 238000005086 pumping Methods 0.000 description 3
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 239000000356 contaminant Substances 0.000 description 2
- 238000011010 flushing procedure Methods 0.000 description 2
- 238000012545 processing Methods 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 238000001816 cooling Methods 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- WGCNASOHLSPBMP-UHFFFAOYSA-N hydroxyacetaldehyde Natural products OCC=O WGCNASOHLSPBMP-UHFFFAOYSA-N 0.000 description 1
- 239000002480 mineral oil Substances 0.000 description 1
- 235000010446 mineral oil Nutrition 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000003921 oil Substances 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 238000005067 remediation Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 230000001052 transient effect Effects 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
- 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
-
- 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
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04D—NON-POSITIVE-DISPLACEMENT PUMPS
- F04D13/00—Pumping installations or systems
- F04D13/02—Units comprising pumps and their driving means
- F04D13/06—Units comprising pumps and their driving means the pump being electrically driven
- F04D13/0653—Units comprising pumps and their driving means the pump being electrically driven the motor being flooded
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04D—NON-POSITIVE-DISPLACEMENT PUMPS
- F04D13/00—Pumping installations or systems
- F04D13/02—Units comprising pumps and their driving means
- F04D13/06—Units comprising pumps and their driving means the pump being electrically driven
- F04D13/08—Units comprising pumps and their driving means the pump being electrically driven for submerged use
- F04D13/10—Units comprising pumps and their driving means the pump being electrically driven for submerged use adapted for use in mining bore holes
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04D—NON-POSITIVE-DISPLACEMENT PUMPS
- F04D13/00—Pumping installations or systems
- F04D13/02—Units comprising pumps and their driving means
- F04D13/06—Units comprising pumps and their driving means the pump being electrically driven
- F04D13/08—Units comprising pumps and their driving means the pump being electrically driven for submerged use
- F04D13/086—Units comprising pumps and their driving means the pump being electrically driven for submerged use the pump and drive motor are both submerged
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04D—NON-POSITIVE-DISPLACEMENT PUMPS
- F04D7/00—Pumps adapted for handling specific fluids, e.g. by selection of specific materials for pumps or pump parts
Definitions
- the invention relates installation and operation of electrical submersible pumps (ESPs), and in particular to a permanent installation of an ESP.
- ESPs electrical submersible pumps
- a variety of fluid lifting systems pump fluids such as hydrocarbons from wellbores to surface holding and processing facilities.
- fluids such as hydrocarbons from wellbores to surface holding and processing facilities.
- one of a number of various types of downhole pumping systems pumps subterranean formation fluids from a particular wellbore to surface collection equipment for transport to processing locations.
- One such system is a submersible pumping assembly that is supported immersed in production fluid within the wellbore.
- the submersible pumping assembly has a pump and a motor to drive the pump to pressurize and pass the production fluid through production tubing to a surface location.
- a typical electric submersible pump assembly includes a submersible pump, an electric motor and a seal section interdisposed between the pump and the motor. The purpose of the seal section is to protect the motor from contamination as the production fluid usually contains deleterious substances such as particulate solids and other debris from the formation.
- Much research focuses on improved seal sections to prevent or at least reduce environmental contamination of the motor. Other efforts have involved development of motors that function even with contaminants present.
- An apparatus includes a pump, a motor, a pressure intensifier, and a hydraulic fluid port.
- the motor is configured to drive the pump.
- the pressure intensifier is configured to maintain pressure of hydraulic fluid in the motor at a predetermined level.
- the hydraulic fluid port configured to provide hydraulic fluid to the pressure intensifier by mating with an external hydraulic fluid source when the apparatus is in a hydrocarbon producing wellbore.
- the apparatus is dimensioned for lowering and retrieving through the string of production tubing.
- a method includes placing an apparatus in a subsea wellbore, and hydraulically connecting the apparatus with an external hydraulic fluid source.
- the apparatus of this method includes a pump, a motor, a pressure intensifier, and a hydraulic fluid port.
- the motor is configured to drive the pump.
- the pressure intensifier is configured to maintain pressure of the hydraulic fluid in the motor at a predetermined level.
- the hydraulic fluid port is configured to provide hydraulic fluid to the pressure intensifier by mating with the external hydraulic fluid source when the apparatus is in a hydrocarbon producing wellbore.
- the apparatus is dimensioned for lowering and retrieving through the string of production tubing.
- Another method includes placing an apparatus in a subsea wellbore and hydraulically connecting the apparatus with an external hydraulic fluid source.
- Pressure of the external hydraulic fluid source acts to maintain pressure of hydraulic fluid in a motor of the apparatus at a predetermined level.
- the apparatus includes a pump, the motor, and a hydraulic fluid port.
- the motor is configured to drive the pump.
- the hydraulic fluid port is configured to provide hydraulic fluid by mating with the external hydraulic fluid source when the apparatus is in a hydrocarbon producing wellbore.
- the apparatus is dimensioned for lowering and retrieving through the string of production tubing.
- FIG. 1 is a cross-sectional view of an apparatus, in accordance with the present disclosure, deployed in a wellbore.
- FIG. 2 is a flowchart of a method of using the apparatus of FIG. 1, in accordance with the present disclosure.
- FIG. 1 shows an apparatus 101 (e.g., an ESP or other electric pump) installed in a hydrocarbon producing wellbore 102 (e.g., an onshore well, an offshore well, a deep sea well).
- Apparatus 101 may include a pump 103, an optional seal 104, and a motor 10S that drives the pump.
- Pressurized hydraulic fluid is present in the apparatus 101 for lubrication and cooling, as well as for preventing intrusion of production fluid 106 into the motor 105.
- the hydraulic fluid may be mineral oil, glycol based, transformer oil, or other similar fluids.
- a motor housing (not shown), pressure, and the seal 104 may protect the motor 10S from the intrusion of damaging production fluid 106.
- the hydraulic fluid will begin to leak into the environment, due to wear, vibration, age, etc.
- the leakage rate is dependent on fluid properties, differential pressure, the transient operating conditions of the pump, and the tightness of the seal(s).
- the presently disclosed design may maintain the pressure of the hydraulic fluid indefinitely by providing an external hydraulic fluid source 107 connected to the apparatus 101 via a hydraulic fluid conduit 108.
- the external hydraulic fluid source 107 may be located on the host and connect via umbilical or the external hydraulic fluid source 107 may be located at the mud line. In this manner, even when the seal 104 fails and hydraulic fluid leaks, pressure can be maintained at a level sufficient to prevent the deleterious effects of production fluid 106 entering the motor 105.
- hydraulic fluid flows to the apparatus 101 for distribution to the motor 105 and or the pump 103 for lubrication internal structures, such as pump rotor bearings, seals and timing gears.
- the pressure in the lubrication fluid circuit of the motor 105 and pump 103 may thus be maintained above the pressure of the production fluid displaced through the pump, in order to prevent intrusion of process fluid and particles into pump bearings, seals, and timing gears.
- the mechanism for maintaining a predetermined level of pressure of hydraulic fluid in the motor 105 may include a pressure intensifier 109 such as is described in U.S. 9, 097,267 or other similar device for providing a boost to the pressure in the motor 105.
- the pressure intensifier 109 may recharge without removing the apparatus 101 from the wellbore 102.
- a hydraulic fluid port 110 may provide hydraulic fluid to the pressure intensifier 109 such that the pressure intensifier 109 can adequately maintain pressure of hydraulic fluid in the motor 105 at the predetermined level.
- a string of casing 111 may be cemented to an inner surface of the wellbore 102, and a string of production tubing 112 may be located within and generally coaxial with casing 111 to form an annulus 113 between casing 1 11 and production tubing 112.
- a packer 114 e.g., a swab cup
- a check valve 115 in the lower portion of production tubing 112 may prevent fluid loss from fluid flowing downward.
- Check valve 115 may also allow for pressure-assisted removal of apparatus 101.
- An additional swab cup, or other type of packer 116 may be located between pump 103 and the inner surface of production tubing 112.
- Packer 116 may be a lip seal and may be run with apparatus 101. Packer 116 may allow upward flow while preventing downward flow therethrough. As apparatus 101 moves into place, packer 116 may slide on the interior of production tubing 112, allowing displaced fluid to flow past packer 116.
- Apparatus 101 may be assembled by securing a lower end of pump 103 to an upper end of seal 104 and securing a lower end of seal 104 to an upper end of motor 105.
- a running tool may releasably engage a neck 117 on the upper end of pump 103, such that production fluid 106 may flow out of neck 117.
- the apparatus 101 may then move into the wellbore 102 with the running tool on a line (not shown), such as coiled tubing or cable, through production tubing 112 until the apparatus 101 and corresponding elements reach the desired depth.
- the running tool and coiled tubing may then be retrieved.
- Apparatus 101 may pass through an orienting sleeve 118 where it may rotate by engagement with a helical shoulder 119 that may assist in rotationally aligning apparatus 101 to the required orientation for positioning within a mating profile 120.
- the running tool may have a swivel, or other bearing, to allow apparatus 101 to rotate during installation without rotating the coiled tubing.
- One or more wet-mateable hydraulic fluid connectors 121 may provide hydraulic fluid to motor 10S.
- Hydraulic fluid connector 121 may affix to production tubing 112 and lie fully within annulus 113 or may slightly protrude within production tubing 112.
- the hydraulic fluid connector 121 may connect to a hydraulic fluid conduit 108 that feeds hydraulic fluid from an external hydraulic fluid source 107 to hydraulic fluid connector 121.
- Hydraulic fluid conduit 108 may extend alongside and be strapped to production tubing 112. Hydraulic fluid conduit 108 may provide high-pressure (e.g., in the range of 15-45 psi higher than the wellbore pressure) hydraulic fluid to the apparatus 101.
- Apparatus 101 may include a hydraulic fluid port 110 positioned for mating with hydraulic fluid connector 121.
- outer hydraulic fluid connector 121 engages the hydraulic fluid port 110.
- the wet-mateable hydraulic fluid connectors 121 may be analogous to the connections described in U.S. 8,381,820, although modifications would be necessary to adapt the technology described therein to provide hydraulic fluid to the intensifier 109 of the present disclosure.
- electrical connections may be provided via a connector and line configured for such purpose.
- the hydraulic fluid connector 121 and the hydraulic fluid port 110 may also include electrical connections and the hydraulic fluid conduit 108 may run alongside an electrical cable.
- a method of using the apparatus 101 described above may include various steps.
- the apparatus 101 may be placed in the wellbore 102.
- the apparatus 101 may be hydraulically connected to the external hydraulic fluid source 107.
- hydraulically connecting the apparatus 101 with the external hydraulic fluid source 107 may occur prior to placing the apparatus 101 in the wellbore 102.
- the step of hydraulically connecting may be accomplished via the hydraulic fluid connector 121.
- the method may further include maintaining pressure of the hydraulic fluid in the motor 105 at a predetermined level via the pressure intensifier 109. This may involve actively measuring and making adjustments or alternatively passive means such as a pressure limit valve.
- the pressure intensifier 109 loses pressure without introduction of additional pressure and/or hydraulic fluid. Therefore, at step 204, it is determined whether the pressure in the pressure intensifier 109 has dropped below an intensifier pressure level or that the level in the intensifier 109 is low. Again, this may involve either active or passive methodology. In any event, at step 205, hydraulic fluid is provided to the pressure intensifier 109 via the hydraulic fluid port 110, which is fed from the external hydraulic fluid source 107. In addition to the above steps, the external hydraulic fluid source 107 may be used to flush the motor 105, clearing any debris that may have entered, despite precautionary measures having been taken. Similarly, the external hydraulic fluid source 107 may be used to flush the wat-mateable connection during mate-up.
- the external hydraulic fluid source 107 may be used to flush the motor 105 without performing most of the steps noted above. For example, once the apparatus is placed at step 201 and hydraulically connected at step 202, the remaining steps may be omitted and only flushing may occur.
- flushing may occur in conjunction with the connecting step 202, to flush fluids during makeup of the connection.
- the external hydraulic fluid pressure may act directly and the pressure intensifier 109 may not be required.
- the method may be as described above but without the inclusion of the pressure intensifier and the addition of pressure of the external fluid source acting to maintain pressure of hydraulic fluid in the motor at a predetermined level.
- the advantages of using the present invention may include a permanently deployed source of high-pressure hydraulic fluid replenishment
- a permanently deployed source of high-pressure hydraulic fluid replenishment By permanently deploying a source of high-pressure hydraulic fluid, the cost and difficulty of removing the pump assembly to remediate wear caused by insufficient hydraulic fluid may be mitigated.
Landscapes
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Physics & Mathematics (AREA)
- Geochemistry & Mineralogy (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Environmental & Geological Engineering (AREA)
- Mechanical Engineering (AREA)
- General Engineering & Computer Science (AREA)
- Geophysics (AREA)
- Jet Pumps And Other Pumps (AREA)
- Structures Of Non-Positive Displacement Pumps (AREA)
- Lubricants (AREA)
- Fluid-Pressure Circuits (AREA)
Abstract
Description
Claims
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
BR112018012813A BR112018012813A2 (en) | 2015-12-22 | 2016-12-15 | high pressure hydraulic line underwater motor sp underwater engine connector integration |
US16/064,308 US20200300068A1 (en) | 2015-12-22 | 2016-12-15 | Integration of in-well wetmate esp motor connector with high pressure hydraulic line |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US201562270753P | 2015-12-22 | 2015-12-22 | |
US62/270,753 | 2015-12-22 |
Publications (2)
Publication Number | Publication Date |
---|---|
WO2017112506A2 true WO2017112506A2 (en) | 2017-06-29 |
WO2017112506A3 WO2017112506A3 (en) | 2017-10-19 |
Family
ID=58995226
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2016/066796 WO2017112506A2 (en) | 2015-12-22 | 2016-12-15 | Integration of in-well wetmate esp motor connector with high pressure hydraulic line |
Country Status (3)
Country | Link |
---|---|
US (1) | US20200300068A1 (en) |
BR (1) | BR112018012813A2 (en) |
WO (1) | WO2017112506A2 (en) |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US11578535B2 (en) * | 2019-04-11 | 2023-02-14 | Upwing Energy, Inc. | Lubricating downhole-type rotating machines |
Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8381820B2 (en) | 2009-02-18 | 2013-02-26 | Baker Hughes Incorporated | In-well rigless ESP |
US9097267B2 (en) | 2009-10-23 | 2015-08-04 | Framo Engineering As | Pressure intensifier system for subsea running tools |
Family Cites Families (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5375656A (en) * | 1992-10-14 | 1994-12-27 | Oil Dynamics, Inc. | Low flow rate oil supply system for an electric submersible pump |
US8322444B2 (en) * | 2009-09-30 | 2012-12-04 | Schlumberger Technology Corporation | Surface refillable protector |
US9689529B2 (en) * | 2014-05-08 | 2017-06-27 | Baker Hughes Incorporated | Oil injection unit |
-
2016
- 2016-12-15 US US16/064,308 patent/US20200300068A1/en not_active Abandoned
- 2016-12-15 WO PCT/US2016/066796 patent/WO2017112506A2/en active Application Filing
- 2016-12-15 BR BR112018012813A patent/BR112018012813A2/en not_active Application Discontinuation
Patent Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8381820B2 (en) | 2009-02-18 | 2013-02-26 | Baker Hughes Incorporated | In-well rigless ESP |
US9097267B2 (en) | 2009-10-23 | 2015-08-04 | Framo Engineering As | Pressure intensifier system for subsea running tools |
Also Published As
Publication number | Publication date |
---|---|
WO2017112506A3 (en) | 2017-10-19 |
BR112018012813A2 (en) | 2018-12-04 |
US20200300068A1 (en) | 2020-09-24 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
AU2004203372B2 (en) | ROV retrievable sea floor pump | |
RU2606196C2 (en) | Pump and pump section | |
US7677320B2 (en) | Subsea well with electrical submersible pump above downhole safety valve | |
US8807966B2 (en) | Pump motor protector with redundant shaft seal | |
US8316938B2 (en) | Subterranean water production, transfer and injection method and apparatus | |
US9166352B2 (en) | Downhole electrical coupler for electrically operated wellbore pumps and the like | |
US20150330194A1 (en) | Downhole Equipment Suspension and Power System Background | |
RU2569139C2 (en) | Electric pump system and method of transfer of fluid medium from underground well using this system | |
US20150354308A1 (en) | Downhole Equipment Suspension and Lateral Power System | |
US20050230121A1 (en) | ESP/gas lift back-up | |
US20110011596A1 (en) | Wellbore drilled and equipped for in-well rigless intervention esp | |
US20110236233A1 (en) | Double Sealing Labyrinth Chamber for Use With a Downhole Electrical Submersible Pump | |
CN110234836B (en) | Electric submersible pump with cover | |
AU2010212164A1 (en) | Landing string assembly | |
Tarcha et al. | Subsea ESP skid production system for Jubarte field | |
US20200300068A1 (en) | Integration of in-well wetmate esp motor connector with high pressure hydraulic line | |
US10087728B2 (en) | Method and apparatus for installing and removing an electric submersible pump | |
EP3358130B1 (en) | Motor protector of an electric submersible pump and an associated method thereof | |
RU2734505C1 (en) | Method for tight installation of packer with cable channel | |
US11970926B2 (en) | Electric submersible pump completion with wet-mate receptacle, electrical coupling (stinger), and hydraulic anchor | |
RU2727944C2 (en) | Rotor pump assembly and rotary pump unit |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
NENP | Non-entry into the national phase |
Ref country code: DE |
|
REG | Reference to national code |
Ref country code: BR Ref legal event code: B01A Ref document number: 112018012813 Country of ref document: BR |
|
121 | Ep: the epo has been informed by wipo that ep was designated in this application |
Ref document number: 16871779 Country of ref document: EP Kind code of ref document: A2 |
|
ENP | Entry into the national phase |
Ref document number: 112018012813 Country of ref document: BR Kind code of ref document: A2 Effective date: 20180621 |
|
122 | Ep: pct application non-entry in european phase |
Ref document number: 16871779 Country of ref document: EP Kind code of ref document: A2 |