EP0201263A1 - Oil recovery method and waterflooding injection system for use therein - Google Patents
Oil recovery method and waterflooding injection system for use therein Download PDFInfo
- Publication number
- EP0201263A1 EP0201263A1 EP86303221A EP86303221A EP0201263A1 EP 0201263 A1 EP0201263 A1 EP 0201263A1 EP 86303221 A EP86303221 A EP 86303221A EP 86303221 A EP86303221 A EP 86303221A EP 0201263 A1 EP0201263 A1 EP 0201263A1
- Authority
- EP
- European Patent Office
- Prior art keywords
- pump
- seawater
- motor
- water
- injection
- 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.)
- Withdrawn
Links
- 238000002347 injection Methods 0.000 title claims abstract description 26
- 239000007924 injection Substances 0.000 title claims abstract description 26
- 238000000034 method Methods 0.000 title claims description 17
- 238000011084 recovery Methods 0.000 title 1
- 239000013535 sea water Substances 0.000 claims abstract description 29
- 239000003208 petroleum Substances 0.000 claims abstract description 4
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 15
- 230000015572 biosynthetic process Effects 0.000 claims description 7
- 238000004519 manufacturing process Methods 0.000 claims description 7
- 239000002245 particle Substances 0.000 claims description 6
- 239000007787 solid Substances 0.000 claims description 4
- 238000012544 monitoring process Methods 0.000 claims description 3
- 230000001681 protective effect Effects 0.000 claims description 3
- 238000005086 pumping Methods 0.000 abstract description 6
- 239000000463 material Substances 0.000 description 6
- 239000003921 oil Substances 0.000 description 6
- 238000001914 filtration Methods 0.000 description 5
- 238000010276 construction Methods 0.000 description 4
- 229910001039 duplex stainless steel Inorganic materials 0.000 description 4
- 229910000831 Steel Inorganic materials 0.000 description 3
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 3
- 230000003115 biocidal effect Effects 0.000 description 3
- 239000003139 biocide Substances 0.000 description 3
- 230000007797 corrosion Effects 0.000 description 3
- 238000005260 corrosion Methods 0.000 description 3
- 239000001301 oxygen Substances 0.000 description 3
- 229910052760 oxygen Inorganic materials 0.000 description 3
- 239000010959 steel Substances 0.000 description 3
- 230000005540 biological transmission Effects 0.000 description 2
- 230000008878 coupling Effects 0.000 description 2
- 238000010168 coupling process Methods 0.000 description 2
- 238000005859 coupling reaction Methods 0.000 description 2
- 238000012423 maintenance Methods 0.000 description 2
- 241000894006 Bacteria Species 0.000 description 1
- 241000195493 Cryptophyta Species 0.000 description 1
- 229910000881 Cu alloy Inorganic materials 0.000 description 1
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 description 1
- 238000005273 aeration Methods 0.000 description 1
- 230000003190 augmentative effect Effects 0.000 description 1
- 239000000919 ceramic Substances 0.000 description 1
- 239000011248 coating agent Substances 0.000 description 1
- 238000000576 coating method Methods 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- 230000008030 elimination Effects 0.000 description 1
- 238000003379 elimination reaction Methods 0.000 description 1
- 239000000835 fiber Substances 0.000 description 1
- 239000000706 filtrate Substances 0.000 description 1
- 239000010419 fine particle Substances 0.000 description 1
- 238000005242 forging Methods 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 238000003475 lamination Methods 0.000 description 1
- 238000005461 lubrication Methods 0.000 description 1
- 239000000696 magnetic material Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 239000002455 scale inhibitor Substances 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- HBMJWWWQQXIZIP-UHFFFAOYSA-N silicon carbide Chemical compound [Si+]#[C-] HBMJWWWQQXIZIP-UHFFFAOYSA-N 0.000 description 1
- 229910010271 silicon carbide Inorganic materials 0.000 description 1
- 239000010802 sludge Substances 0.000 description 1
- 229910001220 stainless steel Inorganic materials 0.000 description 1
- 239000010935 stainless steel Substances 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 239000003643 water by type Substances 0.000 description 1
- 238000004804 winding Methods 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
-
- 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
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/20—Displacing by water
Definitions
- topside pumping facilities constitutes a very considerable capital investment when the injectioniproduction well is situated at other than a very short distance from the surface production facility. Not only must the required flowlines for produced oil and gas be laid between the wellhead and the surface facility, but also suitable flowlines must be provided for passing the pumped seawater from the surface facility to the injection site. In addition, the vast quantity of seawater that is carried by the surface facility at any one time, together with the pumping and treating equipment for that seawater, add considerably to the weight that must be borne by the surface facility.
- the pump is most suitably a multistage centrifugal pump that is capable of delivering up to 2500 m 3 per day (or about 100 m 3 per hour) of seawater at a wellhead pressure of up to 35,000 kPa, although routine operations may require from 1500 to 2400 m 3 per day (65 to 100 m" per hour) at a wellhead pressure of 20.000 to 35.000 kPa.
- the total suspended matter (TSM) content of seawater at about 10 m above the seafloor is of the order of 0.4 mg/I. This is somewhat higher than that encountered at greater heights above the seafloor (for example. 0.04 mg/I at 60 m above the seafloor at a location where water is drawn up to a platform for injection pumping), but is still well below the "polished injection water" standard of 2 mg/I TSM. As a result, fine filtration is not believed necessary and formation plugging is not expected to be a problem.
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)
- Fats And Perfumes (AREA)
Abstract
Description
- This invention relates to a method for recovering oil from a submarine oil reservoir and to a system for the injection of seawater into such a reservoir.
- Present day techniques for the waterflooding of subsea petroleum reservoirs involve lifting seawater to the surface production facility and then pumping that seawater into the reservoir via a suitable injection system to maintain reservoir pressure and displace oil. The seawater may be de-aerated before being pumped into the injection system to minimize corrosion of wellhead and other equipment.
- Quite clearly, the provision of such topside pumping facilities constitutes a very considerable capital investment when the injectioniproduction well is situated at other than a very short distance from the surface production facility. Not only must the required flowlines for produced oil and gas be laid between the wellhead and the surface facility, but also suitable flowlines must be provided for passing the pumped seawater from the surface facility to the injection site. In addition, the vast quantity of seawater that is carried by the surface facility at any one time, together with the pumping and treating equipment for that seawater, add considerably to the weight that must be borne by the surface facility.
- The present invention now seeks to eliminate the necessity for remote surface pumping facilities _ and interconnecting flowlines in subsea waterflooding, by providing a method and system in which a pump located adjacent that subsea wellhead provides the injection water from the seafloor environment.
- According to the present invention, there is provided a method for recovering oil from a submarine petroleum-containing formation penetrated by an injection well and a production well in which seawater is injected under pressure into the formation through the injection well and oil is recovered from the formation through the production well, characterised in that the seawater is injected through a pump located adjacent the seafloor injection wellhead.
- The provision of the seawater injection pump on the seafloor adjacent the injection wellhead, in contrast to its conventional situation on the production platform at a considerable distance from the injection well, results in a number of important advantages. Firstly, the cost of providing and maintaining a long run of piping connecting the topside pump and the wellhead is elminiated. Secondly, the volume and weight of the pump and its associated equipment and the weight of the water that is in it at any one time is removed from the platform. Thirdly, de-aeration and fine filtering of the water drawn from near the seafloor may not be essential. Other advantages resulting from the method and system of the invention are discussed in detail below.
- The invention resides in the use of a seawater injection pump that is located on the seafloor adjacent the injection wellhead. That pump may be electrically or hydraulically driven but is preferably powered by an electric motor which is itself preferably directly coupled to the pump. Quite clearly the pump -and, when the pump is driven by an electric motor, the motor also -must be capable of operating in the submarine environment and are therefore constructed of materials that are highly corrosion resistant and capable of operating for long periods of time without regular maintenance and repair.
- The pump is most suitably a multistage centrifugal pump that is capable of delivering up to 2500 m3 per day (or about 100 m3 per hour) of seawater at a wellhead pressure of up to 35,000 kPa, although routine operations may require from 1500 to 2400 m3 per day (65 to 100 m" per hour) at a wellhead pressure of 20.000 to 35.000 kPa.
- The motor that is preferably used to drive the pump is suitably a high voltage electric motor, for example a 750 kW or 1500 kW motor operating on a 3.3 kV or 6.6 kV, 50 Hz or 60 Hz altemating current supply. The motor is preferably of the water flooded type to eliminate potential sealing problems -especially at the motor-pump junction -and the thrust and joumal bearings for the motor are therefore of materials that are suitable for seawater lubrication and cooling, such as elastomeric compositions or ceramics such as silicon carbide. The bearings in the pump are suitably of similar construction.
- The electric power for the motor will, of course, be supplied by the surface facility or platform via a suitable high voltage submarine power cable. That cable can be combined with a control umbilical incorporating control lines for the water injection tree and pump system, monitoring lines for pressure and flow readings and, if desired or necessary, small bore tubing for chemical injection.
- The pump and motor are suitably directly coupled and mounted on an appropriate base and connected to power, control and monitoring lines and to the wellhead injection system by remotely- operated hydraulic couplings to facilitate removal of the pump/motor unit to the surface for maintenance and/or repair.
- It is common practice to de-aearate seawater used for injection on the conventional surface facility but, quite clearly, such a procedure is not possible in the method of the present invention. It is therefore essential that the pump, pipework and well tubulars are constructed of suitably selected materials based on raw seawater duty, as outlined in NACE Recommendation MR-0175, for example. It is not expected that any problem associated with seawater oxygen content will be encountered in the reservoir since the reducing nature of the reservoir environment will rapidly consume dissolved oxygen.
- It is, of course, necessary to contain the pump/motor system within a secure enclosure to prevent accidental damage from water-borne debris and to prevent such debris and marine flora and fauna being drawn into the pump along with seawater. Normally, that enclosure will include a coarse-mesh sieve to prevent such ingress although it may be necessary to provide fine mesh filters where the amount of suspended matter exceeds a certain value.
- In the North Sea, for example, the total suspended matter (TSM) content of seawater at about 10 m above the seafloor is of the order of 0.4 mg/I. This is somewhat higher than that encountered at greater heights above the seafloor (for example. 0.04 mg/I at 60 m above the seafloor at a location where water is drawn up to a platform for injection pumping), but is still well below the "polished injection water" standard of 2 mg/I TSM. As a result, fine filtration is not believed necessary and formation plugging is not expected to be a problem. However, in locations where the seawater is likely to have a high TSM content, especially shallower waters such as those in the Gulf of Mexico, fine filtration to remove particles larger than 200 um, in diameter, may be necessary to prevent formation plugging problems and to prevent damage to pump and motor bearings.
- Raw seawater contains also sulfate reducing bacteria (SRB). If unchecked, these organisms give rise to increasing levels of HzS in the reservoir. SRB require a reducing environment to multiply - hence injection of non-deaerated seawater will inhibit their growth in the vicinity of the wellbore. Further into the reservoir, however, the removal of free oxygen as described above will lead to reducing conditions which suit the SRB. Some form of biocide injection will therefore be necessary in order to inhibit SRB growth. This may be achieved by providing small bore tubing, for example of stainless steel, within the system control umbilical, to carry biocide to the wellhead. If desired, scale inhibitor can be combined with the biocide.
- It is, of course, essential to monitor the volume of seawater injected into the well and this can be achieved by any one of a number of known flow measurement systems. A preferred system utilizes a standard vortex meter mounted in the suction side of the pump. Alternative systems include a magnetic flow meter in the discharge line of the pump, an orifice plate or flow nozzle in the discharge line of the pump and a differential pressure transmitter, and a turbine meter. The vortex meter, magnetic flow meter and turbine meter all generate a frequency signal proportional to the flow, and a generated signal of 4 to 20 mA DC can be transmitted up to about 12 km. Other data transmission systems such as subsea telemetry and fiber optic data transmission can also be used in this respect.
- The invention will now be described in greater detail by way of example only with reference to the accompanying drawings, in which
- Figure 1 is a diagramatic representation in side elevation of a pump/motor unit in a protective enclosure; and
- Figure 2 is a diagramatic representation in side elevation of a system similar to that shown in Figure 1 but including fine filters to remove all but the finest particles.
- Referring first to Figure 1 of the drawings, a containment tank 1 is attached via stud bolts (not shown) to a fabricated
steel plinth 18 which is itself dowelled to the seabed 20 by piles throughholes 19 in the plinth. Theconical roof 2 of the tank houses a plurality of sieves of, for example, 6 mm mesh. The mesh should be of a copper alloy to prevent growth of algae. Water flows (as indicated by the arrows) down through the mesh to the bottom of the tank where an inner tank 4 directs the water up towards the inlet 5 of a pump 6. The downward flow followed by the upward flow occurs at such a velocity that unacceptable entrained solids gravitate to the bottom of the tank 1 whence they can be removed. - The elimination of the water contaminated by gravitated particles can be achieved by means of an
outlet pipe 8 in which there is an electrically or hydraulically operated pump which is energised periodically, or an ejector continuously energised by high pressure water obtained as a side stream from the discharge of the pump 6. Theoutlet pipe 8 is flanged to apipe 24 for conveying the discharged water to a dispersal zone. - The pump 6 is coaxially attached to an electric motor 7, of about 1500 kW running at about 2950 rpm and fed by a 3.3. kV or 6.6 kV supply. The motor is of the water flooded type and of the "solid" type, being either a one-piece forging or of laminar construction, with a final coating of dielectrical material. The casing of the motor is of the same material as the pump, namely, a duplex stainless steel defined generally as of 50 percent austenitic and 50 percent ferritic steel. All other constructional components such as the shaft, screws, keys, washers, bearings, housings, etc., are made of duplex stainless steel with the exception of the rotor which may be constructed of a modified duplex steel or other established magnetic materials used in the construction of electrical machinery.
- Stator laminations are of a duplex stainless steel and insulated in a manner similar to that of the rotor. Electrical windings are protected by corrosion resisting materials. Motor and pump may have individual shafts in which case the power is transmitted via a suitable coupling.
- The pump is of 10 stages with a co-axial back- to-back impeller array, mounted above the motor. Delivery pressure is attained half way along the shaft and the pump outlet 9 is located in this position. Construction throughout (excepting the rubbing components of bearings) is of duplex stainless steel. The inlet orifice 5 is typically 150 mm in diameter and the delivery orifice 9- is typically i00 mm in diameter.
- For support, the combined pump/motor unit may be secured to the inner tank 4 by
brackets 10, or suspended from the top of inner tank 4. Outlet nozzle 9 is connected by means of aflange 12 to a delivery pipe 11. Pipe 11 is guided throughremovable access plates 13 and 14 in the walls of tanks 1 and 4 and sealed to prevent passage of water. - The
conical roof 2 serves as a support framework for the sieves 3 and also as a lifting hanger. Bolting unites the framework ofroof 2 to tank 1, and after the delivery pipe 11,sludge outlet pipe 8, and any electrical junctions, have been disconnected the whole assembly may be lifted. - Figure 2 illustrates an alternative system for use when filtration of the seawater has to be augmented so that very fine particles, for example, as small as 5 um can be removed. Power driven filters 25 and their
driving motors 29 are housed in the containment tank 1. Seawater enters the tank via filtration grids 3 supported onroof framework 2, and enters the filters atinlet ports 26, the filtrate being conveyed to the pump by pipework 27. It is arranged bycontrol valves 28 that one filter at a time can be backflushed by means of independently controlled valves in the auxiliary piping.Filters 25 are disposed peripherally around the inside of tank 1. The remainder of the device is essen- tally the same as that described above with reference to Figure 1. - The containment tanks 1 of Figures 1 and 2 will generally have a height of up to 12 m and a diameter of up to 4 m. The inner tank 4 shown in Figure 1 may have a diameter of about 2.5 m and a height of about 6.5 m.
Claims (9)
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
GB8511468 | 1985-05-07 | ||
GB858511468A GB8511468D0 (en) | 1985-05-07 | 1985-05-07 | Waterflooding injection system |
Publications (1)
Publication Number | Publication Date |
---|---|
EP0201263A1 true EP0201263A1 (en) | 1986-11-12 |
Family
ID=10578725
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP86303221A Withdrawn EP0201263A1 (en) | 1985-05-07 | 1986-04-29 | Oil recovery method and waterflooding injection system for use therein |
Country Status (4)
Country | Link |
---|---|
EP (1) | EP0201263A1 (en) |
BR (1) | BR8602044A (en) |
GB (1) | GB8511468D0 (en) |
NO (1) | NO861798L (en) |
Cited By (12)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO1997030268A1 (en) * | 1996-02-14 | 1997-08-21 | Capcis Limited | Subsea raw water injection facility |
GB2326655A (en) * | 1997-06-27 | 1998-12-30 | Amerada Hess Ltd | Offshore production of hydrocarbon fluids |
WO2000011314A1 (en) * | 1998-08-21 | 2000-03-02 | Shore-Tec Services As | Method of injecting water and gas |
GB2361721A (en) * | 1999-11-11 | 2001-10-31 | Mentor Subsea Tech Serv Inc | Sub sea pile-sump pumping arrangement |
WO2001011189A3 (en) * | 1999-08-05 | 2001-11-15 | Cidra Corp | Apparatus for optimizing production of multi-phase fluid |
WO2004003335A2 (en) * | 2002-06-28 | 2004-01-08 | Alpha Thames Ltd | System and method to separate particles from water |
WO2007035106A1 (en) * | 2005-09-22 | 2007-03-29 | Well Processing As | Method and device for separation of particles from injection water |
EP2268895A1 (en) * | 2008-04-04 | 2011-01-05 | VWS Westgarth Limited | Fluid treatment system |
WO2011084769A3 (en) * | 2009-12-21 | 2011-09-09 | Chevron U.S.A. Inc. | System and method for waterflooding offshore reservoirs |
KR20120048096A (en) * | 2010-11-05 | 2012-05-15 | 대우조선해양 주식회사 | Preparing apparatus and installing method of filter package for water injection |
WO2012143392A3 (en) * | 2011-04-18 | 2013-04-04 | Siemens Aktiengesellschaft | Pump system, method and uses for transporting injection water to an underwater injection well |
US10161410B2 (en) | 2015-02-24 | 2018-12-25 | Geiger Pump & Equipment | Seal bracket assembly and pump and motor system including same |
Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3402670A (en) * | 1966-06-01 | 1968-09-24 | Borg Warner | Rubber bearing for multistage pump |
GB2067234A (en) * | 1980-01-11 | 1981-07-22 | Shell Int Research | Method and means for waterflooding a hydrocarbon fluid containing permeable formation below a body of water |
-
1985
- 1985-05-07 GB GB858511468A patent/GB8511468D0/en active Pending
-
1986
- 1986-04-29 EP EP86303221A patent/EP0201263A1/en not_active Withdrawn
- 1986-05-06 NO NO861798A patent/NO861798L/en unknown
- 1986-05-07 BR BR8602044A patent/BR8602044A/en unknown
Patent Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3402670A (en) * | 1966-06-01 | 1968-09-24 | Borg Warner | Rubber bearing for multistage pump |
GB2067234A (en) * | 1980-01-11 | 1981-07-22 | Shell Int Research | Method and means for waterflooding a hydrocarbon fluid containing permeable formation below a body of water |
Non-Patent Citations (3)
Title |
---|
OIL & GAS JOURNAL, vol. 75, no. 18, 2nd May 1977, pages 191-195, Tulsa, US; "Packaged water-injection plant aimed at offshore use" * |
OIL & GAS JOURNAL, vol. 76, no. 19, 8th May 1978, pages 167-170, Tulsa, US; A. FRANCO: "Miniplants speed projects, slash costs" * |
THE OIL AND GAS JOURNAL, vol. 74, no. 8, 23th February 1976, pages 99-102, Tulsa, US; R.S. SMITH: " Injection-pump study can cut costs" * |
Cited By (31)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US6171483B1 (en) | 1996-02-14 | 2001-01-09 | Capcis Limited | Subsea raw water injection facility |
GB2328462A (en) * | 1996-02-14 | 1999-02-24 | Capcis Ltd | Subsea raw water injection facility |
AU731484B2 (en) * | 1996-02-14 | 2001-03-29 | Mcdermott Marine Construction Limited | Subsea raw water injection facility |
GB2328462B (en) * | 1996-02-14 | 2000-03-15 | Capcis Ltd | Subsea raw water injection facility |
WO1997030268A1 (en) * | 1996-02-14 | 1997-08-21 | Capcis Limited | Subsea raw water injection facility |
GB2326655B (en) * | 1997-06-27 | 2001-11-28 | Amerada Hess Ltd | Offshore production of hydrocarbon fluids |
WO1999000579A1 (en) * | 1997-06-27 | 1999-01-07 | Amerada Hess Limited | Method and system for offshore production of hydrocarbon fluids |
GB2326655A (en) * | 1997-06-27 | 1998-12-30 | Amerada Hess Ltd | Offshore production of hydrocarbon fluids |
WO2000011314A1 (en) * | 1998-08-21 | 2000-03-02 | Shore-Tec Services As | Method of injecting water and gas |
GB2357792A (en) * | 1998-08-21 | 2001-07-04 | Shore Tec Services As | Method of injecting water and gas |
GB2357792B (en) * | 1998-08-21 | 2003-01-08 | Shore Tec Services As | Method of injecting water and gas |
WO2001011189A3 (en) * | 1999-08-05 | 2001-11-15 | Cidra Corp | Apparatus for optimizing production of multi-phase fluid |
GB2361721A (en) * | 1999-11-11 | 2001-10-31 | Mentor Subsea Tech Serv Inc | Sub sea pile-sump pumping arrangement |
GB2361721B (en) * | 1999-11-11 | 2003-08-20 | Mentor Subsea Tech Serv Inc | Sub sea pile-sump pumping arrangement |
WO2004003335A2 (en) * | 2002-06-28 | 2004-01-08 | Alpha Thames Ltd | System and method to separate particles from water |
WO2004003335A3 (en) * | 2002-06-28 | 2004-03-04 | Alpha Thames Ltd | System and method to separate particles from water |
WO2007035106A1 (en) * | 2005-09-22 | 2007-03-29 | Well Processing As | Method and device for separation of particles from injection water |
AU2006292882B2 (en) * | 2005-09-22 | 2009-10-08 | Well Processing As | Method and device for separation of particles from injection water |
US7604051B2 (en) | 2005-09-22 | 2009-10-20 | Well Processing As | Method and device for separation of particles from injection water |
EP2268895A1 (en) * | 2008-04-04 | 2011-01-05 | VWS Westgarth Limited | Fluid treatment system |
EP2268895B1 (en) * | 2008-04-04 | 2018-06-13 | VWS Westgarth Limited | Fluid treatment system |
US9062542B2 (en) | 2009-12-21 | 2015-06-23 | Chevron U.S.A. Inc. | System and method for waterflooding offshore reservoirs |
CN102652204A (en) * | 2009-12-21 | 2012-08-29 | 雪佛龙美国公司 | System and method for waterflooding offshore reservoirs |
US8813854B2 (en) | 2009-12-21 | 2014-08-26 | Chevron U.S.A. Inc. | System and method for waterflooding offshore reservoirs |
CN102652204B (en) * | 2009-12-21 | 2015-05-06 | 雪佛龙美国公司 | System and method for waterflooding offshore reservoirs |
WO2011084769A3 (en) * | 2009-12-21 | 2011-09-09 | Chevron U.S.A. Inc. | System and method for waterflooding offshore reservoirs |
KR20120048096A (en) * | 2010-11-05 | 2012-05-15 | 대우조선해양 주식회사 | Preparing apparatus and installing method of filter package for water injection |
KR101628846B1 (en) | 2010-11-05 | 2016-06-09 | 대우조선해양 주식회사 | Preparing apparatus and installing method of filter package for water injection |
WO2012143392A3 (en) * | 2011-04-18 | 2013-04-04 | Siemens Aktiengesellschaft | Pump system, method and uses for transporting injection water to an underwater injection well |
GB2504008A (en) * | 2011-04-18 | 2014-01-15 | Siemens Ag | Pump system method and uses for transporting injection water to an underwater injection well |
US10161410B2 (en) | 2015-02-24 | 2018-12-25 | Geiger Pump & Equipment | Seal bracket assembly and pump and motor system including same |
Also Published As
Publication number | Publication date |
---|---|
GB8511468D0 (en) | 1985-06-12 |
BR8602044A (en) | 1987-01-06 |
NO861798L (en) | 1986-11-10 |
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