WO2016167666A1 - Récupération améliorée de pétrole par des impulsions de pression - Google Patents

Récupération améliorée de pétrole par des impulsions de pression Download PDF

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Publication number
WO2016167666A1
WO2016167666A1 PCT/NO2016/050068 NO2016050068W WO2016167666A1 WO 2016167666 A1 WO2016167666 A1 WO 2016167666A1 NO 2016050068 W NO2016050068 W NO 2016050068W WO 2016167666 A1 WO2016167666 A1 WO 2016167666A1
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Prior art keywords
oil
rem
well
pressure pulses
pressure
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PCT/NO2016/050068
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English (en)
Inventor
Svein Hestevik
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Resonator As
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Publication date
Priority claimed from NO20160405A external-priority patent/NO20160405A1/en
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Publication of WO2016167666A1 publication Critical patent/WO2016167666A1/fr

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    • 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
    • E21B28/00—Vibration generating arrangements for boreholes or wells, e.g. for stimulating production
    • 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
    • E21B43/003—Vibrating earth formations
    • 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

  • the present invention concerns a method for improved oil recovery as defined by the preamble of claim 1. According to another aspect the present invention concerns a device for improved oil recovery as defined by the preamble of claim 15. Background
  • the recovery factor for an oil reservoir is limited by the residual oil trapped in the pore system because after a successful water flood the amount of oil left is too small to make a continuous oil system.
  • the continuous water flows easily through pores and around oil regions.
  • the capillary forces between oil and water prevent them from moving.
  • the problem is that the pressure gradient, typically around 0.1 mbar/mm, gives too small pressure differences across the small oil bodies to overcome the capillary forces that keep them stationary.
  • the recovery factor for a hydrocarbon reservoir is one of the most important parameters for the oil industry. It is defined as the amount of hydrocarbons produced divided by the amount of hydrocarbons initially present in the reservoir.
  • the amount of hydrocarbons is measured in different ways, as the total volume of hydrocarbons, the amount of gas and/or oil measured separately, or their energy equivalent; the energy produced by combustion.
  • the standard volume measure of oil and gas at the surface is done at standard atmospheric conditions. For calculations of expected production and recovery factors, the oil and gas in the reservoir it is usually also calculated as their volume at atmospheric conditions. This may be quite different from their volume in the reservoir, especially for gas. However, for calculations of the flow of oil and gas in the reservoir, their actual volume in the reservoir must be used.
  • a part of the reservoir is not produced to the existing wells, for instance due to barriers to flow (low permeability areas). This can be countered by drilling more wells, both to produce from (partly) isolated areas, and to inject fluids to push oil towards the producing wells.
  • the initial water is broken up into drops in the oil that fills all the pore spaces, including the small spaces, cracks and dead ends.
  • This initial irreducible water is discontinuous because the water drops are separated by pores too small to allow the water drops in, so it will not flow, however large the pressure gradient driving liquid flow through the reservoir.
  • the oil is continuous, sharing the larger pore spaces with water drops, but also filling the smaller spaces and is connected through all the small pores. The oil therefore flows readily through the pore system along any pressure gradient. But when sufficient water has invaded the pore system the oil that is left breaks up and fills only the cracks and dead ends, and some of the small pores, but is no longer connected throughout the pore system. At least up to 20% of the oil initially present may be left in the rock due to this, however long the water injection is continued. The producing wells will then end up producing only water.
  • Decreasing viscosity of oil increases the flow rate for a given pressure gradient. Increasing flow rate is increasing total oil production because then it is profitable to keep on production more oil, as termination of production depends on flow rate, see section 1.1 above. Also, if oil viscosity is reduced as compared to that of water, there are fewer tendencies for the oil- water displacement front to become unstable. The water then tends to finger through the oil towards the production wells, resulting in increased water production. Decreasing oil viscosity is often done by heating the oil, either by pumping down, through injection wells, air that will ignite the oil, so the burning oil heats the rest of the oil, or by pumping down heat, usually as hot water steam. This is only economical for heavy, high viscosity oil. It is then a standard method, as energy is readily available in the oil produced, or even better, in any gas produced from the separators.
  • CA patent 1 096 298 (1975) teaches a method for applying vibrations to a formation in which fluid is allowed to flow through and around a number of coaxially arranged cylindrical elements that are localized in a wellbore or the like of the formation.
  • US patent No. 4 884 634 (1986) teaches a method in which oil recovery is attempted increased by generating vibrations close to the resonant frequency of the formation, the means suggested for achieving the vibrations being to inject a metallic fluid into the formation and apply electric energy to at least two electrodes positioned in separate wells penetrating the same formation. This method is intended to also increase the temperature in the formation which may contribute positively to the oil recovery.
  • US patent 8 113 278 teaches a method for stimulating oil recovery by use of vibrations, in which in situ generated seismic energy is applied by the use of an hydraulic, seismic pressure wave source.
  • the generator produces low frequency (sound) waves and comprises an accumulator, a pump, energy transferring section, rotor and stator as well as a pressure transferring valve.
  • the waves are apparently generated by building and releasing pressure.
  • US 2002/ 00070017 describes yet another variant of vibration based stimulation of oil recovery from reservoir.
  • the genuine feature seems to be application of a plurality of vibration generators operating at different or overlapping frequencies.
  • the different generators can run simultaneously or in series.
  • the present invention is a.
  • the present invention also concerns an apparatus as defined by claim 15.
  • reciprocating machine as used herein is understood a reciprocating machine which is typically electrically powered.
  • the machine may be powered solely by electricity, but may also include hydraulic components for conveying movement.
  • vibrations and “pressure pulses” have been used interchangeably in the present description and it is not the intent to distinguish between these terms.
  • pressurized C0 2 is one example of such a fluid, under most conditions a gas, but which may also serve to transmit pressure waves in a well when subjected to sufficiently high pressure.
  • pressurized fluid this shall be considered to contemplate water as well as pressurized fluids like C0 2 when under such a pressure that it has the ability to transmitting pressure waves.
  • the peak pressure differences across the isolated oil drops are much higher than by any possible pressure gradient in a continuous flow, and will mobilize some of the residual oil towards the production wells.
  • the pore pressure in the reservoir decreases, resulting in a decrease in the maximum possible rate of production.
  • Interfacial tension is the energy per area unit needed to form or increase a contact surface between two different substances that do not mix.
  • the interfacial tension represents a small amount of energy per area unit, it is therefore still often given in the old physical unit dynes per square centimeters,
  • drops of oil surrounded by water are spherical
  • the sphere has the least possible surface.
  • Deforming a spherical drop into any other shape increases its surface and changes its surface energy. This additional energy has to be supplied from an external source to deform the drop.
  • Deforming an oil drop is necessary in order to force it into a channel with a diameter that in any direction is smaller than the spherical diameter of the drop.
  • Deforming oil drops by adding energy is therefore a possible means for improving oil recovery.
  • One possible external energy source is a source of vibration of the fluid surrounding the drop. These vibrations will periodically deform the drop shape.
  • Another possibility to get an oil drop into a narrow channel is to divide into several drops. This will increase the total surface of the first, big drop. Dividing it into drops of equal sizes, the surface of each drop decreases with the square of the reduced diameter, but the volume is reduced with the third power of the diameter, and the number of drops therefore increases in inverse proportion to the single drop volume.
  • Interfacial tension is also found between liquids and solids, and is measured as the energy per unit area needed to increase the contact area between the fluid and the solid. If this energy per area unit is small, there is a tendency for the contact area to increase; the fluid is wetting the solid. If the fluid is an oil drop in water on the solid surface of rock the shape of the oil drop is determined by the minimum surface energy in the three contact areas, between oil and water, between oil and rock, and between water and rock.
  • the reciprocating electric machine (ReM) used to generate the vibrations according to the present invention is typically positioned at the top of the well, near the surface in the case of an onshore well and near the seafloor in the case of an offshore well, and may preferably be positioned in direct connection with the well head. Positioning of at least one ReM at the top of the well does not exclude the possibility of positioning and activating additional ReMs in other locations, requiring use of run-in equipment to properly position such additional ReMs in the well in question. Generally ReMs can be used in any number and in any number of wells.
  • the ReMs preferably have hermetically sealed outer housings and do not, with the exceptions specifically mentioned herein, comprise any external moving parts. They are therefore more resistant/ less sensitive to the external environment than most other equipment used for similar purposes, hereunder less influenced by impacts, dirt, high or varying temperatures, corrosive fluids, and the like.
  • the ReMs may be run into the wells by different means, such as with the use of e-lines, pipeline tractors (internal conduit vehicles), coiled tubings, or electrical umbilicals.
  • each ReM may be accompanied by weight bars or the like to facilitate the run-in and also by equipment allowing the exact position of the ReM to be controlled, such as Casing Collar Locator (CCL) units or the like.
  • CCL Casing Collar Locator
  • the present invention provides a means for allowing vibrations to be generated in injection fluids typically water with additions of surfactants or other additives, during production, in connection with injection wells, without interrupting or disturbing the injection- or recovery process, with comparatively inexpensive means which require little maintenance and which are well protected against the tough environment typically predominant in an oil formation under production.
  • Figure 1 is a schematic illustration of an oil field containing a number of injections wells and a productions well.
  • Figure 2 is a side sectional view of the area between an injection well and the production well during oil recovery.
  • Figure 3A is a side sectional view of one of the injection wells of Figure 1 with an implementation of the present invention.
  • Figure 3B is a side sectional view of one of the injection wells of Figure 1 with another implementation of the present invention.
  • Figures 4A-D are schematic illustrations of embodiments of a reciprocal machine suitable for use with the present invention.
  • Figures 5A is a schematic illustration of a different embodiment of a eM suitable for use with the present invention
  • Figure 5B is an example of use of a particular variant thereof.
  • FIGS. 6 A, B, C are schematic illustrations of particular use of an embodiment of a ReM suitable for use with the present invention.
  • FIGS 7A, B, C are schematic illustrations of particular use of another embodiment of a ReM suitable for use with the present invention.
  • FIGS 8A, 8B are schematic views of pressure pulse propagation obtained according to the present invention.
  • FIGS 9A, 9B are schematic views of pressure variations inherent with use of the present invention.
  • Figure 1 shows schematically a top view of an oil field 11 provided with five injections wells 12 x - 12 5 and a production well 13. The direction of flow of injected fluid is indicated by stapled arrows.
  • Two of the injection wells are provided with an apparatus or device 14 in the form of a ReM according to the present invention. Any number of injection wells could, however, be provided with such apparatus or device 14.
  • Figure 2 is a side sectional view of the formation between one injection well 12 2 and the production well 13 having a mainly vertical portion 13v and a deviating or mainly horizontal portion 13h.
  • the production well 13 extends first vertically through a number of non-bearing layers of rock and deviates to a mainly horizontal part 13h in an oil-bearing stratum.
  • a ReM 14 is arranged near the injection head of the injection well 12 2 .
  • Arrows with dotted lines indicate different zones in the formation, a mobile oil zone 21, an intermediate zone 22, and a pressurized, water saturated zone 23. The latter is fully saturated with aqueous injection fluid and is, during production, constantly subjected for pressure pulses from the ReM 14.
  • Arrows with full-drawn lines close to the injection well indicate how the aqueous injection fluid, injected through injection well 12 2 , is spread vertically while moving generally from right to left in the drawing.
  • Pressure pulses propagating from a device arranged at the well head of the injection well, in close contact with the aqueous injection fluid, will propagate all the way to the barrier where the aqueous fluid meets part of the formation still being oil moist rather than water moist, i.e. to the pressurized, water saturated zone 23 shown in Figure 2.
  • the more vertical, full-drawn arrows in the moving oil zone 21 indicate how released oil from the formation flows to the horizontal part of the production well to be produced therefrom to the surface.
  • the combined action of the static pressure of the injection fluid and the pressure pulses from the ReM contributes to releasing oil drops from the formation and to the general movement from right to left in drawing 2 of the zones 21-23, also indicated as "frontal advance" in Figure 2.
  • FIG. 3A shows schematically and simplified a side sectional view of an arbitrary injection well 12, at which the present invention is implemented.
  • the main feature shown by this figure is the positioning of the one ReM 14, at or near the surface where it easily can be monitored, serviced, and if required replaced.
  • the positioning of the ReM 14, immersed in the non-compressible column of aqueous injection fluid, ensures that the pressure fluctuations are effectively conveyed throughout the parts of the reservoir saturated by the injection fluid.
  • the double arrows pointing to the right from the well indicate in a generalized manner how the vibrations propagate from the well.
  • the vibrations have the form of pressure fluctuations that may spread out in all directions from the well, not just in one direction. The pressure fluctuations spread out through the rocks of the formation as well as through the liquids in the formation.
  • Figure 3B shows an embodiment slightly different from that of Figure 3A.
  • the device used for formation of pressure waves is represented by three different ReMs, 14i_ 3 , not just a single one.
  • the issue of main importance in using plural ReMs is that they are tuned for different frequencies. It is difficult to make a ReM of a type suitable for environments of the kind relevant for the present invention, able to operate at varying frequencies; therefore intermittent use of two or more ReMs operating at fixed, but different, frequencies, is a viable and practical option to the idealized continuous sweep through a broad frequency range.
  • connection of the ReMs to the well may be said to be shunted, i.e. arranged in a channel shunted to the well.
  • shunted connection of the ReMs to the well is preferred.
  • Figure 4A shows a side view of an embodiment of a ReM useful with the present invention. It comprises a main body 41, cooling ribs 42 and stabilizing fins 43.
  • the longitudinal axis L is indicated by a dotted line.
  • Figure 4B shows generally the same as Figure 4A, but from a viewing angle 90 degrees different from that of Figure 4A, the difference visible only from the appearance of the stabilizing fins 43.
  • Figure 4C again shows the eM from the same angle as Figure 4A, the difference being that the outer body is partially removed, so that the internal elements thereof are partly shown, hereunder the reciprocating unit (motor) 44 and a chain-like structure 45 connected thereto and also suspended at the opposite end of the ReM, i.e. the end of the stabilizing fins.
  • the chain-like structure 45 is immersed in a fluid, typically a mixture of liquid and gas.
  • the ReM will typically include at least one spring at ach end to cushion and stop the movement in the direction in question, temporarily storing the kinetic energy as potential energy and thereafter releasing the energy as kinetic energy in the opposite direction.
  • the springs may be mechanical springs, gas springs or a combination thereof.
  • the outer body 46 of the ReM is at least partly comprised by e flexible material or "skin"
  • this outer body 46 will temporarily move out to assume a slightly convex shape as a response to the pressure build-up, as shown by the dotted lines of Figure 4D.
  • the reciprocating unit 44 moves to the right
  • the chain like structure 45 is also pulled to the right by its suspension at the right side end.
  • One is a repetition of the action taking place during the movement to the left, i.e. the fluid surrounding the chain-like structure is again forced outwards and in a movement opposite to the chain-like structure, again causing the "skin" material to shortly assume a convex shape.
  • the other scenario is one in which fluid is allowed to flow through the chain-like structure when it moves to the right, due to an arrangement functioning like check-valves arranged at the links of the chain-like structure.
  • This latter variant may be preferable over the first one due to the fact that it allows more time for the skin to resume its original shape before next stroke is generated.
  • Figure 4A - 4D concerns use of an electric reciprocating machine which allows the use of a sealed, liquid tight, continuous outer holster, herein referred to as a hermetically sealed construction, not relying upon seals or packers to allow the internal mechanics and electronics being isolated from the surrounding environment.
  • the sealed, liquid tight continuous holster is typically made in a flexible synthetic resin material which, after being subjected to a suitable heat treatment, constitutes a seamless holster.
  • a vibrating pulse may be generated from the ReM without use of expensive materials (metallic/ magnetic etc.) or materials that should not be left behind in nature, without the need for plural wells localized closely together, without, use of complicated or sensitive equipment with a significant number of valves or other movable parts, and without use of separate flowing materials (other than the injection fluid) which would have required use of pumps and space demanding receptacles or the like.
  • Figure 5A shows an embodiment, designated 14 2 , of a ReM different from that of figures 4A-D.
  • the outer, general shape may be identical, and is shown as identical.
  • the outer body of the ReM is provided with a rib structure 51 of slightly flexible material in which on side of the ribs are generally flat while the other side has a curved or tapered part close to the outer periphery of the ribs. If not suspended to any external structure, this embodiment of the ReM would “swim" in the direction to the right as shown in the drawing. When suspended, this embodiment of the ReM sets up pressure pulses mainly along the direction of the arrows shown in Figure 5, The advantage of the embodiment according to Figure 5 over the embodiment of Figs.
  • this embodiment of the ReM may beneficially be suspended to a membrane like structure in order to provide a better momentum for generating pressure pulses in the fluid in which it is suspended.
  • FIG 5B shows a particular variant of the embodiment of the ReM shown in Figure 5A.
  • one of the ribs, 51L of the rib structure 51 is enlarged so as to typically cover the entire cross-section of a conduit into which the ReM is intended to be suspended by means of brackets 52.
  • the conduit in question may typically be a shunted passage in relation to an injection well. With the brackets rigidly attached, the "swimming" action of the ReM in operation will generate pressure pulses in the conduit and in turn also in the injection well.
  • Figures 6A-C show schematically how a ReM 14 2 of the type illustrated in Figure 5A may beneficially be suspended to a membrane 61, which may be manufactured in any flexible material able to endure the conditions in a well.
  • the ReM 14 indicated in Figure 3A may typically in practice be an assembly of a ReM and such a membrane as shown in Figures 6A-C. It should be understood that the membrane 61 is typically suspended across a conduit associated with an injection well, similar to the embodiment of Figure 5B, within a pressurized fluid in said well.
  • FIGS 7A-C show schematically more or less the same as Figures 6A-C, but using another type of ReM.
  • a ReM 14 3 which comprises a hammer member 141 directly or indirectly connected to or being part of the reciprocating unit (motor) of the ReM.
  • the hammer member 141 protrudes from the ReM 14 3 housing which is suspended from a rigid support 72 which in turn is secured to ground or to a fixed installation (not shown).
  • a membrane 71 constituting an uninterrupted surface is used for this embodiment. The membrane is suspended with desired tension within a well fluid typically at an injection wall, as in the previous embodiment.
  • the hammer member 141 is moving outwards (to the left) and is about to hit the membrane which is in a neutral, even position.
  • Figure 7B shows a situation after the hammer member 141 has made an impact to the membrane and created a pressure pulse in the well. The membrane is at this point displaced, exhibiting a convex left surface and a concave right surface.
  • the hammer member 141 connected directly or indirectly to the reciprocating member of the ReM is now retracting and no longer in contact with the membrane which also has started moving back towards its neutral positon.
  • Figure 7C shows the initial phase of the next stroke, quite similar to the situation shown in Figure 7A, but with the membrane slightly overcompensated as a result of the previous stroke, i.e. the membrane is shown slightly convex on its right side. It should be emphasized that the exact position of the membrane at the time of next hit by the hammer member 141 is not important. It is, however, of importance that the frequency of the reciprocating motion of the eM 14 3 is adapted to the resonant frequency of the membrane 71, or vice versa, ensuring that the membrane 71 is somewhere near its natural, unbiased position each time it receives an impact by the hammer member 141.
  • a mechanical spring, gas spring or a combination thereof may be arranged to retract the hammer member after each blow.
  • Gas springs are preferred for some embodiments for enduring tougher conditions than mechanic springs.
  • FIG. 8A pressure pulses are generated from above at a fixed frequency, Fl, e.g. a frequency of 120 Hz.
  • Fl a fixed frequency
  • Such a low frequency is generally preferred over a higher one due to the fact that attenuation of the vibrations or pressure pulses as a function of distance from the origin of the pressure pulses is higher for high frequency vibrations than for low frequency vibrations.
  • frequencies chosen for the present invention are in the range 1 to 1000 Hz and more preferred in the range 10 to 100 Hz.
  • the pressure fluctuations are transmitted from the well through the perforations, illustrated as PI and P2.
  • the pressure pulses from these seemingly different sources collide and interfere with each other.
  • the frequency is constant there will be zones or directions in which the pressure maximum from PI meets a pressure maximum from P2. In these areas or directions the pulses add to each other and form an increased pressure maximum.
  • changing the frequency of the generated pressure pulses constitutes a preferred embodiment, since it will counteract the negative effects of interference ("quiet zones") between pulses leaving different perforations of a well casing, or more generally interference between different apparent vibrations sources.
  • different apparent vibration sources is understood real, different vibration sources, such as different ReMs arranged in a well, but also just seemingly different vibration sources, such as pressure pulses from one ReM leaving two or more perforations in a well casing.
  • a consistent frequency sweep between an upper value and a lower value may be preferred, e.g. a sweep in the range from about 10 Hz to about 100 Hz.
  • Figures 9A and B show the general effect of the pressure pulses to a pressurized formation. While the basic steady pressure in the formation may be e.g. 10 bars, illustrated by Figure 9A, the fluctuation of the pressure may typically be in the magnitude of +/- 0.5 bars as illustrated by Figure 9B. This is found to be sufficient to expel a surplus amount of oil that is well worth the effort thereby required. It is preferred from energy consideration that the pressure fluctuations generated according to the present invention, in some embodiments are less than +/- 1-5 bars.
  • the reciprocating unit 44 which is known per se. Typically it comprises a piston which is arranged to move back and forth in a mainly closed cylinder, the walls of which being provided with at least one coil of an electric conductor which again is connected to an AC power source. When alternating current is flowing through the coil, the piston moves back and forth by the ever changing forces acting on the permanent magnets as the current in the coil changes direction. Different features may be included to retard the movement of the piston towards the end of each stroke to avoid overburdening of the components of the machine. Since such machines are generally known, it is not described in further detail here.
  • ReM While other principles of operation may be employed, it is preferred a principle selected among electric operation, hydraulic operation and electro-hydraulic operation. For the time being, electric operation is the most preferred principle of operation. This also allows use of ReMs with no externally moving parts, which is also preferred.
  • the ReM should be sealed so as to be fluid-tight under well conditions by any manner known in the business. Specifically preferred is the use of an ReM which has an hermetically sealed outer housing.
  • reciprocating machine is not intended to cover machines having functionality of adding material to a well, such as pumps.
  • the method of the invention is typically conducted in a pressurized well, more typical pressurized injection well, and most typically during ongoing recovery or production from the we

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
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  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
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  • General Life Sciences & Earth Sciences (AREA)
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Abstract

L'invention concerne un procédé et un dispositif permettant la récupération améliorée de pétrole à partir de gisements de pétrole souterrains, par application d'impulsions de pression à au moins une partie du gisement de production de pétrole. Le procédé comprend le positionnement d'au moins un compresseur alternatif (ReM) disposé dans un puits rempli de fluide pénétrant dans le gisement et la production d'impulsions de pression par activation dudit ReM. Le procédé est généralement mis en œuvre dans un puits d'injection sous pression avec ledit ou lesdits ReM disposés près de la surface du puits.
PCT/NO2016/050068 2015-04-15 2016-04-14 Récupération améliorée de pétrole par des impulsions de pression WO2016167666A1 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
NO20150453 2015-04-15
NO20150453 2015-04-15
NO20160405 2016-03-09
NO20160405A NO20160405A1 (en) 2015-04-15 2016-03-09 Improved oil recovery supported by pressure pulses

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Cited By (2)

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CN114687697A (zh) * 2022-03-21 2022-07-01 西安锦海能源科技有限公司 一种井下流体自激压力脉冲震荡解堵装置
US11459856B2 (en) 2019-09-06 2022-10-04 Optimum Petroleum Services Inc. Downhole pressure wave generating device

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US20020070017A1 (en) 2000-12-07 2002-06-13 Soliman Mohamed Y. Method and apparatus for treating a wellbore with vibratory waves to remove particles therefrom
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US4884634A (en) 1985-12-03 1989-12-05 Industrikontakt Ing. O. Ellingsen & Co. Process for increasing the degree of oil extraction
US5080189A (en) * 1991-04-08 1992-01-14 Conoco Inc. Electro-hydraulic dipole vibrator
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US5313025A (en) * 1993-05-05 1994-05-17 Halliburton Logging Services, Inc. Displacement amplified acoustic transmitter
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US11840906B2 (en) 2019-09-06 2023-12-12 Optimum Petroleum Services Inc. Downhole pressure wave generating device
CN114687697A (zh) * 2022-03-21 2022-07-01 西安锦海能源科技有限公司 一种井下流体自激压力脉冲震荡解堵装置
CN114687697B (zh) * 2022-03-21 2024-03-08 西安锦海能源科技有限公司 一种井下流体自激压力脉冲震荡解堵装置

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