US20060254766A1 - Acoustic inhibition of hydrates, scales and paraffins - Google Patents
Acoustic inhibition of hydrates, scales and paraffins Download PDFInfo
- Publication number
- US20060254766A1 US20060254766A1 US11/128,766 US12876605A US2006254766A1 US 20060254766 A1 US20060254766 A1 US 20060254766A1 US 12876605 A US12876605 A US 12876605A US 2006254766 A1 US2006254766 A1 US 2006254766A1
- Authority
- US
- United States
- Prior art keywords
- acoustic
- vibratory element
- frequency
- inhibitor
- flowbore
- 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
- 150000004677 hydrates Chemical class 0.000 title claims description 18
- 230000005764 inhibitory process Effects 0.000 title description 2
- 239000003112 inhibitor Substances 0.000 claims abstract description 23
- 239000012530 fluid Substances 0.000 claims abstract description 16
- 238000000034 method Methods 0.000 claims abstract description 10
- 230000002401 inhibitory effect Effects 0.000 claims abstract description 8
- 239000000463 material Substances 0.000 claims description 5
- 239000012528 membrane Substances 0.000 claims description 3
- 229910010293 ceramic material Inorganic materials 0.000 claims description 2
- 230000001939 inductive effect Effects 0.000 claims 2
- 238000004519 manufacturing process Methods 0.000 abstract description 19
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical group C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 abstract description 9
- 230000008021 deposition Effects 0.000 abstract description 3
- 239000003345 natural gas Substances 0.000 abstract description 3
- -1 natural gas hydrates Chemical class 0.000 abstract description 3
- 230000000644 propagated effect Effects 0.000 abstract description 2
- 230000015572 biosynthetic process Effects 0.000 description 11
- 238000005755 formation reaction Methods 0.000 description 11
- 238000004140 cleaning Methods 0.000 description 9
- 229930195733 hydrocarbon Natural products 0.000 description 5
- 150000002430 hydrocarbons Chemical class 0.000 description 5
- 239000011159 matrix material Substances 0.000 description 5
- 241000191291 Abies alba Species 0.000 description 4
- 239000004215 Carbon black (E152) Substances 0.000 description 4
- 238000005054 agglomeration Methods 0.000 description 3
- 230000002776 aggregation Effects 0.000 description 3
- 239000002245 particle Substances 0.000 description 3
- 230000008569 process Effects 0.000 description 3
- 238000010926 purge Methods 0.000 description 3
- 238000013459 approach Methods 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 239000007789 gas Substances 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 230000009471 action Effects 0.000 description 1
- 230000005540 biological transmission Effects 0.000 description 1
- 239000000919 ceramic Substances 0.000 description 1
- 239000013000 chemical inhibitor Substances 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 230000008602 contraction Effects 0.000 description 1
- 230000001627 detrimental effect Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000012188 paraffin wax Substances 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 230000000246 remedial effect Effects 0.000 description 1
- 238000005067 remediation Methods 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- 230000000284 resting effect Effects 0.000 description 1
- 230000000979 retarding effect Effects 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 230000000638 stimulation Effects 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- 238000004506 ultrasonic cleaning Methods 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 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
- 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
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
Definitions
- the invention relates generally to the use of acoustic energy to retard and prevent deposits of hydrates, scales and paraffins within a wellbore or pipeline and the components associated therewith.
- Multiphase flow in deep sea oil and gas wells and pipelines is an environment conducive to the formation of methane or natural gas hydrates, which consist of gas trapped within an ice matrix. These hydrates can choke off or entirely plug off fluid flow through a wellbore or pipeline. Typically, hydrates tend to form in specific temperature and pressure regimes. As pressure increases, the hydrate formation temperature also increases. For pressures typically seen in deep water wells, this places the hydrate formation temperature in the range of temperatures seen at the mud line of a sea-based well (i.e., around the ocean floor). Thus, hydrate formation generally occurs proximate the ocean floor.
- hydrate formation is often inhibited using chemicals and, in some case, heaters, for remediation of a plugged conduit.
- the use of inhibition chemicals and/or heaters is logistically complex and expensive.
- scales and paraffins also become deposited on wellbore and pipeline components during operation. These also are detrimental to operation of valves and other components within the flowbore or pipeline.
- Some arrangements are known to try to clean hydrates, scales or other matter from wellbores using acoustic energy. However, these arrangements generally rely primarily upon transmitting acoustic energy through the walls of the flowbore or pipeline itself rather than through the fluid within the flowbore.
- the vibratory transducers used in these earlier approaches are typically operated at high vibration frequencies, i.e., 20 kHz or higher. These high frequency vibrations are used to shatter the matrix of an already formed hydrate plug or to remove an existing deposit of hydrates or other matter. It is believed, however, that these higher frequencies are not effective in preventing the initial deposition of hydrates and other deposits within portions of a wellbore or pipeline. Thus, these prior approaches have not been effective in preventing the build-up of hydrates, scales or paraffins within the flowbore.
- Bodine is one example of a prior acoustic energy cleaning arrangement.
- Bodine describes a system for remedial cleaning of foreign matter from tubular members wherein a mechanical oscillator, is secured within a wellbore casing and rotationally driven to create whirling vibratory pressure action in annulus fluid. Rotation speed of the oscillator is on the order 20-100 cycles per second.
- U.S. Pat. No. 5,595,243, issued to Maki, Jr. et al. describes an acoustic well cleaning system wherein a sonde is lowered into a wellbore.
- the sonde contains a number of transducers that are powered to generate a high frequency sonic signal in the range of 20 kHz to 100 kHz. Cleaning occurs as the tool is moved upwardly through a producing zone.
- U.S. Pat. No. 5,727,628, issued to Patzner describes a similar system wherein an ultrasonic cleaning unit is lowered into a wellbore by cable.
- the cleaning unit includes a number of magneto-restrictive ultrasonic oscillator transducers that are pulsed to produce ultrasonic waves that are intended to clean proximate portions of the wellbore.
- the transducers are operated at a frequency in the range of 18 to 25 kHz, and preferably, at around 20 kHz.
- U.S. Pat. No. 5,948,171 issued to Grothaus, teaches an electro-hydraulic transducer device for cleaning the inner surface of pipelines.
- the typical operating parameters for the device include a pulse frequency of 1-25 Hz.
- the method of use requires that an acoustic slow wave, or the point at which the motion of solid and liquid are 180 degrees out of phase, be calculated. This calculation is a function of specific reservoir characteristics, such as reservoir permeability and aggregate porosity.
- U.S. Pat. No. 6,418,960, to Mintz et al. describes a liquid delivery system that is configured for purging cycles between pumping cycles of process fluids.
- Ultrasonic transducers are mounted on fluid transmission lines and operated during the purge cycle to help remove mixed purge and process fluids.
- the preferred operating frequency range for the transducers is from 25 kHz to 200 kHz.
- U.S. Pat. No. 6,467,542 issued to Kostrov et al. illustrates a system for stimulation of fluid-bearing formations using resonant vibration.
- a wave generator is disposed into a wellbore suspended on wireline.
- a vibration sensor detects the eigen frequency or bandwidth of the production formation, and the wave generator is then operated at the eigen frequency or bandwidth.
- U.S. Pat. No. 6,474,349 issued to Laker, describes an ultrasonic tool for the cleaning of tubular members.
- the tool is run into a wellbore on a cable.
- Operation of an acoustic vibrator within the tool causes cavitation that is intended to remove scales and asphaltenes in the wellbore.
- Laker provides no specifics with regard to the preferred frequencies of operation for his vibrator.
- U.S. Pat. No. 6,619,394, issued to Soliman et al., is directed to a well cleaning tool that subjects substantially the same portion of a wellbore to vibratory waves produced by a plurality of vibratory wave generators.
- the vibratory waves may have about the same frequency or a plurality of frequencies that may overlap or be modulated across a range.
- This type of system utilizes a piston pulser and a vibrating pipe to try to remove already deposited mudcake from the inside of a wellbore.
- the present invention addresses the problems of the prior art.
- an acoustic inhibitor is associated with a wellbore proximate the wellhead and is used to generate a low frequency acoustic energy signal that is propagated axially through the wellbore.
- the acoustic inhibitor preferably comprises a transducive element that is pulsed in accordance with a predetermined frequency to generate acoustic waves in fluid located within the flowbore of wellbore production tubing or in a pipeline.
- the tubing string or pipeline is used as a waveguide to propagate the acoustic energy axially.
- the acoustic waves are generated at a frequency in a relatively low frequency range that is generally from about 1000 Hz to about 2200 Hz.
- Particularly effective frequencies for inhibiting the growth and formation of a hydrate matrix are 1130 Hz and 2000 Hz. This pulsing will prevent the agglomeration of hydrate particles that would lead to the formation of a hydrate deposit.
- FIG. 1 is a side, cross-sectional view depicting an exemplary hydrocarbon production wellbore that includes an acoustic inhibitor arrangement constructed in accordance with the present invention.
- FIG. 2 is a schematic diagram depicting the components of a currently preferred acoustic inhibitor, in accordance with the present invention.
- FIG. 3 is a schematic operational diagram illustrating an exemplary vibratory element used with the acoustic inhibitor.
- FIG. 1 illustrates an offshore hydrocarbon production well 10 that includes an offshore platform 12 located within the sea 14 and resting on the sea floor 16 .
- An upper portion of the platform 12 extends above the surface 18 of the sea 14 and supports a production Christmas tree 20 , of a type known in the art for connection of suitable production piping and valving to a hydrocarbon production well.
- a riser 22 extends downwardly from the Christmas tree 20 and to a wellhead 24 located on the sea floor 16 .
- a wellbore 26 extends downwardly from the wellhead 24 through the earth 28 to a hydrocarbon-bearing formation 30 .
- the wellbore 26 includes exterior casing 32 that runs along at least a portion of the length of the wellbore 26 .
- a string 34 of production tubing is disposed within the riser 22 and the casing 32 .
- An annulus 36 is defined between the production tubing string 34 and the casing 32 .
- the interior flowbore of the production tubing string 34 is filled with production fluid.
- the interior flowbore of the production tubing string 34 is, therefore, prone to deposits of scales, paraffins, and hydrates (hereinafter “harmful deposits”) along its length.
- the primary area of concern, particularly for the creation of harmful deposits is the portion of the production string 34 that is generally proximate mud line, or sea floor 16 .
- the Christmas tree 20 and wellhead 24 include portions of an acoustic inhibitor 40 that is associated with the flowbore 42 of the production tubing string 34 , as depicted schematically in FIG. 2 .
- the acoustic inhibitor 40 preferably includes a transducive vibratory element 44 that is formed of electro-ceramic material. Applying a voltage across the element 44 causes it to expand proportionally to an expanded state (see position 44 a in FIG. 2 ). When voltage is removed, the element 44 returns to unexpanded state. If a voltage signal is applied at a given frequency expansion and contraction occurs in concert with the provided frequency.
- the vibratory element 44 is actuated by an actuator that includes a signal generator 46 to generate a sine wave electrical signal that is provided to an amplifier 48 and then to the vibratory element 44 so that the vibratory element 44 will be pulsed in accordance with a particular voltage and frequency.
- the amplifier 48 is used to boost the signal provided to the vibratory element 44 .
- the vibratory element 44 may be constructed in a number of ways.
- FIG. 2 depicts a first embodiment wherein the element 44 is a monolithic rod-shaped member that is formed of magnetostrictive material, of a known type.
- a magnetic coil (not shown) used to selectively actuate the element 44 between expanded and unexpanded conditions in response to the electrical signal provided from the amplifier 48 .
- the element 44 might also be formed as an annular member with a central opening that allows fluid flow through its central opening.
- the element 44 might be formed of piezoelectric material, of a known type, that will deform as a function of applied voltage from the amplifier 48 .
- FIG. 3 depicts one currently preferred construction for a vibratory element 44 ′.
- a number of circular electro-ceramic, magnetostrictive or piezoelectric members, i.e., disks, 50 are glued or otherwise secured together in a stacked configuration with the electrical signal from the amplifier 48 applied to expand each of the individual members 50 .
- the use of a stack of individual members 50 to form the element 44 ′ is advantageous because the stacked device will require a lower voltage to achieve a maximum expansion of the members 50 .
- the stack of circular members 50 is preferably encapsulated in a fluid-resistant membrane 52 .
- the stack of circular members 50 is preferably secured to a base 54 .
- the base 54 may be incorporated into or attached to the wellhead 24 and is used to position the vibratory element 44 relatively centrally within the flowbore 42 .
- the function generator 46 and amplifier 48 meanwhile are preferably located at or near the Christmas tree 20 so that they may be controlled and monitored by rig personnel.
- vibration of the vibratory element 44 or 44 ′ generates cyclical acoustic waves, depicted at 56 in FIG. 2 , within fluid in the flowbore 42 .
- the flowbore 42 acts as a waveguide to provide axial propagation of sonic energy.
- the vibratory element 44 , 44 ′ is operated to pulse at a frequency that is intended to inhibit growth of hydrates within the flowbore 42 particularly proximate the wellhead 24 .
- the acoustic waves 56 are generated in a relatively low frequency range that is generally from about 1000 Hz to about 2200 Hz. Particularly effective frequencies for inhibiting the growth and formation of a hydrate matrix are around 1130 Hz and around 2000 Hz.
- these low frequencies have been shown to be particularly effective in preventing the growth of hydrates within a tubular member. It is believed that these lower range frequencies are particularly suited to preventing and retarding the initial growth of hydrates rather than in shattering an existing matrix of already-deposited hydrates. Similarly, these frequencies are effective in preventing initial deposits and slowing the growth of scales and paraffin deposits within a tubular member.
- the frequencies used and the configuration of the acoustic inhibitor 40 is designed to optimally prevent the initial agglomeration of particles of hydrates, scales, paraffins and other undesirable deposits rather than remedially cleaning deposits from a tubular member.
- the signal generator 46 be operated to vibrate the vibratory element 44 , 44 ′ in a substantially continuous manner during production operations. It is noted that use of the acoustic inhibitor 40 will not preclude the additional use of chemical inhibitors in the flowbore 42 .
- acoustic inhibitor 40 and methods of operation thereof may also be used with land-based wells or with pipelines.
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)
- Apparatuses For Generation Of Mechanical Vibrations (AREA)
Abstract
Devices and methods for inhibiting the deposition of methane or natural gas hydrates, as well as scales, paraffins and other undesirable deposits within a wellbore using acoustic energy. An acoustic inhibitor is associated with a wellbore proximate the wellhead and is used to generate a low frequency acoustic energy signal that is propagated axially through the wellbore. The acoustic inhibitor preferably comprises a magneto-restrictive element that is pulsed in accordance with a predetermined frequency to generate acoustic waves in fluid that is located within the flowbore of wellbore production tubing or in a pipeline. The tubing string or pipeline is used as a waveguide to propagate the acoustic energy axially.
Description
- 1. Field of the Invention
- The invention relates generally to the use of acoustic energy to retard and prevent deposits of hydrates, scales and paraffins within a wellbore or pipeline and the components associated therewith.
- 2. Description of the Related Art
- Multiphase flow in deep sea oil and gas wells and pipelines is an environment conducive to the formation of methane or natural gas hydrates, which consist of gas trapped within an ice matrix. These hydrates can choke off or entirely plug off fluid flow through a wellbore or pipeline. Typically, hydrates tend to form in specific temperature and pressure regimes. As pressure increases, the hydrate formation temperature also increases. For pressures typically seen in deep water wells, this places the hydrate formation temperature in the range of temperatures seen at the mud line of a sea-based well (i.e., around the ocean floor). Thus, hydrate formation generally occurs proximate the ocean floor.
- Removing hydrate deposits is a difficult and lengthy process. Presently, hydrate formation is often inhibited using chemicals and, in some case, heaters, for remediation of a plugged conduit. The use of inhibition chemicals and/or heaters is logistically complex and expensive. In addition to hydrates, scales and paraffins also become deposited on wellbore and pipeline components during operation. These also are detrimental to operation of valves and other components within the flowbore or pipeline.
- Some arrangements are known to try to clean hydrates, scales or other matter from wellbores using acoustic energy. However, these arrangements generally rely primarily upon transmitting acoustic energy through the walls of the flowbore or pipeline itself rather than through the fluid within the flowbore. The vibratory transducers used in these earlier approaches are typically operated at high vibration frequencies, i.e., 20 kHz or higher. These high frequency vibrations are used to shatter the matrix of an already formed hydrate plug or to remove an existing deposit of hydrates or other matter. It is believed, however, that these higher frequencies are not effective in preventing the initial deposition of hydrates and other deposits within portions of a wellbore or pipeline. Thus, these prior approaches have not been effective in preventing the build-up of hydrates, scales or paraffins within the flowbore.
- U.S. Pat. No. 4,280,557, issued to Bodine, is one example of a prior acoustic energy cleaning arrangement. Bodine describes a system for remedial cleaning of foreign matter from tubular members wherein a mechanical oscillator, is secured within a wellbore casing and rotationally driven to create whirling vibratory pressure action in annulus fluid. Rotation speed of the oscillator is on the order 20-100 cycles per second.
- U.S. Pat. No. 5,595,243, issued to Maki, Jr. et al. describes an acoustic well cleaning system wherein a sonde is lowered into a wellbore. The sonde contains a number of transducers that are powered to generate a high frequency sonic signal in the range of 20 kHz to 100 kHz. Cleaning occurs as the tool is moved upwardly through a producing zone. U.S. Pat. No. 5,727,628, issued to Patzner describes a similar system wherein an ultrasonic cleaning unit is lowered into a wellbore by cable. The cleaning unit includes a number of magneto-restrictive ultrasonic oscillator transducers that are pulsed to produce ultrasonic waves that are intended to clean proximate portions of the wellbore. The transducers are operated at a frequency in the range of 18 to 25 kHz, and preferably, at around 20 kHz.
- U.S. Pat. No. 5,948,171, issued to Grothaus, teaches an electro-hydraulic transducer device for cleaning the inner surface of pipelines. The typical operating parameters for the device include a pulse frequency of 1-25 Hz.
- U.S. Pat. No. 6,405,796, issued to Meyer et al., describes an ultrasonic device that is suspended within a borehole by a cable and used to improve production by breaking up particle agglomeration. The method of use requires that an acoustic slow wave, or the point at which the motion of solid and liquid are 180 degrees out of phase, be calculated. This calculation is a function of specific reservoir characteristics, such as reservoir permeability and aggregate porosity.
- U.S. Pat. No. 6,418,960, to Mintz et al. describes a liquid delivery system that is configured for purging cycles between pumping cycles of process fluids. Ultrasonic transducers are mounted on fluid transmission lines and operated during the purge cycle to help remove mixed purge and process fluids. The preferred operating frequency range for the transducers is from 25 kHz to 200 kHz.
- U.S. Pat. No. 6,467,542, issued to Kostrov et al. illustrates a system for stimulation of fluid-bearing formations using resonant vibration. In Kostrov's system, a wave generator is disposed into a wellbore suspended on wireline. A vibration sensor detects the eigen frequency or bandwidth of the production formation, and the wave generator is then operated at the eigen frequency or bandwidth.
- U.S. Pat. No. 6,474,349, issued to Laker, describes an ultrasonic tool for the cleaning of tubular members. The tool is run into a wellbore on a cable. Operation of an acoustic vibrator within the tool causes cavitation that is intended to remove scales and asphaltenes in the wellbore. Laker provides no specifics with regard to the preferred frequencies of operation for his vibrator.
- U.S. Pat. No. 6,619,394, issued to Soliman et al., is directed to a well cleaning tool that subjects substantially the same portion of a wellbore to vibratory waves produced by a plurality of vibratory wave generators. The vibratory waves may have about the same frequency or a plurality of frequencies that may overlap or be modulated across a range. This type of system utilizes a piston pulser and a vibrating pipe to try to remove already deposited mudcake from the inside of a wellbore.
- The present invention addresses the problems of the prior art.
- The invention provides devices and methods for inhibiting the deposition of methane or natural gas hydrates, as well as scales, paraffins and other undesirable deposits within a wellbore using acoustic energy. In a preferred embodiment, an acoustic inhibitor is associated with a wellbore proximate the wellhead and is used to generate a low frequency acoustic energy signal that is propagated axially through the wellbore. The acoustic inhibitor preferably comprises a transducive element that is pulsed in accordance with a predetermined frequency to generate acoustic waves in fluid located within the flowbore of wellbore production tubing or in a pipeline. The tubing string or pipeline is used as a waveguide to propagate the acoustic energy axially.
- In preferred embodiments, the acoustic waves are generated at a frequency in a relatively low frequency range that is generally from about 1000 Hz to about 2200 Hz. Particularly effective frequencies for inhibiting the growth and formation of a hydrate matrix are 1130 Hz and 2000 Hz. This pulsing will prevent the agglomeration of hydrate particles that would lead to the formation of a hydrate deposit.
-
FIG. 1 is a side, cross-sectional view depicting an exemplary hydrocarbon production wellbore that includes an acoustic inhibitor arrangement constructed in accordance with the present invention. -
FIG. 2 is a schematic diagram depicting the components of a currently preferred acoustic inhibitor, in accordance with the present invention. -
FIG. 3 is a schematic operational diagram illustrating an exemplary vibratory element used with the acoustic inhibitor. -
FIG. 1 illustrates an offshore hydrocarbon production well 10 that includes anoffshore platform 12 located within thesea 14 and resting on thesea floor 16. An upper portion of theplatform 12 extends above thesurface 18 of thesea 14 and supports aproduction Christmas tree 20, of a type known in the art for connection of suitable production piping and valving to a hydrocarbon production well. Ariser 22 extends downwardly from theChristmas tree 20 and to awellhead 24 located on thesea floor 16. Awellbore 26 extends downwardly from thewellhead 24 through theearth 28 to a hydrocarbon-bearingformation 30. Thewellbore 26 includesexterior casing 32 that runs along at least a portion of the length of thewellbore 26. Astring 34 of production tubing is disposed within theriser 22 and thecasing 32. Anannulus 36 is defined between theproduction tubing string 34 and thecasing 32. During production of hydrocarbons from theproduction zone 30, the interior flowbore of theproduction tubing string 34 is filled with production fluid. The interior flowbore of theproduction tubing string 34 is, therefore, prone to deposits of scales, paraffins, and hydrates (hereinafter “harmful deposits”) along its length. The primary area of concern, particularly for the creation of harmful deposits is the portion of theproduction string 34 that is generally proximate mud line, orsea floor 16. - In a preferred embodiment, the
Christmas tree 20 andwellhead 24 include portions of anacoustic inhibitor 40 that is associated with theflowbore 42 of theproduction tubing string 34, as depicted schematically inFIG. 2 . Theacoustic inhibitor 40 preferably includes a transducivevibratory element 44 that is formed of electro-ceramic material. Applying a voltage across theelement 44 causes it to expand proportionally to an expanded state (seeposition 44 a inFIG. 2 ). When voltage is removed, theelement 44 returns to unexpanded state. If a voltage signal is applied at a given frequency expansion and contraction occurs in concert with the provided frequency. Thevibratory element 44 is actuated by an actuator that includes asignal generator 46 to generate a sine wave electrical signal that is provided to anamplifier 48 and then to thevibratory element 44 so that thevibratory element 44 will be pulsed in accordance with a particular voltage and frequency. Theamplifier 48 is used to boost the signal provided to thevibratory element 44. - The
vibratory element 44 may be constructed in a number of ways.FIG. 2 depicts a first embodiment wherein theelement 44 is a monolithic rod-shaped member that is formed of magnetostrictive material, of a known type. In this embodiment, a magnetic coil (not shown) used to selectively actuate theelement 44 between expanded and unexpanded conditions in response to the electrical signal provided from theamplifier 48. Theelement 44 might also be formed as an annular member with a central opening that allows fluid flow through its central opening. In addition, theelement 44 might be formed of piezoelectric material, of a known type, that will deform as a function of applied voltage from theamplifier 48. -
FIG. 3 depicts one currently preferred construction for avibratory element 44′. A number of circular electro-ceramic, magnetostrictive or piezoelectric members, i.e., disks, 50 are glued or otherwise secured together in a stacked configuration with the electrical signal from theamplifier 48 applied to expand each of theindividual members 50. The use of a stack ofindividual members 50 to form theelement 44′ is advantageous because the stacked device will require a lower voltage to achieve a maximum expansion of themembers 50. The stack ofcircular members 50 is preferably encapsulated in a fluid-resistant membrane 52. The stack ofcircular members 50 is preferably secured to abase 54. The base 54 may be incorporated into or attached to thewellhead 24 and is used to position thevibratory element 44 relatively centrally within theflowbore 42. Thefunction generator 46 andamplifier 48 meanwhile are preferably located at or near theChristmas tree 20 so that they may be controlled and monitored by rig personnel. - In operation, vibration of the
vibratory element FIG. 2 , within fluid in theflowbore 42. The flowbore 42 acts as a waveguide to provide axial propagation of sonic energy. Thevibratory element flowbore 42 particularly proximate thewellhead 24. Theacoustic waves 56 are generated in a relatively low frequency range that is generally from about 1000 Hz to about 2200 Hz. Particularly effective frequencies for inhibiting the growth and formation of a hydrate matrix are around 1130 Hz and around 2000 Hz. In testing, these low frequencies have been shown to be particularly effective in preventing the growth of hydrates within a tubular member. It is believed that these lower range frequencies are particularly suited to preventing and retarding the initial growth of hydrates rather than in shattering an existing matrix of already-deposited hydrates. Similarly, these frequencies are effective in preventing initial deposits and slowing the growth of scales and paraffin deposits within a tubular member. - The frequencies used and the configuration of the
acoustic inhibitor 40 is designed to optimally prevent the initial agglomeration of particles of hydrates, scales, paraffins and other undesirable deposits rather than remedially cleaning deposits from a tubular member. Thus, to provide maximum effectiveness in inhibiting deposits and growth of hydrates, scales and paraffins, it is suggested that thesignal generator 46 be operated to vibrate thevibratory element acoustic inhibitor 40 will not preclude the additional use of chemical inhibitors in theflowbore 42. - Although shown here used with a sea-based well, those of skill in the art will understand that the
acoustic inhibitor 40 and methods of operation thereof may also be used with land-based wells or with pipelines. - Those of skill in the art will recognize that numerous modifications and changes may be made to the exemplary designs and embodiments described herein and that the invention is limited only by the claims that follow and any equivalents thereof.
Claims (19)
1. An acoustic inhibitor for inhibiting harmful deposits within the flowbore of a tubular member containing fluids, the acoustic inhibitor comprising:
a vibratory element capable of inducing an acoustic wave within the flowbore;
an actuator for operating the vibratory element at a frequency that inhibits deposits of hydrates within the flowbore.
2. The acoustic inhibitor of claim 1 wherein the actuator operates the vibratory element at a frequency that is from about 1000 Hz to about 2200 Hz.
3. The acoustic inhibitor of claim 2 wherein the actuator operates the vibratory element at a frequency that is about 1130 Hz.
4. The acoustic inhibitor of claim 2 wherein the actuator operates the vibratory element at a frequency that is about 2000 Hz.
5. The acoustic inhibitor of claim 1 wherein the actuator comprises a signal generator that produces a sine wave signal of particular frequency.
6. The acoustic inhibitor of claim 5 wherein the actuator further comprises a signal amplifier.
7. The acoustic inhibitor of claim 1 wherein the vibratory element is formed of electro-ceramic material.
8. The acoustic inhibitor of claim 1 wherein the vibratory element is formed of magnetostrictive material.
9. The acoustic inhibitor of claim 1 wherein the vibratory element is covered with a fluid-resistant membrane.
10. The acoustic inhibitor of claim 1 wherein the vibratory element comprises a plurality of stacked members.
11. A system for inhibiting deposits and growth of harmful deposits within a tubular member, the system comprising:
a vibratory element capable of inducing an acoustic wave within the flowbore, the vibratory element comprising:
a member fashioned from a material fro the group of materials consisting essentially of electroceramic, magnetostrictive and piezoelectric; and
an actuator for operating the vibratory element at a frequency that inhibits deposits of hydrates within the flowbore.
12. The system of claim 11 wherein the actuator operates the vibratory element at a frequency that is from about 1000 Hz to about 2200 Hz.
13. The system of claim 11 wherein the actuator operates the vibratory element at a frequency that is about 1130 Hz.
14. The system of claim 11 wherein the actuator operates the vibratory element at a frequency that is about 2000 Hz.
15. The system of claim 11 wherein the vibratory element is covered with a fluid-resistant membrane.
16. The system of claim 11 wherein the vibratory element comprises a plurality of stacked members.
17. A method for inhibiting deposits and growth of harmful deposits within a tubular member comprising the step of:
actuating a vibratory element within the flowbore of a tubular member at a frequency that is from about 1000 Hz to about 2200 Hz.
18. The method of claim 17 wherein the actuator operates the vibratory element at a frequency that is about 1130 Hz.
19. The method of claim 17 wherein the actuator operates the vibratory element at a frequency that is about 2000 Hz.
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US11/128,766 US20060254766A1 (en) | 2005-05-13 | 2005-05-13 | Acoustic inhibition of hydrates, scales and paraffins |
US11/409,687 US7597148B2 (en) | 2005-05-13 | 2006-04-24 | Formation and control of gas hydrates |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US11/128,766 US20060254766A1 (en) | 2005-05-13 | 2005-05-13 | Acoustic inhibition of hydrates, scales and paraffins |
Related Child Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US11/409,687 Continuation-In-Part US7597148B2 (en) | 2005-05-13 | 2006-04-24 | Formation and control of gas hydrates |
Publications (1)
Publication Number | Publication Date |
---|---|
US20060254766A1 true US20060254766A1 (en) | 2006-11-16 |
Family
ID=37417997
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US11/128,766 Abandoned US20060254766A1 (en) | 2005-05-13 | 2005-05-13 | Acoustic inhibition of hydrates, scales and paraffins |
Country Status (1)
Country | Link |
---|---|
US (1) | US20060254766A1 (en) |
Cited By (12)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2009000177A1 (en) * | 2007-06-22 | 2008-12-31 | Biqi Wang | Environment-friendly apparatus for inhibiting paraffin and scales and reducing viscosity |
US20110079402A1 (en) * | 2009-10-02 | 2011-04-07 | Bj Services Company | Apparatus And Method For Directionally Disposing A Flexible Member In A Pressurized Conduit |
CN102278104A (en) * | 2011-07-01 | 2011-12-14 | 郑州大学 | Method for effectively improving drainage efficiency of ground coal bed methane by utilizing external sound field |
US20120228875A1 (en) * | 2011-03-10 | 2012-09-13 | Hardin Jr John R | Systems and methods of harvesting energy in a wellbore |
US8430169B2 (en) | 2007-09-25 | 2013-04-30 | Exxonmobil Upstream Research Company | Method for managing hydrates in subsea production line |
US8436219B2 (en) | 2006-03-15 | 2013-05-07 | Exxonmobil Upstream Research Company | Method of generating a non-plugging hydrate slurry |
US8839856B2 (en) | 2011-04-15 | 2014-09-23 | Baker Hughes Incorporated | Electromagnetic wave treatment method and promoter |
US20190120018A1 (en) * | 2017-10-23 | 2019-04-25 | Baker Hughes, A Ge Company, Llc | Scale impeding arrangement and method |
US10697273B2 (en) | 2018-03-26 | 2020-06-30 | NextStream Sensor, LLC | Method for scale treatment optimization |
CN111810060A (en) * | 2020-09-02 | 2020-10-23 | 西南石油大学 | Double-layer pipe microwave heating short joint for hydrate conveying |
US11448060B2 (en) | 2020-03-27 | 2022-09-20 | Saudi Arabian Oil Company | Method and system for monitoring and preventing hydrate formations |
CN116717217A (en) * | 2023-08-04 | 2023-09-08 | 东北石油大学三亚海洋油气研究院 | Ultrasonic blockage removing device and method for shaft hydrate under intervention operation |
Citations (12)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3520362A (en) * | 1967-08-04 | 1970-07-14 | Hughes Tool Co | Well stimulation method |
US4280557A (en) * | 1979-11-13 | 1981-07-28 | Bodine Albert G | Sonic apparatus for cleaning wells, pipe structures and the like |
US5595243A (en) * | 1994-07-29 | 1997-01-21 | Maki, Jr.; Voldi E. | Acoustic well cleaner |
US5727628A (en) * | 1995-03-24 | 1998-03-17 | Patzner; Norbert | Method and apparatus for cleaning wells with ultrasonics |
US5948171A (en) * | 1997-05-20 | 1999-09-07 | Southwest Research Institute | Electrohydraulic transducer for cleaning the inner surface of pipes |
US6405796B1 (en) * | 2000-10-30 | 2002-06-18 | Xerox Corporation | Method for improving oil recovery using an ultrasound technique |
US6418960B1 (en) * | 1999-10-06 | 2002-07-16 | Applied Materials, Inc. | Ultrasonic enhancement for solvent purge of a liquid delivery system |
US6467542B1 (en) * | 2001-06-06 | 2002-10-22 | Sergey A. Kostrov | Method for resonant vibration stimulation of fluid-bearing formations |
US6474349B1 (en) * | 1998-11-17 | 2002-11-05 | Hamdeen Limited | Ultrasonic cleanout tool and method of use thereof |
US6619394B2 (en) * | 2000-12-07 | 2003-09-16 | Halliburton Energy Services, Inc. | Method and apparatus for treating a wellbore with vibratory waves to remove particles therefrom |
US20050028983A1 (en) * | 2003-08-05 | 2005-02-10 | Lehman Lyle V. | Vibrating system and method for use in scale removal and formation stimulation in oil and gas recovery operations |
US20060181960A1 (en) * | 2005-02-16 | 2006-08-17 | Birchak James R | Acoustic stimulation method with axial driver actuating moment arms on tines |
-
2005
- 2005-05-13 US US11/128,766 patent/US20060254766A1/en not_active Abandoned
Patent Citations (12)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3520362A (en) * | 1967-08-04 | 1970-07-14 | Hughes Tool Co | Well stimulation method |
US4280557A (en) * | 1979-11-13 | 1981-07-28 | Bodine Albert G | Sonic apparatus for cleaning wells, pipe structures and the like |
US5595243A (en) * | 1994-07-29 | 1997-01-21 | Maki, Jr.; Voldi E. | Acoustic well cleaner |
US5727628A (en) * | 1995-03-24 | 1998-03-17 | Patzner; Norbert | Method and apparatus for cleaning wells with ultrasonics |
US5948171A (en) * | 1997-05-20 | 1999-09-07 | Southwest Research Institute | Electrohydraulic transducer for cleaning the inner surface of pipes |
US6474349B1 (en) * | 1998-11-17 | 2002-11-05 | Hamdeen Limited | Ultrasonic cleanout tool and method of use thereof |
US6418960B1 (en) * | 1999-10-06 | 2002-07-16 | Applied Materials, Inc. | Ultrasonic enhancement for solvent purge of a liquid delivery system |
US6405796B1 (en) * | 2000-10-30 | 2002-06-18 | Xerox Corporation | Method for improving oil recovery using an ultrasound technique |
US6619394B2 (en) * | 2000-12-07 | 2003-09-16 | Halliburton Energy Services, Inc. | Method and apparatus for treating a wellbore with vibratory waves to remove particles therefrom |
US6467542B1 (en) * | 2001-06-06 | 2002-10-22 | Sergey A. Kostrov | Method for resonant vibration stimulation of fluid-bearing formations |
US20050028983A1 (en) * | 2003-08-05 | 2005-02-10 | Lehman Lyle V. | Vibrating system and method for use in scale removal and formation stimulation in oil and gas recovery operations |
US20060181960A1 (en) * | 2005-02-16 | 2006-08-17 | Birchak James R | Acoustic stimulation method with axial driver actuating moment arms on tines |
Cited By (17)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8436219B2 (en) | 2006-03-15 | 2013-05-07 | Exxonmobil Upstream Research Company | Method of generating a non-plugging hydrate slurry |
WO2009000177A1 (en) * | 2007-06-22 | 2008-12-31 | Biqi Wang | Environment-friendly apparatus for inhibiting paraffin and scales and reducing viscosity |
US8430169B2 (en) | 2007-09-25 | 2013-04-30 | Exxonmobil Upstream Research Company | Method for managing hydrates in subsea production line |
US20110079402A1 (en) * | 2009-10-02 | 2011-04-07 | Bj Services Company | Apparatus And Method For Directionally Disposing A Flexible Member In A Pressurized Conduit |
US8230934B2 (en) | 2009-10-02 | 2012-07-31 | Baker Hughes Incorporated | Apparatus and method for directionally disposing a flexible member in a pressurized conduit |
US8528651B2 (en) | 2009-10-02 | 2013-09-10 | Baker Hughes Incorporated | Apparatus and method for directionally disposing a flexible member in a pressurized conduit |
US8604632B2 (en) * | 2011-03-10 | 2013-12-10 | Halliburton Energy Services, Inc. | Systems and methods of harvesting energy in a wellbore |
US20120228875A1 (en) * | 2011-03-10 | 2012-09-13 | Hardin Jr John R | Systems and methods of harvesting energy in a wellbore |
US9337705B2 (en) | 2011-03-10 | 2016-05-10 | Halliburton Energy Services, Inc. | Systems and methods of harvesting energy in a wellbore |
US10014802B2 (en) | 2011-03-10 | 2018-07-03 | Halliburton Energy Services, Inc. | Systems and methods of harvesting energy in a wellbore |
US8839856B2 (en) | 2011-04-15 | 2014-09-23 | Baker Hughes Incorporated | Electromagnetic wave treatment method and promoter |
CN102278104A (en) * | 2011-07-01 | 2011-12-14 | 郑州大学 | Method for effectively improving drainage efficiency of ground coal bed methane by utilizing external sound field |
US20190120018A1 (en) * | 2017-10-23 | 2019-04-25 | Baker Hughes, A Ge Company, Llc | Scale impeding arrangement and method |
US10697273B2 (en) | 2018-03-26 | 2020-06-30 | NextStream Sensor, LLC | Method for scale treatment optimization |
US11448060B2 (en) | 2020-03-27 | 2022-09-20 | Saudi Arabian Oil Company | Method and system for monitoring and preventing hydrate formations |
CN111810060A (en) * | 2020-09-02 | 2020-10-23 | 西南石油大学 | Double-layer pipe microwave heating short joint for hydrate conveying |
CN116717217A (en) * | 2023-08-04 | 2023-09-08 | 东北石油大学三亚海洋油气研究院 | Ultrasonic blockage removing device and method for shaft hydrate under intervention operation |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US20060254766A1 (en) | Acoustic inhibition of hydrates, scales and paraffins | |
US6009948A (en) | Resonance tools for use in wellbores | |
AU2016296502B2 (en) | Well abandonment using vibration to assist cement placement | |
US6405797B2 (en) | Enhancement of flow rates through porous media | |
US6691778B2 (en) | Methods of performing downhole operations using orbital vibrator energy sources | |
CA2436966C (en) | Method and apparatus for treating a wellbore with vibratory waves to remove particles therefrom | |
US6588507B2 (en) | Apparatus and method for progressively gravel packing an interval of a wellbore | |
US7644759B2 (en) | Enhancement of flow rates through porous media | |
US9567819B2 (en) | Acoustic generator and associated methods and well systems | |
US5184678A (en) | Acoustic flow stimulation method and apparatus | |
US20020195246A1 (en) | Enhancement of flow rates through porous media | |
US3923099A (en) | Methods of well completion or workover of fluid containing subsurface formations | |
US20070256828A1 (en) | Method and apparatus for reducing a skin effect in a downhole environment | |
US20050257931A1 (en) | Apparatus and method of applying force to a stuck object in a wellbore | |
US6467542B1 (en) | Method for resonant vibration stimulation of fluid-bearing formations | |
US6675914B2 (en) | Pressure reading tool | |
WO2017083237A1 (en) | Noise reduction for tubewave measurements | |
US20220074286A1 (en) | Waveform Energy Generation Systems and Methods of Enhandling Matrix Permeability in a Subsurface Formation | |
CA3053720A1 (en) | Devices and methods for generating radially propogating ultrasonic waves and their use | |
WO1997045622A1 (en) | Wellbore resonance tools | |
EP1491715B1 (en) | Method and apparatus for backing off a tubular member from a wellbore | |
AU728671B2 (en) | Wellbore resonance tools | |
US11767738B1 (en) | Use of pressure wave resonators in downhole operations | |
US20240084659A1 (en) | Preventing or removing contaminants in wellbore fluid using an acoustic actuator |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: BAKER HUGHES INCORPORATED, TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:RICHARD, BENNETT M.;O'MALLEY, EDWARD J.;MCELFRESH, PAUL M.;REEL/FRAME:016568/0881;SIGNING DATES FROM 20050509 TO 20050510 |
|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |