US20090120633A1 - Method for Stimulating a Well Using Fluid Pressure Waves - Google Patents

Method for Stimulating a Well Using Fluid Pressure Waves Download PDF

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Publication number
US20090120633A1
US20090120633A1 US11/938,933 US93893307A US2009120633A1 US 20090120633 A1 US20090120633 A1 US 20090120633A1 US 93893307 A US93893307 A US 93893307A US 2009120633 A1 US2009120633 A1 US 2009120633A1
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Prior art keywords
packers
zone
fluid pressure
pressure waves
isolating
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Abandoned
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US11/938,933
Inventor
Earl Webb
Iosif Hriscu
James Tucker
Gary Wilcox
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Halliburton Energy Services Inc
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Halliburton Energy Services Inc
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Priority to US11/938,933 priority Critical patent/US20090120633A1/en
Assigned to HALLIBURTON ENERGY SERVICES, INC. reassignment HALLIBURTON ENERGY SERVICES, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: WILCOX, GARY, HRISCU, IOSIF, TUCKER, JAMES, WEBB, EARL
Priority to PCT/GB2008/003537 priority patent/WO2009063162A2/en
Publication of US20090120633A1 publication Critical patent/US20090120633A1/en
Abandoned legal-status Critical Current

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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/124—Units with longitudinally-spaced plugs for isolating the intermediate space
    • E21B33/1243—Units with longitudinally-spaced plugs for isolating the intermediate space with inflatable sleeves
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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
    • E21B43/25—Methods for stimulating production

Definitions

  • Oilfield operations such as production enhancement require tools for cleaning of casing, deposits from near well bore areas, perforations, and screens.
  • scale and deposit buildups are often a major cause of decreased production. These buildups can cause a choking effect, which increases the bottomhole pressure required to maintain flow capacity.
  • the fluidic oscillator creates pulsed jets, which cause alternating bursts of fluid. These bursts of fluid create pulsating pressure waves within the well bore and formation fluids. These pressure waves can break up many types of near well bore damage, helping restore and enhance the permeability of the perforations and near well bore area. The pressure waves expand spherically providing 360° coverage as the tool moves through the interval. As damage is removed, the waves penetrate deeper into the formation.
  • Fluidic oscillator well cleaning has been effective in removal of deposits from the near well bore area, including the following: perforations, and screens; perforating damage; scales of all types; formation fines; paraffins and asphaltenes; mud and cement damage; emulsions; drilling damage; and water and gas blocks. Fluidic oscillator well cleaning has also been effective in the following applications: primary stimulation of high permeability formations; preparation prior to stimulation treatments; preparation for gravel packing or frac packing; clean out fill from open hole or casing; alteration of injection profiles; and correct placement of treating chemicals.
  • a fluidic oscillator is deployed on coiled tubing, requiring a dedicated trip out of the well bore for removal of the fluidic oscillator.
  • U.S. Pat. No. 6,976,507 describes a typical fluidic oscillation device, deployed on coiled tubing, used for near well bore cleaning.
  • the present invention relates generally to well stimulation and/or cleaning. More specifically, the present invention relates to a method of isolating a zone and penetrating or cleaning a formation using an isolation tool and a stimulation/cleaning tool.
  • a method for cleaning a well comprises: providing an isolation device, providing a penetration device, isolating a zone, and penetrating a portion of the formation utilizing the penetration device. Isolating and penetrating may be done in a single trip into the well.
  • a method for stimulating a well comprises: providing an isolation device, providing a penetration device, isolating a zone, and penetrating a portion of the formation utilizing the penetration device. Isolating and penetrating may be done in a single trip into the well.
  • FIG. 1 is a side view of a cleaning/stimulation operation using one embodiment of the method of the present invention.
  • FIG. 2 is a side view showing another embodiment according to the present invention.
  • FIG. 3 is a side view of yet another embodiment according to the present invention.
  • isolation device 100 and penetration device 105 may be lowered into well 110 . Once isolation device 100 and penetration device 105 are adjacent to formation 115 , isolation device 100 may be used to isolate zone 120 , which may include at least a portion of formation 115 . After zone 120 has been isolated, penetration device 105 may penetrate at least a portion of formation 115 located within zone 120 .
  • Isolation device 100 may be one or more packers, which are set to isolate zone 120 . More specifically, isolation device 100 may be a straddle cup packer. Alternatively, isolation device 100 may be two or more packers that are set on either end of zone 120 . Thus, penetration device 105 may enhance a standard selective injection packer (SIP) process by inducing pressure pulses between the cups of a straddle cup packer, allowing for deeper matrix penetration.
  • SIP selective injection packer
  • Penetration device 105 may be a pulsating/oscillating hydrajet that jets fluid into formation 115 .
  • Penetration device 105 may be a low frequency, large amplitude wave generating tool, such as, for example, a 2-7 ⁇ 8′′ DeepWave® stimulation services tool, commercially available from Halliburton Energy Services, Inc. of Duncan, Okla. under license from Wavefront Energy and Environmental Services, Inc. of Ontario, Canada.
  • a low frequency, large amplitude tool may be particularly useful for stimulating perforations. It may improve chemical treatments such as matrix acidizing, scale inhibition, remedial sand/proppant control and conformance. This may involve a shockwave or “thumping” at from several seconds per cycle up to minutes per cycle.
  • penetration device 105 may be a high frequency, small amplitude tool, such as, for example, a Pulsonix® TF (tuned frequency) tool, commercially available from Halliburton Energy Services, Inc. of Duncan, Okla.
  • a high frequency, small amplitude tool may be particularly useful for cleaning scale off casing, or removing deposits from the near well bore area, perforations, and screens. For example, it may remove perforating damage, scales of all types, formation fines, paraffins and asphaltenes, mud and cement damage, emulsions, drilling damage, or water and gas blocks.
  • This type of tool may also be useful for enhancement of placement and effectiveness of treatment fluids, primary stimulation of high permeability formations, preparation prior to stimulation treatments, preparation for gravel packing or frac packing, cleaning out fill from open hole or casing, alteration of injection profiles, or correct placement of treating chemicals.
  • This may involve fluid oscillation in fluid flow and pressure at hundreds of hertz. For example, at a 200 psi pressure drop, the range may be from 300 to 600 Hz. Paraffin may be cleaned with solvents and scale may be cleaned with mild acid, solvents, or water.
  • fluid pressure waves 125 may have a low frequency and a large amplitude or fluid pressure waves 125 may have a high frequency and a small amplitude.
  • desirable low frequency/large amplitude ranges include a 1 second pressure rise of 1300 psi followed by 9-10 seconds of pressure decline.
  • penetration device 105 may be run below isolation device 100 , allowing for a single trip cleaning and/or stimulation job.
  • Mandrel 130 with 0 -rings 135 may straddle port section 140 of isolation device 100 , allowing for all fluid to exit penetration device 105 to accomplish cleaning until ready to stimulate.
  • Spear or retrieving head (not shown) may then be run on wireline to retrieve mandrel 130 .
  • plug 155 configured to seat in standing valve 160 may be dropped to block flow through penetration device 105 , causing fluid to exit pressure treating ports 165 in isolation device 100 for stimulation.
  • Plug 155 may then be retrieved by running rod overshot (not shown) and pulling plug 155 , preventing the need for pulling a wet string.
  • This approach may be desirable, for example, when penetration device 105 is a pulsating/oscillating hydrajet and zone 120 includes a methane bed.
  • penetration device 105 may be a Pulsonix® TF oscillator insert (not shown) at ports 165 in isolation device 100 , thus inducing oscillation of the stimulation job.
  • the insert may be preinstalled or dropped via a mandrel with a retrieving neck 180 . After the treatment, the insert may be retrieved on wireline or slick line, allowing the string to be drained while pulling out of hole. Caged ball 185 at bottom may not be needed if the insert is preinstalled.
  • the methods of this disclosure are equally applicable to coil tubing or any other tubular, such as a jointed tubular. Because the penetration device 105 and the isolation device 100 are both run inside of the tubular, there are no extra trips needed to pull them. Thus, the methods of this disclosure provide a hybrid solution for SIP applications using penetration devices 105 for increased pinpoint injection efficiency or for formation damage cleaning/removal in non-through tubing applications. These methods combine the advantages of fluid pressure waves with the ability to run the penetration device either by installation in a tubular at surface prior to running in well 110 or via dropping the penetration device from surface and allowing it to seat inside the tubular.

Abstract

Methods for cleaning or stimulating a well include providing an isolation device, providing a penetration device, isolating a zone, and penetrating a portion of the formation utilizing the penetration device. Isolating and penetrating may occur in a single trip into the well. The isolation device may include one or more packers. The penetration device may be a pulsating/oscillating hydrajet that introduces fluid pressure waves into the formation.

Description

    BACKGROUND
  • Oilfield operations such as production enhancement require tools for cleaning of casing, deposits from near well bore areas, perforations, and screens. In wells with increased water production, waterflood projects, and geothermal wells, scale and deposit buildups are often a major cause of decreased production. These buildups can cause a choking effect, which increases the bottomhole pressure required to maintain flow capacity. Conventional methods of removing buildup-milling, acid wash, wireline broaching, and even replacing the production string and flowlines-are often either expensive or provide only limited success.
  • Another method involves a fluidic oscillator. The fluidic oscillator creates pulsed jets, which cause alternating bursts of fluid. These bursts of fluid create pulsating pressure waves within the well bore and formation fluids. These pressure waves can break up many types of near well bore damage, helping restore and enhance the permeability of the perforations and near well bore area. The pressure waves expand spherically providing 360° coverage as the tool moves through the interval. As damage is removed, the waves penetrate deeper into the formation. Fluidic oscillator well cleaning has been effective in removal of deposits from the near well bore area, including the following: perforations, and screens; perforating damage; scales of all types; formation fines; paraffins and asphaltenes; mud and cement damage; emulsions; drilling damage; and water and gas blocks. Fluidic oscillator well cleaning has also been effective in the following applications: primary stimulation of high permeability formations; preparation prior to stimulation treatments; preparation for gravel packing or frac packing; clean out fill from open hole or casing; alteration of injection profiles; and correct placement of treating chemicals.
  • Generally, a fluidic oscillator is deployed on coiled tubing, requiring a dedicated trip out of the well bore for removal of the fluidic oscillator. For example, U.S. Pat. No. 6,976,507 describes a typical fluidic oscillation device, deployed on coiled tubing, used for near well bore cleaning.
    • SUMMARY
  • The present invention relates generally to well stimulation and/or cleaning. More specifically, the present invention relates to a method of isolating a zone and penetrating or cleaning a formation using an isolation tool and a stimulation/cleaning tool.
  • In one embodiment, a method for cleaning a well comprises: providing an isolation device, providing a penetration device, isolating a zone, and penetrating a portion of the formation utilizing the penetration device. Isolating and penetrating may be done in a single trip into the well.
  • In another embodiment, a method for stimulating a well comprises: providing an isolation device, providing a penetration device, isolating a zone, and penetrating a portion of the formation utilizing the penetration device. Isolating and penetrating may be done in a single trip into the well.
    • BRIEF DESCRIPTION OF THE DRAWINGS
  • FIG. 1 is a side view of a cleaning/stimulation operation using one embodiment of the method of the present invention.
  • FIG. 2 is a side view showing another embodiment according to the present invention.
  • FIG. 3 is a side view of yet another embodiment according to the present invention.
    •  DETAILED DESCRIPTION
  • Referring to FIG. 1, in a single trip, isolation device 100 and penetration device 105 may be lowered into well 110. Once isolation device 100 and penetration device 105 are adjacent to formation 115, isolation device 100 may be used to isolate zone 120, which may include at least a portion of formation 115. After zone 120 has been isolated, penetration device 105 may penetrate at least a portion of formation 115 located within zone 120.
  • Isolation device 100 may be one or more packers, which are set to isolate zone 120. More specifically, isolation device 100 may be a straddle cup packer. Alternatively, isolation device 100 may be two or more packers that are set on either end of zone 120. Thus, penetration device 105 may enhance a standard selective injection packer (SIP) process by inducing pressure pulses between the cups of a straddle cup packer, allowing for deeper matrix penetration.
  • Penetration device 105 may be a pulsating/oscillating hydrajet that jets fluid into formation 115. Penetration device 105 may be a low frequency, large amplitude wave generating tool, such as, for example, a 2-⅞″ DeepWave® stimulation services tool, commercially available from Halliburton Energy Services, Inc. of Duncan, Okla. under license from Wavefront Energy and Environmental Services, Inc. of Ontario, Canada. Such a low frequency, large amplitude tool may be particularly useful for stimulating perforations. It may improve chemical treatments such as matrix acidizing, scale inhibition, remedial sand/proppant control and conformance. This may involve a shockwave or “thumping” at from several seconds per cycle up to minutes per cycle.
  • In another embodiment, penetration device 105 may be a high frequency, small amplitude tool, such as, for example, a Pulsonix® TF (tuned frequency) tool, commercially available from Halliburton Energy Services, Inc. of Duncan, Okla. Such a high frequency, small amplitude tool may be particularly useful for cleaning scale off casing, or removing deposits from the near well bore area, perforations, and screens. For example, it may remove perforating damage, scales of all types, formation fines, paraffins and asphaltenes, mud and cement damage, emulsions, drilling damage, or water and gas blocks. This type of tool may also be useful for enhancement of placement and effectiveness of treatment fluids, primary stimulation of high permeability formations, preparation prior to stimulation treatments, preparation for gravel packing or frac packing, cleaning out fill from open hole or casing, alteration of injection profiles, or correct placement of treating chemicals. This may involve fluid oscillation in fluid flow and pressure at hundreds of hertz. For example, at a 200 psi pressure drop, the range may be from 300 to 600 Hz. Paraffin may be cleaned with solvents and scale may be cleaned with mild acid, solvents, or water.
  • Regardless of the type of penetration device 105 used, penetration of formation 115 is preferably facilitated via fluid pressure pulses or waves 125 introduced by penetration device 105. Depending on the type of penetration device 105, fluid pressure waves 125 may have a low frequency and a large amplitude or fluid pressure waves 125 may have a high frequency and a small amplitude. Various other combinations of frequency and amplitude may also be desirable. Some examples of desirable low frequency/large amplitude ranges include a 1 second pressure rise of 1300 psi followed by 9-10 seconds of pressure decline.
  • Referring now to FIG. 2, penetration device 105 may be run below isolation device 100, allowing for a single trip cleaning and/or stimulation job. Mandrel 130 with 0-rings 135 may straddle port section 140 of isolation device 100, allowing for all fluid to exit penetration device 105 to accomplish cleaning until ready to stimulate. Spear or retrieving head (not shown) may then be run on wireline to retrieve mandrel 130. Then plug 155 configured to seat in standing valve 160 may be dropped to block flow through penetration device 105, causing fluid to exit pressure treating ports 165 in isolation device 100 for stimulation. Plug 155 may then be retrieved by running rod overshot (not shown) and pulling plug 155, preventing the need for pulling a wet string.
  • This approach may be desirable, for example, when penetration device 105 is a pulsating/oscillating hydrajet and zone 120 includes a methane bed.
  • Referring now to FIG. 3, penetration device 105 may be a Pulsonix® TF oscillator insert (not shown) at ports 165 in isolation device 100, thus inducing oscillation of the stimulation job. The insert may be preinstalled or dropped via a mandrel with a retrieving neck 180. After the treatment, the insert may be retrieved on wireline or slick line, allowing the string to be drained while pulling out of hole. Caged ball 185 at bottom may not be needed if the insert is preinstalled.
  • The methods of this disclosure are equally applicable to coil tubing or any other tubular, such as a jointed tubular. Because the penetration device 105 and the isolation device 100 are both run inside of the tubular, there are no extra trips needed to pull them. Thus, the methods of this disclosure provide a hybrid solution for SIP applications using penetration devices 105 for increased pinpoint injection efficiency or for formation damage cleaning/removal in non-through tubing applications. These methods combine the advantages of fluid pressure waves with the ability to run the penetration device either by installation in a tubular at surface prior to running in well 110 or via dropping the penetration device from surface and allowing it to seat inside the tubular. This is accomplished by combining the penetration device with the features of a retrievable jetting tool mechanism to allow the penetration device to be retrieved via either a sandline or applying annulus pressure to force the penetration device up the tubing where is can be captured at surface via a TIW style valve.
  • Therefore, the present invention is well adapted to attain the ends and advantages mentioned as well as those that are inherent therein. The particular embodiments disclosed above are illustrative only, as the present invention may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular illustrative embodiments disclosed above may be altered or modified and all such variations are considered within the scope and spirit of the present invention. Also, the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee.

Claims (20)

1. A method for cleaning a well comprising:
providing an isolation device;
providing a penetration device;
isolating a zone within the well utilizing the isolation device; and
penetrating a portion of a formation located within the zone utilizing the penetration device;
wherein the isolating and penetrating are done in a single trip into the well.
2. The method of claim 1, wherein the isolation device comprises one or more packers and wherein isolating the zone comprises setting the packers.
3. The method of claim 2, wherein the packers comprise at least one straddle cup packer.
4. The method of claim 1, wherein the isolation device comprises at least two packers and wherein isolating the zone comprises setting the packers such that the zone is situated between the packers.
5. The method of claim 1, wherein the penetration device comprises a pulsating/oscillating hydrajet and wherein penetrating comprises introducing fluid into the formation with the pulsating/oscillating hydrajet.
6. The method of claim 1, wherein penetrating comprises introducing fluid pressure waves into the formation.
7. The method of claim 6, wherein the fluid pressure waves are small amplitude waves.
8. The method of claim 6, wherein the fluid pressure waves are high frequency waves.
9. The method of claim 7, wherein the fluid pressure waves are small amplitude waves.
10. The method of claim 1,
wherein the isolation device comprises at least two straddle cup packers;
wherein isolating the zone comprises setting the packers such that the zone is situated between the packers;
wherein the penetration device comprises a pulsating/oscillating hydraj et;
wherein penetrating comprises introducing fluid pressure waves into the formation with the pulsating/oscillating hydrajet; and
wherein the fluid pressure waves are high frequency, small amplitude waves.
11. A method for stimulating a well comprising:
providing an isolation device;
providing a penetration device;
isolating a zone within the well utilizing the isolation device; and
penetrating a portion of a formation located within the zone utilizing the penetration device;
wherein the isolating and penetrating are done in a single trip into the well.
12. The method of claim 10, wherein the isolation device comprises one or more packers and wherein isolating the zone comprises setting the packers.
13. The method of claim 12, wherein the packers comprise at least one straddle cup packer.
14. The method of claim 10, wherein the isolation device comprises at least two packers and wherein isolating the zone comprises setting the packers such that the zone is situated between the packers.
15. The method of claim 10, wherein the penetration device comprises a pulsating/oscillating hydrajet and wherein penetrating comprises introducing fluid into the formation with the pulsating/oscillating hydraj et.
16. The method of claim 10, wherein penetrating comprises introducing fluid pressure waves into the formation.
17. The method of claim 16, wherein the fluid pressure waves are large amplitude waves.
18. The method of claim 16, wherein the fluid pressure waves are low frequency waves.
19. The method of claim 17, wherein the fluid pressure waves are large amplitude waves.
20. The method of claim 11,
wherein the isolation device comprises at least two straddle cup packers;
wherein isolating the zone comprises setting the packers such that the zone is situated between the packers;
wherein the penetration device comprises a pulsating/oscillating hydrajet;
wherein penetrating comprises introducing fluid pressure waves into the formation with the pulsating/oscillating hydrajet; and
wherein the fluid pressure waves are low frequency, large amplitude waves.
US11/938,933 2007-11-13 2007-11-13 Method for Stimulating a Well Using Fluid Pressure Waves Abandoned US20090120633A1 (en)

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PCT/GB2008/003537 WO2009063162A2 (en) 2007-11-13 2008-10-17 Method for stimulating a well using fluid pressure waves

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US20170241247A1 (en) 2014-10-08 2017-08-24 Gtherm Energy, Inc. Pulsing Pressure Waves Enhancing Oil and Gas Extraction in a Reservoir

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