WO2022241055A1 - Dissolvable plug removal with erosive tool - Google Patents
Dissolvable plug removal with erosive tool Download PDFInfo
- Publication number
- WO2022241055A1 WO2022241055A1 PCT/US2022/028860 US2022028860W WO2022241055A1 WO 2022241055 A1 WO2022241055 A1 WO 2022241055A1 US 2022028860 W US2022028860 W US 2022028860W WO 2022241055 A1 WO2022241055 A1 WO 2022241055A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- plug
- well
- degradable
- fluid
- jet
- Prior art date
Links
- 230000003628 erosive effect Effects 0.000 title claims abstract description 49
- 239000012530 fluid Substances 0.000 claims abstract description 84
- 238000000034 method Methods 0.000 claims abstract description 64
- 230000015556 catabolic process Effects 0.000 claims abstract description 47
- 238000006731 degradation reaction Methods 0.000 claims abstract description 47
- 239000000463 material Substances 0.000 claims abstract description 24
- 239000007787 solid Substances 0.000 claims abstract description 15
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 7
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 7
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 6
- 230000000593 degrading effect Effects 0.000 claims description 22
- YMWUJEATGCHHMB-UHFFFAOYSA-N Dichloromethane Chemical compound ClCCl YMWUJEATGCHHMB-UHFFFAOYSA-N 0.000 claims description 18
- ZMXDDKWLCZADIW-UHFFFAOYSA-N N,N-Dimethylformamide Chemical compound CN(C)C=O ZMXDDKWLCZADIW-UHFFFAOYSA-N 0.000 claims description 18
- 239000003082 abrasive agent Substances 0.000 claims description 13
- WYURNTSHIVDZCO-UHFFFAOYSA-N Tetrahydrofuran Chemical compound C1CCOC1 WYURNTSHIVDZCO-UHFFFAOYSA-N 0.000 claims description 12
- YXFVVABEGXRONW-UHFFFAOYSA-N Toluene Chemical compound CC1=CC=CC=C1 YXFVVABEGXRONW-UHFFFAOYSA-N 0.000 claims description 9
- HEDRZPFGACZZDS-UHFFFAOYSA-N Chloroform Chemical compound ClC(Cl)Cl HEDRZPFGACZZDS-UHFFFAOYSA-N 0.000 claims description 8
- CSCPPACGZOOCGX-UHFFFAOYSA-N Acetone Chemical compound CC(C)=O CSCPPACGZOOCGX-UHFFFAOYSA-N 0.000 claims description 6
- FXHOOIRPVKKKFG-UHFFFAOYSA-N N,N-Dimethylacetamide Chemical compound CN(C)C(C)=O FXHOOIRPVKKKFG-UHFFFAOYSA-N 0.000 claims description 6
- YLQBMQCUIZJEEH-UHFFFAOYSA-N tetrahydrofuran Natural products C=1C=COC=1 YLQBMQCUIZJEEH-UHFFFAOYSA-N 0.000 claims description 6
- 230000000903 blocking effect Effects 0.000 claims description 4
- 239000003518 caustics Substances 0.000 claims description 4
- 230000000694 effects Effects 0.000 claims description 4
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- 230000005641 tunneling Effects 0.000 description 3
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 2
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- XQMVBICWFFHDNN-UHFFFAOYSA-N 5-amino-4-chloro-2-phenylpyridazin-3-one;(2-ethoxy-3,3-dimethyl-2h-1-benzofuran-5-yl) methanesulfonate Chemical compound O=C1C(Cl)=C(N)C=NN1C1=CC=CC=C1.C1=C(OS(C)(=O)=O)C=C2C(C)(C)C(OCC)OC2=C1 XQMVBICWFFHDNN-UHFFFAOYSA-N 0.000 description 1
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- WDJHALXBUFZDSR-UHFFFAOYSA-M acetoacetate Chemical compound CC(=O)CC([O-])=O WDJHALXBUFZDSR-UHFFFAOYSA-M 0.000 description 1
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- WPBNNNQJVZRUHP-UHFFFAOYSA-L manganese(2+);methyl n-[[2-(methoxycarbonylcarbamothioylamino)phenyl]carbamothioyl]carbamate;n-[2-(sulfidocarbothioylamino)ethyl]carbamodithioate Chemical compound [Mn+2].[S-]C(=S)NCCNC([S-])=S.COC(=O)NC(=S)NC1=CC=CC=C1NC(=S)NC(=O)OC WPBNNNQJVZRUHP-UHFFFAOYSA-L 0.000 description 1
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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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/1208—Packers; Plugs characterised by the construction of the sealing or packing means
-
- 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
- E21B29/00—Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
- E21B29/02—Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground by explosives or by thermal or chemical means
-
- 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
- E21B7/00—Special methods or apparatus for drilling
- E21B7/18—Drilling by liquid or gas jets, with or without entrained pellets
-
- 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
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
- E21B2200/08—Down-hole devices using materials which decompose under well-bore conditions
Definitions
- the invention relates to methods, devices, and systems for temporary plugging of wells or a portion thereof, and more particularly to methods of removing degradable plugs using a combination of erosive tools and one or more degradation fluids.
- Well completion equipment is installed in hydrocarbon producing wells to facilitate the production of hydrocarbons from subsurface formations to the well surface.
- Temporary plugs are frequently installed in the production tubing or casing or liner to accomplish various tasks.
- a temporary plug can be installed in the lower end of the production tubing to permit tests for the pressure bearing integrity of the tubing.
- the plug can permit the selective pressurization of the tubing to permit the operation of pressure sensitive tools within the tubing.
- Another example is the installation of temporary plugs to allow staged fracking of the well.
- Temporary plugs are typically removed from the well by mechanical retrieval techniques such as wirelines, slick lines, and coiled tubing. Because other well operations cannot be performed during such work, the retrieval of the temporary plug delays the well operations and adds additional cost to the well operations. Thus, temporary plugs that do not require retrieval have been designed. In particular, several groups have designed degradable plugs that can be solubilized or degraded at will and thereby avoid any mechanical retrieval processes.
- US5607017 for example, describes a dissolvable plug that can be used for temporary plugging of a well.
- These inventors suggest using Series 300-301 dissolvable metal manufactured by TAFA Incorporated of Concord, N.H. Such material has strength and machinability characteristics of certain metals but will disintegrate when exposed to water.
- US9151143 describes acid soluble metals including, but not limited to, barium, calcium, sodium, magnesium, aluminum, manganese, zinc, chromium, iron, cobalt, nickel, tin, any alloy thereof, or any combination thereof.
- US20150354310 describes dissolvable resin and fiber plugs.
- US9416903 and US7493956 describe hydrate plugs made of low molecular weight gas trapped in solid lattice of water molecule, that can be dissolved by means of heat or by means of a hydrate dissolving fluid, for example methanol, monoethylene glycol (MEG), diesel, and the like. Combinations of heat and dissolving fluids are typically used for this type of plug.
- a hydrate dissolving fluid for example methanol, monoethylene glycol (MEG), diesel, and the like. Combinations of heat and dissolving fluids are typically used for this type of plug.
- US20050205264 describes plugs made of an epoxy resin, a fiberglass, or a combination thereof, that can be dissolved with caustic or acidic fluids.
- US9757796 teaches wrought magnesium dissolvable alloys.
- the present disclosure provides a new way to remove degradable plugs, wherein the degradation fluid is applied with fluid jets at high pressure, thus applying an erosive force to the
- Plugs that would normally require hours or days to degrade are removable in minutes using combined erosive forces and chemical degradation.
- the advantages of the new method include one or more of the following:
- BHA bottom hole assemble
- Erosive jets can be added to coiled tubing (CT) or other tubing and used in the methods herein.
- CT coiled tubing
- any existing jet designed for acid tunneling or jet drilling may potentially be used herein, depending on both the plug position and the particular tool design.
- Such tools are typically deployed at the end of CT and the BHA consists of a jetting nozzle mole and one or more pressure-activated elbow joints that allow the jet to be directed at a variety of angles laterally. If, however, the plug is in-line with the well, the elbow or knuckle joints may not be needed, and can be either omitted or not activated.
- the jet may have a deflection component to direct the jet at 90°, 60°, 45°, or other specified angle from the well direction.
- the jet mole the distal tip of the tool that houses one or more nozzles — is optimized in size and shape for the plug type being eroded/dissolved, but this may not be essential, and existing tools may instead be repurposed without modification.
- Features that are typically optimized for use include number, placement, and angles of nozzles on the mole, shape and size of nozzle openings and thus spray parameters, fixed versus spinning jet moles, and the like.
- a turbo nozzle may be used which rotates to cover a larger area with a directed jet.
- frac plugs are provided around the circumference of the well, e.g., three at 60° from one another
- three nozzles similarly arranged around the periphery of the jet mole may direct degradation fluid at 90° to the jet hose, thus precisely targeting the three frac plugs. If this is combined with a spinning tip even a single nozzle may suffice — the rotation ensuring that all plugs are hit by erosive forces, although wasting force between the plugs.
- a rotating jet is shown in US6062311 wherein angled baffles/turbines inside the jet mole cause the mole to spin as fluid drives against the baffles.
- the size of the jets is optimized to fully cover at least the size of the plug, and the angle and spread/spray of the jets may be optimized for different plugs.
- jets may be provided at more than one angle (e.g., 80, 85, 90° for a lateral jet mole that jets fluids at 90° to the tool and well, or 0, 5, 10° for a linear system that jets fluid in-line with the well), ensuring that the plug is fully degraded even if the contours of the plug are not perfectly cylindrical.
- the tool has a fan or 360° spray that erodes the plug evenly across the entire diameter of the casing or wellbore surface, or a conical spray for an inline plug.
- Modular interchangeable jet moles may be provided for differing plug styles, allowing the main body of the tool to be used for a wide variety of different plugs.
- FIG. 1 An exemplary tool by Baker Hughes is shown in FIG. 1 and another by Calvate is shown in FIG. 2. Although these tools were developed to etch or drill tunnels off the main wells, they can be repurposed as described herein, especially where optimized nozzles are used with the main body of the tool.
- the Baker Hughes tool for example, was designed for acid drilling of carbonate plays and can be used with many acidic degradation tools for degrading acid labile plugs.
- the tool in FIG. 1 is straight until a high pressure activates the elbows (aka knuckles), causing the tool to deviate at some angle from the long axis of the well/tool, allowing lateral acid drilling.
- a mathematical model has been developed for the Baker Hughes tool (Livescu 2018; Livescu & Aitken 2019) to calculate the theoretical tunnel length and radius depending on the BHA parameters (i.e., kick-off angles, length between the two joints, length between the second joint and the jetting mole, and jetting mole diameter) and well parameters (i.e., open-hole diameter, tunnel initiation depth, and direction).
- This model can thus be used to optimize the Baker Hughes tool for plug erosion use, instead of tunnel etching use. Together with plug erosion optimized nozzles, the Baker Hughes design can easily be repurposed for use herein.
- the invention includes any one or more of the following embodiment s) in any one or more combination(s) thereof:
- a method of temporarily plugging a hydrocarbon well comprising: providing a section of tubing in a well, said tubing having one or more degradable plug(s) therein, thus providing a plugged section of well; performing a downhole activity in said plugged section of well for a period of time; and providing one or more degrading fluid(s) downhole to degrade said degradable plug, leaving no solid plug material behind and thereby opening said plugged section of well; wherein said degrading fluid is deployed at a high pressure so as to provide an erosive force to completely remove said plug in 50% of the time required to remove said plug without said high pressure and just said one or more degrading fluid(s).
- a method of temporarily plugging a hydrocarbon well comprising: providing a section of tubing in a well, said tubing having one or more degradable plug(s) therein, thus providing a plugged section of well; performing a downhole activity in said plugged section of well for a period of time; and providing one or more degrading fluid(s) downhole to degrade said degradable plug, leaving no solid plug material behind and thereby opening said plugged section of well; wherein said degrading fluid is deployed at a high pressure of > 1500 psi so as to provide an erosive force that removes said plug faster than a time required to remove said plug without said high pressure and just said one or more degrading fluid(s).
- any method herein described wherein said plug is in a side wall of a casing or tubing and said degradation fluid is applied with a jet angled at about 90° to said well.
- said plug is inline said well and said degradation fluid is applied with a jet angled at less than +/-10° to said well.
- any method herein described said method further comprising providing one or more blocking devices above and below said section, wherein said blocking devices are selected from a plug, a packer, a basket, or combinations thereof.
- said degradation fluid is an aqueous acid, an aqueous caustic, or an aqueous brine, or said degradation fluid comprises xylene, toluene, chloroform CHCh, or other aromatic solvent, or said degradation fluid is selected from dimethylformamide (DMF), dimethylacetamide (DMA), dichloromethane CH2CI2 (DCM), tetrahydrofuran (THF) acetone, hexafluoroisopropanol, or combinations thereof.
- DMF dimethylformamide
- DMA dimethylacetamide
- DCM dichloromethane CH2CI2
- THF tetrahydrofuran
- degradable plug is a threaded plug and wherein said threads are wrapped with a degradable thread tape.
- aqueous degrading fluid is an acid, such as HC1.
- degradation and its variants are intended to be read broadly to include a variety of chemical processes to remove a component, including processes of solubilizing, melting, disaggregating, monomerizing, and other sorts of chemical degradation or destruction. “Dissolving” by contrast is to become or cause to become incorporated into a liquid so as to form
- a “degradation fluid” is one that will degrade a degradable plug, leaving no discernable solids.
- Degradation triggers are usually chemical reactants, with optional accelerators or retarders to provide the desired timing for plug removal, but temperature is also a factor.
- PEU polyetherurethane
- DMF dimethylformamide
- DMA dimethylacetamide
- PAA polylactic acid
- CHCh chloroform CHCh
- DCM dichloromethane
- THF tetrahydrofuran
- acetone hexafluoroisopropanol
- Water-soluble polymers including vinyl acetate-ethylene copolymer (VAE), polyvinyl alcohol (PVOH), ethylene vinyl acetate emulsions (EVA), carboxymethyl cellulose (CMC), polyanionic cellulose (PAC), hydroxypropyl methylcellulose (HPMC), and the like will degrade in aqueous solutions.
- Silicon can be degraded with strong acids, polar organic solvents, or DYNASOLVE 230 (by DYNOLOGY®). Most degradable metals are degraded in acid, such as HC1 or synthetic HC1 (an aqueous solution of hydrogen chloride that is acidic).
- Temporary cement plugs may be eroded by water or acids at high pressures. Some elastomeric plugs are degraded in xylene, toluene, chloroform, or other aromatic solvents.
- a “dissolution fluid” is one that will dissolve a dissolvable plug, leaving no discernable solids.
- a “degradable plug” is a downhole temporary plug that serves to temporarily plug a well or a portion thereof for a period of time, but will dissolve, melt, disaggregate, or otherwise degrade under specified conditions in a degradation fluid, comprising any one or more of water, solvents, acid, caustic and/or heat.
- a “dissolvable plug” is one that is primarily removed by dissolution processes, although other processes may of course contribute in the complex downhole environment.
- Various degradable materials are used with embodiments of the invention.
- Such materials include inorganic fibers, for example of limestone or glass, but are more commonly polymers or co-polymers of esters, amides, or other similar materials. They may be partially hydrolyzed at non-backbone locations. Examples include polyhdroxyalkanoates, polyamides,
- polycaprolactones polyhydroxybutyrates, polyethyleneterephthalates, polyvinyl alcohols, polyvinyl acetate, partially hydrolyzed polyvinyl acetate, and copolymers of these materials.
- Polymers or co-polymers of esters include substituted and unsubstituted lactide, glycolide, polylactic acid, and polyglycolic acid.
- Polymers or co-polymers of amides for example, may include polyacrylamides.
- Polyols useful in the present invention are polymeric polyols that solubilize upon heating, desalination or a combination thereof, and consist essentially of hydroxyl-substituted carbon atoms in a polymer chain spaced from adjacent hydroxyl-substituted carbon atoms by at least one carbon atom in the polymer chain.
- the useful polyols are preferably essentially free of adjacent hydroxyl substituents.
- the polyols have a weight average molecular weight greater than 5000 up to 500,000 or more, and from 10,000 to 200,000 in another embodiment.
- the polyols may if desired be hydrophobically modified to further inhibit or delay solubilization, e.g., by including hydrocarbyl substituents such as alkyl, aryl, alkaryl or aralkyl moieties and/or side chains having from 2 to 30 carbon atoms.
- the polyols may also be modified to include carboxylic acid, thiol, paraffin, silane, sulfuric acid, acetoacetate, polyethylene oxide, quaternary amine, or cationic monomers.
- the polyol is a substituted or unsubstituted polyvinyl alcohol that can be prepared by at least partial hydrolysis of a precursor polyvinyl material with ester substituents.
- the degradation may be assisted or accelerated by a wash containing an appropriate dissolver or that changes the pH or salinity.
- the degradation may also be assisted by an increase in temperature.
- Preferred polymers may include polyglycolic acid (PGA), polylactic acid (PLA), polycaprolactones (PCL), polyethylene terephthalate (PET), polybutylene adipate terephthalate (PBAT), polybutylene succinate (PBS), and the like.
- PGA polyglycolic acid
- PLA polylactic acid
- PCL polycaprolactones
- PET polyethylene terephthalate
- PBAT polybutylene adipate terephthalate
- PBS polybutylene succinate
- the degradable metal alloys are usually alloys of magnesium or aluminum, and exemplary metal alloys are e.g., Magnalloy by Bubbletight (TX), EliteTM Dissolvable Magnesium Alloy by Fivestar Downhole Service (TX).
- TX Bubbletight
- TX EliteTM Dissolvable Magnesium Alloy by Fivestar Downhole Service
- An exemplary biodegradable polymer is KyronTM BP Resin by Mitsubishi Advanced Materials.
- a “jet” is a tool that expels a degradation fluid at high pressure so as to provide significant erosive force in addition to the chemical action of the degradation fluid.
- a simple hose with narrowed opening acts as a jet, but typically the nozzle is specifically designed to further increase the force of the fluid, and there may be elbows or other features to direct the jet, various connectors, and the like.
- an aluminum plug dissolved with HC1 would normally require 2-4 weeks to remove. However, using a jet tool to apply the HC1, the time would be at least reduced in half (1-2 weeks), although preferred dissolution would occur within 48-72 hours or even 12-24 hours. If combined with high temperatures, abrasives, ultrasonic cavitation, and the like, a plug may be completely dissolved with a jet erosive tool in less than 1 day, and even in hours.
- the fluid emitted from the jet may be combined with ultrasonic cavitation and/or abrasives, which will significantly increase the speed of plug degradation. See e.g., US6474349.
- a “high pressure” is that erosive pressure of degradation fluid that speeds the degradation of a solid, flat, disc of plug material at 90° to a same diameter jet by at least 50% when compared the same plug just soaking in said degradation fluid under the same conditions (typically 22 °C and 1 atm, but temperature can be increased if needed for the material in question).
- the force exerted by a jet of fluid on a flat surface can be resolved by applying the momentum equation (see e.g., uta.pressbooks.pub/appliedfluidmechanics/chapter/experiment-5/).
- a 2 cm disc material that degrades in 48 hours in a bench top experiment will be completely degraded in 24 or fewer hours by a 2 cm jet under high pressure, where conditions are otherwise the same except for the high pressure application of the erosive fluid.
- the time decrease will be 75%, 80%, 85%, 90%, 95% or more.
- Typical pressures are about 1000 psi, 1500 psi, and 2000 psi, and go up to 5000 psi, but pressures may be reduced if combined with abrasives and/or cavitation and achieve the same speed of degradation.
- an “erosive force” is a force that is applied by a fluid. It excludes mechanical forces that are supplied by tools, such as mills and drills.
- a “tape” or “thread tape” is a long flat strip of material that can be used to seal the threads or other connecting surfaces.
- a “degrading tape” is one that dissolves, melts, disaggregates, or otherwise degrades under specified conditions in a degradation fluid, leaving no discernable solid remnants in the downhole environment.
- a “dissolving tape” is a tape that is primary dissolved, although other processes can contribute to tape removal.
- Tubing can be used generically to refer to any type of oilfield pipe, such as drill pipe, drill collars, pup joints, casing, production tubing and pipeline.
- coiled tubing a thin tube stored in a coil and often used to deliver fluid to the jets.
- a “joint” is a length of pipe, usually referring to drill pipe, casing or tubing. While there are different standard lengths, the most common drill pipe joint length is around 30 ft (9 m). For casing, the most common length of a joint is 40 ft (12 m).
- tubular string or “tubing string” refers to a number of joints, connected end to end (one at a time) so as to reach down into a well, e.g., a tubing string lowers a sucker rod pump to the fluid level.
- Tubing string has a similar meaning, as applied to casing.
- the “jet mole” is a term of art in high pressure water cleaning and is evocative of the burrowing mammal. It refers to the nozzle assembly at the distal tip of the tool which houses one or more nozzles.
- FIG. 1A Prior art acid tunneling tool.
- FIG. IB Enlargement of jet mole or nozzle assembly.
- FIG. 2 Prior art jet drill for making 90° laterals.
- the jet is set to about 90°, but it be set at any desired angle by changing out the deflection shoe which functions to bend the jet hose.
- FIG. 3A well with an inline plug.
- FIG. 3B Plug being removed with jet tool of FIG. 1, leaving behind the open well in FIG. 3C.
- the small amount of debris shown in FIG. 3C is merely
- FIG. 4A well with a sidewall plug.
- FIG. 4B Plug being removed with tool having 90° jets, leaving behind the open well in FIG. 4C.
- the tool is similar to that of FIG. 1, but the jet mole is configured to provide a 90° jet rather than an inline jet.
- FIG. 5A well with a sidewall plug.
- FIG. 5B Plug being removed with the tool of FIG. 2 having a deflection shoe to turn the jet hose to 90° to reach sidewall plug, leaving behind the open well in FIG. 5C.
- the degradable plug When the degradable plug is no longer needed, it is removed by its degradation fluid which is provide by jet under high pressure directly at the plug, so as to speed its degradation by at least 50%. Thus, not only is plug removal faster, but the probability of solid remnants is also much reduced.
- the degradable plug may be combined with degradable thread tape, as described in US11053762.
- both the plug and the tape would degrade under the same degradation fluids, but it is also possible to use two fluids sequentially, if needed. If this is done, it may be preferred to dissolve the tape in advance of the plug, thus improving access to the plug by the degradation fluid.
- FIG. 1A shows one exemplary tool 100 that can be repurposed for use herein, or preferably optimized for this new use.
- Coiled tubing 99 is connected to the left end of the tool 100.
- the motorhead 101 which is a combination tool that consists of a CT connector, back pressure valve and disconnect.
- first 103, second 105 and third 107 knuckle assemblies which allow the tool to bend under high pressure. This is followed by a short spacer 109 and the jetting mole 113.
- FIG. IB shows the details of the jetting mole 113 in exploded form, wherein again from the left, we see the nozzle inlet sub 117, O-rings 111a, a short filter 118 which may be optional if abrasives are used, a locator disk 121 for holding the jet nozzles 120, and the jet nozzle O-rings 111b, finally covered by the bull nose 122 which protects the jet nozzles from impact.
- 7 small jet nozzles 120 but of course the number and shape of the nozzles may be varied depending on the plugs to be eroded.
- the nozzles can be placed at any angle, though herein shown they are inline with the well.
- the number and length of the knuckle subassemblies 103, 105, 107 may vary and this will change the angles for which the tool is capable.
- FIG. 2 provides a cross-section of a reservoir and well 200.
- Tool 203 that allows a 90° jet to be applied to a plug in the sidewall, such as frac plugs and the like.
- a plug in the sidewall such as frac plugs and the like.
- the tool is held in the center of the casing with centralizers 217, and a deflection shoe 215 bends the jet pipe 213 to an angle of 90° or any other desired angle, allowing the jet to drill laterally.
- the jet mole 219 and nozzle details are omitted herein, but as above, nozzles can vary and are typically optimized for the use.
- this tool is for jet drilling, similar design principles can be used to optimize a tool for plug erosion. Different layers of limestone 205, oil sands 207, shale 209 and near well damage 211 are also shown, but not relevant to the tool 203.
- FIG. 1 and FIG. 2 may be combined, such that the tool contains one or more knuckle subassemblies as well as a deflection shoe, thus allowing the tool use in deviated or deformed wells, yet still provided for a precise angle of deflection at the plug.
- FIG. 3 shows the method of the invention in a simplified schematic form, wherein tools such as those in FIG. 1 are repurposed for use in the method.
- FIG. 3A Shown in FIG. 3A is well with casing 301 and an inline plug 302.
- FIG. 3B shows the tool 100 deployed by coiled tubing 99 or otherwise to erode the plug 302 by a jetting degradation fluid at high pressure towards the plug 302, and
- FIG. 3C shows the plug is completely removed (a small amount of debris is shown to indicate where the plug was, but typically there will be no remnants).
- FIG. 4 shows another embodiment of the invention in a simplified schematic form.
- a side jetting tool 405 is repurposed for use in the
- FIG. 4A Shown in FIG. 4A is well with casing 401 and a sidewall plug 402.
- FIG. 4B shows the tool 405 set to erode the plug 402 by a jetting degradation fluid at high pressure towards it, and
- FIG. 4C shows the plug is completely removed.
- FIG. 5A-C The cross section of well and reservoir 500 in FIG. 5A-C is similar, showing well 501 with lateral well 503 having plug 505.
- FIG. 5B shows the repurposed tool 213 of FIG. 2 with jetting mole or head 219 reaching down the lateral well to erode plug 505.
- FIG. 5C the plug has been removed.
- the testing consisted of 4 different styles of degradable ball plugs from 4 separate vendors. These plugs were the Innovex’ s dissolvable frac ball, Yellow Jacket Ml Frac plug, Steel Haus’s ReacXion complete plug, and Kureha Degradable Plug (KDP).
- All plugs are dissolvable in aqueous solution and were set in 7’ joints of 5 1 ⁇ 2”, 23 ppf casing. The plugs were not exposed to elevated temperatures, fluids, or differential pressure. Each casing joint was installed in the test fixture and the StimTunnel BHA was placed in the casing on top of the plug. The 2.75” OD version of the StimTunnel was used for the Innovex frac balls and the 2.50” OD version was used for the rest.
- TEST 1 GENERAL The first round of tests was performed on all 4 plug types and consisted of simply jetting with fresh water with the StimTunnel tool. The tool was run pressed onto the face of the plug with a nominal amount of force while the balls were on seat. At periodic intervals pumping was stopped and the plug face was inspected. During the last 45-60 min the ball (or what was left of it) was removed and the tool pumped on the plug body only.
- TEST 1A Innovex This test consisted of 192 min of pumping, 161 min of which was done with ball on seat and 31 min was done after the ball was removed. The ball was difficult to keep on seat, and so the plug leaked for the entire duration of the test. In this test the casing between shutdowns was also rotated. The pump rate varied anywhere between 95 gpm to 105 gpm and pressures from 4400-4500 psi. Pumping and inspection occurred 5 times in this test.
- TEST IB Yellow Jacket The test consisted of 163 min of pumping, 118 min of which was done with the ball on seat and 45 min with the ball removed. The ball was epoxied on to the seat by the vendor and thus held fluid for 73 min. The pump rate varied anywhere between 95 gpm to 105 gpm and pressures from 4400-4500 psi. Pumping and inspection occurred 3 times in this test.
- Test 1C Steel Haus. The test consisted of 160 min of pumping, 121 min of which was done with ball on seat and 39 min was pumped with the ball removed. The ball was epoxied on to the seat but only held fluid for 10 min. The pump rate varied anywhere between 95 gpm to 105 gpm and pressures from 4400-4500 psi. Pumping and inspection occurred 3 times in this test.
- Test ID - Kureha The test consisted of 157 min of pumping, 78 min of which was done with ball on seat and 79 min with the ball removed. The ball was left loose on the seat and held fluid for 2 min. The pump rate varied anywhere between 95 gpm to 105 gpm and pressures from 4400 - 4500 psi. Pumping and inspection occurred 2 times in this test.
- Test 2A Innovex The test consisted of 8 min of pumping a solids-laden fluid consisting of a 0.2 ppg silica flour in a 20# gel. The ball did not stay on seat, and so the plug leaked for the entire duration of the test. The pump rate varied anywhere between 95 gpm to 105 gpm and pressures from 4400 - 4500 psi.
- Test 2B Yellow Jacket The test consisted of 16 min of pumping a solids-laden fluid consisting of a 0.2 ppg silica flour in a 20# gel. This test was pumped in 2 stages of 21 bbl each. The ball was epoxied on seat, and initially held fluid. Approximately 5 min into the pumping the plug began leaking. The pump rate varied anywhere between 95 gpm to 105 gpm and pressures from 4400 - 4500 psi.
- Test 2C Steel Haus The test consisted of 8 min of pumping, a solids-laden fluid consisting of a 0.2 ppg silica flour in a 20# gel. The ball was epoxied in place and initially held fluid. The plug began leaking 2 minutes into the test. The pump rate varied anywhere between 95 gpm to 105 gpm and pressures from 4400 - 4500 psi.
- a larger OD nozzle should be effective, e.g., a drift nozzle (a larger OD nozzle, closer to the ID of the casing) can be utilized. This will allow the erosive jets to work along the outside of the plug, attacking the slips and sealing element. The pressure drop across the nozzle may need to be adjusted in certain wells due to high well head pressures.
- the nozzle pattern needs to be altered due to use of an undersized BHA.
- the existing 2.50” OD StimTunnel tool may not cut a large enough hole to allow drift of the tool itself.
- Proposed changes for further testing may include:
- Targeted acid sweeps throughout the erosional process could also be very beneficial.
- a toughened tool will be able to accommodate abrasives.
- abrasives accelerated the erosion process significantly. However, as the plugs will most likely be in a semi-dissolved state when encountered downhole the abrasives may not be very helpful unless the ball is still mostly intact. On the plugs with larger balls, abrasives could be useful in quickly eroding past the ball to begin working on the plug body. With semi-dissolved plugs, application of acid along with erosive force will probably be most effective, but further testing will need to be done to confirm our predictions.
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CA3218336A CA3218336A1 (en) | 2021-05-14 | 2022-05-11 | Dissolvable plug removal with erosive tool |
AU2022274818A AU2022274818A1 (en) | 2021-05-14 | 2022-05-11 | Dissolvable plug removal with erosive tool |
EP22808306.9A EP4337842A1 (en) | 2021-05-14 | 2022-05-11 | Dissolvable plug removal with erosive tool |
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US202163188806P | 2021-05-14 | 2021-05-14 | |
US63/188,806 | 2021-05-14 |
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US (1) | US20220364429A1 (en) |
EP (1) | EP4337842A1 (en) |
AU (1) | AU2022274818A1 (en) |
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CN117603669A (en) * | 2024-01-24 | 2024-02-27 | 北京石大瑞伽石油技术开发有限公司 | Comprehensive blocking remover for oil, gas and water wells and use method thereof |
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US7168494B2 (en) * | 2004-03-18 | 2007-01-30 | Halliburton Energy Services, Inc. | Dissolvable downhole tools |
US20060278393A1 (en) * | 2004-05-06 | 2006-12-14 | Horizontal Expansion Tech, Llc | Method and apparatus for completing lateral channels from an existing oil or gas well |
US9920589B2 (en) * | 2016-04-06 | 2018-03-20 | Thru Tubing Solutions, Inc. | Methods of completing a well and apparatus therefor |
NO20211203A1 (en) * | 2019-04-16 | 2021-10-07 | Nexgen Oil Tools Inc | Dissolvable plugs used in downhole completion systems |
US11459846B2 (en) * | 2019-08-14 | 2022-10-04 | Terves, Llc | Temporary well isolation device |
-
2022
- 2022-05-02 US US17/735,043 patent/US20220364429A1/en active Pending
- 2022-05-11 AU AU2022274818A patent/AU2022274818A1/en active Pending
- 2022-05-11 EP EP22808306.9A patent/EP4337842A1/en active Pending
- 2022-05-11 CA CA3218336A patent/CA3218336A1/en active Pending
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US2852078A (en) * | 1954-08-12 | 1958-09-16 | Jersey Prod Res Co | Removal of cement from well casing |
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CN117603669A (en) * | 2024-01-24 | 2024-02-27 | 北京石大瑞伽石油技术开发有限公司 | Comprehensive blocking remover for oil, gas and water wells and use method thereof |
CN117603669B (en) * | 2024-01-24 | 2024-04-19 | 北京石大瑞伽石油技术开发有限公司 | Comprehensive blocking remover for oil, gas and water wells and use method thereof |
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AU2022274818A1 (en) | 2023-11-23 |
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CA3218336A1 (en) | 2022-11-17 |
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