EP3551839A1 - Bohrlochhochleistungslaserheizung im bohrloch und frakturierungsstimulation und verfahren - Google Patents

Bohrlochhochleistungslaserheizung im bohrloch und frakturierungsstimulation und verfahren

Info

Publication number
EP3551839A1
EP3551839A1 EP17822858.1A EP17822858A EP3551839A1 EP 3551839 A1 EP3551839 A1 EP 3551839A1 EP 17822858 A EP17822858 A EP 17822858A EP 3551839 A1 EP3551839 A1 EP 3551839A1
Authority
EP
European Patent Office
Prior art keywords
formation
laser
laser beam
delivery device
motor
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.)
Granted
Application number
EP17822858.1A
Other languages
English (en)
French (fr)
Other versions
EP3551839B1 (de
Inventor
Sameeh Issa BATARSEH
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Saudi Arabian Oil Co
Original Assignee
Saudi Arabian Oil Co
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Saudi Arabian Oil Co filed Critical Saudi Arabian Oil Co
Publication of EP3551839A1 publication Critical patent/EP3551839A1/de
Application granted granted Critical
Publication of EP3551839B1 publication Critical patent/EP3551839B1/de
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
    • E21B43/2405—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection in association with fracturing or crevice forming processes
    • 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
    • E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
    • E21B36/001—Cooling arrangements
    • 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
    • E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
    • E21B36/04—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using electrical heaters
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • E21B43/2607—Surface equipment specially adapted for fracturing operations
    • 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
    • E21B47/00—Survey of boreholes or wells
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/11—Perforators; Permeators
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/11—Perforators; Permeators
    • E21B43/114—Perforators using direct fluid action on the wall to be perforated, e.g. abrasive jets

Definitions

  • apparatus and methods for wellbore stimulation More specifically, embodiments related to apparatus and methods that incorporate lasers for wellbore stimulation applications.
  • Hydraulic fracturing is one method for stimulating a wellbore.
  • Conventional hydraulic fracturing injects water at high pressure into the wellbore, which causes fractures of the formation.
  • an explosive charge is used to perforate the casing and cementing.
  • An explosive charge is a high impact technology that can cause compaction, deformation of the hole, and sanding and crushing the grains of the rock material. The crushed grains of rock material can be pushed into the formation, blocking the formation and reducing production.
  • apparatus and methods for wellbore stimulation More specifically, embodiments related to apparatus and methods that incorporate lasers for wellbore stimulation applications.
  • a system for fracturing a formation from a wellbore extending into the formation from a surface includes a laser surface unit located on the surface, the laser surface unit configured to generate a laser beam, a fiber optic cable optically connected to a laser delivery device of a thermal shocking tool, the fiber optic cable configured to transmit the laser beam to the laser delivery device to produce a focused laser beam, a power cable electrically connected to a power source on the surface, the power cable configured to transmit electrical energy to a motor, a fluid line connected to a cooling fluid source on the surface, the fluid line configured to supply a cooling fluid to a cooling system of the thermal shocking tool to produce a cooling fluid stream, a protective shaft extending into the wellbore, wherein the fiber optic cable, the power cable, and the fluid line are contained within the protective shaft, the motor configured to rotate a motor shaft, and the thermal shocking tool physically connected to the motor.
  • the thermal shocking tool includes a protective case configured to encompass the laser delivery device and the cooling system, a rotational shaft connected to the motor shaft such that as the motor shaft rotates the rotational shaft rotates, the laser delivery device extending from the rotational shaft, the laser delivery device configured to transform the laser beam to a focused laser beam, wherein the focused laser beam is operable to increase the temperature of the formation to a fracture temperature, and the cooling system extending from the rotational shaft opposite the laser delivery device, the cooling system comprising one or more cooling nozzles extending through the protective case such that the one or more cooling nozzles are configured to introduce the cooling fluid stream onto the formation such that the cooling fluid stream reduces the temperature of the formation, where the laser delivery device and the cooling system rotate around the wellbore as the rotational shaft rotates, where rotation of the rotational shaft is configured to alternate between increasing the temperature of the formation and reducing the temperature of the formation such that thermal shocks occur and fractures are formed in the formation.
  • the system further includes a purge nozzle, the purge nozzle positioned between the surface and the motor, where the purge nozzle is configured to keep debris from settling on the motor.
  • the cooling fluid is selected from the group consisting of nitrogen gas, liquid nitrogen, helium, air, carbon dioxide, and water.
  • the fracture temperature is 2000 deg. C.
  • the system further includes an acoustic capability.
  • the focused laser beam can increase the temperature of the formation to the fracture temperature in less than 1 second.
  • the laser delivery device can be positioned to introduce the focused laser beam to the formation at a pre-determined angle.
  • a method for fracturing a formation from a wellbore extending into the formation from a surface includes the steps of introducing a focused laser beam to the formation such that the focused laser beam is operable to increase the temperature of the formation to a fracture temperature.
  • the focused laser beam is produced by a laser delivery device extending from a rotational shaft.
  • the method further includes a step of introducing a cooling fluid stream to the formation such that the cooling fluid stream is operable to reduce the temperature of the formation, where the cooling fluid stream is produced by a cooling system.
  • the cooling system device extending from the rotational shaft opposite from the laser delivery device; and rotating the rotational shaft such that the formation is alternately introduced to the focused laser beam and the cooling fluid such that thermal shocks occur and fractures in the formation are formed.
  • the method further includes the steps of generating a laser beam in a laser surface unit, and transmitting the laser beam from the laser surface unit to the laser delivery device through a fiber optic cable.
  • the method further includes the steps of transmitting electrical energy from a power source to a motor through a power cable, and transforming the electrical energy to mechanical energy in the motor, such that the mechanical energy rotates a motor shaft, wherein the motor shaft is connected to the rotational shaft such that as the motor shaft rotates the rotational shaft rotates.
  • the method further includes the step of measuring the sound emitted by an acoustic capability.
  • FIG. 1 is a plan view of an embodiment of the laser fracturing tool.
  • FIG. 2 is a plan view of the laser fracturing tool including the motor and the thermal shocking tool.
  • FIG. 3 is a plan view of an embodiment of the thermal shocking tool.
  • FIG. 4 is a pictorial representation of core samples fractured by laser.
  • the laser fracturing tool can be used to establish fluid communication between the wellbore and the formation to improve production of formation fluids.
  • the laser fracturing tool can provide a targeted method of fracturing the formation as compared to a conventional hydraulic fracturing.
  • the laser fracturing tool can be used to target the location of the fracture, such as targeting the angle and depth of the fracture.
  • the laser can be located along fault lines.
  • the rotation of the laser fracturing tool means the method of fracturing can be implemented around the entire circumference of the wellbore without the need to reposition the tool.
  • the laser fracturing tool in the absence of a hydraulic fracturing step.
  • the absence of hydraulic fracturing has environmental advantages as hydraulic fracturing consumes and pollutes large quantities of water.
  • the laser fracturing tool produces less damage to the rock material of a formation than conventional hydraulic fracturing.
  • FIG. 1 is an elevation view of laser fracturing tool 100.
  • Laser fracturing tool 100 is deployed in wellbore 10 of formation 40.
  • Surface 30 is the surface of the earth from which wellbore 10 extends.
  • Wellbore 10 extends from surface 30 into formation 40.
  • Formation 40 can be any type of formation composed of any type of rock material. In at least one embodiment, formation 40 contains limestone. In at least one embodiment, formation 40 contains sandstone. In at least one embodiment, formation 40 contains shale.
  • Wellbore 10 can be finished with casing 20 and cement 25 for reinforcement.
  • Laser surface unit 50 can be located on surface 30 near wellbore 10. Laser surface unit 50 can be in optical communication with laser fracturing tool 100 via fiber optic cable 55. Laser surface unit 50 can be configured to excite energy to a level above the sublimation point of formation 40 to form a laser beam (not shown). The sublimation point of formation 40 can be determined based on the rock material contained in formation 40, where the rock material controls the sublimation point which then controls the excitation energy of the laser beam. In at least one embodiment, laser surface unit 50 can be tuned to excite energy to different excitation levels as can be required for different formations. Laser surface unit 50 can by any type of laser unit capable of generating a laser beam and introducing said laser beam into a fiber optic cable.
  • laser surface unit 50 examples include lasers of ytterbium, erbium, neodymium, dysprosium, praseodymium, and thulium ions.
  • laser surface unit 50 can be a 5.34-kW ytterbium doped multiclad fiber laser.
  • Fiber optic cable 55 can be any cable containing an optical fiber capable of transmitting a laser beam from laser surface unit 50 to laser fracturing tool 100.
  • Fiber optic cable 55 can include one or more optical fibers.
  • one or more fiber optic cables can provide electrical communication between laser surface unit 50 and laser fracturing tool 100.
  • fiber optic cable 55 provides a path for light from laser surface unit 50 to laser fracturing tool 100.
  • fiber optic cable 55 can conduct a raw laser beam from laser surface unit 50 to laser fracturing tool 100.
  • a "raw laser beam” as used herein refers to a laser beam that has not been passed through lenses or otherwise focused.
  • Power source 60 can be located on surface 30 near wellbore 10. Power source 60 can be in electrical communication with laser fracturing tool 100 via power cable 65. Power source 60 can be any apparatus capable of generating electrical energy. Power cable 65 can be any type of cable capable of transmitting electrical energy to laser fracturing tool 100.
  • Cooling fluid source 70 can be located on surface 30 near wellbore 10 and can provide a cooling fluid to laser fracturing tool 100. Cooling fluid source 70 is in fluid communication with laser fracturing tool 100 via fluid line 75, such that the cooling fluid is delivered to laser fracturing tool 100 from cooling fluid source 70.
  • Fluid line 75 can be any type of tube capable of supplying a fluid to laser fracturing tool 100.
  • the cooling fluid can include nitrogen gas, liquid nitrogen, helium, air, carbon dioxide, and water.
  • the cooling fluid can be selected based on the rock material of formation 40 and the thermal properties of the rock material. The temperature gradient desired between the fracture temperature and the cooled temperature, the rotation period of the thermal shocking tool, and the efficiency of the cooling fluid in reducing the temperature of the rock material.
  • one or more fluid lines 75 can be in fluid communication with cooling fluid source 70 and laser fracturing tool 100.
  • Fiber optic cable 55, power cable 65, and fluid line 75 can be encompassed in protective shaft 80.
  • Protective shaft 80 can be any material of construction suitable for use in a downhole environment without experiencing mechanical or chemical failure.
  • downhole environment refers to the high operating pressure, high operating temperature, and fluid conditions that can be found in a wellbore extending into a formation.
  • FIG. 2 is a section view in elevation of one embodiment of laser fracturing tool 100 as understood with reference to FIG. 1.
  • Laser fracturing tool 100 includes motor 200 and thermal shocking tool 300.
  • Power cable 65 is in electrical communication with motor 200, such that power cable 65 transmits electrical energy to motor 200.
  • Motor 200 is physically connected to motor shaft 210.
  • Motor 200 can be any motor capable of converting electrical energy transmitted by power cable 65 into mechanical energy to rotate motor shaft 210 in a downhole environment.
  • Motor shaft 210 is physically connected to rotational shaft 310 of thermal shocking tool 300.
  • Fiber optic cable 55 is in optical communication with thermal shocking tool 300.
  • Cooling fluid line 75 is in fluid communication with thermal shocking tool 300.
  • purge nozzle 220 can be located between motor 200 and surface 30, such that purge nozzle 220 is configured to deliver a fluid to the wellbore. In at least one embodiment, purge nozzle 220 can be located between motor 200 and surface 30 near motor 200 such that purge nozzle 220 is operable to deliver the fluid near motor 200. In at least one embodiment, purge nozzle 220 delivers the fluid such that the fluid is operable to clean motor 200, such that the purge fluid from purge nozzle 220 can keep dust and debris from settling on motor 200. In at least one embodiment, purge nozzle 220 delivers the fluid such that the fluid is operable to direct the produced fluid in wellbore 10.
  • purge nozzles 220 can be configured in a purge nozzle configuration (not shown) such that the purge nozzle configuration is configured to deliver the fluid to multiple points in wellbore 10.
  • the purge fluid can be any fluid capable of cleaning the motor and directing fluid. Examples of purge fluid can include air and nitrogen gas.
  • the purge fluid can be at the ambient temperature of the purge fluid source (not shown). In an alternate embodiment, the purge fluid is from cooling fluid source 70.
  • FIG. 3 is a section view in elevation of a thermal shocking tool 300 with reference to features described in FIG. 2.
  • Thermal shocking tool 300 includes protective case 305, rotational shaft 310, cooling system 320, and laser delivery device 330.
  • Protective case 305 surrounds rotational shaft 310, cooling system 320, and laser delivery device 330.
  • Protective case 305 can be formed from any materials capable of withstanding the downhole environment without suffering mechanical failure. Cooling system 320 and laser delivery device 330 can extend into and through protective case 305.
  • Rotational shaft 310 connected to motor shaft 210 extends through protective case 305.
  • Rotational shaft 310 rotates as motor shaft 210 rotates as driven by motor 200.
  • Rotational shaft 310 provides an axis around which cooling system 320 and laser delivery device 330 rotate.
  • Rotational shaft 310 can provide physical support, such as an anchor to cooling system 320 and laser delivery device 330.
  • Cooling system 320 and laser delivery device 330 are mounted to rational shaft 310 such that cooling system 320 is opposite laser delivery device 330.
  • Rotational shaft 310 can be any material of construction suitable for use in a downhole environment that is rigid enough to provide physical support to cooling system 320 and laser delivery device 330.
  • Cooling system 320 can include one or more cooling nozzles 325 as shown in FIG. 3. Cooling nozzles 325 are fluidly connected to fluid line 75, such that the cooled purge fluid is delivered from cooling fluid source 70. Cooling system 320 can be configured to introduce the cooling fluid to formation 40 as a cooling fluid stream. The cooling fluid stream is operable to reduce the temperature formation 40.
  • Laser delivery device 330 is optically connected to fiber optic cable 55.
  • Laser delivery device 330 can be configured to focus the laser beam from fiber optic cable 55 to produce a focused beam.
  • laser delivery device 330 can incorporate the features and details set forth in U.S. Pat. No. 9,217,291.
  • the focused laser beam is operable to increase the temperature of formation 40.
  • the focused laser beam can be directed to sublimate the casing and the cement prior to contact formation 40.
  • the focused laser beam can precisely cut the casing and the cement.
  • the focused laser beam can increase the temperature of formation 40 in less than one second to a fracture temperature.
  • the fracture temperature can reach 2,000 degrees Celsius (deg C).
  • the less than one second increase in temperature to the fracture temperature can cause thermal shocks in formation 40 which results in fractures, microfractures and cracks in the rock material of formation 40.
  • microfractures refers to fractures in the range from a millimeter to a few centimeters that can be used for initiating fractures.
  • thermal shocks refers to the expansion and contraction of the formation rock over a time period on the order of seconds.
  • laser delivery device 330 continuously causes an increase in temperature of formation 40 around the wellbore. While laser delivery device 330 increases the temperature of formation 40, cooling system 320 decreases the temperature.
  • the cooling fluid stream can be directed at formation 40, such that the cooling fluid stream can reduce the temperature of the formation to a cooled temperature. The cooled temperature depends on the fluid used as the cooling fluid stream.
  • the laser delivery device can include acoustic capability to monitor and record the fracturing sound due to the thermal shocking tool.
  • Acoustic capability can include transducers or geophones. Fracturing sound can be used to indicate the fracture length and size.
  • the acoustic capability can be placed above the motor, below the thermal shocking tool, or both above the motor and below the thermal shocking tool. Power can be supplied to the acoustic capability from power source 60 (not shown). The acoustic capability can transmit the measurements directly to the surface or can be stored and retrieved after the laser fracturing.
  • Example 1 A dry core sample measuring 2" x 2" of Berea and limestone was obtained. A 3 kW power laser was used to produce a continuous laser beam of 0.35 inches. The laser beam was turned on for four (4) seconds before being switched off. Fractures immediately formed in the core sample. Air , at room temperature, was used as the cooling fluid stream on one side of the core sample to orient the fractures. As can be seen in FIG. 4, fractures formed in the core sample.
  • Optional or optionally means that the subsequently described event or circumstances can or may not occur.
  • the description includes instances where the event or circumstance occurs and instances where it does not occur.
  • Ranges may be expressed as from one particular value to another particular value. When such a range is expressed, it is to be understood that another embodiment is from the one particular value to the other particular value, along with all combinations within said range.

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  • 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)
  • Geophysics (AREA)
  • Laser Beam Processing (AREA)
EP17822858.1A 2016-12-08 2017-12-07 Bohrlochhochleistungslaserheizung im bohrloch und frakturierungsstimulation und verfahren Active EP3551839B1 (de)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US15/373,070 US10385668B2 (en) 2016-12-08 2016-12-08 Downhole wellbore high power laser heating and fracturing stimulation and methods
PCT/US2017/065003 WO2018106857A1 (en) 2016-12-08 2017-12-07 Downhole wellbore high power laser heating and fracturing stimulation and methods

Publications (2)

Publication Number Publication Date
EP3551839A1 true EP3551839A1 (de) 2019-10-16
EP3551839B1 EP3551839B1 (de) 2020-09-16

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EP17822858.1A Active EP3551839B1 (de) 2016-12-08 2017-12-07 Bohrlochhochleistungslaserheizung im bohrloch und frakturierungsstimulation und verfahren

Country Status (5)

Country Link
US (1) US10385668B2 (de)
EP (1) EP3551839B1 (de)
CN (1) CN110036179B (de)
CA (1) CA3045929C (de)
WO (1) WO2018106857A1 (de)

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Also Published As

Publication number Publication date
CA3045929C (en) 2021-04-27
US10385668B2 (en) 2019-08-20
EP3551839B1 (de) 2020-09-16
WO2018106857A1 (en) 2018-06-14
US20180163524A1 (en) 2018-06-14
CN110036179B (zh) 2021-07-30
CN110036179A (zh) 2019-07-19
CA3045929A1 (en) 2018-06-14

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