EP2607607A1 - Procédé de stimulation - Google Patents

Procédé de stimulation Download PDF

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Publication number
EP2607607A1
EP2607607A1 EP11194998.8A EP11194998A EP2607607A1 EP 2607607 A1 EP2607607 A1 EP 2607607A1 EP 11194998 A EP11194998 A EP 11194998A EP 2607607 A1 EP2607607 A1 EP 2607607A1
Authority
EP
European Patent Office
Prior art keywords
activation means
stimulation
wells
activated
production
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.)
Withdrawn
Application number
EP11194998.8A
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German (de)
English (en)
Inventor
Jørgen HALLUNDBAEK
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.)
Welltec AS
Original Assignee
Welltec AS
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 Welltec AS filed Critical Welltec AS
Priority to EP11194998.8A priority Critical patent/EP2607607A1/fr
Priority to MX2014006799A priority patent/MX2014006799A/es
Priority to CA2858477A priority patent/CA2858477A1/fr
Priority to EP12813833.6A priority patent/EP2795047B1/fr
Priority to RU2014127065A priority patent/RU2014127065A/ru
Priority to US14/362,706 priority patent/US20140332206A1/en
Priority to PCT/EP2012/076287 priority patent/WO2013092803A1/fr
Priority to DK12813833.6T priority patent/DK2795047T3/en
Priority to BR112014013835A priority patent/BR112014013835A8/pt
Priority to CN201280060410.4A priority patent/CN103987912A/zh
Priority to AU2012357079A priority patent/AU2012357079B2/en
Publication of EP2607607A1 publication Critical patent/EP2607607A1/fr
Withdrawn legal-status Critical Current

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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
    • E21B28/00—Vibration generating arrangements for boreholes or wells, e.g. for stimulating production
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/003—Vibrating earth formations
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • E21B43/263—Methods for stimulating production by forming crevices or fractures using explosives
    • 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
    • E21B43/28—Dissolving minerals other than hydrocarbons, e.g. by an alkaline or acid leaching agent
    • E21B43/281—Dissolving minerals other than hydrocarbons, e.g. by an alkaline or acid leaching agent using heat

Definitions

  • the present invention relates to a stimulation system for stimulation of oil production in an oil field. Furthermore, the invention relates to a stimulation method.
  • hydrocarbon-containing fluid such as oil
  • primary recovery methods which utilise only the natural forces present in the reservoir.
  • supplemental recovery techniques have been employed in order to increase the recovery of oil from subterranean reservoirs.
  • the most widely used supplemental recovery technique is waterflooding which involves the injection of water into the reservoir from an injection well. As the water moves through the reservoir, it acts to displace or flush the oil therein towards a production well through which the oil is recovered.
  • reservoir pressure is thus maintained by injecting water from injection wells 1 surrounding the production wells 2.
  • the water cut of the recovered hydrocarbon-containing fluid is measured on a regular basis in production wells 2 to detect water breakthrough.
  • the water may come from the injection well or may be water which is naturally occurring from the reservoir.
  • secondary recovery methods using other drive fluids, such as CO2, methane gas or similar fluids that often are miscible in hydrocarbons.
  • stimulation of the reservoir comprises the use of tools and is rarely initiated before it is absolutely necessary, e.g. when the water cut is above a certain level, e.g. 90% water.
  • Known stimulations tools send out mechanical vibrations into the reservoir when the water cut is increasing or is above a predetermined level.
  • the tool for emitting the vibrations is then submerged into the production well to the point approximately opposite the production zone while the production is set on hold.
  • the production is then resumed after stimulation has been completed.
  • Stimulation tools may also be arranged in the injection well so that production can continue during the stimulation process. Enhancement of hydrocarbon recovery by mechanical stimulation is difficult, time consuming and extremely expensive, especially since deep wells become increasingly widespread in the extraction of oil.
  • a stimulation system for stimulation of oil production in an oil field comprising
  • the wells may be both a plurality of production wells and a plurality of injection wells, wherein the plurality of activation means may be arranged in the injection wells and/or production wells.
  • Said activation means may be activated with the frequency of once within the period of 1-185 days, preferably within the period of 1-90 days, more preferably within the period of 1-30 days, and even more preferably within the period of 5-20 days.
  • the activation means may be activated with the energy discharge of at least 0,5 kilograms TNT equivalence per activation, preferably at least 1 kilograms TNT equivalence per activation, more preferably at least 5 kilograms TNT equivalence per activation.
  • a first activation means of the plurality of activation means may be activated before a second activation means of the plurality of activation means.
  • Said first activation means may be determined as being nearest to the production well in which water cut is increasing.
  • first and second activation means may be activated on the same day, or even simultaneously.
  • first activation means may be activated on a first day of the period
  • second activation means may be activated on another day of the period.
  • the activation means may be a fluid-activated gun, said fluid being pressurised injection fluid, and the gun may convert energy from the pressurised fluid into mechanical waves, where said gun is activated several times during the period, providing vibrations having an energy of at least 0.1 kilograms TNT equivalence in total during the period.
  • the gun may be activated continuously during the period.
  • At least part of the plurality of activation means may be arranged in the plurality of injection wells, said injection wells encircling at least one production well.
  • said injection wells may encircle a plurality of production wells.
  • At least part of the plurality of said activation means may be arranged in a plurality of periphery injection wells, said periphery injection wells encircling at least one production well and at least one non-periphery injection well.
  • the activation means may be activated in a predetermined pattern determining in which injection well and/or production well the activation means is activated.
  • the activation means may consist of at least one member selected from explosives, downhole perforation guns, fluid-activated guns, seismic sources and transducers, chemical reaction guns or solid fuel guns.
  • Such solid fuel gun may comprise solid fuel, such as charcoal, graphite or cordite, and potassium nitrate or sodium nitrate.
  • the solid fuel may also be mixed with sulphur.
  • the perforation gun may comprise non-perforating charges.
  • the activation means may be activated simultaneously to the injection of an injection fluid from at least an injection well towards the at least one production well.
  • the injection fluid may have a temperature at a point of injection downhole which is higher than that of the formation.
  • the temperature of the hot fluid may be at least 10°C higher than the temperature of the formation, preferably at least 25°C higher than the temperature of the formation, and more preferably at least 50°C higher than the temperature of the formation.
  • the temperature of the hot fluid may be at least 150°C, preferably at least 175°C, and more preferably at least 200°C.
  • the injection fluid may be a fluid selected from a group consisting of gas, such as methane gas, carbon dioxide, nitrogen gas and water, or other liquids.
  • the stimulation system as described above may further comprise a plurality of openings in at least one of the wells, wherein at least two neighbouring openings have different inlet flow settings, wherein the activation means may be arranged between said two neighbouring openings having different inlet flow settings for transmission of mechanical waves into a region of the formation having a high pressure gradient, thereby releasing oil in said region.
  • inlet valves may be arranged in the openings and at least two neighbouring valves may have different inlet flow settings, wherein the activation means may be arranged between said two neighbouring valves having different inlet flow settings for transmission of mechanical waves into a region of the formation having a high pressure gradient, thereby releasing oil in said region.
  • the present invention further relates to a stimulation method comprising the steps of:
  • the activation means may be arranged in injection wells and/or production wells, the injection wells and/or production wells encircling at least one production well.
  • Said stimulation method may also comprise the step of activating the activation means in a predetermined pattern determining in which well an activation means is activated.
  • the stimulation method as described above may comprise the steps of:
  • the stimulation method as described above may comprise the step of activating all activation means of the plurality of activation means encircling at least one production well before activating any of the activation means once more.
  • the stimulation method as described above may further comprise the step of arranging a plurality of activation means in a plurality of periphery injection wells, said periphery injection wells encircling at least one production well and at least one non-periphery injection well.
  • the stimulation method as described above may further comprise the steps of:
  • stimulation method as described above may further comprise the steps of:
  • Fig. 1 shows an illustration of an oil field 101 seen from above, comprising two production wells 2a, 2b and six injection wells 1a, 1b, 1c, 1d, 1e, 1f.
  • the invention relates to a stimulation system 100 comprising a plurality of wells and a plurality of activation means 3 arranged in the wells.
  • the activation means are arranged each in a well in the oil field 101, where each well may be an injection well 2 and/or a production well 3.
  • the activation means may be arranged all in production wells or all in injection wells, or a combination thereof.
  • the activation means 3 are activated with a frequency between 1 and 365 days and with an energy discharge of at least 0.1 kilograms TNT equivalence per activation.
  • the activation period is 1-365 days before the activation means 3 is activated again.
  • Fig. 2 shows a stimulation system 100 for stimulation of oil production in the oil field 101.
  • the stimulation system 100 comprises a plurality of injection wells 1, a plurality of production wells 2 and a plurality of activation means 3 arranged in the injection wells 1.
  • the production is stimulated on a regular basis and not just when the water cut is increasing.
  • the pools of oil i.e. subsurface oil accumulations such as volumes of rock, such as limestone, sandstone or shale, filled with small oil-filled pores, are then affected continuously by the discharged energies and the production of oil from the formation is enhanced.
  • the low frequency mechanical stimulation initiate micro-fracturing of the formation, especially in limestone formation but also in sandstone and other types of oil-bearing formation, or maybe even collapses of micro-cavities in the formation containing oil, gas or a mixed fluid, thereby changing the pressure regime in the formation and displacing the fluids towards the production wells 2.
  • the micro bores created by the stimulation enable the oil to flow and accumulate in larger pools or areas of oil-containing fluid.
  • an injection fluid simultaneously to the stimulation of the reservoir by mechanical stimulation
  • the larger pools or areas of oil-containing fluid may be forced towards the production wells 2 close to the injection wells 1.
  • Stimulation and injection are not necessarily performed simultaneously, since interchanging patterns of stimulation and injection may also be equally effective, since the velocity of propagation is very different in injection and stimulation e.g. water penetration or mechanical wave propagation.
  • the activation frequency of the stimulation system of Fig. 2 may be that one activation means is activated in one well every 6 days, where a first activation means 3a of a first injection well 1a is activated on day one. On the second day, the activation means opposite the production wells 2a, 2b and most remote from the first activation means 3a is activated. The activation means 3 not already activated, opposite the production wells 2a, 2b and most remote from the second activation means 3b of the second injection well 1b, is activated on the third day.
  • the fourth activation means 3d of the fourth injection well 1d is activated since this activation means is the activation means furthest away from the third activation means 2b and opposite the production wells 2a, 2b, which is not activated in this activation period. Then the fifth activation means 3e of the fifth injection well 1e is activated, and finally the sixth activation means of the sixth injection well is activated. Thus, the activation period is 6 days during which all activation means involved are activated once.
  • the sequence of activations 3a, 3f, 3b, 3d, 3c, 3e resembles an alternating "star" pattern sequence, also known from other technical fields such as from the tightening bolts on car wheels, flanges etc.
  • sequences may be superimposed or suboptimised due to specific knowledge of characteristics of a given formation.
  • the production may be stimulated continuously and not just when the water cut has increased to above a certain level.
  • the energy resource for recovering the hydrocarbon-containing fluid is utilised in a more optimal manner than when stimulation is only initiated above a predetermined water cut level. In the latter case, energy is then used for recovering an unnecessary amount of water while continuous stimulation keeps the water content and therefore also the energy used for bringing up water at a minimum.
  • the area/volume of oil is changed or displaced.
  • the area of oil may be split into several areas as shown in Fig. 3a , or the area may no longer occur as a level horizontal layer as shown in Fig. 4a .
  • the oil-containing area 20 may therefore be displaced relative to the production zone 10, 10a, 10b in the production well 2 so that the production well produces oil-containing fluid with a water cut which is too high.
  • the area containing oil accumulates again, so the injection fluid pushes the oil-containing area from one side as shown in Fig. 3b , or levels out so the injection fluid pushes the oil-containing area from below, as shown in Fig. 4b .
  • the energy discharged from the activation means is thus transmitted to oil-containing parts of the formation which may then accumulate oil in larger areas.
  • the oil-containing fluid is accumulated in a large area surrounding the production well and oil-containing fluid is thus able to flow into the production well again.
  • the injection fluid from the other injection wells 1 flows into the production well and takes over the keeping the oil-containing fluid from flowing into the production well. It is therefore important that more than one of the surrounding injection wells 1 of the production well are activated to force the oil-containing fluid towards the production well and to surround the production well, so that the injection fluid leaves the oil-containing fluid to act as drive fluid.
  • the oil-containing fluid By activating the oil field 101 continuously from various injection wells 1 and/or production wells 2, the oil-containing fluid is helped accumulate in larger areas. Furthermore, the energy discharge provides micro bores in the formation in areas or collapses in micro-cavities where an adequate pressure gradient is present and thus helps the oil-containing fluid trapped in pockets to flow and accumulate into larger areas of oil-containing fluid.
  • the activation means 3 is controlled to discharge energy in a predetermined pattern determining in which injection well and/or production well the activation means 3 is activated. Some of the activation means may be activated more than others, and some may even be activated on the same day. The activation means being activated more than some of the others is/are the first activation means determined as being nearest to the production well in which water cut is increasing.
  • the activation means 3 are activated more frequently in the predetermined pattern or the pattern is changed. If the water cut still increases, the pattern is changed so that the activation means nearest to the production well, in which the water cut is increasing, is activated more frequently than others, or the pattern is maintained and the frequency is increased until the water cut is decreasing again.
  • the activation means may be arranged both in the injection wells 1 and the production wells 2.
  • the source of the energy is closer to the area to be activated. However, it may disturb the production of that production well.
  • the activation means in the injection wells 1 the source may be further away from the area to be activated. Hence, this activation means does not disturb production, and when using some activation means, e.g. a fluid-activated gun, the injection of injection fluid or drive fluid is not hindered either.
  • the activation means 3 of the stimulation system is a fluid-activated gun in which the injection well is pressurised with injection fluid in order to activate the gun and inject fluid into the reservoir at the same time and thereby convert energy from the pressurised fluid into mechanical waves.
  • the gun is activated several times during the activation period, providing vibrations having a total energy of at least 0.1 kilograms TNT equivalence during the period 1-365 days.
  • the activation means needs to be activated more than the explosive-activated gun due to the fact that in one discharge, the perforating gun discharges much more energy than possible for a fluid-activated gun.
  • the explosive-activated gun needs to be reloaded on a regular basis, hindering the production if the gun is arranged in the production well.
  • the fluid-activated gun is arranged in the injection well and does not need to be reloaded and furthermore does not necessarily hinder the flow in the well.
  • the production well is often closed while performing the activation as a safety precaution, and thus the production is set on hold while stimulating.
  • the activation means may be a downhole perforation gun, a fluid-activated gun, a seismic source, a chemical reaction gun or a solid fuel gun.
  • the perforation gun may comprise non-perforating charges, and thus be a non-perforating gun.
  • the fluid activated gun may be a gas activated gun, and thus the injection fluid 3 is gas, such as methane gas, carbon dioxide or nitrogen gas.
  • the gas accumulates in a piston chamber in the gun, driving a piston in one direction in the chamber compressing a spring, and when the spring cannot be compressed any further, a release mechanism is activated and the piston moves at a high velocity in the opposite direction hammering into the back wall of the chamber creating the mechanical waves.
  • the gas gun is activated by pulsed injection fluid 3, creating the hammering effect to generate the mechanical waves.
  • the chemical reaction gun is a gun in which at least two chemicals react to vaporise and thus provide mechanical waves travelling into the formation.
  • the chemicals may be sent down in two flow lines, each supplying a chemical which is mixed in the gun.
  • the chemicals may be the two gases oxygen and methane or the potassium permanganate and dichromate.
  • One or all of the chemicals that are to react may also be present in the gun from the beginning, working as an oxidant, such as potassium dichromate or potassium permanganate, that may be activated using another chemical, and thereby, in a controlled process, release energy and a rapidly expanding gas.
  • Hydrocarbon-based fuels such as gasoline, gasoil or diesel may also be used as reagents and be supplied through a flowline.
  • the solid fuel gun comprises solid fuel, such as charcoal, graphite or cordite, and potassium nitrate or sodium nitrate.
  • the solid fuel may also be mixed with sulphur.
  • the solid fuel gun is ignited by arc ignition.
  • the injection fluid is hot fluid having a temperature at a point of injection downhole which is higher than that of the formation.
  • the temperature of the hot fluid is at least 10°C higher than the temperature of the formation, preferably at least 25°C higher than the temperature of the formation, and more preferably at least 50°C higher than the temperature of the formation.
  • the temperature of the hot fluid is at least 150°C, preferably at least 175°C, and more preferably at least 200°C in order to be higher than the formation temperature.
  • the injection fluid is gas, such as methane gas or carbon dioxide, or water, such as sea water.
  • the stimulation system comprises 10 production wells 2 and 18 injection wells 1, wherein some of the injection wells are periphery injection wells encircling at least one production well and at least one non-periphery injection well.
  • the periphery injection wells are marked in Fig. 6 by a dotted line 27.
  • the activation means in the periphery injection wells are activated before the other injection well and may also be activated more frequently in order to encircle the oil-containing fluid and force the oil-containing fluids towards the production wells 2.
  • the non-periphery injection wells are activated more frequently than the periphery injection wells due to the fact that the fluid surrounding the production wells 2 are drained from the formation, and therefore room is provided for the injection fluid to find its way to the production zone as illustrated in Fig. 4a .
  • the water cut and also the water hold are determined using a water cut meter and a flow meter in at least the production well.
  • the activation of activation means may be performed even though the production wells 2 are producing satisfactorily in order to prevent the production from decreasing or the water cut from increasing.
  • the activation frequency of the activation means may be increased if the water cut is above a preselected range or decreased if the water cut is below a preselected range.
  • the production is optimised, meaning that the water cut is kept at an optimal level.
  • activation means continuously with the predetermined frequency By having such continuous activation, it is possible to bring up more oil-containing fluid from the oil field 101 than by means of conventional methods and to increase the percentage which the oil-producing company is able bring up from a reservoir.
  • oil is recovered, only a maximum of 40% is brought up. The rest is left in the reservoir, and by bringing up the 40%, the reservoir may be disturbed to a degree where it is not possible to bring up the remaining 60%. Therefore, there has been a long-felt need to increase this percentage.
  • the production well 2 has a plurality of openings in a first production zone 10a, and in a second production zone 10b the production well comprises other openings.
  • inlet valves 7a are arranged, and in the openings in the second production zone inlet valves 7b having different inlet flow settings from the valve of the first production zone are arranged.
  • a pressure gradient is created in a region 8 of the formation between the two production zones illustrated by a dotted line area, and by arranging the activation means transmitting mechanical waves into the region of the formation having the pressure gradient, oil-containing fluid is released in that region as micropores are created enabling the oil-containing fluid to flow and accumulate into greater pools.
  • the production zones are separated by means of annular barriers 9.
  • the activation means is arranged in an injection well 1 between two injection sections 5a, 5b having different outlet flow settings at the openings 5 in the casing 25.
  • the two outlet sections 5a, 5b where one outlet section 5a has a different flow setting than the other outlet section 5b, creating the pressure difference in the region 8 between the two injection sections 5a, 5b.
  • the activation means transmits mechanical waves into the region 8 having the high pressure gradient, thereby creating micro bores in the formation, in particularly in sandstone or limestone formation and thus releases oil trapped therein.
  • Water injection typically leads to an increase in the amount of oil which may be extracted from a reservoir; however, at some point, water injection will not be able to force any more oil out of the reservoir leading to an increase in the water cut.
  • the increase in water cut may originate from the water injection or from water presence close to the reservoir.
  • mechanical waves through such part of the formation, may energise the formation such that oil droplets or particles in the formation may gain enough energy to escape surfaces binding the oil droplets or particles in the formation, thereby allowing them to be dissolved in the free flowing fluids in the formation, e.g. injection fluid. This may further increase the oil production in the reservoir, leading to a decrease in the water cut of the oil-containing fluid in the production wells 2.
  • the formation may be forced to crack, fracture or splinter allowing oil droplets or particles to escape closed oil pools, closed pores in the formation or other closed volumes in the formation, thereby increasing the level of oil in the oil-containing fluid.
  • the activation means may be powered and controlled via a wireline 18.
  • the activation of the activation means can be controlled from the top of the well, and the activation pattern can easily be changed from surface if the water cut has changed.
  • activations means pre-integrated in well tubular structures of injection wells during completion may be appropriate and activated from the surface, e.g. by propagation of pressure waves through the injection fluid present in the injection well.

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  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Physical Or Chemical Processes And Apparatus (AREA)
  • Edible Oils And Fats (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Physical Water Treatments (AREA)
  • Other Liquid Machine Or Engine Such As Wave Power Use (AREA)
EP11194998.8A 2011-12-21 2011-12-21 Procédé de stimulation Withdrawn EP2607607A1 (fr)

Priority Applications (11)

Application Number Priority Date Filing Date Title
EP11194998.8A EP2607607A1 (fr) 2011-12-21 2011-12-21 Procédé de stimulation
MX2014006799A MX2014006799A (es) 2011-12-21 2012-12-20 Metodo de estimulacion.
CA2858477A CA2858477A1 (fr) 2011-12-21 2012-12-20 Procede de stimulation
EP12813833.6A EP2795047B1 (fr) 2011-12-21 2012-12-20 Procédé de stimulation
RU2014127065A RU2014127065A (ru) 2011-12-21 2012-12-20 Способ воздействия на пласт
US14/362,706 US20140332206A1 (en) 2011-12-21 2012-12-20 Stimulation method
PCT/EP2012/076287 WO2013092803A1 (fr) 2011-12-21 2012-12-20 Procédé de stimulation
DK12813833.6T DK2795047T3 (en) 2011-12-21 2012-12-20 Stimulate process
BR112014013835A BR112014013835A8 (pt) 2011-12-21 2012-12-20 sistema de estimulação para estimulação de produção de petróleo em um campo petrolífero e método de estimulação
CN201280060410.4A CN103987912A (zh) 2011-12-21 2012-12-20 增产方法
AU2012357079A AU2012357079B2 (en) 2011-12-21 2012-12-20 Stimulation method

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP11194998.8A EP2607607A1 (fr) 2011-12-21 2011-12-21 Procédé de stimulation

Publications (1)

Publication Number Publication Date
EP2607607A1 true EP2607607A1 (fr) 2013-06-26

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EP11194998.8A Withdrawn EP2607607A1 (fr) 2011-12-21 2011-12-21 Procédé de stimulation
EP12813833.6A Not-in-force EP2795047B1 (fr) 2011-12-21 2012-12-20 Procédé de stimulation

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Application Number Title Priority Date Filing Date
EP12813833.6A Not-in-force EP2795047B1 (fr) 2011-12-21 2012-12-20 Procédé de stimulation

Country Status (10)

Country Link
US (1) US20140332206A1 (fr)
EP (2) EP2607607A1 (fr)
CN (1) CN103987912A (fr)
AU (1) AU2012357079B2 (fr)
BR (1) BR112014013835A8 (fr)
CA (1) CA2858477A1 (fr)
DK (1) DK2795047T3 (fr)
MX (1) MX2014006799A (fr)
RU (1) RU2014127065A (fr)
WO (1) WO2013092803A1 (fr)

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Publication number Priority date Publication date Assignee Title
GB2526297A (en) * 2014-05-20 2015-11-25 Maersk Olie & Gas Method for stimulation of the near-wellbore reservoir of a wellbore
CN105781511A (zh) * 2016-02-29 2016-07-20 烟台智本知识产权运营管理有限公司 一种中高渗透油藏增产的方法
RU2674354C1 (ru) * 2017-03-24 2018-12-07 Виктор Владимирович Варакута Комплект оборудования для виброволнового воздействия на углеводородсодержащий пласт

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US9228419B1 (en) * 2014-03-18 2016-01-05 Well-Smart Technologies—Global, Inc Acoustic method and device for facilitation of oil and gas extracting processes
US9745839B2 (en) * 2015-10-29 2017-08-29 George W. Niemann System and methods for increasing the permeability of geological formations
CN105735952B (zh) * 2016-02-29 2018-05-08 烟台智本知识产权运营管理有限公司 一种中高渗透油藏提高原油采收率的方法
CN109469468A (zh) * 2017-09-07 2019-03-15 中国石油天然气股份有限公司 一种通过振动叠加改变油藏渗流性的方法
CN109973037B (zh) * 2019-05-22 2021-06-25 西南石油大学 储层开采激励结构以及页岩气储层的开采方法
CN112576215B (zh) * 2020-12-09 2021-10-01 河海大学 一种用于油页岩分段水力压裂的超声波装置及施工方法
CN114412434B (zh) * 2022-01-20 2022-09-13 中国矿业大学 一种深部煤炭资源地下原位流态化开采方法

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RU2014127065A (ru) 2016-02-10
DK2795047T3 (en) 2016-10-24
EP2795047B1 (fr) 2016-07-06
CA2858477A1 (fr) 2013-06-27
BR112014013835A2 (pt) 2017-06-13
EP2795047A1 (fr) 2014-10-29
MX2014006799A (es) 2014-07-09
WO2013092803A1 (fr) 2013-06-27
BR112014013835A8 (pt) 2017-06-13
US20140332206A1 (en) 2014-11-13
AU2012357079B2 (en) 2015-09-17
AU2012357079A1 (en) 2014-07-24

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