EP2469018A1 - Procédé de récupération de méthane dans le charbon - Google Patents

Procédé de récupération de méthane dans le charbon Download PDF

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Publication number
EP2469018A1
EP2469018A1 EP10015909A EP10015909A EP2469018A1 EP 2469018 A1 EP2469018 A1 EP 2469018A1 EP 10015909 A EP10015909 A EP 10015909A EP 10015909 A EP10015909 A EP 10015909A EP 2469018 A1 EP2469018 A1 EP 2469018A1
Authority
EP
European Patent Office
Prior art keywords
injection well
driving fluid
injection
well
coal seam
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Withdrawn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
EP10015909A
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German (de)
English (en)
Inventor
Michael Heisel
Heinz-Dieter Obermeyer
José Angelo Gianezi
José Carlos Esmeraldo
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.)
Linde GmbH
Original Assignee
Linde GmbH
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 Linde GmbH filed Critical Linde GmbH
Priority to EP10015909A priority Critical patent/EP2469018A1/fr
Publication of EP2469018A1 publication Critical patent/EP2469018A1/fr
Withdrawn legal-status Critical Current

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    • 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
    • E21B43/006—Production of coal-bed methane

Definitions

  • the invention is related to a process for the recovery of methane stored in a coal seam, whereby a driving fluid is injected through at least one injection well into the coal seam, and whereby the desorbed products including methane are recovered by at least one production well.
  • an injection well is an essentially vertical pipe in the ground into which water, other liquids, or gases are pumped or allowed to flow.
  • a production well is an essentially vertical pipe in the ground through which product gases or liquids are lifted to the surface.
  • Coal seams usually contain methane adsorbed on the solid matrix of the coal.
  • methane adsorbed on the solid matrix of the coal.
  • Such kind of methane is usually called coalbed methane, often referred to as CBM, or 'sweet gas' because of its lack of hydrogen sulfide is distinct from a typical sandstone or other conventional gas reservoir, as the methane is stored within the coal by an adsorption process.
  • the methane is in a near-liquid state, lining the inside of pores within the coal (called the matrix).
  • the open fractures in the coal (called the cleats) can also contain free gas or can be saturated with water.
  • coalbed methane Unlike much natural gas from conventional reservoirs, coalbed methane contains very little heavier hydrocarbons such as propane or butane, and no natural gas condensate. It often contains up to a few percent carbon dioxide. Usually such coalbed methane consists of mainly methane and trace quantities of ethane, nitrogen, carbon dioxide and few other gases.
  • the adsorbed methane could be recovered.
  • the methane is released when the coal seam is depressurised.
  • wells are drilled into the coal seam, the seam is dewatered, then the methane is extracted from the seam, compressed and piped to market.
  • the goal is to decrease the water pressure by pumping water from the well. The decrease in pressure allows methane to desorb from the coal and flow as a gas up the well to the surface.
  • Another known method is the use of a driving fluid, which is injected into the coal seam by an injection well. This decreases the partial pressure of the methane which leads to an increased desorption of methane, or displaces the methane due to better adsorption properties of the injected fluid in comparison to methane.
  • the desorbed methane could be recovered to the surface through a production well.
  • the injection of the driving fluid into the coal seam thereby usually takes place via horizontal holes in the wall of the injection well, which are distributed across the entire periphery of the line. The driving fluid is thus pressed out of the injection well so as to be distributed in all spatial directions in a spherically even manner.
  • the present invention is thus based on the objective of embodying a process for the recovery of methane stored in a coal seam of the afore-mentioned type in such a manner that the needed amount of the driving fluid is reduced.
  • the driving fluid is pressed out of the vertical injection well into the coal seam under pressure in a positioned and directed manner under pressure and the driving fluid is pressed out of the vertical injection well into the coal seam via at least one horizontal outlet means in the wall of the vertical injection well.
  • the basic idea of the invention is the use of simple outlet means in or at the wall of the vertical injection well to introduce the driving fluid in a directed and positioned manner into the coal seam.
  • the directed and positioned injection of the driving fluid according to the invention creates a rather finger-shaped expansion front of the driving fluid.
  • Such outlet means could be simple openings or any other kind of means which are suitable for a more or less horizontal injection of the driving fluid into the coal seam.
  • the simplest possibility for ensuring a positioned press-in in terms of the invention are one-sided holes in the injection well, that is, the injection well encompasses holes for the driving fluid escape, which are only distributed across a part of the periphery, maximally across half of the periphery.
  • an escape of the driving fluid in a positioned manner refers to the flow of the largest part of the driving fluid along a preferred axis.
  • an escape in the case of which the driving fluid quantity flows in a solid angle of 360° so as to be uniformly distributed, that is, when it flows out of the injection well in all directions of space in a uniform manner, is an undirected escape.
  • the fluid immediately around the segment of the injection well from which the fluid escapes is not uniformly distributed in an imaginary cone volume, but mainly within a certain solid angle of 180° at most.
  • the flowing fluid is limited at least within a hemispherical segment, but for the most part within a cone segment within an imaginary sphere volume around the injection well.
  • the driving fluid is not equally distributed around the injection well.
  • the driving fluid is pressed out of the injection well in a defined directed and positioned manner. Therefore the needed amount of driving fluid could be minimised.
  • the directed and positioned injection enables a directed stream of the driving fluid in the coal seam and allows the desorption of methane from specific, predetermined volumes of the coal seam.
  • the driving fluid is simply pressed out of injection well in an undirected manner into the surrounding coal seam via holes, which are uniformly distributed across the periphery of the line. Due to the large pressure difference between the injection well for the fluid supply and the surrounding rock, it is assumed that the driving fluid expands from the injection well into the surroundings in a spherical and uniformly distributed manner. However, tests in practice reveal that this is not the case. A uniform expansion of the fluid from the injection well in all directions of space requires the geological surrounding of the injection well to have approximately the same conditions. However, this is not the case in most of the coal seams.
  • one or several injection wells are used for pressing in the driving fluid, wherein an effect is to be attained at points, such as one or several productions wells, for example, which are located at a distance from one another. Pressing a fluid into a geological surrounding is thereby not necessarily successful.
  • an effect in terms of an increased production of methane in the production well can often only be established after several weeks and after a high consumption of fluid.
  • the driving fluid expands to a considerably improved extent in the direction away from the production well than in the direction towards the production well. According to a method of the state of the art, a large quantity of driving fluid is used in such a case, possibly without thereby attaining an increased production rate.
  • the driving fluid is pressed out of the injection well into the surroundings in a positioned manner.
  • the fluid can hereby be directed and positioned to a point, where the presumed effect is to be attained, such as the production well.
  • the fluid expands much more rapidly in the direction of the production well than in the case of a method according to the state of the art.
  • fingering occurs when too much driving fluid is pressed into the coal seam at too high pressure or speed. In such a case the driving fluid breaks through to the production well without any driving effect at the desorbed methane. Since such a break-through leads to mechanical cleaning of the break-through channel the pressure drop there is lower than in the adjacent coal seam. As a result any further injected driving fluid preferably flows through this channel and therefore does not drive any methane from adjacent coal volumes. Fingering is therefore feared because it bears the risk of rendering an injection well inefficient, in extreme cases even useless. Such a common effect of the prior art could be avoided or even used as advantage by the inventive process.
  • carbon dioxide in the gaseous or supercritical stage and/or nitrogen in the gaseous or liquid stage are used as driving fluid.
  • suitable micro organism are injected together with the above mentioned driving fluids into the coal seam.
  • the driving fluid is pressed out of the injection well into the coal seam via at least one horizontal outlet means designed as injection nozzle.
  • Injection nozzles are means, which have been well-proven for establishing a fluid flow in a positioned manner.
  • the pressing into the surroundings of the injection well is mainly carried out within a solid angle of 90°, preferably of 45°, particularly preferably between 10° and 30°.
  • the reduced amount of used driving fluid has an additional advantage at the further processing of the recovered methane.
  • the reduced amount of fluid to drive the methane to the production well leads to a reduced dilution of the recovered methane. Therefore the number of purification stages of the recovered methane could be reduced/minimised.
  • the direction of escape of the driving fluid preferably the angle between main axes of the injection well and direction of escape
  • the geological factors, where the greatest desired effect is attained by means of the driving fluid supply, can be ascertained particularly quickly by means of a step by step variation of the angle between main axis of the injection well and fluid escape. It is thus furthermore possible to press the driving fluid from one injection point into the entire coal seam. The entire coal seam can thus be exploited with little effort.
  • the number of boreholes can be reduced as compared to a method according to the state of the art.
  • the angle is thereby preferably changed by controlling the orientation of the free moving nozzle.
  • the direction of escape of the driving fluid is oriented on the structure of the rock in the surroundings, that it preferably does not deviate more than 45° from the rock structure and that it is particularly preferably oriented parallel to the rock structure.
  • the driving fluid is pressed in a positioned manner via two different injection wells, wherein the press-in direction of the driving fluid of the first injection well encompasses an angle to the press-in direction of the driving fluid of the second injection well.
  • the methane which is driven in a direction between the production well and the second injection well by pressing in the driving fluid via the first injection well, in the direction of the production well by pressing driving fluid via the second injection well in a positioned manner.
  • the driving fluid is pressed into the coal seam via a first injection well and via a second injection well, wherein the second injection well is not located on the connecting line between the first injection well and the production well, and the driving fluid is pressed out of the second injection well in a positioned manner such that the methane is pushed in the direction of the production well.
  • the angle between press-in direction of the driving fluid out of the first injection well and the connecting line between first injection well and production well is changed in such a manner that the angle area between the connecting line of first injection well and production well and the connecting line of first injection well and second injection well is passed successively.
  • all of the methane in a triangle which is formed by the three lines, e.g. the two injection wells and the production well, can be recovered by means of two lines for pressing in driving fluid in a positioned manner and by means of one production well.
  • the first driving fluid flow is diverted in such a manner that the methane is always pressed in the direction of the production well from each point within the triangle.
  • the driving fluid is pressed out in succeeding pulses.
  • the driving fluid is advantageously injected in regular pulses of predetermined length.
  • a pulse is thereby understood to be the time period from start to stop of the injection of the driving fluid.
  • several pulses of predetermined length are thereby injected consecutively. There is no fluid injection between two pulses. The velocity respectively the pressure of the fluid is roughly constant during a pulse.
  • the injection of different driving fluids in response to succeeding pulses has also proven to be advantageous.
  • the time lag between two injection pulses is not shorter than the length of a single pulse, preferably it is one to ten times the length of a single pulse.
  • the size of the fluid cushion is reduced by increasing the pressure during the injection process and is subsequently increased again as the pressure drops.
  • This effect becomes smaller with decreasing pulse lengths. Measurements have shown that it is even possible for a negative effect to occur in the case of pulses, which are too short. In these cases, the injected fluid substantially escapes again through the injection well, without having driven the methane in the direction of the production well. A sufficiently long pulse period must be observed.
  • the time lag between two injection pulses is thus not shorter than the length of a single pulse. Measurements have shown that a negative effect may occur in the case of shorter periods, that is, the fluid is not pressed in the direction towards the production well by means of the pulse. However, longer periods are possible. A time lag between two injection pulses, which is one to ten times the pulse length, is preferred for an economically sensible operation.
  • the period required by the gas to cover half the distance between the injection well and the production well is particularly preferred as minimal pulse length.
  • a speed in the range of from 0.5 m/min to 5 m/min is assumed. The speed is thereby a function of the porosity of the respective coal seam. In the case of a coal seam comprising a high porosity, a high fluid speed can be assumed.
  • the driving fluid is pressed out from more than one injection well in a positioned manner, wherein pulse length, pulse distance and/or start of the injection in the case of at least one injection well is/are different from pulse length, pulse distance and/or start of the injection in the case of at least one other injection well.
  • pulse length, pulse distance and/or start of the injection in the case of at least one injection well is/are different from pulse length, pulse distance and/or start of the injection in the case of at least one other injection well.
  • the combined fluid flow is conveyed past the production well; pulse length, pulse distance and/or time of the injections must therefore be chosen in such a manner that all of the fluid is injected in the direction of the production well.
  • the quantities of injected fluids from at least two lines are adjusted in such a manner that the injected fluid from a first injection well is diverted in the direction of the production well by means of the quantity of the injected fluid from at least a second injection well.
  • the quantity of injected fluid from the second injection well is thereby adjusted in such a manner that it can divert the injected fluid from the first injection well in the direction of the production well.
  • the quantity of the fluid injected in the second injection well is similar to the magnitude of the quantity of the injected fluid from the first injection well.
  • the ratio of the quantities of the injected fluids lies between 10:1 and 1:1.
  • the direction of the introduced fluids from at least two injection wells is advantageously adjusted in such a manner that the combined fluid flow from the injection wells is oriented in the direction of the production well.
  • the quantities of introduced driving fluid from at least two injection wells are adjusted in such a manner that the introduced driving fluid from a first injection well is diverted in the direction of the production well by means of the quantity of the injected driving fluid from at least a second injection well.
  • Figure 1 shows an exemplary embodiment of the method according to the invention, wherein the fluid is injected into coal seam via the two injection wells 1 and 2. Both injection wells 1 and 2 are located at approximately the same distance from the production well 3.
  • the driving gas flow G1 is injected into the coal seam from the injection well 1 in a pulsed manner.
  • the driving gas flow G2 is also introduced into the coal seam from the injection well 2 in a pulsed manner. Pulse durations of approx. 20 min are used thereby.
  • the time lag between two pulses of an injection is approx. 1 hour.
  • the injected gas quantities G1 and G2 are thereby in the same magnitude in each case.
  • a resulting gas flow G3 forms, which moves in the direction of the production well 3.
  • the methane is thus driven in the direction of the production well 3 by means of the positioned and pulsed driving gas flows.
  • nitrogen and carbon dioxide are injected so as to alternate, so that the different characteristics of both gases can be used for the coal bed methane recovery.

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Chemical & Material Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Solid Fuels And Fuel-Associated Substances (AREA)
EP10015909A 2010-12-21 2010-12-21 Procédé de récupération de méthane dans le charbon Withdrawn EP2469018A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
EP10015909A EP2469018A1 (fr) 2010-12-21 2010-12-21 Procédé de récupération de méthane dans le charbon

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Application Number Priority Date Filing Date Title
EP10015909A EP2469018A1 (fr) 2010-12-21 2010-12-21 Procédé de récupération de méthane dans le charbon

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EP2469018A1 true EP2469018A1 (fr) 2012-06-27

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Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5332036A (en) * 1992-05-15 1994-07-26 The Boc Group, Inc. Method of recovery of natural gases from underground coal formations
US5944104A (en) * 1996-01-31 1999-08-31 Vastar Resources, Inc. Chemically induced stimulation of subterranean carbonaceous formations with gaseous oxidants

Patent Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5332036A (en) * 1992-05-15 1994-07-26 The Boc Group, Inc. Method of recovery of natural gases from underground coal formations
US5944104A (en) * 1996-01-31 1999-08-31 Vastar Resources, Inc. Chemically induced stimulation of subterranean carbonaceous formations with gaseous oxidants

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