WO2015062922A1 - Procédé d'extraction de gaz naturel et de condensats de gaz naturel à partir de gisements de gaz à condensats - Google Patents

Procédé d'extraction de gaz naturel et de condensats de gaz naturel à partir de gisements de gaz à condensats Download PDF

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Publication number
WO2015062922A1
WO2015062922A1 PCT/EP2014/072601 EP2014072601W WO2015062922A1 WO 2015062922 A1 WO2015062922 A1 WO 2015062922A1 EP 2014072601 W EP2014072601 W EP 2014072601W WO 2015062922 A1 WO2015062922 A1 WO 2015062922A1
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Prior art keywords
gas condensate
natural gas
production
deposit
underground
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PCT/EP2014/072601
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German (de)
English (en)
Inventor
Vladimir Stehle
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Wintershall Holding GmbH
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Publication of WO2015062922A1 publication Critical patent/WO2015062922A1/fr

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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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in 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
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • 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
    • E21B43/14—Obtaining from a multiple-zone well

Definitions

  • the present invention relates to a process for the production of natural gas and / or natural gas condensate from a subterranean gas condensate deposit containing a gas mixture with retrograde condensation behavior.
  • Gas mixtures with retrograde (retrogressive) condensation behavior coming from the gas phase, undergo a partial condensation in the event of an isothermal reduction in pressure and return to the gas phase on further lowering of the pressure.
  • retrograde condensation behavior occurs in a gas mixture whose temperature is above the critical temperature of the gas mixture.
  • Natural gas mixtures containing, for example, besides methane, ethane, propanes and butanes, 2 to 20% by volume of heavy hydrocarbons (C 5 +, such as, for example, pentanes and hexanes) generally have a retrograde condensation behavior.
  • the phase behavior of gas mixtures with retrograde condensation behavior is shown by way of example in FIG.
  • This liquid gas condensate can block the Bohrlochnahzone, whereby the delivery rate of natural gas and / or natural gas condensate through the production wells decreases sharply or even completely comes to a standstill.
  • This effect is particularly pronounced in the production of natural gas and / or natural gas condensate deposits from gas condensate deposits which have a low permeability.
  • the area where the liquid gas condensate blocks the flow of natural gas and / or natural gas condensate to the production well may be 5 to 100 m wide.
  • the region in which the blocking is brought about by the liquid gas condensate generally has a quasi-cylindrical shape in the center of which the production bore lies. The lowering of the reservoir ruck occurring due to the conveyance and the consequent blocking with liquid gas condensate can in some cases even lead to the loss of the reservoir.
  • RU 2018639 describes a method for preventively preventing the formation of liquid gas condensate in a gas condensate reservoir.
  • the process described there is also known as "cycling-process.”
  • the heavy hydrocarbons (C 5 +) are separated from light hydrocarbons (such as methane, ethane, and propanes) by light hydrocarbons Gas “pressed back into the deposit to increase the reservoir pressure.
  • the "cyc // ng" process is very time-consuming and cost-intensive and, with this process, the formation of liquid gas condensate in gas condensate deposits can not be reliably prevented.
  • SU 605429 describes a process for the development of gas condensate deposits.
  • the deposit is flooded with highly mineralized water.
  • the high mineralization prevents the dissolution of gases in the flood water and thus allows the displacement of the natural gas and the natural gas condensate the area of the borehole near the production well.
  • a disadvantage of this method is the massive destruction of the deposit by the injected flood water.
  • the injected flood water itself can lead to a blockage of the Bohrlochnahzone. This method does not allow for an effective increase in production rates.
  • SU 1596081 and RU 2064572 disclose methods of treating the gas condensate reservoir with seismic waves.
  • the seismic waves should thereby lead to an increase in the delivery rate from the gas condensate deposit. This process is not very efficient, especially in low-lying deposits.
  • RU 2415257 describes a method of stimulating the rates of delivery of gas condensate deposits by electromagnetic waves. This method is also unsuitable, especially for low-lying deposits.
  • RU 2245997 discloses a method in which solvents are injected into the well area at cyclic intervals to dissolve the liquid gas condensate.
  • the solvents used for this purpose are aqueous mixtures of acetone and methanol, chloroform and methanol or acetone and chloroform.
  • a disadvantage of this method is that the introduced aqueous mixtures also lead to a dilution of Bohrlochnah Kunststoffs.
  • the process is associated with the organic solvents used at an enormous cost.
  • the organic solvents used also cause environmental problems due to their toxicity.
  • EP 12 186 281 and EP 12 186 285 describe processes for the extraction of natural gas and / or natural gas condensate from underground gas condensate deposits, in which the liquid gas condensate blocking the Bohrlochnahzone is converted into the gaseous state of matter. This is done by injecting flowable compositions containing urea and optionally metals such as aluminum, magnesium or calcium. After injecting the flowable composition, the urea in the subterranean gas condensate reservoir hydrolyzes to ammonia and carbon dioxide and the metals are oxidized with evolution of heat. As a result, a significant pressure increase is achieved in the blocked Bohrlochnahzone.
  • RU 2 366 803 discloses a process for the development of underground gas condensate deposits. To release the blockage in the well area In the method according to RU 2 366 803, the production of natural gas from the underground gas condensate deposit is cyclically reduced or completely stopped. After a blockage of the Bohrlochnahzone is registered by liquid gas condensate, the production is throttled or completely adjusted in the process according to RU 2 366 803. By throttling or ceasing production, the pressure in the blocked borehole near zone of the underground gas condensate deposit increases again. The pressure increase is brought about here by a pressure equalization within the underground gas condensate deposit.
  • the present invention is therefore based on the object to provide an improved method for the production of natural gas and / or natural gas condensate from underground gas condensate deposits containing a gas mixture having a retrograde condensation behavior.
  • the method should not or only to a lesser extent have the disadvantages of the prior art described above.
  • the process should be inexpensive and easy to carry out and result in an effective increase in the production rate of natural gas and / or natural gas condensate from gas condensate deposits after the well area has been blocked by liquid gas condensate.
  • the method should be feasible in particular without lengthy production interruptions.
  • the object is achieved by a method for the production of natural gas and / or natural gas condensate from a subterranean gas condensate deposit (5), the Containing a gas mixture with retrograde condensation behavior, comprising at least the process steps a) placing a production well (1) in the underground gas condensate deposit (5), b) perforating the production well (1) to form a first perforation section (61) in the underground gas condensate C) perforating the production well (1) to form a second perforation section (62) located in the underground gas condensate reservoir (5), d) installing a production tubing (14) in the production well ( 1) and sealing the annular space (11) between the outer wall of the production tubing (14) and the inner wall of the production well (1) in the region between the first and the second perforation section (61, 62), e) conveying natural gas and / or natural gas condensate from the underground gas condensate deposit (5) either ei) through the first perforation abs chn
  • the present invention also provides a process for the production of natural gas and / or natural gas condensate from a subterranean gas condensate deposit (5) containing a gas mixture with retrograde condensation behavior, comprising at least the process steps a) placing a production well (1) in the underground gas condensate - Bearing (5), b) perforating the production well (1) to form a first perforation section (61) disposed in the underground gas condensate deposit (5), c) perforating the production well (1) to form a second perforation section (Fig.
  • the inventive method allows the effective increase in the delivery rate of natural gas and / or natural gas condensate from a gas condensate deposit.
  • the inventive method allows the resolution of blockages by liquid natural gas condensate in the Bohrlochnahzone.
  • the method according to the invention has the advantage that it manages without toxicologically harmful substances.
  • the inventive method prevents dilution of the Bohrlochnahzone the gas condensate deposit.
  • the method according to the invention enables the continuous production of natural gas and / or natural gas condensate from a subterranean gas condensate deposit without lengthy production interruptions.
  • the production bore (1) for dissolving the blockage does not have to be converted. This increases the cost efficiency of the inventive method over the methods described in the prior art.
  • the process according to the invention can be used in all gas condensate deposits (5) which contain a gas mixture with a retrograde condensation behavior.
  • Such gas condensate deposits (5) are also referred to as retrograde gas condensate deposits (5).
  • the gas mixture contained in the underground gas condensate deposit (5) generally contains from 80 to 98% by volume of light hydrocarbons and from 2 to 20% by volume of heavy hydrocarbons.
  • light hydrocarbons are understood according to the invention methane, ethane, propanes and butanes.
  • Heavy hydrocarbons according to the invention hydrocarbons with 5 and more Carbon atoms understood, for example, pentanes, hexanes and heptanes, and optionally higher hydrocarbons.
  • propanes, butanes, pentanes, hexanes and heptanes are understood in the present case to mean both the unbranched hydrocarbon compounds and also all branched isomers of the abovementioned hydrocarbon compounds.
  • the properties of gas mixtures with retrograde condensation behavior are shown purely by way of example in FIG.
  • the area denoted by (al) describes the single-phase region in which the gas mixture is present exclusively in liquid form.
  • the single-phase region marked with (av) shows the region in which the gas mixture is exclusively gaseous.
  • the region marked (l + v) shows the biphasic region in which one part of the gas mixture is in liquid form and another part is in gaseous form.
  • (CP) shows the critical point of the gas mixture connecting the bubble point curve (bpc) to the dew point curve (dpc).
  • the Bubble Point Curve (bpc) is also referred to as the bubble-point curve
  • the dew point curve (dpc) is also called the dew-point curve.
  • the bubble point curve (bpc) separates the single-phase liquid region (a1) from the biphasic region (l + v).
  • the gas mixture is virtually 100% liquid and contains only infinitesimal amounts of gas.
  • the dew point curve (dpc) separates the single-phase gaseous region (av) from the two-phase region (l + v).
  • the gas mixture is virtually 100% gaseous and contains only infinitesimal amounts of liquid.
  • T On the horizontal axis is the temperature (T), on the vertical axis the pressure (P) is plotted.
  • a gas mixture with a retrograde condensation behavior undergoes a partial condensation in the event of an isothermal reduction in pressure and reverts to the gas phase on further lowering of the pressure.
  • the retrograde condensation behavior usually occurs at temperatures which are above the critical point (CP) of the gas mixture.
  • T-i critical point of the gas mixture.
  • the gas mixture with retrograde condensation behavior at point (A) is gaseous and single-phase.
  • the gas mixture at point (B) reaches the dew point curve (dpc).
  • the gas mixture is virtually 100% gaseous, but it begins a to form an infinitesimal amount of liquid.
  • the gas mixture passes into the two-phase region (l + v), in which a liquid phase is formed by partial condensation in addition to the gas phase.
  • natural gas and liquid natural gas condensate are juxtaposed in a two-phase system.
  • the gas mixture again reaches the dew point curve (dpc) (marked by dot (D) in FIG. 1).
  • the dew point curve (dpc) is exceeded, the gas mixture reverts to the single-phase gaseous state.
  • point (E) in Figure 1 the gas mixture is again in gaseous and single-phase.
  • the illustration in FIG. 1 merely serves to explain the condensation behavior of retrograde gas mixtures without restricting the present invention.
  • the reservoir temperature T L of the gas condensate reservoirs (5) from which natural gas and / or natural gas condensate are conveyed by the process according to the invention is usually in the range from greater than 65 to 200 ° C., preferably in the range from 70 to 150 ° C., particularly preferably in the range of 80 to 140 ° C and in particular in the range of 85 ° C to 120 ° C.
  • the present invention thus also relates to a process in which the underground gas condensate deposit (5) has an initial reservoir temperature (T L ) in the range of greater than 65 to 200 ° C, preferably in the range of 70 to 150 ° C, particularly preferably in Range of 80 to 140 ° C and in particular in the range of 85 to 120 ° C.
  • the initial reservoir pressure (P L ) that is, the pressure of prior to carrying out the method according to the invention (initial pressure) is usually in the range of 80 to 1500 bar preferably the initial reservoir pressure (P L ) in the range of 300 to 600 bar
  • the permeability of the underground gas condensate deposits (5) is generally in the range of 0.01 to 10 mD (MilliDarcy).
  • 1 Darcy corresponds to 1 ⁇ 2 .
  • the permeability of the underground gas condensate deposit is therefore generally in the range of 0.01 * 10 -3 to 10 * 10 -3 ⁇ 2.
  • the porosity of the underground gas condensate deposits (5) is generally in the range of 0.1 to 30%.
  • the underground gas condensate deposit (5) is bounded on its upper side generally by a cover layer (2) and on its underside by a sole (3).
  • the cover layer (2) and the sole (3) are generally impermeable layers, for example, rock or clay layers.
  • the subject matter of the present invention is thus also a method in which the underground gas condensate deposit (5) is bounded on its upper side by a covering layer (2) and on its underside by a sole (3).
  • the underground gas condensate deposit (5) is generally stored at depths (depths) in the range of 0.5 to 5 km (km means kilometers).
  • the underground gas condensate deposit (5) generally has a layered structure.
  • the underground gas condensate reservoir (5) generally comprises production layers (5a) containing the gas mixture with retrograde condensation behavior.
  • the number of production layers (5a) can vary widely.
  • the number of production layers (5a) may be, for example, 2 to 100, preferably 3 to 50.
  • the production layers (5a) are generally separated by intermediate layers (5b).
  • the intermediate layers (5b) may be impermeable or partially permeable.
  • the intermediate layers (5b) can be constructed of clay, sand or other minerals.
  • the thickness of the underground gas condensate deposit (5) can vary widely.
  • the thickness of the underground gas condensate deposit (5) is generally in the range of 5 m to 200 m, preferably in the range of 10 m to 150 m (m means meters).
  • the present invention thus also relates to a process in which the underground gas condensate deposit (5) has a thickness in the range of 5 to 200 m.
  • the underground gas condensate deposit (5) generally has a layered structure, with the stratification being generally horizontal.
  • the permeability of the underground oil reservoir is therefore generally much higher in the horizontal direction than in the vertical direction.
  • the term "horizontal” is understood to mean not only laminations which run exactly parallel to the horizontal plane, but rather also stratifications which deviate from the horizontal plane by up to 30 °, the deviation being positive in this case
  • the deviation from the horizon plane may also be negative, in which case the stratification will have a negative slope, towards the center of the earth.
  • the alignment of the stratification of the underground gas condensate deposit (5) may thus deviate by a maximum of +/- 30 °, preferably by a maximum of +/- 20 ° and more preferably by a maximum of +/- 10 ° from the horizontal plane.
  • a production well (1) is drilled into the underground gas condensate deposit (5).
  • the sinking of the production well (1) into the underground gas condensate deposit (5) is carried out by conventional methods known to the person skilled in the art and is described, for example, in EP 0 952 300.
  • two or more production holes (1) can be drilled, in which then each of the further method steps b) to e) are performed.
  • the term "a production well (1)" according to the invention thus understood both exactly one production well (1) and two or more production wells (1).
  • the production well (1) can be a vertical, horizontal or a deflected production well (1).
  • the production bore (1) in step a) is deflected down (drilled).
  • the production well is a deflected bore comprising a quasi-vertical section (12) and an arcuate section (13).
  • the subject matter of the present invention is thus also a method in which the production bore (1) comprises a quasi-vertical section (12) and an arcuate section (13).
  • quadsi-vertical is understood to mean not exclusively sections (12) of the production bore (1) which exactly follow the direction of the solder, but also sections (12) of the production bore (1) which are up to a maximum of 40 °, preferably up to a maximum 25 ° and particularly preferably at most 15 ° deviate from the direction of the solder.
  • the quasi-vertical section (12) of the production well (1) generally corresponds to the depth of the underground gas condensate deposit (5).
  • the depth here defines the distance from the surface (9) to the top of the underground gas condensate deposit (5). In other words, the distance from the surface (9) to the bottom of the cover layer (2).
  • the quasi-vertical section (12) of the production well (1) may, for example, have a length in the range of 0.5 to 5 km.
  • natural gas and / or natural gas condensate can be pumped from underground gas condensate deposits (5) which lie in a depth in the range from 0.5 to 5 km (km means kilometers).
  • the quasi-vertical section (12) is followed, in a preferred embodiment, by an arcuate section (13).
  • arcuate is understood according to the invention that the arcuate portion (13), starting from the quasi-vertical portion (12), initially has a negative slope, which merges into a positive slope at the apex of the arc.
  • the subject matter of the present invention is thus also a method in which the arcuate section (13), starting from the quasi-vertical section (12), initially has a negative slope which changes into a positive slope at the vertex of the arc.
  • the arcuate portion (13) of the production well (1) generally has a length in the range of 0, 1 to 1 km.
  • the portion of the negative pitch arcuate portion (13) traverses the underground gas condensate deposit (5) from the top layer (2) to the bottom (3).
  • the traversing of the gas condensate deposit (5) from the top layer (2) to the bottom (3) is also referred to as "first traversal".
  • the vertex of the arcuate portion (13) is preferably in the sole (3).
  • the subject of the present invention is thus also a method in which the vertex of the arcuate section (13) is arranged in the sole (3).
  • the portion of the arcuate portion (13) of positive slope traverses through the subsurface gas condensate deposit (5) from the sole (3) to the top layer (2).
  • the traversing of the gas condensate deposit (5) from the sole (3) to the top layer (2) is also referred to as "second traversal".
  • the production well (1) thus passes through the underground gas condensate deposit (5) twice.
  • the subject of the present invention is therefore also a method in which the production well (1) the gas condensate deposit first coming from the cover layer (2) to the sole (3) and a second time at least partially from the sole in the direction of the cover layer (2) traversed.
  • the portion of the arcuate portion (13) of positive slope need not fully pass through the underground gas condensate deposit (5).
  • the production well (1) is cased and cemented for stabilization by casings.
  • the production bore (1) is perforated to form a first perforation section (61).
  • the production bore (1) is perforated to form a second perforation section (62).
  • Both the first perforation section (61) and the second perforation section (62) are arranged in the underground gas condensate deposit (5).
  • first perforation section (61) and “second perforation section (62)" are introduced here only for distinguishing the two perforation sections.
  • the first perforation section (61) is preferably arranged in the region of the first crossing of the production bore (1) through the underground gas condensate deposit (5).
  • the second perforation section (62) is preferably arranged in the region of the second crossing of the production well (1) through the underground gas condensate deposit (5).
  • the first perforation section (61) is preferably in the portion of the arcuate section (13) of negative slope.
  • the second perforation section (62) is preferably located in that part of the arcuate section (13) which has a positive slope.
  • the first perforation section (61) corresponds to the path of the negative slope arcuate section (13) traversing the subterranean gas condensate reservoir (5) from the cover layer (2) to the sole (3).
  • the second perforation section (62) corresponds to the entire length of the arcuate section (13) of the production well (1) which traverses the underground gas condensate deposit (5) from the sole (3) towards the cover layer (2) , In other words, this means that the production well (1) is perforated over the entire length of the second crossing of the underground gas condensate deposit (5).
  • first perforation section (61) and “second perforation section (62)” are introduced only to distinguish the perforation sections. This means that the sequence of process steps b) and c) can be varied.
  • first method step b) and then method step c) is performed.
  • method step c) and then method step b) are carried out first.
  • the method steps b) and c) are carried out simultaneously.
  • the length of the perforation sections (61; 62) is selected in a preferred embodiment such that the perforation sections (61; 62) each traverse the entire underground gas condensate deposit (5).
  • the length of the perforation sections (61, 62) may independently of one another be, for example, in the range from 1 to 250 m, preferably in the range from 5 to 200 m and particularly preferably in the range from 10 to 150 m.
  • the subject matter of the present invention is thus also a method in which the length of the perforation sections (61, 62) is in each case independently in the range from 1 to 250 m.
  • the distance between the first perforation section (61) and the second perforation section (62) can vary within wide ranges.
  • the distance between the first perforation section (61) and the second perforation section (62) is in the range of 50 to 2000 m, preferably in the range of 100 to 1000 m, and particularly preferably in the range of 100 to 500 m.
  • the subject matter of the present invention is therefore also a method in which the distance between the perforation sections (61, 62) is in the range of 50 to 2000 m.
  • the perforation sections (61) and (62) known methods described in the prior art are used.
  • the ball perforation can be used.
  • a cumulative perforator can be used. Methods for ball perforation are described for example in RU 2 358 100.
  • the generation of the perforation sections (61, 62) can take place directly after method step a).
  • the casing is perforated with.
  • further perforation sections can optionally be produced before method step d).
  • a third perforation section, a fourth perforation section and further perforation sections can be produced.
  • a production tubing string (14) is installed in the production well (1).
  • the annulus (11) is formed between the outer wall of the production tubing (14) and the inner wall of the casing (s).
  • the sealing of the annular space (1 1) can be done by conventional methods.
  • the seal is made in a preferred embodiment by installing at least one packer (10) in the annulus (1 1).
  • the underground gas condensate deposit (5) has a first connection to the surface (9) through the first perforation section (61) via the annular space (11).
  • the underground gas condensate reservoir (5) has a second connection to the surface (9) through the second perforation section (62) above the production tubing (14).
  • the underground gas condensate deposit (5) has two connections to the surface (9).
  • the first connection is in this case formed by the first perforation section (61) and the annular space (11).
  • the second connection is formed by the second perforation section (62) and the production tubing (14).
  • the two compounds may optionally be equipped with conventional filters to reduce the discharge of sand from the underground gas condensate deposit (5) into the production well (1).
  • valves (151, 152) are installed at the wellhead (15) of the underground gas condensate reservoir (5).
  • the valve (151) of the production tubing (14) can be opened or shut off (second connection).
  • the valve (152) With the valve (152), the annular space (1 1) can be opened or shut off (first connection).
  • the valve (152) can thus be the first connection from the wellhead (15) to the underground gas condensate deposit (5) control, that is opening or shutting off.
  • the second connection from the wellhead (15) to the second perforation section (62) of the underground gas condensate reservoir (5) can be controlled, ie open or shut off.
  • the distance of the first perforation section (61) from the second perforation section (62) can vary within wide ranges. Suitable distances are for example in the range of 50 to 2000 m, preferably in the range of 150 to 1000 m, more preferably in the range of 200 to 800 m.
  • the distance between the two perforation sections (61, 62) is determined from the first intersection of the arcuate section (13) from the subterranean gas condensate deposit (5) to the sole (3) until the re-entry of the arcuate section (13) from the sole (3 ) into the underground gas condensate deposit (5).
  • the reservoir pressure is Generally sufficient to promote natural gas and / or natural gas condensate through the production well (1).
  • the promotion can either
  • natural gas and natural gas condensate do not in this context mean a pure hydrocarbon mixture.
  • the natural gas and / or natural gas condensate can of course also contain other substances in addition to methane, ethane, propanes, butanes, hexanes and heptanes and optionally higher hydrocarbons.
  • formation water is understood to mean water which is originally present in the deposit, and water which has been introduced into the deposit through secondary and tertiary production process steps, for example so-called floodwater.
  • the formation water also comprises water which has optionally been introduced into the gas condensate deposit (5) by the process according to the invention.
  • a gas mixture with a retrograde condensation behavior has the following composition (data in mol%):
  • natural gas is understood as meaning gaseous gas mixtures which are conveyed from the underground gas condensate deposit (5).
  • natural gas condensate liquid mixtures are understood, which are funded from the underground gas condensate deposit (5).
  • the aggregate state of the gas mixtures conveyed from the underground gas condensate deposit (5) depends on the temperature and the pressure in the underground gas condensate deposit (5) or in the production well (1).
  • the method of the invention it is possible to extract only natural gas through the production well (1).
  • the state of aggregation of the further substances optionally present in the natural gas or in the natural gas condensate likewise depends on the pressure and the temperature in the lower gas condensate deposit (5) or in the production well (1).
  • the other substances may likewise be present in liquid form or in gaseous form in the mixture conveyed through the production well (1).
  • the extraction of natural gas and / or natural gas condensate from the underground gas condensate deposit (5) may also be preceded by both compounds, i. E. through the first perforation section (61) via the annulus (11) and through the second perforation section (62) via the production tubing (14).
  • the promotion takes place either
  • the subject matter of the present invention is thus also a method in which the method steps ei) and eii) are carried out alternately.
  • the delivery begins with process step ei) or process step eii).
  • the process steps ei) and eii) can also be carried out simultaneously for a certain period of time.
  • the period of simultaneous execution of the process steps ei) and eii) is generally not more than one month, preferably a maximum of one week, and more preferably a maximum of one day.
  • the delivery can thus begin with process step ei) through the first perforation section (61) via the annular space (11) and thereafter continue with process step eii) via the second perforation section (62) through the production tubing (14).
  • the process step eii) is followed again by the promotion according to process step ei), etc.
  • the delivery can also begin with process step eii) through the second perforation section (62) via the production tubing (14) and then continue with process step ei) through the annulus (11) via the first perforation section (61).
  • the process step ei) is followed again by the promotion according to process step eii), etc.
  • the one-time execution of the process step ei) and the one-time execution of the process step eii) is also referred to as a cycle.
  • the subject matter of the present invention is therefore also a process in which process step e) is carried out cyclically, one cycle comprising the one-time performance of process step ei) and the one-time performance of process step eii).
  • a cycle begins with process step ei) or process step eii).
  • a cycle includes process step ei) followed by process step eii).
  • a cycle comprises the process step eii) followed by process step ei).
  • the number (n) of cycles may be in the range of 3 to 100, preferably in the range of 5 to 50, and more preferably in the range of 5 to 40.
  • the present invention also provides a process in which the number (n) of cycles in process step e) is in the range of 3 to 100.
  • method step e) thus comprises the method steps: e), eiii), ei 2 ) and eii 2 ).
  • Cycle 1 comprises the process steps e) and eiii).
  • Cycle 2 comprises the process steps ei 2 ) and eii 2 ).
  • method step e) thus comprises the method steps: eh), eih) to ei 10 o) and eii 0 o) -
  • step ei) natural gas and / or natural gas condensate by conventional methods from the underground gas condensate reservoir (5) via the first perforation section (61) through the annulus (1 1) promoted.
  • the pressure in the underground gas condensate deposit (5) decreases, the temperature of the underground gas condensate deposit (5) remains largely unchanged.
  • the extraction of natural gas and / or natural gas condensate from the underground gas condensate reservoir (5) leads to an isothermal reduction in pressure.
  • the temperature of the underground gas condensate deposit (5) in the implementation of the method according to the invention remains largely constant, that is, that the temperature of the underground gas condensate deposit (5) by a maximum of +/- 20 ° C. , preferably at + 1-10 ° C., and more preferably at +/- 5 ° C. when carrying out the process according to the invention in comparison to the initial reservoir temperature (T L ) before carrying out the process according to the invention.
  • the pressure reduction (pressure decrease) is most pronounced in the vicinity of the first perforation section (61), through which natural gas and / or natural gas condensate is conveyed through the annulus (11), and increases with increasing distance from the first perforation section (61) of the production well (1) from.
  • FIG. 2 shows by way of example the pressure curve in the underground gas condensate deposit (5) as a function of the distance to the production well (1), in the region in which the first perforation section (61) is arranged.
  • the distance to the production hole (1) is plotted on the horizontal axis in meters (m).
  • the reservoir jerk (P) is plotted on the dashed vertical axis.
  • the reservoir pressure (P) reaches a value at which partial condensation of the retrograde gas mixture starts. This distance is shown by the vertical dotted line in FIG.
  • Point (B) on the dashed reservoir pressure curve (P) formation of a biphasic mixture containing natural gas and natural gas condensate begins.
  • Point (B) on the dashed reservoir pressure curve (P) corresponds to point (B) in FIG. 1.
  • the gas mixture is biphasic (range (l + v)).
  • the gas mixture is in single phase (area (av)).
  • the proportion of liquid natural gas condensate is plotted on the vertical axis (KG) and is shown by the solid curve (KG) in Figure 2. From a certain concentration of liquid natural gas condensate, the near zone of the production well (1) in the region of the first perforation (61) is blocked, whereby the delivery rate of natural gas and / or natural gas condensate via the first perforation section (61) via the annulus (1 1) decreases or completely come to a standstill. This critical area is represented by the gray-shaded area (KB) in FIG. The critical concentration of the liquid natural gas condensate in the gas mixture is represented by the point (KS) on the curve (KG) in FIG.
  • FIG. 2 merely illustrates the conditions in an underground gas condensate Deposit (5) having a gas mixture with retrograde condensation behavior, without limiting the present invention thereto.
  • Process step ei) is generally carried out until a reduction of the delivery rate from the underground gas condensate reservoir (5) via the first perforation section (61) through the annular space (1 1) is registered.
  • Process step ei) is generally carried out until a decrease in the delivery rate of natural gas and / or natural gas condensate of at least 5%, preferably at least 10% and particularly preferably at least 20% is registered, in each case based on the delivery rate of natural gas and / or natural gas condensate Beginning of process step ei).
  • Process step ei) is generally carried out for a time (T ei ) in the range of one week to six months.
  • the duration (T ei ) depends on the initial reservoir (P L ).
  • the time period for which process step ei) is carried out can therefore also be shorter or longer.
  • the production of natural gas according to process step eii) is continued through the second perforation section (62) via the production pipeline (14).
  • a simultaneous delivery according to method step ei) and eii) can also take place here.
  • this period will generally be in the range of less than one month, preferably less than one week and most preferably less than one day.
  • the promotion according to step ei) is set before the promotion according to step eii) is recorded. Subsequently, the production of natural gas and / or natural gas condensate according to process step eii) is continued.
  • the above statements and preferences with regard to process step ei) apply accordingly.
  • two valves (151 and 152) are arranged at the wellhead (15) in a preferred embodiment. Through the valve (152), the annular space (1 1) of the wellhead (15) connects to the first perforation step (61) shut off.
  • the valve (151) is opened, thereby opening the connection of the second perforation section (61) via the production tubing (14) to the wellhead (15).
  • the liquid natural gas condensate which forms the critical region (KB)
  • the critical area (4; KB) generally has a radial extent measured from the first or second perforation section in the range of 1 to 50 m, preferably in the range of 3 to 40 m and particularly preferably in the range of 4 to 30 m.
  • the time required for this pressure equalization can also vary widely. It is usually in the range of one week to 10 months. However, the reason for the change from process step ei) to process step eii) and vice versa is generally not the pressure equalization in the region of the unused perforation step (61; 62) but the reduction of the feed rate by the used perforation section (61; 62).
  • Process step eii) is generally carried out until the delivery rate of natural gas and / or natural gas condensate decreases. For the decrease of the delivery rate as well as the time duration for carrying out the process step eii), the above statements and preferences with regard to process step ei) apply correspondingly.
  • the process steps ei) and eii) can be repeated as often as desired.
  • the number of cycles may be as described above, for example, 1 to 500.
  • the limiting factor for the number of cycles is the initial reservoir pressure (P L ) of the underground gas condensate reservoir (5) and the duration of the individual cycles. The higher the initial reservoir pressure (P L ) is, the more cycles can generally be performed. This is because with the execution of each cycle, the total reservoir pressure of the underground gas condensate reservoir (5) decreases.
  • Process step ei) is generally carried out only so long that the pressure decrease within the underground gas condensate deposit (5) does not spread to the second perforation section (62), i. there a pressure decrease can be registered.
  • the valves 151 and 152 can be opened and the pressure in the annular space 11 ) or in the production tubing (14) are measured.
  • step e) of the method according to the invention is explained in more detail by way of example, whereby three cycles are carried out and the production of natural gas and / or natural gas condensate according to method step ei) is started via the first perforation section (61). Cycle 1 e) - start of the production of natural gas and / or natural gas condensate from the underground gas condensate deposit (5) through the first perforation section (61) via the annulus (11),
  • cycle 3 can be followed by further cycles.
  • the periods T ei1 and T eii1 are approximately equal.
  • the following condition applies:
  • the period of time for which natural gas and / or natural gas condensate can be pumped according to process steps ei) and eii) generally decreases with increasing number of cycles. This is because the reservoir is generally lower after completion of a cycle than the reservoir immediately prior to performing this cycle. In general, therefore, the period T ei1 is longer than the period T ei2 and the period T eii1 is generally longer than the period T eii 2. In general, therefore, for the periods of the individual cycles, the following condition applies:
  • T ei2 Part> T ei2 ; T ei2 > T ei3 ; to; T once i> T and
  • n is the number of cycles.
  • Suitable flooding agents may be gaseous or liquid.
  • Suitable gaseous flooding agents (FM) are for example selected from the group consisting of nitrogen, carbon dioxide and natural gas.
  • Suitable liquid flooding agents (FM) are, for example, water, to which any customary additives, such as, for example, thickeners, can be added.
  • known methods for thermal treatment can be used.
  • the subject matter of the present invention is thus also a method in which, after completion of the cyclical execution of method step e), either through the first perforation section (61) or through the second perforation section (62), a flooding agent (FM) is introduced into the underground gas condensate reservoir (5 ) is injected.
  • a flooding agent FM
  • FIGS. 1 to 8 The present invention is further illustrated by the following example and FIGS. 1 to 8 without being limited thereto.
  • the reference numerals have the following meanings: a single-phase liquid region
  • FIG. 1 A first figure.
  • FIG. 2 The phase behavior of gas mixtures with retrograde condensation behavior.
  • Figure 3 shows a preferred embodiment of the present invention.
  • Figure 3 40 shows a vertical section through the underground gas condensate deposit (5).
  • the production bore (1) has a quasi-vertical section (12), which is adjoined by the arcuate section (13).
  • the production well (1) passes through the Underground gas condensate deposit (5) coming from the top layer (2) to the bottom (3). Starting from the vertex of the arcuate section (13), the production well (1) traverses the underground gas condensate reservoir (5) a second time from the sole (3) to the cover layer (2).
  • the first perforation section (61) and the second perforation section (62) are arranged inside the underground gas condensate deposit (5).
  • FIG. 4 shows a preferred embodiment of the method according to the invention.
  • Figure 4 shows a vertical section through the underground gas condensate deposit (5).
  • FIG. 4 shows the state after method step ei) has been carried out for a certain period of time.
  • the critical area (4) has formed.
  • the flow direction of natural gas and / or natural gas condensate is indicated by the arrows with the reference numeral 7.
  • the pressure profile within the underground gas condensate deposit (5) is indicated by the curve with the reference numeral 8.
  • the pressure curve it becomes clear that the decrease in pressure in the region of the first perforation section (61) is particularly strong.
  • the pressure within the underground gas condensate reservoir (5) increases and reaches a constant plateau in the area of the second perforation section (62).
  • FIG. 5 shows a preferred embodiment of the present invention, in which the delivery has been adjusted according to method step ei) and the delivery is continued according to method step eii).
  • the flow direction of natural gas and / or natural gas condensate is indicated by the arrows with the reference numeral 7.
  • the delivery takes place via the second perforation section (62) via the production tubing (14, not shown).
  • FIG. 6 shows the state toward the end of process step eii).
  • FIG. 7A shows a vertical section through the underground gas condensate deposit (5) with a higher density of detail.
  • FIG. 7A shows a section enlargement in the region of the arcuate section (13) of the production bore (1).
  • FIG. 7A corresponds to the state shown in FIG. 4 toward the end of the execution of method step ei).
  • the flow direction of natural gas and / or natural gas condensate is indicated by the arrows with the reference numeral 7.
  • the natural gas and / or natural gas condensate is conveyed through the annulus (11).
  • the annular space (11) is sealed in the region between the first perforation section (61) and the second perforation section (62) by two packers (10).
  • FIG. 7B
  • FIG. 7B shows the state as shown in FIG.
  • the promotion according to process step ei) has been discontinued.
  • the promotion according to process step eii) was continued.
  • the natural gas and / or natural gas condensate is conveyed through the second perforation section via the production conveyor line (14).
  • the pressure profile within the underground gas condensate deposit (5) is indicated by the curve with the reference numeral 8.
  • FIG. 8 shows a detailed cross section through the underground gas condensate deposit (5).
  • natural gas and / or natural gas condensate is conveyed through the second perforation section (62) through the production tubing (14).
  • FIG. 8 shows a detailed illustration of the installation of the wellhead (15).
  • the wellhead (15) has two valves (151, 152).
  • the valve (151) controls the opening or shut-off of the production tubing (14).
  • the valve (152) controls the opening or shut-off of the annular space (1 1).
  • By opening the valve (151), natural gas and natural gas condensate can be conveyed through the second perforation section (62).
  • By opening the valve (152), natural gas and / or natural gas condensate can be conveyed through the annular space (11) via the first perforation section (61).
  • the present invention will be further illustrated by the following embodiment, without, however, limiting it thereto.
  • a deflected production well (1) is drilled.
  • the drilling down of the bore as well as the formation of the perforation sections (61, 62) as well as the installation of a production line (14) and the packer (10) takes place as shown in FIG.
  • the production well (1) is cased and cemented with casings.
  • the arcuate portion (13) traverses the underground gas condensate deposit (5) twice.
  • the perforation sections (61; 62) are each arranged in the underground gas condensate deposit (5).
  • the distance between the two perforation sections (61; 62) is 200 m.
  • the thickness of the underground gas condensate deposit (5) is in the range of 50 to 80 m.
  • the reservoir temperature (T L ) is 105 ° C.
  • the initial reservoir pressure (P L ) is approximately 658.6 bar.
  • the permeability of the underground gas condensate deposit (5) ranges between 0.5 * 10 -3 and 5.0 * 10 -3 ⁇ 2 . ⁇ Porosity of the underground gas condensate deposit (5) is in the range of 0.2 to 0.25%.
  • the completion of the production bore (1) takes place as shown in FIG.
  • the production of natural gas and / or natural gas condensate is started according to process step ei) via the first perforation section (61).
  • the valve (152) is opened and the valve (151) is closed.
  • the radius, starting from the first perforation section (61) of the production bore (1), has an extension in the range of 5 to 10 m.
  • the promotion according to step ei) by the first perforation section (61) is set.
  • the valve (152) is closed.
  • the connection to the second perforation section (62) is made by opening the valve (151).
  • the production of natural gas and / or natural gas condensate according to process step eii) is continued.
  • the reservoir pressure recovers in the vicinity of the first perforation section (61).
  • the critical area (4) which is blocked with liquid natural gas condensate, reduced and is partially or completely in the gas phase.
  • the blocking by the critical area (4) is canceled.

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  • Mining & Mineral Resources (AREA)
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Abstract

La présente invention concerne un procédé d'extraction de gaz naturel et/ou de condensats de gaz naturel à partir d'un gisement souterrain de gaz à condensats (5) qui contient un mélange gazeux ayant un profil de condensation rétrograde. Ce procédé comprend au moins les étapes consistant à : a) forer un puits de production (1) dans le gisement souterrain de gaz à condensats (5), b) perforer le puits de production (1) afin de former un premier segment perforé (61) disposé dans le gisement souterrain de gaz à condensats (5), c) perforer le puits de production (1) afin de former un deuxième segment perforé (62) disposé dans le gisement souterrain de gaz à condensats (5), d) installer un train de tiges de production (14) dans le puits de production (1) et étanchéifier l'espace annulaire (11) entre la paroi extérieure du train de tiges de production (14) et la paroi intérieure du puits de production (1) dans la zone située entre le premier et le deuxième segment perforé (61, 62), e) extraction du gaz naturel et/ou des condensats de gaz naturel à partir du gisement souterrain de gaz à condensats (5) soit ei) à travers le premier segment perforé (61) par le biais de l'espace annulaire (11), soit eii) à travers le deuxième segment perforé (62) par le biais du train de tiges de production (14), les étapes de procédé ei) et eii) étant exécutées en alternance.
PCT/EP2014/072601 2013-10-29 2014-10-22 Procédé d'extraction de gaz naturel et de condensats de gaz naturel à partir de gisements de gaz à condensats WO2015062922A1 (fr)

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US4823880A (en) * 1988-06-16 1989-04-25 374928 Alberta Limited Gaswell dehydrate valve
SU1596081A1 (ru) 1988-06-27 1990-09-30 Институт физики Земли им.О.Ю.Шмидта Способ разработки обводненного нефт ного месторождени
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RU2064572C1 (ru) 1993-06-25 1996-07-27 Научно-производственное предприятие "Биотехинвест" Способ разработки газоконденсатного или нефтегазоконденсатного месторождения
WO1998013579A2 (fr) * 1996-09-27 1998-04-02 Baker Hughes Limited Separation d'huile et systeme de pompage
EP0952300A1 (fr) 1998-03-27 1999-10-27 Cooper Cameron Corporation Procédé et dispositif pour le forage de plusieurs puits submergés
US20030141073A1 (en) 2002-01-09 2003-07-31 Kelley Terry Earl Advanced gas injection method and apparatus liquid hydrocarbon recovery complex
US20070000663A1 (en) 2002-01-09 2007-01-04 Kelley Terry E Enhanced liquid hydrocarbon recovery by miscible gas injection water drive
RU2245997C2 (ru) 2002-07-08 2005-02-10 Общество с ограниченной ответственностью "Оренбурггазпром" (ООО "Оренбурггазпром") Способ эксплуатации газоконденсатного месторождения
US20100025227A1 (en) 2002-12-23 2010-02-04 Aldivia Sa Chemical synthesis comprising heat treatment by intermittent dielectric heating combined with a recycling system
US20040200615A1 (en) * 2003-04-09 2004-10-14 Optimum Production Technologies Inc. Apparatus and method for enhancing productivity of natural gas wells
RU2358100C2 (ru) 2007-06-28 2009-06-10 Олег Евдокимович Васильев Способ гидравлического разрыва пласта в скважине
RU2366803C1 (ru) 2008-02-11 2009-09-10 Кувандыков Ильис Шарифович Способ эксплуатации газоконденсатного месторождения
US20100252271A1 (en) * 2009-04-06 2010-10-07 Terry Earl Kelley Total in place hydrocarbon recovery by isolated liquid & gas production through expanded volumetric wellbore exposure +
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