CA1096768A - Starting hydrocarbon fluid production by injecting nitrogen-generating liquid - Google Patents
Starting hydrocarbon fluid production by injecting nitrogen-generating liquidInfo
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- CA1096768A CA1096768A CA324,170A CA324170A CA1096768A CA 1096768 A CA1096768 A CA 1096768A CA 324170 A CA324170 A CA 324170A CA 1096768 A CA1096768 A CA 1096768A
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- nitrogen gas
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Abstract
ABSTRACT
STARTING HYDROCARBON FLUID PRODUCTION BY
INJECTING NITROGEN-GENERATING LIQUID
Production is initiated from a well which is kept from producing by the hydrostatic pressure of the liquid it contains, by injecting an aqueous liquid that contains reactants which form nitrogen gas within the well or reservoir which gas displaces enough liquid out of the well to lower the hydrostatic pressure to less than the fluid pressure in the adjacent portion of the reservoir and cause fluid to flow from the reservoir to the well.
STARTING HYDROCARBON FLUID PRODUCTION BY
INJECTING NITROGEN-GENERATING LIQUID
Production is initiated from a well which is kept from producing by the hydrostatic pressure of the liquid it contains, by injecting an aqueous liquid that contains reactants which form nitrogen gas within the well or reservoir which gas displaces enough liquid out of the well to lower the hydrostatic pressure to less than the fluid pressure in the adjacent portion of the reservoir and cause fluid to flow from the reservoir to the well.
Description
~0"6768 STARTING HYDROCARBON FLUID PRODUCTION BY
INJECTING NITROGEN-GENERATING LIQUID
The invention relates to treating a liquid-containing well by passing a nitrogen gas-generating solution into the well to cause a gas-effected displacement of liquid from the well. More particularly, it relates to "kicking off" or initiating pro-duction from a well which is "dead" due to hydrostatic pressureof the liquid it contains; without the necessity of swabbing the well, or injecting nitrogen or other gas which has been com-pressed at a surface location.
The process according to the invention for treating a well communicating with a hydrocarbon fluid-containing formation from which production is prevented by the hydrostatic pressure of liquid contained within the well, comprises displacing sufficient liquid from the well to reduce the hydrostatic pressure to less than the reservoir fluid pressure by means of gas generated from at least one aqueous liquid solution which forms or contains a nitrogen gas-forming mixture of (a) at least one water-soluble compound which contains at least one nitrogen atom to which at least one hydrogen atom is attached and is capable of reacting within an aqueous medium to yield nitrogen gas and by-products which are substantially inert to the components of the well and reservoir formation, (b) at least one oxidizing agent which is capable of reacting with said nitrogen-containing compound to form said gas and by-products, and (c) an aqueous liquid 10~67~8 which is capable of dissolving or homogeneously dispersing said nitrogen-containing compound, the oxidizing agent and the by-products of the nitrogen gas-producing reaction.
In one embodiment of the invention the nitrogen gas-forming mixture is injected into a production tubing string at a rate such that the gas is formed within and accumulated at the top of the tubing string. The gas is subsequently released to initiate the production of fluids from the well and reservoir. In another embodiment of the invention, the composition of the gas-forming mixture and its rate of injection can be adjusted so that at least some of the gas is formed within the porés of the reservoir formation.
In still another embodiment, an aqueous solution or dispersion of a foam-forming surfactant is injected, before, during of after the injection of the nitrogen gas-forming mixture, so that a release of gas from the well induces foaming and a foam-transporting of liquid out of the well.
Water-soluble amino nitrogen compounds, which contain at least one nitrogen atom to which at least one hydrogen atom is attached and are capable of reacting with an oxidizing agent to yield nitrogen gas within an aqueous medium, which are suitable for use in the present invention can comprise sub-stantially any water-soluble ammonium salts of organic or inorganic acids, amines, amides and/or nitrogen-linked hydrocarbon-radical substituted homo-logues of such compounds as long as the substituted compounds react in a man-ner substantially equivalent to the parent compounds with respect to the production of nitrogen gas and by-products which are liquid or dissolve to form aqueous liquid which are substantially inert relative to the well con-duits and reservoir formation. Examples of such compounds include ammonium chloride, ammonium nitrate, ammonium acetate, ammonium formate, ethylene diamine, formamide, acetamide, urea, benzyl urea, butyl urea, hydrazine, phenylhydrazine, phenylhydrazine hydrochloride, and the like. Such ammonium salts, e.g., ammonium chloride, ammonium formate or ammonium acetate are particularly suitable.
Oxidizing agents suitable for use in the present process can com-prise substantially any water-soluble oxidizing agents capable of reacting with a water-soluble nitrogen-containing compound such as an ammonium salt or a urea or hydrazine compound as described above to produce nitrogen gas and the indicated types of by-products. Examples of such oxidizing agents include alkali metal hypochlorites (which can, of course, be formed by in-jecting chlorine gas into a stream of alkaline liquid being injected into the well), alkali metal or ammonium salts of nitrous acid, such as sodium or potassium or ammonium nitrite and the like. The alkali metal or ammonium nitrites are particularly suitable for use with nitrogen-containing compounds such as the ammonium salts.
Aqueous liquids suitable for use in the present invention can com-prise substantially any relatively soft fresh water or brine. Such aqueous liquid solutions preferably have a total dissolved salt content of from about 1 to 100 ppm, and a total hardness in terms of calcium ion equivalents of no more than about 50 ppm.
Foam-forming surfactants suitable for use in the present invention can comprise substantially any which are capable of being dissolved or dis-persed in an aqueous liquid solution containing the nitrogen-containing com-pound and oxidizing agent and remaining substantially inert during the nit-rogen gas-producing reaction between the nitrogen-containing compounds and the oxidizing agent. Examples of suitable surfactants comprise non-ionic and anionic surfactants, commercially available sodium dodecylbenzene sulphonates, e.g., SIPONATE DS-10 (trade name), mixtures of the Siponate or similar sul-phonate surfactants with sulphated polyoxyalkylated alcohol surfactants, e.g., the NEODOL (trade name) sulphate surfactants; sulphonate sulphate 10~6768 surfactant mixtures; petroleum sulphonates; BRYTON (trade name) sulphonates;
PETRONATES and PYRO~ATES (trade names); fatty acid and tall oil acid soaps, e.g., ACTYNOL HEADS (trade name); non-ionic surfactants, e.g., TRITON X100 (trade name), and the like surfactant materials which are soluble or dis-persible in aqueous liquids.
To increase the viscosity of the aqueous solution to an extent enhancing the effectiveness of the gas in the gas-lifting liquid of the present process, water-thickening agents may be added to the liquid, such agents comprising substantially any water-soluble polymer or gel capable of dissolving in an aqueous liquid solution containing the nitrogen-containing compound and oxidizing agent and remaining substantially inert during the nitrogen gas-producing reaction between them.
Examples of suitable water-thickening agents include Xanthan gum polymer solutions such as marketed under the trade names KELZAN or XANFLOOD;
hydroxyethyl cellulose, carboxymethyl cellulose, guar gum and the like thickening agents. Such thickening agents are particularly effective within a well conduit. They retard the rising velocity of gas bubbles so that more liquid is removed by the rising gas, and thus such thickening agents are par-ticularly effective in treatments in which most of the nitrogen gas is gen-erated within the well.
The composition of the nitrogen gas-forming mixture should be cor-related with the pressure, temperature and volume properties of the reservoir and well components. In general, the rate of gas formation tends to increase with increasing temperature and inceasing concentration of reactants. With certain reactants the amount of gas production tends to be limited where the pressure is particularly high. By means of calculations and/or tests, the composition of the gas-forming mixture can be adjusted so that the volume of the liquid which contains or forms that mixture need to be no more than about 1~196768 the volume of the tubing string plus the volume of the annular space between the tubing string and the casing in order to generate an amount of gas that will displace enough liquid to reduce the hydrostatic pressure to less than the fluid pressure in the adjacent portion of the reservoir. Such a liquid can be circulated within the borehole by flowing it into the tubing string while flowing fluid out of the casing without injecting into the reservoir.
Alternatively, in certain situations, it is advantageous to cause a significant amount of flow of gaseous fluid from the reservoir to the well.
In such situations the composition of the nitrogen gas-forming mixture can be adjusted relative to the ambient temperature and the pressure and temper-ature of the reservoir so that the rate of gas generation is slow enough to allow a significant portion of the gas-forming mixture to be displaced into the reservoir. The generation of gas within the reservoir tends to increase the fluid pressure adjacent to the well and, when gas is released from the well, to ensure a relatively large inflow of gaseous fluid into the well.
By way of example, reference is now made to a procedure for cor-relating the composition of the nitrogen gas-forming mixture with the res-ervoir properties and the selected duration of the treatment, wherein use is made of an amino nitrogen compound which is a salt of ammonia and an oxidizing agent which is an alkali metal or ammonium salt of nitrous acid as the gas-generating reactants. Such composition has a slower reaction rate than, for example, the composition comprising urea and hypochloride as reactants, and thus can be used in place of the latter to provide (a) a slower reaction rate at a given temperature and concentration or (b) a similar rate of reaction at a higher temperature or concentration. Such reactants can also form relat-ively concentrated solutions which minimize the amount of water that must be injected to induce the gas generation in the selected location. In addition, since their reaction rate increases with increasing pH, the nitrogen gas-~0~6768 generating reaction rate of a solution of them can be buffered (a) at a relatively high pH at which the rate is relatively slow at the reservoir temperature by adding, for example, sodium acetate or other compatible buf-fer providing a near neutral or slightly alkaline solution; or (b) at a rel-atively low pH at which the rate is relatively fast at the reservoir tem-perature by adding, for example, a mixture of acidic acid and sodium acetate or other compatible buffer providing a slightly acidic solution.
In addition to being useful for initiating a sustained production of fluids from a dead well, such as a gas well or an oil well, the present process can also be used to displace a slug of treating liquid into a reser-voir and then produce it back out of the reservoir without a need for employ-ing swabbing equipment or gas which has been highly pressurized at a surface location. Such a treatment could comprise, injecting one or more fluids such as an oil solvent and/or acid, or scale-dissolving liquid with which it is desired to wash the perforations and/or near well zone by injecting and sub-sequently backflowing.
The injecting and subsequent backflowing of the treating liquid may be conducted as follows. A sequence of one or more slugs of treating liquid is arranged to precede a slug or volume of the present gas-generating liquid which, if desired, may be followed by a slug or volume of inert aqueous liquid. Then, the sequence of liquids is spotted within or near the bottom of the well being treated; for example, by injecting the liquids sequentially into the well through a tubing string (and/or an annulus around it) so that the liquid already in the well is displaced into the reservoir and continuing the injection until the frontal portion of the treatment liquid is at or near the bottom of the well. Alternatively, the sequence can be such that the liquids are sequentially included within a stream of fluid which is being circulated into the well (through the annulus or tubing string) and terminat-lQ9676~
ing the fluid cirulation when the frontal portion of the treating liquid isat or near the bottom of the well. The wellhead is then closed so that gas generated by the gas-generating liquid accumulates above the liquid within the well while it displaces the treating liquid into the reservoir. At least a portion of the so-accumulated nitrogen gas is then released in order .
to initiate a back-flowing of the treating liquid from the reservoir into the well.
As will be apparent to those skilled in the art, where the well depth and/or tubing size is sufficient to accommodate a significant portion of the nitrogen gas-forming mixture, the composition of such a mixture can be adjusted so that a significant volume of pressurized gas will be formed.
The injecting and producing of the treating liquid slug can be repeated a plurality of times, by closing the wellhead so that the accumulating gas injects the treating liquid slug and releasing gas so that the treating liquid flows back; and, then again closing the wellhead so that the dis-placement of treating liquid slug into the reservoir is repeated.
In an alternative procedure for initiating a sustained flow of production fluid from a well in which production has been prevented by the hydrostatic pressure of liquid in the well, gas generated by the gas-gener-ating mixture is allowed to collect in at least one of the upper ends of theproduction tubing or the annulus. In one embodiment, fluid is circulated into the top of one well conduit and out the top of the other until a slug of the gas-generating liquid is present within at least one of the conduits.
The top of the conduit containing the gas-generating liquid is then closed while the top of the other is left open. As the gas is generated it ini-tially accumulates above the liquid in the so-closed conduit while displac-ing liquid down through the bottom of that conduit and out through the open top of the other conduit. Where the vo ume of the so-generated gas is suf-~L0~768 ficient and/or where the gas-generating liquid is injected within both of the conduits, at least some portions of the liquid are displaced by a gas-lifting type action of the generated gas. While the gas-generating liquid is present within both of such conduits the tops of both may be left open.
In another alternative procedure for initiating a fluid flow from a well (such as a flow of hydrocarbon gas, or a flow of hydrocarbon liquids, or a flow of hydrocarbon liquids and gas), a composition of a gas-generating liquid is correlated with the temperature and injectivity properties of the reservoir and injected into the reservoir in a manner such that a significant proportion of the gas is generated within the reservoir formation. Where desirable, a pair of well conduits such as a tubing string and the annulus between it and a surrounding pipe string can be utilized to relatively rapidly circulate a slug of the treatment liquid to the bottom of the well and then displace that liquid into the reservoir formation in a way which reduces the overall time for which the gas-generating liquid is exposed to the reservoir temperature before it has entered the reservoir formation. A
particularly suitable gas-generating liquid for use in such a procedure is one in which the nitrogen-containing reactant is an ammonium salt and oxidiz-ing reactant is an alkali metal or ammonium nitrite.
, ~.
INJECTING NITROGEN-GENERATING LIQUID
The invention relates to treating a liquid-containing well by passing a nitrogen gas-generating solution into the well to cause a gas-effected displacement of liquid from the well. More particularly, it relates to "kicking off" or initiating pro-duction from a well which is "dead" due to hydrostatic pressureof the liquid it contains; without the necessity of swabbing the well, or injecting nitrogen or other gas which has been com-pressed at a surface location.
The process according to the invention for treating a well communicating with a hydrocarbon fluid-containing formation from which production is prevented by the hydrostatic pressure of liquid contained within the well, comprises displacing sufficient liquid from the well to reduce the hydrostatic pressure to less than the reservoir fluid pressure by means of gas generated from at least one aqueous liquid solution which forms or contains a nitrogen gas-forming mixture of (a) at least one water-soluble compound which contains at least one nitrogen atom to which at least one hydrogen atom is attached and is capable of reacting within an aqueous medium to yield nitrogen gas and by-products which are substantially inert to the components of the well and reservoir formation, (b) at least one oxidizing agent which is capable of reacting with said nitrogen-containing compound to form said gas and by-products, and (c) an aqueous liquid 10~67~8 which is capable of dissolving or homogeneously dispersing said nitrogen-containing compound, the oxidizing agent and the by-products of the nitrogen gas-producing reaction.
In one embodiment of the invention the nitrogen gas-forming mixture is injected into a production tubing string at a rate such that the gas is formed within and accumulated at the top of the tubing string. The gas is subsequently released to initiate the production of fluids from the well and reservoir. In another embodiment of the invention, the composition of the gas-forming mixture and its rate of injection can be adjusted so that at least some of the gas is formed within the porés of the reservoir formation.
In still another embodiment, an aqueous solution or dispersion of a foam-forming surfactant is injected, before, during of after the injection of the nitrogen gas-forming mixture, so that a release of gas from the well induces foaming and a foam-transporting of liquid out of the well.
Water-soluble amino nitrogen compounds, which contain at least one nitrogen atom to which at least one hydrogen atom is attached and are capable of reacting with an oxidizing agent to yield nitrogen gas within an aqueous medium, which are suitable for use in the present invention can comprise sub-stantially any water-soluble ammonium salts of organic or inorganic acids, amines, amides and/or nitrogen-linked hydrocarbon-radical substituted homo-logues of such compounds as long as the substituted compounds react in a man-ner substantially equivalent to the parent compounds with respect to the production of nitrogen gas and by-products which are liquid or dissolve to form aqueous liquid which are substantially inert relative to the well con-duits and reservoir formation. Examples of such compounds include ammonium chloride, ammonium nitrate, ammonium acetate, ammonium formate, ethylene diamine, formamide, acetamide, urea, benzyl urea, butyl urea, hydrazine, phenylhydrazine, phenylhydrazine hydrochloride, and the like. Such ammonium salts, e.g., ammonium chloride, ammonium formate or ammonium acetate are particularly suitable.
Oxidizing agents suitable for use in the present process can com-prise substantially any water-soluble oxidizing agents capable of reacting with a water-soluble nitrogen-containing compound such as an ammonium salt or a urea or hydrazine compound as described above to produce nitrogen gas and the indicated types of by-products. Examples of such oxidizing agents include alkali metal hypochlorites (which can, of course, be formed by in-jecting chlorine gas into a stream of alkaline liquid being injected into the well), alkali metal or ammonium salts of nitrous acid, such as sodium or potassium or ammonium nitrite and the like. The alkali metal or ammonium nitrites are particularly suitable for use with nitrogen-containing compounds such as the ammonium salts.
Aqueous liquids suitable for use in the present invention can com-prise substantially any relatively soft fresh water or brine. Such aqueous liquid solutions preferably have a total dissolved salt content of from about 1 to 100 ppm, and a total hardness in terms of calcium ion equivalents of no more than about 50 ppm.
Foam-forming surfactants suitable for use in the present invention can comprise substantially any which are capable of being dissolved or dis-persed in an aqueous liquid solution containing the nitrogen-containing com-pound and oxidizing agent and remaining substantially inert during the nit-rogen gas-producing reaction between the nitrogen-containing compounds and the oxidizing agent. Examples of suitable surfactants comprise non-ionic and anionic surfactants, commercially available sodium dodecylbenzene sulphonates, e.g., SIPONATE DS-10 (trade name), mixtures of the Siponate or similar sul-phonate surfactants with sulphated polyoxyalkylated alcohol surfactants, e.g., the NEODOL (trade name) sulphate surfactants; sulphonate sulphate 10~6768 surfactant mixtures; petroleum sulphonates; BRYTON (trade name) sulphonates;
PETRONATES and PYRO~ATES (trade names); fatty acid and tall oil acid soaps, e.g., ACTYNOL HEADS (trade name); non-ionic surfactants, e.g., TRITON X100 (trade name), and the like surfactant materials which are soluble or dis-persible in aqueous liquids.
To increase the viscosity of the aqueous solution to an extent enhancing the effectiveness of the gas in the gas-lifting liquid of the present process, water-thickening agents may be added to the liquid, such agents comprising substantially any water-soluble polymer or gel capable of dissolving in an aqueous liquid solution containing the nitrogen-containing compound and oxidizing agent and remaining substantially inert during the nitrogen gas-producing reaction between them.
Examples of suitable water-thickening agents include Xanthan gum polymer solutions such as marketed under the trade names KELZAN or XANFLOOD;
hydroxyethyl cellulose, carboxymethyl cellulose, guar gum and the like thickening agents. Such thickening agents are particularly effective within a well conduit. They retard the rising velocity of gas bubbles so that more liquid is removed by the rising gas, and thus such thickening agents are par-ticularly effective in treatments in which most of the nitrogen gas is gen-erated within the well.
The composition of the nitrogen gas-forming mixture should be cor-related with the pressure, temperature and volume properties of the reservoir and well components. In general, the rate of gas formation tends to increase with increasing temperature and inceasing concentration of reactants. With certain reactants the amount of gas production tends to be limited where the pressure is particularly high. By means of calculations and/or tests, the composition of the gas-forming mixture can be adjusted so that the volume of the liquid which contains or forms that mixture need to be no more than about 1~196768 the volume of the tubing string plus the volume of the annular space between the tubing string and the casing in order to generate an amount of gas that will displace enough liquid to reduce the hydrostatic pressure to less than the fluid pressure in the adjacent portion of the reservoir. Such a liquid can be circulated within the borehole by flowing it into the tubing string while flowing fluid out of the casing without injecting into the reservoir.
Alternatively, in certain situations, it is advantageous to cause a significant amount of flow of gaseous fluid from the reservoir to the well.
In such situations the composition of the nitrogen gas-forming mixture can be adjusted relative to the ambient temperature and the pressure and temper-ature of the reservoir so that the rate of gas generation is slow enough to allow a significant portion of the gas-forming mixture to be displaced into the reservoir. The generation of gas within the reservoir tends to increase the fluid pressure adjacent to the well and, when gas is released from the well, to ensure a relatively large inflow of gaseous fluid into the well.
By way of example, reference is now made to a procedure for cor-relating the composition of the nitrogen gas-forming mixture with the res-ervoir properties and the selected duration of the treatment, wherein use is made of an amino nitrogen compound which is a salt of ammonia and an oxidizing agent which is an alkali metal or ammonium salt of nitrous acid as the gas-generating reactants. Such composition has a slower reaction rate than, for example, the composition comprising urea and hypochloride as reactants, and thus can be used in place of the latter to provide (a) a slower reaction rate at a given temperature and concentration or (b) a similar rate of reaction at a higher temperature or concentration. Such reactants can also form relat-ively concentrated solutions which minimize the amount of water that must be injected to induce the gas generation in the selected location. In addition, since their reaction rate increases with increasing pH, the nitrogen gas-~0~6768 generating reaction rate of a solution of them can be buffered (a) at a relatively high pH at which the rate is relatively slow at the reservoir temperature by adding, for example, sodium acetate or other compatible buf-fer providing a near neutral or slightly alkaline solution; or (b) at a rel-atively low pH at which the rate is relatively fast at the reservoir tem-perature by adding, for example, a mixture of acidic acid and sodium acetate or other compatible buffer providing a slightly acidic solution.
In addition to being useful for initiating a sustained production of fluids from a dead well, such as a gas well or an oil well, the present process can also be used to displace a slug of treating liquid into a reser-voir and then produce it back out of the reservoir without a need for employ-ing swabbing equipment or gas which has been highly pressurized at a surface location. Such a treatment could comprise, injecting one or more fluids such as an oil solvent and/or acid, or scale-dissolving liquid with which it is desired to wash the perforations and/or near well zone by injecting and sub-sequently backflowing.
The injecting and subsequent backflowing of the treating liquid may be conducted as follows. A sequence of one or more slugs of treating liquid is arranged to precede a slug or volume of the present gas-generating liquid which, if desired, may be followed by a slug or volume of inert aqueous liquid. Then, the sequence of liquids is spotted within or near the bottom of the well being treated; for example, by injecting the liquids sequentially into the well through a tubing string (and/or an annulus around it) so that the liquid already in the well is displaced into the reservoir and continuing the injection until the frontal portion of the treatment liquid is at or near the bottom of the well. Alternatively, the sequence can be such that the liquids are sequentially included within a stream of fluid which is being circulated into the well (through the annulus or tubing string) and terminat-lQ9676~
ing the fluid cirulation when the frontal portion of the treating liquid isat or near the bottom of the well. The wellhead is then closed so that gas generated by the gas-generating liquid accumulates above the liquid within the well while it displaces the treating liquid into the reservoir. At least a portion of the so-accumulated nitrogen gas is then released in order .
to initiate a back-flowing of the treating liquid from the reservoir into the well.
As will be apparent to those skilled in the art, where the well depth and/or tubing size is sufficient to accommodate a significant portion of the nitrogen gas-forming mixture, the composition of such a mixture can be adjusted so that a significant volume of pressurized gas will be formed.
The injecting and producing of the treating liquid slug can be repeated a plurality of times, by closing the wellhead so that the accumulating gas injects the treating liquid slug and releasing gas so that the treating liquid flows back; and, then again closing the wellhead so that the dis-placement of treating liquid slug into the reservoir is repeated.
In an alternative procedure for initiating a sustained flow of production fluid from a well in which production has been prevented by the hydrostatic pressure of liquid in the well, gas generated by the gas-gener-ating mixture is allowed to collect in at least one of the upper ends of theproduction tubing or the annulus. In one embodiment, fluid is circulated into the top of one well conduit and out the top of the other until a slug of the gas-generating liquid is present within at least one of the conduits.
The top of the conduit containing the gas-generating liquid is then closed while the top of the other is left open. As the gas is generated it ini-tially accumulates above the liquid in the so-closed conduit while displac-ing liquid down through the bottom of that conduit and out through the open top of the other conduit. Where the vo ume of the so-generated gas is suf-~L0~768 ficient and/or where the gas-generating liquid is injected within both of the conduits, at least some portions of the liquid are displaced by a gas-lifting type action of the generated gas. While the gas-generating liquid is present within both of such conduits the tops of both may be left open.
In another alternative procedure for initiating a fluid flow from a well (such as a flow of hydrocarbon gas, or a flow of hydrocarbon liquids, or a flow of hydrocarbon liquids and gas), a composition of a gas-generating liquid is correlated with the temperature and injectivity properties of the reservoir and injected into the reservoir in a manner such that a significant proportion of the gas is generated within the reservoir formation. Where desirable, a pair of well conduits such as a tubing string and the annulus between it and a surrounding pipe string can be utilized to relatively rapidly circulate a slug of the treatment liquid to the bottom of the well and then displace that liquid into the reservoir formation in a way which reduces the overall time for which the gas-generating liquid is exposed to the reservoir temperature before it has entered the reservoir formation. A
particularly suitable gas-generating liquid for use in such a procedure is one in which the nitrogen-containing reactant is an ammonium salt and oxidiz-ing reactant is an alkali metal or ammonium nitrite.
, ~.
Claims (15)
PROPERTY OR PRIVILEGE IS CLAIMED ARE DEFINED AS FOLLOWS:
1. A process for treating a well communicating with a hydrocarbon fluid-containing formation from which production is prevented by the hydro-static pressure of liquid contained within the well, comprising displacing sufficient liquid from the well to reduce the hydrostatic pressure to less than the reservoir fluid pressure by means of gas generated from at least one aqueous liquid solution which forms or contains a nitrogen gas-forming mixture of (a) at least one water-soluble compound which contains at least one nitrogen atom to which at least one hydrogen atom is attached and is capable of reacting within an aqueous medium to yield nitrogen gas and by-products which are substantially inert to the components of the well and reservoir formation, (b) at least one oxidizing agent which is capable of reacting with said nitrogen-containing compound to form said gas and by-products, and (c) an aqueous liquid which is capable of dissolving or homo-geneously dispersing said nitrogen-containing compound, the oxidizing agent and the by-products of the nitrogen gas-producing reaction.
2. The process according to claim 1, wherein the well comprises at least two conduits that are in communication near the lower ends thereof, and the generated gas is collected in one of the conduits near the top thereof, and at least part of the liquid in the well is displaced from the well via the other conduit.
3. The process according to claim 2, in which the gas-forming mix-ture is injected into one of the conduits.
4. The process according to claim 1, in which the gas-forming mix-ture is injected into a production tubing string present in the well, at a rate such that substantially all of the nitrogen gas produced by each increment of the injected fluid is produced while that increment of the fluid is in the tubing string and substantially all of the so-generated gas is accumulated at the top of the tubing string.
5. The process according to claim 1, in which the gas-forming mix-ture is injected at least partly into the formation.
6. The process according to claim 1, comprising the consecutive steps of:
injecting into the well a slug of treating liquid;
injecting into the well behind the treating liquid slug at least one aqueous liquid solution which forms or contains the nitrogen gas-forming mixture;
closing the well and allowing the generation of nitrogen gas to displace at least a portion of the treating liquid slug to the location to be treated;
treating the location by the treating liquid; and producing fluid from the well by outflowing gas generated by the nitrogen gas-forming mixture, so that the treating liquid slug is backflowed out of the well.
injecting into the well a slug of treating liquid;
injecting into the well behind the treating liquid slug at least one aqueous liquid solution which forms or contains the nitrogen gas-forming mixture;
closing the well and allowing the generation of nitrogen gas to displace at least a portion of the treating liquid slug to the location to be treated;
treating the location by the treating liquid; and producing fluid from the well by outflowing gas generated by the nitrogen gas-forming mixture, so that the treating liquid slug is backflowed out of the well.
7. The process according to any one of the claims 1, 3 and 6, in which the nitrogen-containing compound is salt of ammonia and the oxidizing agent is an alkali metal or ammonium nitrite.
8. The process according to any one of the claims 1, 3 and 6, in which the nitrogen gas-forming mixture consists essentially of an aqueous solution of ammonium chloride and sodium nitrite.
9. The process according to any one of the claims 1, 3 and 6, in which the nitrogen gas-forming mixture consists essentially of an aqueous solution of urea and sodium hypochlorite.
10. The process according to any one of the claims 1, 3 and 6, in which the nitrogen gas-forming mixture consists essentially of an aqueous solution of urea and sodium nitrite.
11. The process according to any one of the claims 1, 3 and 6, in which the injected solution contains a buffering agent for maintaining a reaction rate controlling pH.
12. The process according to any one of the claims 1, 3 and 6, in which the injection into the well of the nitrogen gas-forming mixture is accompanied by an injection into the well of an aqueous liquid solution or dispersion of a foam-forming surfactant.
13. The process according to any one of the claims 1, 3 and 6, in which the injection into the well of the nitrogen gas-forming mixture is accompanied by an injection into the well of an aqueous liquid solution or dispersion of a water-thickening agent.
14. The process according to any one of the claims 1, 3 and 6, wherein the hydrocarbon fluid consists of liquid hydrocarbons.
15. The process according to any one of the claims 1, 3 and 6, wherein the hydrocarbon fluid consists of liquid and gaseous hydrocarbons.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA324,170A CA1096768A (en) | 1979-03-26 | 1979-03-26 | Starting hydrocarbon fluid production by injecting nitrogen-generating liquid |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA324,170A CA1096768A (en) | 1979-03-26 | 1979-03-26 | Starting hydrocarbon fluid production by injecting nitrogen-generating liquid |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA1096768A true CA1096768A (en) | 1981-03-03 |
Family
ID=4113823
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA324,170A Expired CA1096768A (en) | 1979-03-26 | 1979-03-26 | Starting hydrocarbon fluid production by injecting nitrogen-generating liquid |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA1096768A (en) |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4787450A (en) * | 1987-05-07 | 1988-11-29 | Union Oil Company Of California | Gas lift process for restoring flow in depleted geothermal reservoirs |
| US11299663B2 (en) | 2020-06-04 | 2022-04-12 | Saudi Arabian Oil Company | Method for modifying well injection profile and enhanced oil recovery |
-
1979
- 1979-03-26 CA CA324,170A patent/CA1096768A/en not_active Expired
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4787450A (en) * | 1987-05-07 | 1988-11-29 | Union Oil Company Of California | Gas lift process for restoring flow in depleted geothermal reservoirs |
| US11299663B2 (en) | 2020-06-04 | 2022-04-12 | Saudi Arabian Oil Company | Method for modifying well injection profile and enhanced oil recovery |
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