Tight Gas Stimulation by In-Situ Nitrogen Generation

Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include nitrogen generating compounds, which upon activation, react to generate heat and nitrogen gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, heat and nitrogen gas are generated. Upon the generation of nitrogen gas and heat within the formation, microfractures are produced within the formation and the hydrostatic pressure within the reservoir is reduced to less than the reservoir fluid pressure, such that the rate of production of hydrocarbons from the formation is increased. 1. A reaction mixture for the in-situ generation of nitrogen within tight gas wells , the reaction mixture comprising:an ammonium containing compound;a nitrite containing compound; anda hydrogen releasing activator;wherein at least one of the ammonium containing compound and the nitrite containing compound are encapsulated with a coating designed to delay the reaction of the ammonium and nitrite containing compounds.2. The reaction mixture of wherein the ammonium containing compound is selected from ammonium chloride claim 1 , ammonium bromide claim 1 , ammonium nitrate claim 1 , ammonium sulfate claim 1 , ammonium carbonate claim 1 , ammonium nitrite claim 1 , and ammonium hydroxide.3. The reaction mixture of wherein the nitrite containing compound is selected from sodium nitrite claim 1 , potassium nitrite claim 1 , and sodium hypochlorite.4. The reaction mixture of claim 1 , wherein the coating encapsulating at least one of the ammonium containing compound and the nitrite containing compound is a polymer selected from guar claim 1 , chitosan claim 1 , polyvinyl alcohol claim 1 , and like compounds.5. The reaction mixture of claim 1 , wherein the coating encapsulating at least one of the ammonium containing compound and the nitrite containing compound is selected from 55- ...

Non-Acidic Exothermic Sandstone Stimulation Fluids

Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include nitrogen generating compounds, which upon activation, react to generate heat and nitrogen gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, the heat and nitrogen gas generated 1. A non-acidic well stimulation composition for use in sandstone formations , the composition comprising:an ammonium containing compound;a nitrite containing compound; anda non-acidic well stimulation fluid.2. The composition of claim 1 , wherein at least one of the ammonium containing compound and the nitrite containing compound are encapsulated with a coating that delays the reaction of the ammonium and nitrite containing compounds.3. The composition of claim 1 , wherein the non-acidic well stimulation fluid includes an alkali or alkaline earth hydroxide.4. The composition of claim 1 , wherein the non-acidic well stimulation fluid includes sodium hydroxide.5. The composition of claim 1 , wherein the non-acidic well stimulation fluid comprises at least about 5% sodium hydroxide by weight.6. The composition of claim 1 , wherein the non-acidic well stimulation fluid comprises at least about 10% sodium hydroxide by weight.7. The composition of claim 1 , wherein the non-acidic well stimulation fluid comprises at least about 15% sodium hydroxide by weight.8. The composition of claim 1 , wherein the ammonium containing compound is selected from ammonium chloride.9. The composition of claim 1 , wherein the nitrite containing compound is selected from sodium nitrite.10. The composition of claim 2 , wherein the coating encapsulating at least one of the ammonium containing compound and the nitrite containing compound is a polymer selected from guar claim 2 , chitosan claim 2 , polyvinyl alcohol claim 2 , and like compounds.11. The composition of claim 2 , wherein the coating ...

ENHANCED OIL RECOVERY BY IN-SITU STEAM GENERATION

Embodiments of the invention provide methods and composition for stimulating a hydrocarbon-bearing, heavy oil containing formation, a deep oil reservoir, or a tight oil reservoir, whereby exothermic reactants are utilized to generate in-situ steam and nitrogen gas downhole in the formation or the reservoir as an enhanced oil recovery process. An oil well stimulation method is provided, which includes injecting, into the one of the formation and the reservoir, an aqueous composition including an ammonium containing compound and a nitrite containing compound. The method further includes injecting, into the one of the formation and the reservoir, an activator. The activator initiates a reaction between the ammonium containing compound and the nitrite containing compound, such that the reaction generates steam and nitrogen gas, increasing localized pressure and improving oil mobility, in the one of the formation and the reservoir, thereby enhancing oil recovery from the one of the formation and the reservoir. 1. An oil well stimulation method for enhancing oil recovery from one of a formation and a reservoir , the oil well stimulation method comprising:injecting, into the one of the formation and the reservoir, an aqueous composition comprising an ammonium containing compound and a nitrite containing compound; andinjecting, into the one of the formation and the reservoir, an activator, the activator initiating a reaction between the ammonium containing compound and the nitrite containing compound, such that the reaction generates steam and nitrogen gas, increasing localized pressure and improving oil mobility, in the one of the formation and the reservoir, thereby enhancing oil recovery from the one of the formation and the reservoir.2. An oil well stimulation method as defined in claim 1 , wherein the injecting the aqueous composition comprises injecting the ammonium containing compound being selected from the group consisting of ammonium chloride claim 1 , ammonium ...

Evaluating Effectiveness of Ceramic Materials for Hydrocarbons Recovery

Example methods and systems are described for evaluating an effectiveness of ceramic particles to recover heavy oil from a subterranean region. In some aspects, a heavy oil recovery evaluation system includes a vessel containing a mixture of heavy oil and sand, the vessel including a chamber to receive a plurality of ceramic particles and water, a probe connected to the vessel to transfer energy from an energy source for energizing the plurality of ceramic particles, wherein the energized ceramic particles convert the water into steam to recover the heavy oil from the mixture, and a computer system connected to the vessel to evaluate an effectiveness of the plurality of ceramic particles to recover heavy oil from the mixture. 1. A heavy oil recovery evaluation system comprising:a vessel containing a mixture of heavy oil and sand, the vessel including a chamber to receive a plurality of ceramic particles and water;a probe connected to the vessel to transfer energy from an energy source for energizing the plurality of ceramic particles, wherein the energized ceramic particles convert the water into steam to recover the heavy oil from the mixture; anda computer system connected to the vessel to evaluate an effectiveness of the plurality of ceramic particles to recover heavy oil from the mixture.2. The system of claim 1 , wherein the probe is configured to transfer at least one of microwave energy claim 1 , radio frequency energy claim 1 , electrical energy claim 1 , or laser energy to heat the plurality of ceramic particles.3. The system of claim 1 , wherein the vessel is a first vessel claim 1 , and wherein the system further comprises a second vessel positioned in the chamber claim 1 , wherein the plurality of ceramic particles and the water are received in the second vessel.4. The system of claim 3 , wherein the second vessel comprises a mesh to permit the steam to pass through.5. The system of claim 1 , further comprising a plurality of sensors connected to the ...

Methods and apparatus for spatially-oriented chemically-induced pulsed fracturing in reservoirs

Apparatus and methods for spatially orienting a subterranean pressure pulse to a hydrocarbon-bearing formation. The apparatus includes an injection body with a fixed shape, where the injection body is operable to hold an exothermic reaction component prior to triggering an exothermic reaction of the exothermic reaction component, and where the injection body maintains the fixed shape during and after triggering of the exothermic reaction component. The injection body includes a chemical injection port, where the chemical injection port is operable to feed components of the exothermic reaction component to the injection body. The injection body includes a reinforced plug, where the reinforced plug is operable to direct a pressure pulse generated by the exothermic reaction component within the injection body to a perforation to generate a spatially-oriented fracture, where spatial orientation of the spatially-oriented fracture is pre-determined.

REDUCING WATER PERMEABILITY IN SUBTERRANEAN FORMATIONS USING PETROLEUM PRODUCTS

Reducing water permeability in a subterranean formation includes decreasing a viscosity of a petroleum product including at least one of asphaltenes and tar to yield a treatment material, providing the treatment material to an oil-producing well in a subterranean formation, solidifying the treatment material in the subterranean formation, and initiating production from the oil-producing well. 1. A method of reducing water permeability in a subterranean formation , the method comprising:decreasing a viscosity of a petroleum product to yield a treatment material;providing the treatment material to an oil-producing well in a subterranean formation;solidifying the treatment material in the subterranean formation; andinitiating production from the oil-producing well.2. The method of claim 1 , wherein the petroleum product comprises at least one of asphaltenes and tar.3. The method claim 1 , wherein decreasing the viscosity of the petroleum product comprises combining the petroleum product with a solvent.4. The method of claim 3 , wherein the solvent comprises at least one of pentane claim 3 , cyclohexane claim 3 , methylcyclohexane claim 3 , benzene claim 3 , xylene claim 3 , toluene claim 3 , isopropyl benzene claim 3 , decalin claim 3 , tetralin claim 3 , methylnaphthalene claim 3 , acetone claim 3 , and chloroform.5. The method of claim 4 , wherein the solvent comprises xylene.6. The method of claim 5 , wherein the solvent consists essentially of xylene.7. The method of claim 6 , wherein the solvent consists of xylene.8. The method of claim 5 , wherein the solvent further comprises acetone and chloroform.9. The method of claim 8 , wherein the solvent consists essentially of xylene claim 8 , acetone claim 8 , and chloroform.10. The method of claim 9 , wherein the solvent consists of xylene claim 9 , acetone claim 9 , and chloroform.11. The method of claim 1 , wherein decreasing the viscosity of the petroleum product comprises heating the petroleum product.12. The ...

METHODS FOR REDUCING CONDENSATION

A method for reducing condensate in a subsurface formation is disclosed. The method comprises introducing a first reactant and a second reactant into the subsurface formation. The first reactant and the second reactant produce an exothermic reaction that increases temperature and pressure in the subsurface formation to greater than a dew point of the condensate. Increasing the temperature and pressure in the subsurface formation to greater than the dew point of the condensate vaporizes, and thereby reduces, condensate in the subsurface formation. 1. A method for reducing condensate in a subsurface formation , the method comprising: 'the first reactant and the second reactant produce an exothermic reaction that increases temperature and pressure in the subsurface formation to greater than a dew point of the condensate, wherein increasing the temperature and pressure in the subsurface formation to greater than the dew point of the condensate vaporizes and thereby reduces condensate in the subsurface formation.', 'introducing a first reactant and a second reactant into the subsurface formation, wherein'}2. The method of claim 1 , in which introducing the first reactant and the second reactant into the subsurface formation comprises introducing each reactant into the subsurface formation separately.3. The method of claim 2 , in which introducing the first reactant and the second reactant into the subsurface formation comprises introducing the first reactant into the subsurface formation through coiled tubing and introducing the second reactant into the subsurface formation through an annulus of a wellbore.4. The method of claim 1 , in which introducing the first reactant and the second reactant into the subsurface formation comprises introducing a mixture comprising the first reactant and the second reactant into the subsurface formation.5. The method of claim 4 , in which the method further comprises introducing a buffer solution with the first and second reactants ...

NON-ACIDIC EXOTHERMIC SANDSTONE STIMULATION FLUIDS

Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include nitrogen generating compounds, which upon activation, react to generate heat and nitrogen gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, the heat and nitrogen gas generated. 1. A non-acidic well stimulation composition for use in a sandstone formation , the composition comprising:an ammonium ion containing compound;a nitrite ion containing compound, wherein at least one of the ammonium ion containing compound and nitrite ion containing compound is encapsulated with an erodible coating such that a reaction between the ammonium and nitrite ions is delayed in situ until the ammonium ion containing compound and the nitrite ion containing compound have migrated to within the sandstone formation, and wherein the ammonium ion containing compound and nitrite ion containing compound are present at concentrations sufficient to generate heat and nitrogen gas upon reacting with one another via an exothermic reaction within the sandstone formation; anda non-acidic well stimulation fluid, wherein the non-acidic well stimulation fluid comprises an alkali hydroxide or an alkaline earth hydroxide, wherein the alkali hydroxide or alkaline earth hydroxide is present at a concentration operable to dissolve at least a portion of a sandstone formation without forming precipitates, at an increased temperature caused by the exothermic reaction between the ammonium ion containing compound and the nitrite ion containing compound, for between greater than about 1 hour to about 12 hours.2. The composition of claim 1 , wherein the non-acidic well stimulation fluid comprises sodium hydroxide.3. The composition of claim 1 , wherein the non-acidic well stimulation fluid comprises at least about 5% sodium hydroxide by weight.4. The composition of claim 1 , wherein the non- ...

TRIGGERING AN EXOTHERMIC REACTION FOR RESERVOIRS USING MICROWAVES

Compositions and methods for triggering an exothermic reaction of an exothermic reaction component are provided. A method includes the steps of mixing the exothermic reaction component in an aqueous solution to achieve a pre-selected solution pH, where the aqueous solution operably delays triggering of the exothermic reaction upon reaching a pre-determined temperature of a hydrocarbon-bearing formation; disposing the exothermic reaction component within the hydrocarbon-bearing formation; applying microwaves to the exothermic reaction component, where the microwaves are operable to trigger the exothermic reaction of the exothermic reaction component; and generating heat and gas in situ by the exothermic reaction to increase pressure and temperature of the hydrocarbon-bearing formation proximate the exothermic reaction component. 1. A method for triggering an exothermic reaction of an exothermic reaction component , the method comprising the steps of:mixing the exothermic reaction component in an aqueous solution to achieve a pre-selected solution pH, where the aqueous solution operably delays triggering of the exothermic reaction upon reaching a pre-determined temperature of a hydrocarbon-bearing formation;disposing the exothermic reaction component within the hydrocarbon-bearing formation;applying microwaves to the exothermic reaction component, where the microwaves are operable to trigger the exothermic reaction of the exothermic reaction component; andgenerating heat and gas in situ by the exothermic reaction to increase pressure and temperature of the hydrocarbon-bearing formation proximate the exothermic reaction component.2. The method according to claim 1 , further comprising the steps of:mixing the exothermic reaction component in the aqueous solution, such that the exothermic reaction component is operable to react to generate a pressure pulse;mixing the aqueous solution with a viscous fluid component to form a fracturing fluid, the viscous fluid component ...

METHODS AND APPARATUS FOR SPATIALLY-ORIENTED CHEMICALLY-INDUCED PULSED FRACTURING IN RESERVOIRS

Apparatus and methods for spatially orienting a subterranean pressure pulse to a hydrocarbon-bearing formation are provided. The apparatus includes an injection body with a fixed shape, where the injection body is operable to hold an exothermic reaction component prior to triggering an exothermic reaction of the exothermic reaction component, and where the injection body maintains the fixed shape during and after triggering of the exothermic reaction component. The injection body includes a chemical injection port, where the chemical injection port is operable to feed components of the exothermic reaction component to the injection body. The injection body includes a reinforced plug, where the reinforced plug is operable to direct a pressure pulse generated by the exothermic reaction component within the injection body to a perforation to generate a spatially-oriented fracture, where spatial orientation of the spatially-oriented fracture is pre-determined. 1. An apparatus for spatially orienting a subterranean pressure pulse in a hydrocarbon-bearing formation , the apparatus comprising:an injection body with a fixed shape, where the injection body is operable to hold an exothermic reaction component prior to triggering an exothermic reaction of the exothermic reaction component, and where the injection body maintains the fixed shape during and after triggering of the exothermic reaction component;a chemical injection port, where the chemical injection port is operable to feed components of the exothermic reaction component to the injection body; anda reinforced plug, where the reinforced plug is operable to direct a pressure pulse generated by the exothermic reaction component within the injection body to a perforation to generate a spatially-oriented fracture, where spatial orientation of the spatially-oriented fracture is pre-determined.2. The apparatus of claim 1 , where the injection body further comprises a liner with a slot.3. The apparatus of claim 2 , where ...

Flowing Fracturing Fluids to Subterranean Zones

Implementations provide flowing of fracturing fluids to subterranean zones. Actions can include In some examples, a method includes actions of flowing a mixture of a first quantity of acid and a second quantity of a polymer diverting agent (PDA) having a viscosity that changes with acid concentration to a first portion of a subterranean zone, wherein the first quantity decreases as the acid reacts with metal in the first portion, and wherein the viscosity of the PDA increases as the first quantity decreases to form a PDA gel and flowing a third quantity of acid through the subterranean zone, wherein the PDA gel diverts the acid from the first portion to a second portion of the subterranean zone.

HEAVY OIL AS FRACTURING FLUID TO INCREASE HYDRAULIC FRACTURING EFFICIENCY

Compositions, systems, and methods for hydraulically fracturing a hydrocarbon-bearing formation, a method including injecting into the hydrocarbon-bearing formation under increased pressure a heavy oil fracturing fluid; allowing the heavy oil fracturing fluid to remain in situ for a period of time suitable to create fractures in the hydrocarbon-bearing reservoir, the heavy oil fracturing fluid operable to undergo an at least about 70% viscosity decrease in situ; and flowing back the heavy oil fracturing fluid to the surface without damaging the hydrocarbon-bearing formation or reducing production of hydrocarbons from the hydrocarbon-bearing formation. 1. A method for hydraulically fracturing a hydrocarbon-bearing formation , the method comprising the steps of:injecting into the hydrocarbon-bearing formation under increased pressure a heavy oil fracturing fluid;allowing the heavy oil fracturing fluid to remain in situ for a period of time suitable to create fractures in the hydrocarbon-bearing reservoir, the heavy oil fracturing fluid operable to undergo an at least about 70% viscosity decrease in situ; andflowing back the heavy oil fracturing fluid to the surface without damaging the hydrocarbon-bearing formation or reducing production of hydrocarbons from the hydrocarbon-bearing formation.2. The method according to claim 1 , where the heavy oil fracturing fluid is operable to undergo an at least about 90% viscosity decrease in situ.3. The method according to claim 1 , where the at least about 70% viscosity decrease in situ allows for an at least about 30% reduction in breakdown pressure of a rock matrix in the hydrocarbon-bearing formation versus breakdown pressure applying a fracturing fluid at viscosity conditions of the heavy oil fracturing fluid at surface conditions.4. The method according to claim 2 , where the at least about 90% viscosity decrease in situ allows for an at least about 40% reduction in breakdown pressure of a rock matrix in the hydrocarbon- ...

Sandstone stimulation using in-situ mud acid generation

A method for stimulating production of hydrocarbons from a sandstone formation includes the steps of injecting a stimulation fluid formed from a hydrofluoric acid generating precursor and an oxidizing agent, an ammonium containing compound, and a nitrite containing compound into the sandstone formation, where one or both of the hydrofluoric acid generating precursor and the oxidizing agent comprise a degradable encapsulation. The method further includes maintaining the stimulation fluid, the ammonium containing compound, and the nitrite containing compound in the sandstone formation to initiate reaction and generate heat and nitrogen gas. Upon generation of heat and degradation of the degradable encapsulation, the hydrofluoric acid generating precursor and the oxidizing agent react to form hydrofluoric acid in-situ to dissolve silica and silicate minerals and stimulate the sandstone formation. A treatment fluid for use in stimulating sandstone formations includes the stimulation fluid, the ammonium containing compound, and the nitrite containing compound.

TIGHT GAS STIMULATION BY IN-SITU NITROGEN GENERATION

Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include nitrogen generating compounds, which upon activation, react to generate heat and nitrogen gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, heat and nitrogen gas are generated. Upon the generation of nitrogen gas and heat within the formation, microfractures are produced within the formation and the hydrostatic pressure within the reservoir is reduced to less than the reservoir fluid pressure, such that the rate of production of hydrocarbons from the formation is increased. 1. A method for stimulating production of gas in a tight-gas formation , the method comprising the steps of:injecting into the tight-gas formation an aqueous solution comprising an ammonium containing compound and a nitrite containing compound, wherein at least one of the ammonium containing compound and the nitrite containing compound are encapsulated with a coating operable to delay reaction therebetween, wherein the aqueous solution is injected at a sufficient rate and pressure to cause fractures in the tight-gas formation, wherein the fractures extend into the tight-gas formation, wherein the fractures have a fracture surface; andinjecting an activator into the tight-gas formation, the activator being capable of initiating reaction between the ammonium containing compound and the nitrite containing compound such that the reaction generates heat and nitrogen gas; andallowing the generation of nitrogen gas and heat within the tight-gas formation to effect stimulation of the fracture surface, wherein the stimulation of the fracture surface produces microfractures at the fracture, wherein the hydrostatic pressure within the reservoir is reduced to less than the reservoir fluid pressure, such that the rate of production of hydrocarbons from the tight-gas formation is increased.2. ...

Compositions and Methods For Enhanced Fracture Cleanup Using Redox Treatment

A cleanup fluid for reducing a viscosity of a residual viscous material in fractures of a hydrocarbon-bearing formation. The cleanup fluid includes an exothermic reaction component operable to generate heat, where the heat is operable to reduce a viscosity of the residual viscous material to create a reduced viscosity material, the reduced viscosity material operable to flow from the fractures. 1. A method for use of a cleanup fluid in a wellbore disposed in a reservoir , the method comprising the steps of: where the cleanup fluid comprises only liquid components in solution prepared to be fluidly compatible with a viscous fluid component,', 'where the cleanup fluid does not include viscosifying components at concentrations that generate foam or introduce foam into the wellbore;, 'preparing an exothermic reaction component operable to generate heat, and the exothermic reaction component comprising at least one component selected from the group consisting of: urea; sodium hypochlorite; ammonium chloride; ammonium bromide; ammonium nitrate; ammonium sulfate; ammonium carbonate; ammonium hydroxide; sodium nitrite; potassium nitrite; and mixtures thereof,'}injecting the exothermic reaction component into the wellbore;allowing the exothermic reaction component to react in situ to produce heat and nitrogen gas, the heat and nitrogen gas operable to increase temperature and pressure in situ, to create a reduced viscosity material; andsqueezing the exothermic reaction component into the reservoir with a foamed material comprising a foamed brine solution after the step of injecting the exothermic reaction component into the wellbore, where the exothermic reaction component and the foamed material are used in a volume ratio of about 1 to 1.2. The method according to claim 1 , further comprising the step of preparing a foamed brine solution from non-foamed brine to reduce a pressure gradient of the non-foamed brine.3. The method according to claim 2 , where the step of ...

Compositions and Methods For Enhanced Fracture Cleanup Using Redox Treatment

A cleanup fluid for reducing a viscosity of a residual viscous material in fractures of a hydrocarbon-bearing formation. The cleanup fluid includes an exothermic reaction component operable to generate heat, where the heat is operable to reduce a viscosity of the residual viscous material to create a reduced viscosity material, the reduced viscosity material operable to flow from the fractures.

Compositions and Methods For Enhanced Fracture Cleanup Using Redox Treatment

A cleanup fluid for reducing a viscosity of a residual viscous material in fractures of a hydrocarbon-bearing formation. The cleanup fluid includes an exothermic reaction component operable to generate heat, where the heat is operable to reduce a viscosity of the residual viscous material to create a reduced viscosity material, the reduced viscosity material operable to flow from the fractures.

FILTERCAKE REMOVAL USING EXOTHERMIC IN-SITU NITROGEN-PRODUCING REACTANTS

Removal of filtercake particles from a wellbore is achieved by injecting two (2) water-soluble nitrogen-containing salts and an organic acid resulting in the generation of nitrogen gas and elevated temperature. 1. A method of removing filtercake particles formed in a wellbore extending into a hydrocarbon reservoir , which comprises:a. injecting at least two water-soluble nitrogen-containing salts and an organic acid into a wellbore containing a filtercake sufficient to liberate nitrogen gas and generate heat;b. dissolving the filtercake by the organic acid, the nitrogen gas formed and the heat generated from the reaction between the acid and the nitrogen salts in the borehole.2. The method of claim 1 , wherein the water-soluble nitrogen-containing salts are NHCl and NaNOand the organic acid is acetic acid.3. The method of claim 2 , wherein the NaNOand the acetic acid are injected separately from the NHCl.4. The method of claim 2 , wherein the NaNOand the acetic acid are injected through the wellbore's connective tubing and the NHCl is injected through the wellbore's production tubing.5. The method of claim 2 , wherein the NHCl is injected at about two times the rate that the NaNOand acetic acid are injected.6. The method of claim 2 , wherein the heat generated is about 75 kcal/mole. This invention relates generally to a process for the removal of filtercake from oil wells producing medium to heavy oil, and also oil wells found in low draw-down pressure reservoirs. More particularly, the present invention relates to a process for a filtercake breaker system achieved by a theromochemical reaction.In the drilling of oil wells, the drilling fluid is used to aid in the drilling of boreholes into the earth. The liquid drilling fluids, which are often referred to as drilling muds, are classified into three main types of muds. They are:The drilling fluid serves many roles, including providing a hydrostatic pressure to prevent the fluids in the formation from entering into ...

Reduction of breakdown pressure by filter cake removal using thermochemicals

A method for the simultaneous removal of filter cake from a wellbore and fracturing of the wellbore using a mixture including a chelating agent and a thermochemical. The method including feeding a mixture into the wellbore, contacting the filter cake with the mixture, reacting the chelating agent and the thermochemical to produce heat and pressure, removing the filter cake from the wellbore, and creating microfractures in the wellbore using pressure produced from the reacting.

Composition For Enhanced Fracture Cleanup Using Redox Treatment

A composition for improved hydrocarbon recovery from a formation due to cleanup of a residual viscous material is provided. The composition comprises an acid precursor, the acid precursor operable to trigger an exothermic reaction component; and the exothermic reaction component operable to generate heat, where the heat is operable to reduce a viscosity of the residual viscous material to create a reduced viscosity material, the reduced viscosity material operable to flow from the fractures.

Sand consolidation with petroleum products

Consolidating sand in a subterranean formation includes decreasing a viscosity of a petroleum product to yield a consolidating material, providing the consolidating material to the subterranean formation, and consolidating sand in the subterranean formation with the consolidating material to yield a consolidated region in the subterranean formation.

Method For Enhanced Fracture Cleanup Using Redox Treatment

A method for improved hydrocarbon recovery from a formation due to cleanup of a residual viscous material is provided. The method comprising the steps of fracturing the formation with a fracturing fluid to generate fractures, the fracturing fluid comprising a viscous fluid component operable to fracture the formation leaving behind residual viscous material in the fractures, the viscous fluid having a viscosity; a proppant component comprising a proppant, the proppant operable to hold open the fractures, wherein the proppant component is carried to the fractures by the viscous fluid component; and a cleanup fluid, the cleanup fluid comprising: an acid precursor operable to trigger an exothermic reaction component, and the exothermic reaction component operable to generate heat, where the generated heat is operable to reduce a viscosity of the residual viscous material to create a reduced viscosity material operable to flow from the formation.

Chemically-Induced Pulsed Fracturing Method

A method of increasing a stimulated reservoir volume in a wellbore in a gas-containing formation includes the steps of mixing an exothermic reaction component to achieve a pre-selected solution pH, the exothermic reaction component is operable to react at a wellbore temperature to generate a pressure pulse, mixing the exothermic reaction component with a viscous fluid component operable to fracture the gas-containing formation to create fractures, and a proppant component, the proppant component carried to the fractures by the viscous fluid, the proppant component comprises a proppant operable to hold open the fractures, to form a fracturing fluid, injecting the fracturing fluid into the wellbore in the gas-containing formation to create fractures, and generating the pressure pulse when the exothermic reaction component reaches the wellbore temperature, the pressure pulse operable to create auxiliary fractures, wherein the auxiliary fractures create a fracture network, the fracture network increases the stimulated reservoir volume. 1. A method of increasing a stimulated reservoir volume in a wellbore in a gas-containing formation , the method comprising the steps of:mixing an exothermic reaction component in an aqueous solution to achieve a pre-selected solution pH, wherein the exothermic reaction component is operable to react at a pre-selected wellbore temperature to generate a pressure pulse;mixing the aqueous solution with a viscous fluid component to form a fracturing fluid, the viscous fluid component operable to fracture the gas-containing formation to create fractures, and the fracturing fluid further comprising a proppant component, the proppant component carried to the fractures by the viscous fluid component, the proppant component comprises a proppant, the proppant operable to hold open the fractures;injecting the fracturing fluid into the wellbore in the gas-containing formation to create fractures; andgenerating the pressure pulse when the exothermic ...

Compositions For Enhanced Fracture Cleanup Using Redox Treatment

A cleanup fluid for reducing a viscosity of a residual viscous material in fractures of a hydrocarbon-bearing formation is disclosed. The cleanup fluid includes an acid precursor, the acid precursor operable to trigger an exothermic reaction component and the exothermic reaction component operable to generate heat, where the heat is operable to reduce a viscosity of the residual viscous material to create a reduced viscosity material, the reduced viscosity material operable to flow from the fractures. 1. A cleanup fluid for reducing a viscosity of a viscous material in and around a wellbore of a hydrocarbon-bearing formation , the cleanup fluid comprising:an acid precursor, the acid precursor operable to trigger an exothermic reaction component; and 'where the heat is operable to reduce a viscosity of the viscous material to create a reduced viscosity material, the reduced viscosity material operable to flow to allow increased fluid flow in the wellbore.', 'the exothermic reaction component operable to generate heat,'}2. The cleanup fluid of claim 1 , where the exothermic reaction component comprises an ammonium containing compound and a nitrite containing compound.3. The cleanup fluid of claim 2 , where the ammonium containing compound comprises NHCl and the nitrite containing compound comprises NaNO.4. The cleanup fluid of claim 3 , where the concentration of the NHCl and NaNOis about 3 M.5. The cleanup fluid of claim 1 , where the acid precursor is selected from the group consisting of triacetin claim 1 , methyl acetate claim 1 , hydrochloric acid claim 1 , acetic acid claim 1 , and combinations thereof.6. The cleanup fluid of claim 1 , where the acid precursor comprises triacetin.7. The cleanup fluid of claim 1 , where the exothermic reaction component reacts when a temperature within the hydrocarbon-bearing formation reaches about 120° F.8. The cleanup fluid of claim 1 , further comprising a cross-linked gel.9. The cleanup fluid of claim 1 , further comprising ...

Compositions and Methods For Enhanced Fracture Cleanup Using Redox Treatment

A cleanup fluid for reducing a viscosity of a residual viscous material in fractures of a hydrocarbon-bearing formation. The cleanup fluid includes an exothermic reaction component operable to generate heat, where the heat is operable to reduce a viscosity of the residual viscous material to create a reduced viscosity material, the reduced viscosity material operable to flow from the fractures. 1. A method for use of a cleanup fluid in a wellbore or reservoir , the method comprising the steps of: where the cleanup fluid comprises only liquid components in solution prepared to be fluidly compatible with a viscous fluid component such that the cleanup fluid and viscous fluid component quickly mix,', 'where the cleanup fluid does not include viscosifying components at concentrations that generate foam or introduce foam into the wellbore;, 'preparing an exothermic reaction component operable to generate heat, and the exothermic reaction component comprising at least one component selected from the group consisting of: urea; sodium hypochlorite; ammonium chloride; ammonium bromide; ammonium nitrate; ammonium sulfate; ammonium carbonate; ammonium hydroxide; sodium nitrite; potassium nitrite; and mixtures thereof,'}injecting the exothermic reaction component into the wellbore; andallowing the exothermic reaction component to react in situ to produce heat and nitrogen gas, the heat and nitrogen gas operable to increase temperature and pressure in situ, to create a reduced viscosity material.2. The method according to claim 1 , further comprising the step of squeezing the exothermic reaction component into a reservoir with a foamed material after the step of injecting the exothermic reaction component into the wellbore.3. The method according to claim 2 , where the exothermic reaction component and foamed material are used in a volume ratio of about 1 to 1.4. The method according to claim 2 , further comprising the step of preparing a foamed brine solution from non-foamed ...

ENHANCED OIL RECOVERY BY IN-SITU STEAM GENERATION

Embodiments of the invention provide methods and composition for stimulating a hydrocarbon-bearing, heavy oil containing formation, a deep oil reservoir, or a tight oil reservoir, whereby exothermic reactants are utilized to generate in-situ steam and nitrogen gas downhole in the formation or the reservoir as an enhanced oil recovery process. An oil well stimulation method is provided, which includes injecting, into the one of the formation and the reservoir, an aqueous composition including an ammonium containing compound and a nitrite containing compound. The method further includes injecting, into the one of the formation and the reservoir, an activator. The activator initiates a reaction between the ammonium containing compound and the nitrite containing compound, such that the reaction generates steam and nitrogen gas, increasing localized pressure and improving oil mobility, in the one of the formation and the reservoir, thereby enhancing oil recovery from the one of the formation and the reservoir. 1. An oil well stimulation composition , comprising:an ammonium containing compound;a nitrite containing compound; andan activator, the activator being operable to initiate a reaction between the ammonium containing compound and the nitrite containing compound, such that the reaction generates steam and nitrogen gas, increasing localized pressure and improving oil mobility, in the one of the formation and the reservoir, thereby enhancing oil recovery from the one of the formation and the reservoir.2. An oil well stimulation composition as defined in claim 1 , wherein the ammonium containing compound is selected from the group consisting of ammonium chloride claim 1 , ammonium bromide claim 1 , ammonium nitrate claim 1 , ammonium sulfate claim 1 , ammonium carbonate claim 1 , ammonium nitrile claim 1 , and ammonium hydroxide.3. An oil well stimulation composition as defined in claim 1 , wherein the nitrite containing compound being selected from the group consisting ...

Well Testing

Techniques for well testing include providing an amount of a chemical material to a location in a wellbore; reacting the chemical material to generate an exothermic chemical reaction at the location in the wellbore; and fracturing the formation by the exothermic chemical reaction. 1. A well testing method , comprising:providing an amount of a chemical material to a location in a wellbore;reacting the chemical material to generate an exothermic chemical reaction at the location in the wellbore; andfracturing the formation by the exothermic chemical reaction.2. The well testing method of claim 1 , further comprising:generating a pressure pulse, by the exothermic chemical reaction, to fracture the formation.3. The well testing method of claim 1 , wherein the chemical material comprises an ammonium material and a nitrite material.4. The well testing method of claim 3 , wherein the ammonium material comprises at least one of ammonium chloride claim 3 , ammonium bromide claim 3 , ammonium nitrate claim 3 , ammonium sulfate claim 3 , ammonium carbonate claim 3 , or ammonium hydroxide claim 3 , and the nitrite material comprises at least one of sodium nitrite claim 3 , potassium nitrite claim 3 , or sodium hypochlorite.51. The well testing method of clam claim 3 , wherein the chemical material comprises a combination of urea and sodium hypochlorite claim 3 , urea and sodium nitrite claim 3 , ammonium hydroxide and sodium hypochlorite claim 3 , or ammonium chloride and sodium nitrite.6. The well testing method of claim 1 , further comprising:producing a hydrocarbon fluid from the formation to the wellbore; anddetermining at least one well parameter based on the produced hydrocarbon fluid, the well parameter comprising at least one of well head pressure, well head temperature, sand presence, oil gravity, gas gravity, or water salinity.7. The well testing method of claim 2 , wherein the pressure pulse comprises a pressure magnitude that is greater than a breakdown pressure of ...

METHODS FOR RECOVERING PETROLEUM THAT INCLUDE USING EXOTHERMIC REACTIONS IN AQUEOUS ZONES OF RESERVOIRS

According to one or more embodiments presently described, petroleum may be recovered from a sub-surface reservoir by a method that may include passing one or more exothermic reaction components into an aqueous zone of the sub-surface reservoir in a geological formation. The reservoir may comprise a petroleum zone including petroleum and an aqueous zone including water. The petroleum zone and the aqueous zone may be separated, at least partially, by a tar zone. The method may further include reacting the one or more exothermic reaction components to increase the temperature, pressure, or both, in the aqueous zone to reduce the viscosity of the tar zone such that pressure in the aqueous zone may drive extraction of petroleum from the petroleum zone to the surface. 1. A method for recovering petroleum from a sub-surface reservoir , the method comprising:passing one or more exothermic reaction components into an aqueous zone of the sub-surface reservoir in a geological formation, the sub-surface reservoir comprising the aqueous zone, a petroleum zone comprising petroleum, and an aqueous zone comprising water, where the petroleum zone and the aqueous zone are separated, at least partially, by the tar zone; andreacting the one or more exothermic reaction components to increase the temperature, pressure, or both, in the aqueous zone to reduce the viscosity of the tar in the tar zone such that pressure in the aqueous zone may drive extraction of petroleum from the petroleum zone to the surface.2. The method of claim 1 , where following the exothermic reaction the pressure is increased in the petroleum zone.3. The method of claim 1 , where the reduction of the viscosity of the tar in the tar zone enhances fluid communication between the aqueous zone and the petroleum zone.4. The method of claim 1 , where the aqueous zone comprises water injected into the sub-surface reservoir from the surface.5. The method of claim 1 , where the aqueous zone comprises a naturally occurring ...

METHODS FOR RECOVERING PETROLEUM BY REDUCING GEOLOGICAL FORMATION BREAK-DOWN PRESSURES

According to one or more embodiments presently described, petroleum may be recovered from a sub-surface reservoir by a method that may include reducing the break-down pressure of a geological formation from an original break-down pressure to a reduced break-down pressure by exothermically reacting one or more reaction components in a carrier fluid adjacent to or within the geological formation, and forming fractures in the geological formation by hydraulic fracturing the geological formation. 1. A method for recovering petroleum from a sub-surface reservoir , the method comprising:reducing the break-down pressure of a geological formation from an original break-down pressure to a reduced break-down pressure by exothermically reacting one or more reaction components in a carrier fluid adjacent to or within the geological formation, where the exothermic reaction increases the temperature, pressure, or both of the carrier fluid adjacent to or within the geological formation, and where carrier fluid adjacent to or within the geological formation has a pressure less than the original break-down pressure of the geological formation prior to the start of the exothermic reaction; andforming fractures in the geological formation by hydraulic fracturing the geological formation, the hydraulic fracturing comprising contacting the geological formation having the reduced break-down pressure with a hydraulic fracturing fluid at a pressure greater than or equal to the reduced break-down pressure.2. The method of claim 1 , where the exothermic reaction forms microfractures in the geological formation claim 1 , increases the porosity of the geological formation claim 1 , or both.3. The method of claim 1 , where at least a portion of the reaction components that undergo the exothermic reaction penetrate pores of the geological formation.4. The method of claim 1 , where the one or more exothermic reaction components comprise an ammonium-containing compound and a nitrite-containing ...

Sandstone stimulation using in-situ mud acid generation

A method for stimulating production of hydrocarbons from a sandstone formation includes the steps of injecting a stimulation fluid formed from a hydrofluoric acid generating precursor and an oxidizing agent, an ammonium containing compound, and a nitrite containing compound into the sandstone formation, where one or both of the hydrofluoric acid generating precursor and the oxidizing agent comprise a degradable encapsulation. The method further includes maintaining the stimulation fluid, the ammonium containing compound, and the nitrite containing compound in the sandstone formation to initiate reaction and generate heat and nitrogen gas. Upon generation of heat and degradation of the degradable encapsulation, the hydrofluoric acid generating precursor and the oxidizing agent react to form hydrofluoric acid in-situ to dissolve silica and silicate minerals and stimulate the sandstone formation. A treatment fluid for use in stimulating sandstone formations includes the stimulation fluid, the ammonium containing compound, and the nitrite containing compound.

SANDSTONE STIMULATION USING IN-SITU MUD ACID GENERATION

A method for stimulating production of hydrocarbons from a sandstone formation includes the steps of injecting a stimulation fluid into the sandstone formation, the stimulation fluid formed from a hydrofluoric acid precursor and an oxidizer; injecting an ammonium containing compound into the sandstone formation; and injecting a nitrite containing compound into the sandstone formation. The method further includes maintaining the stimulation fluid, the ammonium containing compound, and the nitrite containing compound in the sandstone formation to initiate reaction of the ammonium containing compound and the nitrite containing compound to generate heat and nitrogen gas, where upon generation of heat within the formation the hydrofluoric acid precursor and the oxidizer react to form hydrofluoric acid in-situ to dissolve silica and silicate minerals and stimulate the sandstone formation. A treatment fluid for use in stimulating sandstone formations includes the stimulation fluid, the ammonium containing compound, and the nitrite containing compound. 1. A method for stimulating production of hydrocarbons from a sandstone formation , the method comprising the steps of:injecting a stimulation fluid into the sandstone formation, the stimulation fluid comprising a hydrofluoric acid precursor and an oxidizer;injecting an ammonium containing compound into the sandstone formation;injecting a nitrite containing compound into the sandstone formation; and initiate reaction of the ammonium containing compound and the nitrite containing compound to generate heat and nitrogen gas, where upon generation of heat within the formation the hydrofluoric acid precursor and the oxidizer react to form hydrofluoric acid in-situ; and', 'dissolve silica and silicate minerals to stimulate the sandstone formation., 'maintaining the stimulation fluid, the ammonium containing compound, and the nitrite containing compound in the sandstone formation to2. The method of claim 1 , where the hydrofluoric ...

Tight gas stimulation by in-situ nitrogen generation

Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include nitrogen generating compounds, which upon activation, react to generate heat and nitrogen gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, heat and nitrogen gas are generated. Upon the generation of nitrogen gas and heat within the formation, microfractures are produced within the formation and the hydrostatic pressure within the reservoir is reduced to less than the reservoir fluid pressure, such that the rate of production of hydrocarbons from the formation is increased.

Method to remove well bore damage using thermochemical fluid

A method for the removal of well bore damage, the method including performing an acid cleaning of one or more of a coiled tubing and the well bore using a hydrochloric acid mixture of 7 to 15 wt% hydrochloric acid and displacing the hydrochloric acid mixture with a first fresh water stream. After acid cleaning, a composition comprising at least 10wt% acetic acid into the well bore is injected into the well bore. After injecting acetic acid, gel jetting of the well is performed with a gel mixture, and the gel mixture is subsequently displaced with a second fresh water stream. After gel jetting, an organic solvent mixture is injected into the well bore and allowing the organic solvent mixture to soak for 2 to 6 hours. Finally, a thermochemical mixture is injected into the well bore, thereby increasing temperature and pressure and cleaning build up from the well bore.

Filtercake removal using exothermic in-situ nitrogen-producing reactants

Removal of filtercake particles from a wellbore is achieved by injecting two (2) water-soluble nitrogen-containing salts and an organic acid resulting in the generation of nitrogen gas and elevated temperature.

Method for enhanced fracture cleanup using redox treatment

A method for improved hydrocarbon recovery from a formation due to cleanup of a residual viscous material is provided. The method comprising the steps of fracturing the formation with a fracturing fluid to generate fractures, the fracturing fluid comprising a viscous fluid component operable to fracture the formation leaving behind residual viscous material in the fractures, the viscous fluid having a viscosity; a proppant component comprising a proppant, the proppant operable to hold open the fractures, wherein the proppant component is carried to the fractures by the viscous fluid component; and a cleanup fluid, the cleanup fluid comprising: an acid precursor operable to trigger an exothermic reaction component, and the exothermic reaction component operable to generate heat, where the generated heat is operable to reduce a viscosity of the residual viscous material to create a reduced viscosity material operable to flow from the formation.

Non-acidic-exothermic sandstone stimulation fluids

Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include nitrogen generating compounds, which upon activation, react to generate heat and nitrogen gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, the heat and nitrogen gas generated

Non-acidic exothermic sandstone stimulation fluids

Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include nitrogen generating compounds, which upon activation, react to generate heat and nitrogen gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, the heat and nitrogen gas generated.

Flowing fracturing fluids to subterranean zones

Implementations provide flowing of fracturing fluids to subterranean zones. Actions can include In some examples, a method includes actions of flowing a mixture of a first quantity of acid and a second quantity of a polymer diverting agent (PDA) having a viscosity that changes with acid concentration to a first portion of a subterranean zone, wherein the first quantity decreases as the acid reacts with metal in the first portion, and wherein the viscosity of the PDA increases as the first quantity decreases to form a PDA gel and flowing a third quantity of acid through the subterranean zone, wherein the PDA gel diverts the acid from the first portion to a second portion of the subterranean zone.

Flowing fracturing fluids to subterranean zones.

Las implementaciones proporcionan el flujo de fluidos de fracturación a zonas subterráneas. Las acciones pueden incluir en algunos ejemplos un método que incluye acciones de hacer fluir una mezcla de una primera cantidad de ácido y una segunda cantidad de un agente de desviación de polímeros (PDA) que tiene una viscosidad que cambia con la concentración de ácido a una primera porción de una zona subterránea, en donde la primera cantidad disminuye a medida que el ácido reacciona con metal en la primera porción y en donde la viscosidad del PDA se incrementa a medida que la primera cantidad disminuye para formar un gel de PDA y hacer fluir una tercera cantidad de ácido a través de la zona subterránea, en donde el gel de PDA desvía el ácido de la primera porción a una segunda porción de la zona subterránea.

Systems, methods, and compositions for reservoir stimulation treatment diversion using thermochemicals

Reservoir stimulation treatment diversion methods, systems, and compositions. One method includes identifying a reservoir requiring liquid stimulation treatment in a lesser-permeability portion of the reservoir. The method includes identifying a greater-permeability portion of the reservoir, the greater-permeability portion of the reservoir having a greater permeability than the lesser-permeability portion. The method also includes disposing a gas in the greater-permeability portion of the reservoir; injecting a liquid stimulation treatment into the reservoir, and allowing the gas in the greater-permeability portion of the reservoir to divert the liquid stimulation treatment into the lesser-permeability portion to stimulate fluid production from the lesser-permeability portion of the reservoir.

Reduction of breakdown pressure by filter cake removal using thermochemicals

A method for the simultaneous removal of filter cake from a wellbore and fracturing of the wellbore using a mixture including a chelating agent and a thermochemical. The method including feeding a mixture into the wellbore, contacting the filter cake with the mixture, reacting the chelating agent and the thermochemical to produce heat and pressure, removing the filter cake from the wellbore, and creating microfractures in the wellbore using pressure produced from the reacting.

Sand consolidation using asphaltene/tar with solvents and adsorption system

A sand consolidation composition includes a hydrocarbon mixture comprising asphaltene, bitumen, or tar, and a binding agent, where the binding agent is an amino silane, and where the composition has a viscosity ranging from 5 to 20 cP at 20 to 25° C. A method of sand consolidation includes introducing the sand consolidation composition in a wellbore, contacting sand downhole with the sand consolidation composition, maintaining the wellbore such that a viscosity of the sand consolidation composition and the sand increases from an initial viscosity of the sand consolidation composition, introducing a thermochemical reagent comprising sodium nitrite and ammonium chloride such that it intimately intermingles downhole with the sand consolidation composition and releases a gas, and after a period, forming a productive consolidated sand.

Sandstone stimulation using in-situ mud acid generation

A method for stimulating production of hydrocarbons from a sandstone formation includes the steps of injecting a stimulation fluid formed from a hydrofluoric acid generating precursor and an oxidizing agent, an ammonium containing compound, and a nitrite containing compound into the sandstone formation, where one or both of the hydrofluoric acid generating precursor and the oxidizing agent comprise a degradable encapsulation. The method further includes maintaining the stimulation fluid, the ammonium containing compound, and the nitrite containing compound in the sandstone formation to initiate reaction and generate heat and nitrogen gas. Upon generation of heat and degradation of the degradable encapsulation, the hydrofluoric acid generating precursor and the oxidizing agent react to form hydrofluoric acid in-situ to dissolve silica and silicate minerals and stimulate the sandstone formation. A treatment fluid for use in stimulating sandstone formations includes the stimulation fluid, the ammonium containing compound, and the nitrite containing compound.

Nitrate treatment for injectivity improvement

Methods of enhancing water injectivity into a subterranean wellbore may include injecting a first composition comprising nitrate anions having a nitrate concentration into a target zone of the subterranean wellbore; injecting a second composition comprising nitrate anions into the target zone of the subterranean wellbore, where the second composition has a nitrate concentration of from about 20% to about 70% the nitrate concentration of the first composition; optionally injecting a third composition comprising nitrate anions into the target zone of the subterranean wellbore, where the third composition has a nitrate concentration of from about 20% to about 70% the nitrate concentration of the second composition; and injecting water, where the water injection pressure is reduced by about 5% to 25% compared to the water injection pressure in an untreated subterranean wellbore, where the nitrate anions are reduced by bacteria present in the subterranean wellbore.

Removal of filter cake

A method, system, and drilling fluid for treating a wellbore for filter cake removal, including providing the drilling fluid having thermochemical reagents that are encapsulated and acid-generating material that is encapsulated into a wellbore in a subterranean formation to attack filter cake in the wellbore, and attacking the filter cake via the drilling fluid.

In-situ foam generation for water shutoff

A system and method for water shutoff, including providing a treatment fluid including a polymer and a nitrogen-generating compound through a wellbore into a water zone in a subterranean formation, generating nitrogen gas in the water zone by a reaction of the nitrogen-generating compound, generating foam from the nitrogen gas and the treatment fluid in the water zone to give foamed polymer in the water zone, and sealing the water zone with the foamed polymer.

Enhanced oil recovery by in-situ steam generation

In-situ foamed gel for lost circulation

A system and method for treating lost circulation, including providing a treatment fluid including a polymer and a nitrogen-generating compound through a wellbore into a lost circulation zone in a subterranean formation, generating nitrogen gas in the lost circulation zone by a reaction of the nitrogen-generating compound, generating foam from the nitrogen gas and the treatment fluid in the lost circulation zone to give foamed polymer in the lost circulation zone, and plugging the lost circulation zone with the foamed polymer.

Self-destructive barite filter cake in water-based and oil-based drilling fluids

Drilling fluid compositions may include a weighting agent, a nitrite-containing compound, and an ammonium-containing compound, where the nitrite-containing compound and the ammonium-containing compound may be encapsulated together in copolymer micro-particles forming encapsulated thermochemical compounds, and where at least one property selected from the group consisting of the density, the plastic viscosity, the yield point, the gel strength, and the pH, of the drilling fluid composition may be substantially similar to the at least one property of a comparable drilling fluid composition devoid of the encapsulated thermochemical compounds. Methods for reducing a filter cake from a wellbore surface in a subterranean formation are also provided. The methods may include introducing into the wellbore the drilling fluid compositions, allowing the drilling fluid composition to reach a temperature in the wellbore sufficient for the encapsulated thermochemical compounds to react, where the reaction of the encapsulated thermochemical compounds generates heat and nitrogen gas.

Methods for recovering petroleum that include using exothermic reactions in aqueous zones of reservoirs

According to one or more embodiments presently described, petroleum may be recovered from a sub-surface reservoir by a method that may include passing one or more exothermic reaction components into an aqueous zone of the sub-surface reservoir in a geological formation. The reservoir may comprise a petroleum zone including petroleum and an aqueous zone including water. The petroleum zone and the aqueous zone may be separated, at least partially, by a tar zone. The method may further include reacting the one or more exothermic reaction components to increase the temperature, pressure, or both, in the aqueous zone to reduce the viscosity of the tar zone such that pressure in the aqueous zone may drive extraction of petroleum from the petroleum zone to the surface.

Method for removing condensate banking in a subsurface formation

A method of removing condensate banking in a subsurface formation using a treatment fluid includes injecting a treatment fluid including nanoparticles and a thermochemical component, the thermochemical component including sodium nitrite and ammonium chloride, into a wellbore having condensate banking, thereby exposing the treatment fluid to subsurface formation conditions. The method further includes allowing a temperature of the wellbore to activate the thermochemical component, causing an exothermic reaction generating nitrogen gas, pressure, and heat. The method further includes allowing the treatment fluid and generated nitrogen gas to mix with the condensate banking, thereby forming a homogenous multi-phase foam and lowering hydrostatic pressure in the wellbore. The method further includes allowing the homogenous multi-phase foam to flow back to the surface due to the pressure generated by the exothermic reaction and lowered hydrostatic pressure in the wellbore, thereby removing the condensate banking.

Heavy oil as fracturing fluid to increase hydraulic fracturing efficiency

Compositions, systems, and methods for hydraulically fracturing a hydrocarbon-bearing formation, a method including injecting into the hydrocarbon-bearing formation under increased pressure a heavy oil fracturing fluid; allowing the heavy oil fracturing fluid to remain in situ for a period of time suitable to create fractures in the hydrocarbon-bearing reservoir, the heavy oil fracturing fluid operable to undergo an at least about 70% viscosity decrease in situ; and flowing back the heavy oil fracturing fluid to the surface without damaging the hydrocarbon-bearing formation or reducing production of hydrocarbons from the hydrocarbon-bearing formation.

Method and composition for acidizing a subsurface formation utilizing a nitrogen gas-generating treatment fluid

A method for acidizing a subsurface formation using a treatment fluid includes injecting a treatment fluid including a strong acid, a buffer, a thermochemical component, a foaming agent and nanoparticles into the wellbore, thereby exposing the treatment fluid to subsurface formation conditions. The method further includes allowing a temperature of the wellbore to activate the thermochemical component, causing an exothermic reaction generating nitrogen gas, pressure, and heat, thereby forming fractures within the subsurface formation. The method further includes allowing the treatment fluid and nitrogen gas to mix within the subsurface formation, thereby forming a foamed acid within the fractures to acidize the subsurface formation.

Methods for reducing condensation

A method for reducing condensate in a subsurface formation is disclosed. The method comprises introducing a first reactant and a second reactant into the subsurface formation. The first reactant and the second reactant produce an exothermic reaction that increases temperature and pressure in the subsurface formation to greater than a dew point of the condensate. Increasing the temperature and pressure in the subsurface formation to greater than the dew point of the condensate vaporizes, and thereby reduces, condensate in the subsurface formation.

In-Situ Foamed Gel for Lost Circulation

A system and method for treating lost circulation, including providing a treatment fluid including a polymer and a nitrogen-generating compound through a wellbore into a lost circulation zone in a subterranean formation, generating nitrogen gas in the lost circulation zone by a reaction of the nitrogen-generating compound, generating foam from the nitrogen gas and the treatment fluid in the lost circulation zone to give foamed polymer in the lost circulation zone, and plugging the lost circulation zone with the foamed polymer.

Sand consolidation using asphaltene/tar with solvents and adsorption system

A sand consolidation composition includes a hydrocarbon mixture comprising asphaltene, bitumen, or tar, and a binding agent, where the binding agent is an amino silane, and where the composition has a viscosity ranging from 5 to 20 cP at 20 to 25° C. A method of sand consolidation includes introducing the sand consolidation composition in a wellbore, contacting sand downhole with the sand consolidation composition, maintaining the wellbore such that a viscosity of the sand consolidation composition and the sand increases from an initial viscosity of the sand consolidation composition, introducing a thermochemical reagent comprising sodium nitrite and ammonium chloride such that it intimately intermingles downhole with the sand consolidation composition and releases a gas, and after a period, forming a productive consolidated sand.

Method for removing condensate banking in a subsurface formation

A method of removing condensate banking in a subsurface formation using a treatment fluid includes injecting a treatment fluid including nanoparticles and a thermochemical component, the thermochemical component including sodium nitrite and ammonium chloride, into a wellbore having condensate banking, thereby exposing the treatment fluid to subsurface formation conditions. The method further includes allowing a temperature of the wellbore to activate the thermochemical component, causing an exothermic reaction generating nitrogen gas, pressure, and heat. The method further includes allowing the treatment fluid and generated nitrogen gas to mix with the condensate banking, thereby forming a homogenous multi-phase foam and lowering hydrostatic pressure in the wellbore. The method further includes allowing the homogenous multi-phase foam to flow back to the surface due to the pressure generated by the exothermic reaction and lowered hydrostatic pressure in the wellbore, thereby removing the condensate banking.

Methods for wellbore formation using thermochemicals

A method for stimulating a well includes mixing at least one thermochemical with fracturing fluid to create a fracturing fluid mixture, injecting the fracturing fluid mixture into the well, creating an exothermic reaction with the fracturing fluid mixture, generating a pressure pulse in the well from the exothermic reaction, and fracturing a formation around the well with pressure from the pressure pulse and a hydraulic pressure source.

Removal of water blockage in tight gas reservoir using thermochemical fluids

Methods, systems, and compositions for increasing hydrocarbon production from a wellbore where the wellbore or a nearby hydrocarbon reservoir is suffering from water blockage, one method including identifying water blockage in a rock sample of a formation via increased capillary pressure in the rock sample; formulating an exothermic reaction component to remove water blockage from a reservoir rock in situ via heat and pressure release, the reservoir rock type the same as the rock sample; injecting the exothermic reaction component into the wellbore; and allowing the exothermic reaction component to react to remove water blockage in situ to decrease capillary pressure of the reservoir rock without substantially changing porosity of the reservoir rock.

Sand consolidation with petroleum products

INTERNATIONAL APPLICATION PUBLISHED UNDER THE PATENT COOPERATION TREATY (PCT) (19) World Intellectual Property Organization International Bureau (43) International Publication Date 04 October 2018 (04.10.2018) W I PO I PCT 0111111010 0111 °nolo III OH OH ioo Imo oimIE (10) International Publication Number WO 2018/183157 Al (51) International Patent Classification: CO9K 8/565 (2006.01) (21) International Application Number: PCT/US2018/024271 (22) International Filing Date: 26 March 2018 (26.03.2018) (25) Filing Language: English (26) Publication Language: English (30) Priority Data: 62/477,051 27 March 2017 (27.03.2017) US Published: — with international search report (Art. 21(3)) (71) Applicant: SAUDI ARABIAN OIL COMPANY [SA/SA]; 1 Eastern Avenue, Dhahran, 31311 (SA). (71) Applicant (for AG only): ARAMCO SERVICES COM- PANY [US/US]; 9009 West Loop South, Houston, Texas 77210-4535 (US). (72) Inventors: AL-NAKHLI, Ayman Raja; Saudi Aramco, P.O. Box 12586, Dhahran, 31311 (SA). RIZQ, Ahmad Noor Al-deen Hassan; Research and Development Cen- ter, Building: 2291; Second floor; Room; HB210, Dhahran, 31311 (SA). (74) Agent: BRUCE, Carl E. et al.; FISH & RICHARDSON P.C., P.O. Box 1022, Minneapolis, Minnesota 55440-1022 (US). (81) Designated States (unless otherwise indicated, for every kind of national protection available): AE, AG, AL, AM, AO, AT, AU, AZ, BA, BB, BG, BH, BN, BR, BW, BY, BZ, CA, CH, CL, CN, CO, CR, CU, CZ, DE, DJ, DK, DM, DO, DZ, EC, EE, EG, ES, FI, GB, GD, GE, GH, GM, GT, HN, HR, HU, ID, IL, IN, IR, IS, JO, JP, KE, KG, KH, KN, KP, KR, KW, KZ, LA, LC, LK, LR, LS, LU, LY, MA, MD, ME, MG, MK, MN, MW, MX, MY, MZ, NA, NG, NI, NO, NZ, OM, PA, PE, PG, PH, PL, PT, QA, RO, RS, RU, RW, SA, SC, SD, SE, SG, SK, SL, SM, ST, SV, SY, TH, TJ, TM, TN, TR, TT, TZ, UA, UG, US, UZ, VC, VN, ZA, ZM, ZW. (84) Designated States (unless otherwise indicated, for every kind of regional protection available): ARIPO (BW, GH, GM, KE, LR, LS, MW, MZ, NA, RW, SD, SL, ST, SZ, TZ, UG, ZM, ...

Sand consolidation with petroleum products

Consolidating sand in a subterranean formation includes decreasing a viscosity of a petroleum product to yield a consolidating material, providing the consolidating material to the subterranean formation, and consolidating sand in the subterranean formation with the consolidating material to yield a consolidated region in the subterranean formation.

Nitrate treatment for injectivity improvement

Methods of enhancing water injectivity into a subterranean wellbore may include injecting a first composition comprising nitrate anions having a nitrate concentration into a target zone of the subterranean wellbore; injecting a second composition comprising nitrate anions into the target zone of the subterranean wellbore, where the second composition has a nitrate concentration of from about 20% to about 70% the nitrate concentration of the first composition; optionally injecting a third composition comprising nitrate anions into the target zone of the subterranean wellbore, where the third composition has a nitrate concentration of from about 20% to about 70% the nitrate concentration of the second composition; and injecting water, where the water injection pressure is reduced by about 5% to 25% compared to the water injection pressure in an untreated subterranean wellbore, where the nitrate anions are reduced by bacteria present in the subterranean wellbore.

Thermochemical soap stick for well lifting and deliquification

A thermochemical soap stick, system, and method for unloading liquid from a well, the thermochemical soap stick having thermochemical reagents and to be provided into a wellbore in a subterranean formation, the thermochemical soap stick to dissolve in the liquid giving a thermochemical reaction to generate gas to foam the liquid, and displacing the liquid from the wellbore via pressure of the subterranean formation.

Controlled reaction rates of thermochemical fluids using emulsions

Compositions containing a first reactant; an emulsion comprising a surfactant and silicon dioxide (SiO 2 ) nanoparticles; and a carrier fluid containing a second reactant and methods of making. When the first and second reactants react, they generate heat. At a first time, the emulsion surrounds the first reactant, and the carrier fluid with the second reactant surrounds the emulsion. At a second time, the emulsion surrounds a first portion of the first reactant; and a second portion of the first reactant surrounds the emulsion.

Self-destructive barite filter cake in water-based and oil-based drilling fluids

Drilling fluid compositions may include a weighting agent, a nitrite-containing compound, and an ammonium-containing compound, where the nitrite-containing compound and the ammonium-containing compound may be encapsulated together in copolymer micro-particles forming encapsulated thermochemical compounds, and where at least one property selected from the group consisting of the density, the plastic viscosity, the yield point, the gel strength, and the pH, of the drilling fluid composition may be substantially similar to the at least one property of a comparable drilling fluid composition devoid of the encapsulated thermochemical compounds. Methods for reducing a filter cake from a wellbore surface in a subterranean formation are also provided. The methods may include introducing into the wellbore the drilling fluid compositions, allowing the drilling fluid composition to reach a temperature in the wellbore sufficient for the encapsulated thermochemical compounds to react, where the reaction of the encapsulated thermochemical compounds generates heat and nitrogen gas.

Methods and apparatus for spatially-oriented chemically-induced pulsed fracturing in reservoirs

Apparatus and methods for spatially orienting a subterranean pressure pulse to a hydrocarbon-bearing formation are provided. The apparatus includes an injection body with a fixed shape, where the injection body is operable to hold an exothermic reaction component prior to triggering an exothermic reaction of the exothermic reaction component, and where the injection body maintains the fixed shape during and after triggering of the exothermic reaction component. The injection body includes a chemical injection port, where the chemical injection port is operable to feed components of the exothermic reaction component to the injection body. The injection body includes a reinforced plug, where the reinforced plug is operable to direct a pressure pulse generated by the exothermic reaction component within the injection body to a perforation to generate a spatially-oriented fracture, where spatial orientation of the spatially-oriented fracture is pre-determined.

Sandstone stimulation using in-situ mud acid generation

Sandstone stimulation using in-situ mud acid generation

Sandstone stimulation using in-situ mud acid generation

A method for stimulating production of hydrocarbons from a sandstone formation includes the steps of injecting a stimulation fluid into the sandstone formation, the stimulation fluid formed from a hydrofluoric acid precursor and an oxidizer; injecting an ammonium containing compound into the sandstone formation; and injecting a nitrite containing compound into the sandstone formation. The method further includes maintaining the stimulation fluid, the ammonium containing compound, and the nitrite containing compound in the sandstone formation to initiate reaction of the ammonium containing compound and the nitrite containing compound to generate heat and nitrogen gas, where upon generation of heat within the formation the hydrofluoric acid precursor and the oxidizer react to form hydrofluoric acid in-situ to dissolve silica and silicate minerals and stimulate the sandstone formation. A treatment fluid for use in stimulating sandstone formations includes the stimulation fluid, the ammonium containing compound, and the nitrite containing compound.

Sandstone stimulation using in-situ mud acid generation

A method for stimulating production of hydrocarbons from a sandstone formation includes the steps of injecting a stimulation fluid into the sandstone formation, the stimulation fluid formed from a hydrofluoric acid precursor and an oxidizer; injecting an ammonium containing compound into the sandstone formation; and injecting a nitrite containing compound into the sandstone formation. The method further includes maintaining the stimulation fluid, the ammonium containing compound, and the nitrite containing compound in the sandstone formation to initiate reaction of the ammonium containing compound and the nitrite containing compound to generate heat and nitrogen gas, where upon generation of heat within the formation the hydrofluoric acid precursor and the oxidizer react to form hydrofluoric acid in-situ to dissolve silica and silicate minerals and stimulate the sandstone formation. A treatment fluid for use in stimulating sandstone formations includes the stimulation fluid, the ammonium containing compound, and the nitrite containing compound.

Sandstone stimulation using in-situ mud acid generation

A method for stimulating production of hydrocarbons from a sandstone formation includes the steps of injecting a stimulation fluid into the sandstone formation, the stimulation fluid formed from a hydrofluoric acid precursor and an oxidizer; injecting an ammonium containing compound into the sandstone formation; and injecting a nitrite containing compound into the sandstone formation. The method further includes maintaining the stimulation fluid, the ammonium containing compound, and the nitrite containing compound in the sandstone formation to initiate reaction of the ammonium containing compound and the nitrite containing compound to generate heat and nitrogen gas, where upon generation of heat within the formation the hydrofluoric acid precursor and the oxidizer react to form hydrofluoric acid in-situ to dissolve silica and silicate minerals and stimulate the sandstone formation. A treatment fluid for use in stimulating sandstone formations includes the stimulation fluid, the ammonium containing compound, and the nitrite containing compound.

Thermochemical soap stick for well lifting and deliquification

A thermochemical soap stick, system, and method for unloading liquid from a well, the thermochemical soap stick having thermochemical reagents and to be provided into a wellbore in a subterranean formation, the thermochemical soap stick to dissolve in the liquid giving a thermochemical reaction to generate gas to foam the liquid, and displacing the liquid from the wellbore via pressure of the subterranean formation.

Evaluating effectiveness of ceramic materials for hydrocarbons recovery

Example methods and systems are described for evaluating an effectiveness of ceramic particles to recover heavy oil from a subterranean region. In some aspects, a heavy oil recovery evaluation system includes a vessel containing a mixture of heavy oil and sand, the vessel including a chamber to receive a plurality of ceramic particles and water, a probe connected to the vessel to transfer energy from an energy source for energizing the plurality of ceramic particles, wherein the energized ceramic particles convert the water into steam to recover the heavy oil from the mixture, and a computer system connected to the vessel to evaluate an effectiveness of the plurality of ceramic particles to recover heavy oil from the mixture.

Flowing fracturing fluids to subterranean zones

Implementations provide flowing of fracturing fluids to subterranean zones. Actions can include In some examples, a method includes actions of flowing a mixture of a first quantity of acid and a second quantity of a polymer diverting agent (PDA) having a viscosity that changes with acid concentration to a first portion of a subterranean zone, wherein the first quantity decreases as the acid reacts with metal in the first portion, and wherein the viscosity of the PDA increases as the first quantity decreases to form a PDA gel and flowing a third quantity of acid through the subterranean zone, wherein the PDA gel diverts the acid from the first portion to a second portion of the subterranean zone.

Composition for enhanced fracture cleanup using redox treatment

A composition for improved hydrocarbon recovery from a formation due to cleanup of a residual viscous material is provided. The composition comprises an acid precursor, the acid precursor operable to trigger an exothermic reaction component; and the exothermic reaction component operable to generate heat, where the heat is operable to reduce a viscosity of the residual viscous material to create a reduced viscosity material, the reduced viscosity material operable to flow from the fractures.

Evaluating effectiveness of ceramic materials for hydrocarbons recovery

Example methods and systems are described for evaluating an effectiveness of ceramic particles to recover heavy oil from a subterranean region. In some aspects, a heavy oil recovery evaluation system includes a vessel containing a mixture of heavy oil and sand, the vessel including a chamber to receive a plurality of ceramic particles and water, a probe connected to the vessel to transfer energy from an energy source for energizing the plurality of ceramic particles, wherein the energized ceramic particles convert the water into steam to recover the heavy oil from the mixture, and a computer system connected to the vessel to evaluate an effectiveness of the plurality of ceramic particles to recover heavy oil from the mixture.

Enhanced oil recovery by in-situ steam generation

Embodiments of the invention provide methods and composition for stimulating a hydrocarbon-bearing, heavy oil containing formation, a deep oil reservoir, or a tight oil reservoir, whereby exothermic reactants are utilized to generate in-situ steam and nitrogen gas downhole in the formation or the reservoir as an enhanced oil recovery process. An oil well stimulation method is provided, which includes injecting, into the one of the formation and the reservoir, an aqueous composition including an ammonium containing compound and a nitrite containing compound. The method further includes injecting, into the one of the formation and the reservoir, an activator. The activator initiates a reaction between the ammonium containing compound and the nitrite containing compound, such that the reaction generates steam and nitrogen gas, increasing localized pressure and improving oil mobility, in the one of the formation and the reservoir, thereby enhancing oil recovery from the one of the formation and the reservoir.

Tight gas stimulation by in-situ nitrogen generation

Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include nitrogen generating compounds, which upon activation, react to generate heat and nitrogen gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, heat and nitrogen gas are generated. Upon the generation of nitrogen gas and heat within the formation, microfractures are produced within the formation and the hydrostatic pressure within the reservoir is reduced to less than the reservoir fluid pressure, such that the rate of production of hydrocarbons from the formation is increased.

Method for enhanced fracture cleanup using redox treatment

A method for improved hydrocarbon recovery from a formation due to cleanup of a residual viscous material is provided. The method comprising the steps of fracturing the formation with a fracturing fluid to generate fractures, the fracturing fluid comprising a viscous fluid component operable to fracture the formation leaving behind residual viscous material in the fractures, the viscous fluid having a viscosity; a proppant component comprising a proppant, the proppant operable to hold open the fractures, wherein the proppant component is carried to the fractures by the viscous fluid component; and a cleanup fluid, the cleanup fluid comprising: an acid precursor operable to trigger an exothermic reaction component, and the exothermic reaction component operable to generate heat, where the generated heat is operable to reduce a viscosity of the residual viscous material to create a reduced viscosity material operable to flow from the formation.

Chemically-induced pulsed fracturing method

A method of increasing a stimulated reservoir volume in a wellbore in a gas-containing formation includes the steps of mixing an exothermic reaction component to achieve a pre-selected solution pH, the exothermic reaction component is operable to react at a wellbore temperature to generate a pressure pulse, mixing the exothermic reaction component with a viscous fluid component operable to fracture the gas-containing formation to create fractures, and a proppant component, the proppant component carried to the fractures by the viscous fluid, the proppant component comprises a proppant operable to hold open the fractures, to form a fracturing fluid, injecting the fracturing fluid into the wellbore in the gas-containing formation to create fractures, and generating the pressure pulse when the exothermic reaction component reaches the wellbore temperature, the pressure pulse operable to create auxiliary fractures, wherein the auxiliary fractures create a fracture network, the fracture network increases the stimulated reservoir volume.