WO2019175792A1 - Système de fluide de forage pour réguler la perte de circulation - Google Patents

Système de fluide de forage pour réguler la perte de circulation Download PDF

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Publication number
WO2019175792A1
WO2019175792A1 PCT/IB2019/052030 IB2019052030W WO2019175792A1 WO 2019175792 A1 WO2019175792 A1 WO 2019175792A1 IB 2019052030 W IB2019052030 W IB 2019052030W WO 2019175792 A1 WO2019175792 A1 WO 2019175792A1
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Prior art keywords
drilling fluid
fluid system
range
concentration
polymer
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PCT/IB2019/052030
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English (en)
Inventor
Mahaboob Subhahani MOHAMED ALI
Mohamed Iqbal Batcha IMAM JAFAR KHAN
Arivudainambi UDAIYAR SHANMUGAVEL EZHIL
Senthilkumar SUNDARARAJ
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Oren Hydrocarbons Private Limited
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Publication of WO2019175792A1 publication Critical patent/WO2019175792A1/fr

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    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/04—Aqueous well-drilling compositions
    • C09K8/06—Clay-free compositions
    • C09K8/08—Clay-free compositions containing natural organic compounds, e.g. polysaccharides, or derivatives thereof
    • C—CHEMISTRY; METALLURGY
    • C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
    • C08L—COMPOSITIONS OF MACROMOLECULAR COMPOUNDS
    • C08L3/00—Compositions of starch, amylose or amylopectin or of their derivatives or degradation products
    • C08L3/02—Starch; Degradation products thereof, e.g. dextrin
    • C—CHEMISTRY; METALLURGY
    • C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
    • C08L—COMPOSITIONS OF MACROMOLECULAR COMPOUNDS
    • C08L5/00—Compositions of polysaccharides or of their derivatives not provided for in groups C08L1/00 or C08L3/00
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
    • C09K8/504—Compositions based on water or polar solvents
    • C09K8/506—Compositions based on water or polar solvents containing organic compounds
    • C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
    • C09K8/514—Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/003—Means for stopping loss of drilling fluid
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
    • C09K2208/12—Swell inhibition, i.e. using additives to drilling or well treatment fluids for inhibiting clay or shale swelling or disintegrating
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
    • C09K2208/18—Bridging agents, i.e. particles for temporarily filling the pores of a formation; Graded salts
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
    • C09K2208/32—Anticorrosion additives
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
    • C09K2208/34—Lubricant additives

Definitions

  • the present invention relates to drilling fluid system. More particularly, the present invention relates to a water-based drilling fluid system for controlling loss circulation in wellbores.
  • Natural resources such as oil and gas present in the subterranean formation are recovered by drilling a wellbore that penetrates the formation.
  • a fluid called drilling fluid or mud
  • drilling fluid is injected into the well through a drill pipe and re-circulated to the surface in the annular area formed by the wellbore wall and drill string.
  • the drilling fluid is physically and chemically treated and conditioned before it is pumped back into the well.
  • the drilling fluid can be water-based, oil-based, pseudo-oil based or foam-based. Water-based drilling fluids are preferred these days over oil-based or pseudo oil-based for economic and environmental reasons.
  • the drilling operation involves driving by rotation a drilling apparatus including a column of drill pipes to the bottom of which is attached a multi-pronged/toothed drill bit.
  • a drilling apparatus including a column of drill pipes to the bottom of which is attached a multi-pronged/toothed drill bit.
  • these cuttings are to be continuously removed from the vicinity of the drill bit at the bottom of the hole.
  • the drilling fluid is pumped down-hole through the drill pipe.
  • the cuttings are removed from the down-hole to the surface by the drilling fluid through the annular space between the formation and the drill pipe.
  • an efficient drilling fluid In drilling operations the role of a drilling fluid is extremely important, and to perform these functions, an efficient drilling fluid must exhibit characteristics, such as desired rheological properties, capable of cooling and lubricating the drill bit as it grinds through the earth, fluid loss prevention, stability under various temperature and pressure operating conditions, stability against contaminating fluids, such as salt water, calcium sulfate, cement and potassium contaminated fluids, etc.
  • characteristics such as desired rheological properties, capable of cooling and lubricating the drill bit as it grinds through the earth, fluid loss prevention, stability under various temperature and pressure operating conditions, stability against contaminating fluids, such as salt water, calcium sulfate, cement and potassium contaminated fluids, etc.
  • contaminating fluids such as salt water, calcium sulfate, cement and potassium contaminated fluids, etc.
  • additives may be added to the drilling fluid formulation to achieve the above properties.
  • Water-based drilling fluids have water as the continuous phase.
  • the continuous phase may contain several dissolved or dispersed substances, including, alkalis, salts and surfactants, organic polymers in colloidal state, droplets of emulsified oil and various insoluble substances, such as barite, clay and cuttings in suspension.
  • US Pat. No. 5789349 which comprises a cross-linked polymeric fluid loss control agent obtained by reaction of an acrylamide monomer, a sulfonated anionic monomer and a non-sulfonated anionic monomer.
  • Another aqueous drilling fluid is taught by US Pat. No. 7829506 which teaches a drilling fluid with aqueous base fluid, viscosifying polymer, starch and chloride-free clay stabilizer.
  • Yet another water-based wellbore fluid is taught by US Pub. No. 201 10136701 which comprises an aqueous fluid, a micronized weighting agent, a polysaccharide derivative, and at least one fatty acid ester derivative.
  • lost circulation occurs when drilling fluid flows into the geological formations instead of returning up from the annular area. Lost circulation can be a serious problem during the drilling of an oil or gas well as wellbore instability may result from shale hydration and dispersion.
  • These conventional water-based drilling fluids used to drill through water-sensitive shale formations may cause wellbore instability.
  • the polymers such as polyanionic cellulose and partially-hydrolyzed polyacrylamide are generally added in the conventional water-based drilling fluid system. Addition of these polymers in the fluid preparation may cause poor dispersion during the mixing process, and lead to formation of hard lumps or fish eyes, thereby reducing the product efficiency.
  • the fish eyes are insoluble polymers surrounded by a gelatinous hydrated polymer which inhibits the hydration process, thereby making the dispersion of the fish eyes difficult.
  • Other drawbacks of the traditionally used drilling fluid systems include wellbore instability, fracture carbonate formation, vugular formation, stuck pipes and depleted zones.
  • Another drawback of the known drilling fluid systems is that they may pose disposal problems. Stricter environmental regulations and guidelines around the world have made it a mandate to minimize environmental impact caused by the drilling operations. To meet the new stringent regulations, the oil and gas industry is striving to develop new drilling fluids and ancillary additives that meet the present demands in the field of wellbore drilling. Thus, there is a need to develop drilling fluids and additives thereof that have very little or no adverse effects on the environment or on the drilling economics. Yet another drawback of the known water-based drilling fluid systems is that they do not provide a high-performance efficiency comparable to that of the oil-based drilling fluid systems with regard to formation damage, lubricity, wellbore stability and penetration rates.
  • an object of the present invention is to provide a rapid-mix, water-based drilling fluid system for controlling loss circulation.
  • the drilling fluid system of the present invention aims to improve wellbore stability, enhance the rate of penetration, provide effective shale inhibition, control high temperature high pressure (HTHP) filtrate loss, improve lubricity and reduce the risk of stuck pipe.
  • HTHP high temperature high pressure
  • the drilling fluid system of the present invention has an improved rheology profile with no lumps or“fish eyes”, thereby, improving the Low Shear Rate Viscosity (LSRV) and gel strength.
  • LSRV Low Shear Rate Viscosity
  • the drilling fluid system of the present invention inhibits shale or gumbo clays from hydrating and minimizes bit balling. Further, the drilling fluid system of the present invention promotes cuttings encapsulation and minimizes cuttings dispersion.
  • a drilling fluid system for controlling loss circulation having an aqueous base fluid comprising:
  • At least one shale inhibitor including a liquid polyamine present in a concentration in the range of 10 to 30 % by weight;
  • At least one encapsulating agent including a cross-linked, anionic acrylamide polymer present in a concentration in the range of 2 to 6 % by weight;
  • At least one lubricating agent and borehole stabilizer including a high viscosity polymer present in a concentration in the range of 6 to 14 % by weight;
  • At least one filtration control additive including a non-ionic starch derivative in a concentration in the range of 6 to 15 % by weight.
  • the drilling fluid system comprises at least one corrosion inhibitor including a liquid polyamine present in a concentration in the range of 2 to 4 % by weight.
  • the drilling fluid system has a pH in the range of 9.0 to 10.0.
  • the viscosifier is a biopolymer selected from polysaccharides and modified polysaccharides including xanthan gum, guar gum, wellum gums, gellan gums, succinoglycan, succinoglycan polysaccharides, scleroglycan, schleroglucan polysaccharides, polyvinylsaccharides, o- carboxychitosans, polyanionic cellulose, carboxymethylcellulose, hydroxyethylcellulose, hydroxypropylcellulose, natural and modified starches, and combinations thereof.
  • polysaccharides and modified polysaccharides including xanthan gum, guar gum, wellum gums, gellan gums, succinoglycan, succinoglycan polysaccharides, scleroglycan, schleroglucan polysaccharides, polyvinylsaccharides, o- carboxychitosans, polyanionic cellulose, carboxymethylcellulose, hydroxyethylcellulose, hydroxypropyl
  • the viscosifier is clarified xanthan gum.
  • the viscosifier is pre- dispersed in a water-miscible, oil-free and clay-free carrier fluid to obtain a drilling fluid system with improved rheology profile.
  • the at least one encapsulating agent is a cross-linked, anionic acrylamide polymer selected from polyacrylamide, partially hydrolyzed polyacrylamide, acrylamide copolymers, acrylamide terpolymers, acrylamide tetrapolymers, and combinations thereof.
  • the encapsulating agent is a fully cross-linked, anionic, dispersed acrylamide polymer.
  • the acrylamide polymer is more preferably a partially hydrolyzed polyacrylamide (PHPA).
  • the at least one lubricating agent and borehole stabilizer is a high viscosity polymer having viscosity in the range of about 2 to 10 cP.
  • the at least one lubricating agent and borehole stabilizer is a polyanionic cellulose polymer.
  • the lubricating agent and borehole stabilizer is suspended in a non-aromatic, ultra-clean mineral oil.
  • the at least one filtration control additive is a liquid polysaccharides derivative.
  • the filtration control additive is a liquid polyanionic cellulose.
  • the filtration control additive may act synergistically with the viscosifier to enhance the Low Shear Rate Viscosity (LSRV).
  • LSRV Low Shear Rate Viscosity
  • a bridging agent including a salt, preferably sized calcium carbonate, is used in conjunction with the filtration control additive to produce thin, pliable and easily removable filter cakes.
  • the present invention teaches a drilling fluid system, particularly a drilling fluid system for controlling loss circulation.
  • the drilling fluid system according to the present invention is a rapid mix drilling fluid system primarily comprising the following components in an aqueous base fluid: one or more viscosifiers, one or more shale inhibitors/clay hydration suppressants, one or more encapsulating agents, one or more lubricating agents and borehole stabilizers and one or more filtration control additives. Additionally, the drilling fluid system may further comprise corrosion inhibitors.
  • the base fluid may be fresh water, sea water, brine, mixtures of water and water-soluble organic compounds.
  • the drilling fluid system according to the present invention provides superior drilling performance while meeting the environmental regulations.
  • the rapid mix drilling fluid system improves wellbore stability.
  • the system is designed to achieve high performance and thereby reduce the gap between conventional water-based mud and oil-based mud in drilling fluids.
  • the drilling fluid system of the present invention provides effective shale inhibition in water-based drilling fluids for safe, fast and superior performance. Additionally, the rapid mix drilling fluid system affords superior shale stability, improved lubricity, enhanced rate of penetration (ROP) and less risk of stuck pipe.
  • ROP rate of penetration
  • the drilling fluid system comprises one or more viscosifiers in a concentration in the range of about 2 to 10% by weight.
  • the viscosifier is present in a concentration in the range of about 3 to 6 % by weight.
  • the viscosifier includes one or more biopolymers.
  • Suitable biopolymers include, but are not limited to, polysaccharides and modified polysaccharides including xanthan gum, guar gum, wellum gums, gellan gums, succinoglycan, succinoglycan polysaccharides, scleroglycan, schleroglucan polysaccharides, polyvinylsaccharides, o-carboxychitosans, polyanionic cellulose, carboxymethylcellulose, hydroxyethylcellulose, hydroxypropylcellulose, natural and modified starches, and mixtures thereof.
  • the viscosifiers are suitable for water-based drilling fluids from low-solids to highly weighted systems. This includes fresh water, salt, and some heavy brine systems.
  • the viscosifier of the rapid mix drilling fluid system is a high yield, clarified xanthan gum which is pre-dispersed in a water-miscible, oil-free and clay-free carrier fluid.
  • the high molecular-weight biopolymer is the primary economical shear-thinning viscosifier for displacement spacers to provide solids transport, solids suspension, friction reduction and improved displacement efficiency.
  • the water-miscible carrier fluid helps at dispersing the biopolymer and preventing lumps or“fisheyes” so that the polymer rapidly and smoothly viscosities without the need for high shear.
  • the biopolymer As the biopolymer is pre-dispersed in a water-miscible carrier fluid, it provides a unique rheology profile much more readily than dry material. This is especially critical when the proper mixing equipment is not available.
  • the viscosifier produces elevated Low Shear Rate Viscosity (LSRV) and high, but fragile, gel strengths.
  • the drilling fluid system comprises one or more shale inhibitors or clay hydration suppressants in a concentration in the range of about 10 to 30 % by weight.
  • the shale inhibitor includes liquid polyamine.
  • the shale inhibitor is suitable for polymer-based drilling and drill-in fluids.
  • the shale inhibition is achieved by preventing water uptake by clays, and by providing superior cuttings integrity. Further, the shale inhibitor effectively inhibits shale or gumbo clays from hydrating and minimizes the potential for bit balling. It can be added directly to the drilling fluid system with no effect on viscosity or filtration properties.
  • the shale inhibitor of the present invention is a liquid additive that acts as a clay hydration suppressant by intercalating and reducing the space between clay platelets so that water molecules do not penetrate and cause shale swelling.
  • the shale inhibitor provides outstanding shale inhibition and minimizes dilution rates.
  • the shale inhibitor enables a drilling fluid system having a buffered pH in the range of 9.0 - 10.0, thereby eliminating any need for adding caustic soda or potassium hydroxide. Further, the shale inhibitor improves the inhibitive properties and temperature resistance of the drilling fluid. It reduces the clay damage & hydration associate with conventional water-based drilling system.
  • the amine-based shale inhibitor of the present invention is thermally stable & flexible additive.
  • the drilling fluid system comprises one or more encapsulating agents in a concentration in the range of 2 to 6 % by weight.
  • the encapsulating agent is a cross-linked, anionic acrylamide polymer which provides cuttings encapsulation and shale stabilization.
  • the acrylamide polymer also acts as a viscosifier, friction reducer, flocculant and fluid loss controller.
  • Suitable acrylamide polymer may be selected from polyacrylamide (“PA”, i.e., acrylamide homopolymer having substantially less than about 1 % of its acrylamide groups converted to carboxylate groups), partially hydrolyzed polyacrylamide (“PHPA”, i.e., acrylamide homopolymers having more than about 1 %, but not 100%, of its acrylamide groups converted to carboxylate groups), acrylamide copolymers, acrylamide terpolymers containing to acrylamide, a second species and a third species, and acrylamide tetrapolymers containing acrylamide, acrylate, a third species, and a fourth species, and mixtures thereof.
  • PA polyacrylamide
  • PHPA partially hydrolyzed polyacrylamide
  • acrylamide copolymers acrylamide terpolymers containing to acrylamide, a second species and a third species
  • acrylamide tetrapolymers containing acrylamide, acrylate, a third species, and a fourth
  • the encapsulating agent is a fully cross-linked, anionic, dispersed acrylamide polymer that can be used in solids-free drilling fluids to obtain cuttings encapsulation, improve wellbore stability and enhance solids removal by flocculating the undesired solids.
  • reduced-bentonite muds it extends bentonite to increase viscosity, flocculates the drill solids for more efficient removal, encapsulates cuttings and improves wellbore stability.
  • the encapsulating agent can also be used in mud systems using make-up waters from freshwater to saltwater. The agent acts as an excellent cuttings encapsulator to suppress cuttings dispersion.
  • the drilling fluid system comprises one or more lubricating agents and borehole stabilizers in a concentration in the range of 6 to 14 % by weight.
  • the lubricating agent and borehole stabilizer includes at least one high viscosity polymer having a viscosity in the range of about 2 to 10 cP.
  • the high viscosity polymer is preferably suspended in an ultra-clean mineral oil that contains no aromatic.
  • the polymer can be a cellulose, particularly a polyanionic cellulose polymer, which acts as a lubricant and borehole stabilizer. The polymer also reduces fluid loss in the mud system, and produces thin, slick, tough filter cake.
  • the polymer As a suspension in mineral oil, the polymer is more readily dispersible in the mud without formation of“fish eye”, as compared to the polymer in its dry form. Further, the lubricating agent and borehole stabilizer reduces friction and increases the lubricity of the drilling fluid, thereby promoting faster penetration rates while reducing torque and drag. It further inhibits the hydration of drill solids and encapsulates the drill solids for easier removal. It exhibits superior mixing in low shear environments. Additionally, the stability and performance of the polymer is maintained during a freeze and thaw cycle.
  • a preferred embodiment of the drilling fluid system comprises one or more corrosion inhibitors in a concentration in the range of 2 to 4 % by weight.
  • the corrosion inhibitor is a liquid polyamine corrosion inhibitor suitable for use in polymer-based drilling and drill-in fluids, and systems which are sensitive to brines.
  • the corrosion inhibitor assists in increasing the pH in water-based systems.
  • the corrosion inhibitor is compatible with different brine fluids and helps to prevent general corrosion attack on casing, tubing and downhole tools in contact with clear completion brines. It protects both tubular goods and completion tools exposed to work over or clear completion brines.
  • the drilling fluid system of the present invention further comprises a filtration control additive in a concentration in the range of 6 to 14 % by weight.
  • the filtration control additive is a special starch derivative intended for reducing high temperature high pressure (HTHP) filtrate loss for water-based fluids.
  • HTHP high temperature high pressure
  • Suitable filtration control additives may be selected liquid polysaccharide derivatives.
  • the filtration control additive is preferably a liquid polyanionic cellulose.
  • the additive is non-ionic in nature and suitable for fluids containing salts or ion sensitive additives.
  • the additive reduces fluid loss, and further contributes to elevated LSRV compared to conventional fluid-loss additives.
  • the liquid polysaccharides derivative used as the filtration control additive increases the LSRV.
  • the filtration control additive can be used in all water-based fluids including drilling, completion and workover.
  • a bridging agent may be used with the filtration control additive to obtain a thin, pliable and easily removable filter cake.
  • the bridging agent can be a sized salt such as sized calcium carbonate.
  • the filtration control additive acts synergistically with the biopolymer viscosifier to further enhance the Low Shear Rate Viscosity (LSRV).
  • the drilling fluid system is environmentally friendly and readily biodegradable.
  • the high mixing rates result in reduced downtime in event of lost circulation.
  • the drilling fluid system reduces stuck pipe or hole instability and provides better performance than conventional water-based muds.
  • the system is economical in comparison with oil-based mud systems. Further, the system avoids formation damage due to the absence of solids in the system. Therefore, fractured carbonate formations with low permeability could be protected effectively when drilling with the present drilling fluid system.
  • Tables below indicate the characteristics of the components of the drilling fluid system in accordance to the present invention.
  • Table III Physical and chemical characteristics of cross-linked, anionic acrylamide polymer encapsulating agent
  • the drilling fluid/mud formulations were aged, with rolling, for 16 hours at 150° F, and then analyzed using OFITE Extreme pressure and lubricity tester to determine the lubricity coefficient of the drilling fluid, API water loss, etc.
  • the rheological properties of the fluid were determined by FANN Viscometer as described in "Standard Procedure for Testing Drilling Fluids", American Petroleum Institute, API RP 13B. Other properties such as mud weight and pH were also checked. Table 1 below lists sea water mud formulations obtained using the drilling fluid system of present invention:
  • the water-based drilling fluid of formulation 1 was prepared by adding 10 L/m3 of xanthan gum, 12 L/m 3 of liquid polyamine, 3 L/m 3 of PHPA, 10 L/m 3 of PAC, 2.86 L/m 3 of polyamine corrosion inhibitor to 962.14 L/m 3 of sea water.
  • the water-based drilling fluid of formulation 2 was prepared by adding 10 L/m3 of xanthan gum, 12 L/m 3 of liquid polyamine, 5.2 L/m 3 of PHPA, 7.8 L/m 3 of PAC, 2.86 L/m 3 of polyamine corrosion inhibitor to 982.14 L/m 3 of sea water.
  • the water-based drilling fluid of formulation 3 was prepared by adding 10 L/m3 of xanthan gum, 12 L/m 3 of liquid polyamine, 5.2 L/m 3 of PHPA, 7.8 L/m 3 of PAC, 2 L/m 3 of polyamine corrosion inhibitor, 7.2 (80 kg/m3) KCI Brine to 954.94 L/m 3 of sea water.
  • the water-based drilling fluid of formulation 4 was prepared by adding 10 L/m3 of xanthan gum, 12 L/m 3 of liquid polyamine, 5.2 L/m 3 of PHPA, 7.8 L/m 3 of starch derivative, 2.86 L/m 3 of polyamine corrosion inhibitor to 962.14 L/m 3 of sea water.
  • the water-based drilling fluid of formulation 5 was prepared by adding 10 L/m3 of xanthan gum, 30 L/m 3 of liquid polyamine, 5.2 L/m 3 of PHPA, 14 L/m 3 of PAC, 2.86 L/m 3 of polyamine corrosion inhibitor, 14 (80 kg/m3) KCI Brine to 904 L/m 3 of sea water.
  • the water-based drilling fluid of formulation 6 was prepared by adding 10 L/m3 of xanthan gum, 30 L/m 3 of liquid polyamine, 5.2 L/m 3 of PHPA, 12 L/m 3 of starch derivative, 2.86 L/m 3 of polyamine corrosion inhibitor, 14 (80 kg/m3) KCI Brine to 904 L/m 3 of sea water.
  • Table 2 represents performance of rapid mix drilling fluid system in sea water mud formulations 1 , 2 & 3.
  • KCI Potassium chloride Table 3 represents performance of rapid mix drilling fluid system in sea water mud regarding formulations 4, 5 & 6.
  • the performance of a drilling fluid during drilling operations is influenced by its properties including, but not limited to, mud viscosity, density, pH, filtration loss and lubricity coefficient.
  • properties including, but not limited to, mud viscosity, density, pH, filtration loss and lubricity coefficient.
  • the analysis was performed by means of properties including the rheological properties, yield point, gel strength, mud density, fluid loss and lubricity coefficient.
  • the fundamental reason for choosing to study the rheological properties, plastic viscosity, yield point and gel strength, as well as the filtration properties, fluid loss and lubricity coefficient, is the relevance these properties offer to the overall drilling mud performance.
  • Filtration rate is often the most important property of a drilling fluid, particularly when drilling permeable formations where the hydrostatic pressure exceeds the formation pressure. Proper control of filtration can prevent or minimize wall sticking and drag and improve borehole stability.
  • the PHPA-L concentration was increased from 3 (formulation 1 ) to 5.2 (L/m 3 ) and the concentration of PAC L was reduced from 10 (formulation 1 ) to 7.8 (L/m 3 ).
  • the mud formulation 1 compared to the formulation 2 provided better rheological profiles and less fluid loss in both before and after hot rolled mud.
  • the mud formulation 3 with 7.2 (L/m 3 ) of KCI brine also improved the rheological profiles in both before and after hot rolled mud. It was observed that the API fluid loss was higher in after hot rolled mud.
  • PAC L was replaced with Starch L at concentration 7.8 to 12 (L/m 3 ), respectively.
  • the rheological profiles were drastically reduced, and the API fluid loss was higher in before and after hot rolled mud.
  • the formulation 6 provided better rheological profiles and API fluid loss were controlled.
  • the PAC L concentration was increased to 14 (L/m 3 ) with 14 (L/m 3 ) of KCI brine.
  • the formulation 5 provided the highest rheological profiles with effectively controlled API fluid loss in before and after hot rolled.
  • the formulation 5 provided the best performance in rheological properties, plastic viscosity, yield point, and gel strength, as well as API fluid loss and lubricity coefficient.

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Abstract

L'invention concerne un système de fluide de forage pour réguler la perte de circulation. Le système de fluide de forage comprend un fluide de base aqueux comprenant au moins un agent de viscosité comprenant un biopolymère, au moins un inhibiteur de schiste comprenant une polyamine liquide, au moins un agent d'encapsulation comprenant un polymère d'acrylamide anionique réticulé, au moins un agent lubrifiant et un agent stabilisant de trou de forage comprenant un polymère à viscosité élevée, et au moins un additif de régulation de filtration comprenant un dérivé d'amidon non ionique. Le système de fluide de forage améliore la stabilité du puits de forage, améliore le taux de pénétration, assure une inhibition efficace du schiste, régule la perte de filtrat haute pression à haute température (HTHP), améliore le pouvoir lubrifiant et réduit le risque de tuyau coincé.
PCT/IB2019/052030 2018-03-14 2019-03-13 Système de fluide de forage pour réguler la perte de circulation WO2019175792A1 (fr)

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CN111484653A (zh) * 2020-05-11 2020-08-04 中国石油大学(北京) 一种用于欠平衡钻井中的黄原胶复合凝胶以及制备方法和应用
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CN110734746A (zh) * 2019-12-20 2020-01-31 东营泰尔石油技术有限公司 一种防漏堵漏提黏剂
CN111484653A (zh) * 2020-05-11 2020-08-04 中国石油大学(北京) 一种用于欠平衡钻井中的黄原胶复合凝胶以及制备方法和应用
CN111484653B (zh) * 2020-05-11 2021-06-29 中国石油大学(北京) 一种用于欠平衡钻井中的黄原胶复合凝胶以及制备方法和应用
CN112300764A (zh) * 2020-09-24 2021-02-02 中石化石油工程技术服务有限公司 一种针对水敏地层安全钻井的泡沫配方及制备方法
GB2599674A (en) * 2020-10-08 2022-04-13 Clear Solutions Holdings Ltd Drilling fluid additive
CN112375550A (zh) * 2020-12-02 2021-02-19 中联煤层气有限责任公司 一种上部地层防塌型钻井液及其制备方法
CN112375550B (zh) * 2020-12-02 2022-06-03 中联煤层气有限责任公司 一种上部地层防塌型钻井液及其制备方法
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CN115746311A (zh) * 2021-09-03 2023-03-07 中国石油天然气集团有限公司 一种环保型钻井液提切剂及其制备方法
CN115746311B (zh) * 2021-09-03 2024-02-06 中国石油天然气集团有限公司 一种环保型钻井液提切剂及其制备方法

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