CN110951468A - Ocean high-temperature high-pressure water-based drilling fluid - Google Patents
Ocean high-temperature high-pressure water-based drilling fluid Download PDFInfo
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Abstract
The invention discloses an ocean high-temperature and high-pressure water-based drilling fluid which comprises the following components in percentage by weight: 2.5% of bentonite slurry, 0.6% of polyanionic cellulose, 2% of sulfonated asphalt, 2-3% of sulfonated resin, 3-4% of sulfonated polyfurnace, 2% of high temperature resistant polymer, 1-2% of high temperature resistant diluent, 0.5-0.9% of caustic soda, 7.5-8.2% of barite, 10% of potassium formate, 1.5% of lubricant and the balance of water, wherein the pH value of the drilling fluid is 10-11, the total filtration loss is less than 8mL/30min under the conditions of 150 ℃ and 100MPa, and the filtration loss after 15min is less than 0.7 mL/min. The water-based drilling fluid disclosed by the invention has lower high-temperature high-pressure filtration loss, the formed filter cake is thin and tough, the rheological property is good, the reservoir protection effect is good, the drilling difficulty and the underground accident pre-control in the drilling process can be better solved, and the water-based drilling fluid has certain reference significance and popularization value for subsequent similar well operation.
Description
Technical Field
The invention belongs to the technical field of offshore oil drilling, and particularly relates to an ocean high-temperature and high-pressure water-based drilling fluid.
Background
The Yingqiong block located in the west of the south China sea is one of three global high-temperature and high-pressure oil and gas resource deposit areas, and the formation pressure coefficient is as high as 2.40g/cm3The safe operation density window is small 0.08g/cm3The underground maximum temperature reaches 246 ℃, and the maximum drilling fluid density is 2.8g/cm3. In a drilled high-temperature high-pressure well, the rheological property of the drilling fluid is easily damaged at high temperature, so that the underground well wall is easy to collapse, and complex problems of underground malignant leakage, drilling tool jamming and the like are caused. Meanwhile, under complex conditions of high temperature and high pressure, the problems of cable logging, reservoir protection and the like become more severe.
Disclosure of Invention
Aiming at the problems in the prior art, the invention provides the ocean high-temperature high-pressure water-based drilling fluid which has good high-temperature resistance and rheological property, lower high-temperature high-pressure filtration loss, excellent filter cake quality and good reservoir protection effect, and can solve the problems of difficult control of the rheological property of drilling fluid, severe underground leakage, out-of-control reservoir protection and drill sticking under the conditions of high temperature and high pressure.
In order to achieve the purpose, the invention adopts the following technical scheme:
the invention provides an ocean high-temperature high-pressure water-based drilling fluid which comprises the following components in percentage by weight: 2.5% of bentonite slurry, 0.6% of polyanionic cellulose, 2% of sulfonated asphalt, 2-3% of sulfonated resin, 3-4% of sulfonated polyfurnace, 2% of high temperature resistant polymer, 1-2% of high temperature resistant diluent, 0.5-0.9% of caustic soda, 7.5-8.2% of barite, 10% of potassium formate, 1.5% of lubricant and the balance of water, wherein the pH value of the drilling fluid is 10-11, the total filtration loss is less than 8mL/30min under the conditions of 150 ℃ and 100MPa, and the filtration loss after 15min is less than 0.7 mL/min.
As a preferable technical scheme, the polyanionic cellulose is low-viscosity polyanionic cellulose PF-PAC-LV.
Preferably, the lubricant is a lubricating pellet, an oil lubricant or graphite.
As a preferable technical scheme, the density of the barite is 4.5g/cm3。
As a preferred technical scheme, the high-temperature resistant polymer is a polymer of AA, AM and AMPS.
As a preferred technical scheme, the high-temperature resistant diluent is sulfonated styrene maleic anhydride copolymer.
The marine high-temperature and high-pressure water-based drilling fluid system disclosed by the invention is composed of a sulfonated material, a high-temperature resistant polymer, an inhibitory salt, a weighting agent and a high-temperature resistant diluent, and has good capability of inhibiting hydration and dispersion of clay minerals, strong high-temperature rheological property, excellent lubricity and rock debris suspension capability. In the aspect of reservoir protection effect, the invasion of drilling fluid and filtrate needs to be reduced, and the coring quality during cable logging coring operation is ensured.
The screening process of the components of the marine high-temperature high-pressure water-based drilling fluid comprises the following steps:
(1) selecting a basic formula: 2.5 percent of bentonite slurry, 0.6 percent of polyanionic cellulose, 2 percent of sulfonated asphalt, 2 to 3 percent of sulfonated resin, 3 to 4 percent of sulfonated polycoal, 2 percent of high temperature resistant polymer, 1 to 2 percent of high temperature resistant diluent, 0.5 to 0.9 percent of caustic soda and 7.5 to 8.2 percent of barite (4.5 g/cm)3) And the balance being water.
In the basic formula, the polyanionic cellulose is low-viscosity polyanionic cellulose PF-PAC-LV of Macoba (magcobar), the sulfonated asphalt is PF-GBL of the Macoba (magcobar), the sulfonated resin is PF-SHP of the Macoba (magcobar), the sulfonated polyfurnace is PF-SKCH of the Macoba (magcobar), the high-temperature resistant polymer is SL-HT-FL and is a polymer of AA, AM and AMPS, and the high-temperature resistant diluent Drillidillute is sulfonated styrene maleic anhydride copolymer. The properties of the base formulation drilling fluids at different densities are shown in Table 1
TABLE 1 basic formulation drilling fluid Performance at different densities
The experimental conditions were: the temperature is 240 ℃, and the aging time is 16 h.
(2) The inhibitor is preferably
The activity value of the salt solution in a saturated state is tested by an adsorption isothermal method, and the experimental result is shown in table 2
TABLE 2 Activity values of salt solutions in saturated state
The results show that the activity value of potassium formate is the lowest and is suitable for addition to drilling fluids as an inhibitor.
Stratum detritus of an oriole-qiong basin is selected in a laboratory to carry out mud shale expansion and detritus rolling recovery rate experiments, inhibitors are preferably selected and evaluated, equal amounts of sodium chloride and potassium formate are added into a basic formula, the measured linear expansion rate of a drilling fluid sample for 16h is shown in table 3, and the results of the experiments in table 2 show that potassium formate as the inhibitor of the drilling fluid can effectively reduce the activity of solution water and has an excellent effect of inhibiting mud shale hydration.
TABLE 3 evaluation of inhibition Properties
(3) The lubricant is preferably
The results of the coefficient of lubricity tests of the drilling fluid system, which were performed after adding different types of lubricants to the base formulation, are shown in table 4, wherein the lubricant pellets were selected from PF-BLAB of macmba (magcobar), the oil lubricant was selected from PF-LUBE of macmba (magcobar), and the graphite was selected from GRA of macmba (magcobar). Experimental results show that the lubricants can meet the requirement on lubricity under the working conditions of high temperature and high pressure, and can be used in a matched manner in the drilling process to achieve the best effect.
Table 4 drilling fluid lubricity test results
(4) Evaluation of high temperature Polymer and high temperature Diluent resistance
The drilling fluid uses high temperature resistant polymer and high temperature resistant diluent to effectively inhibit and reduce the high temperature dispersion of bentonite particles, and the content of the bentonite in the drilling fluid is controlled to be below 3 percent, so that the novel high temperature and high pressure water-based drilling fluid only undergoes high temperature thickening and is not gelled. A water-based drilling fluid A having a density of 2.5g/cm3 and a water-based drilling fluid B having a density of 2.3g/cm3 were evaluated. The drilling fluid A adopts a basic formula, the drilling fluid B removes the high-temperature resistant polymer SL-HT-FL on the basis of the basic formula, and the evaluation result is shown in Table 5.
TABLE 5 evaluation of the stability of Water-based drilling fluids A and B
Remarking: the experimental conditions of hot rolling of the formula A are 248 ℃ and 16 hours, and the experimental conditions of static aging are 248 ℃ and standing for 7 days. The experimental conditions of hot rolling of the formula B are 180 ℃ and 16h, and the experimental conditions of aging are 180 ℃ and standing for 7 d. A. Indoor evaluation of the formula B shows that no barite precipitate exists.
As can be seen from Table 5, the density was 2.50/cm3The performance change of the water-based drilling fluid A is relatively small at 240 ℃; and a density of 2.30g/cm3The performance of the water-based drilling fluid B at 180 ℃ is relatively greatly changed. Experimental results show that the stability of the drilling fluid under the high-temperature working condition can be obviously improved by adding 2% of high-temperature resistant polymer.
(5) Evaluation of plugging Properties
And (4) evaluating the plugging performance of the drilling fluid prepared by the basic formula. The sulfonated asphalt can well block sandstone pores and prevent drilling fluid filtrate from excessively invading the stratum. And (3) performing a leakage test by using a high-temperature high-pressure fluid loss instrument with openings at two ends, and performing the leakage test under the test conditions of the pressure of 10MPa and the temperature of 150 ℃ to evaluate the plugging performance. As can be seen from the statistics of the filtration rate (see figure 1), the total filtration loss is less than 8mL/30min, and the filtration rate of the drilling fluid system is nearly gentle after 15min and less than 0.7mL/min, which shows that effective plugging is formed on the end face of the rock core, so that the filtrate and solid phase can be prevented from entering the rock core, and a good plugging pressure-bearing effect is achieved.
(8) Evaluation of anti-debris contamination capability
On the basis of a basic formula, 10% by mass of potassium formate is added to evaluate the anti-debris pollution capacity of the rock debris composite material, and the potassium formate is added to serve as an inhibitor, so that the inhibition is determined by the low water activity and the mechanism of ion embedding and double electric layer compression. The strong inhibitive property makes the rock debris which pollutes the drilling fluid become inert, and has no great adverse effect on the performance. The debris of the oriole-qiong blocks are selected to be dried and then subjected to an anti-pollution experiment, and the experimental results are shown in table 6. The experimental result analysis can find that the drilling fluid system has good anti-debris pollution capacity, and the system still maintains stable rheological property after 10% of debris is added, so that the operation requirement of complex working conditions in the well is met.
TABLE 6 results of anti-debris contamination experiments
(9) Reservoir protection evaluation
And selecting a rock core of the oriole-qiong block to perform a permeability recovery value experiment, wherein the experimental result is shown in table 7, and the permeability recovery value is more than 90% as can be seen from table 7, which shows that the high-temperature high-pressure drilling fluid system has a good reservoir evaluation effect. The sulfonated asphalt and the potassium formate are added into the drilling fluid, so that the plugging and inhibiting performance under high temperature and high pressure can be improved. The high-temperature resistant polymer is added to control the high-temperature and high-pressure filtration loss, so that a large amount of drilling fluid filtrate is prevented from entering the pore throat of the reservoir, and the filtrate is prevented from causing physical and chemical reactions of reservoir sensitive minerals to damage the reservoir. The barite is selected, so that the content of bentonite in the drilling fluid can be controlled, a high-quality filter cake is formed, and the phenomenon that solid-phase particles of the drilling fluid enter a reservoir stratum to block a throat is reduced.
TABLE 7 reservoir protection evaluation results
(10) Evaluation of sedimentation stability
The high temperature and high temperature can be controlled by adding the high temperature resistant polymer in the drilling processThe pressure loss is in the design range, the drilling fluid is firstly prepared into glue solution, and then the high temperature resistant polymer is slowly and uniformly supplemented to the circulating system. The concentration of the high-temperature resistant material is increased along with the increase of the well temperature and the density, so that the drilling fluid is kept to have good sedimentation stability at high temperature and high density. Evaluating the sedimentation stability of a high-temperature and high-pressure drilling fluid system by using a static sedimentation method, wherein the sedimentation factor S of the drilling fluid systemfThe calculation was carried out using the formula (1), and the results are shown in Table 8. As can be seen from table 8, the settling factor of the drilling fluid system was maintained at 0.51, indicating that the system had good settling stability.
Sf＝ρbottom/(ρbottom+ρtop)
In the formula: sf-a sedimentation factor;
ρbottomdrilling fluid density at lower part after hot rolling, g/cm3；
ρtopUpper drilling fluid density after hot rolling, g/cm3。
TABLE 8 evaluation results of sedimentation stability
(11) Stability contrast experiment under high temperature conditions
X1, X2, X3 are three high temperature and high pressure wells drilled in the Oringa-Jongqin block. The formation pressure coefficients of X1, X2 and X3 are respectively 2.22, 2.21 and 2.37, and the formation temperatures are respectively 190 ℃, 210 ℃ and 220 ℃. The water-based drilling fluid with the basic formula of the X1 well is prepared by adding 10 mass percent of potassium formate into X2 and X3 on the basis of the basic formula, and the stability under the high-temperature working condition of field measurement and indoor evaluation is shown in Table 9. It can be seen from table 9 that the drilling fluid with potassium formate added has relatively small performance change and better stability under high temperature working conditions in the drilling process and indoor high temperature aging experiments.
TABLE 9 stability of water-based drilling fluids at high temperature
(12) Drilling fluid friction resistance data comparison
The lubricating globule, the oily lubricant and the graphite are good lubricants and can be adsorbed on the surface of metal or clay to form a lubricating film. The drilling fluid is matched with the lubricants, and the solid content is kept low, so that the friction coefficient is effectively reduced. 1.5 percent of lubricating pellets are added into the drilling fluid of the basic formula, and the drilling fluid friction resistance data of X1, X2 and X3 wells in the drilling process are shown in a table 10.
As can be seen from Table 10, the novel high-temperature high-pressure water-based drilling fluid has a friction resistance equivalent density of about 0.05-0.08g/cm in a slim hole of phi 149.22mm3(ii) a Compared with the conventional polysulfonate high-temperature and high-pressure water-based drilling fluid, the novel high-temperature and high-pressure water-based drilling fluid has the friction resistance equivalent density of 0.05-0.06g/cm lower in a phi 212.73mm well hole3Therefore, the water-based drilling fluid added with the lubricant has better rheological property and is more suitable for being applied to complex stratum with narrow density window.
TABLE 10 drilling fluid friction resistance data comparison table
From the above experiments, it can be seen that: by adding the potassium formate, the performance of the drilling fluid for inhibiting clay hydration expansion can be guaranteed, the viscosity of a liquid phase is controlled, and the invasion depth of filtrate is reduced. The high-temperature and high-pressure filtration loss of the drilling fluid is controlled to be less than 8mL/30min by adding the high-temperature resistant polymer and the sulfonated asphalt, and a high-quality mud cake is formed. The lubricity of the drilling fluid is improved by adding a lubricant. The high-temperature resistant diluent is used for adjusting the flow pattern of the drilling fluid and maintaining the rheological property of the drilling fluid; in order to prevent gelation under high-temperature working conditions and maintain a performance adjustment window for subsequent weight, the viscosity of the drilling fluid is as low as possible on the premise of ensuring the suspension of barite. The pH value of the drilling fluid is ensured to be 10-11 by adding caustic soda, and the acid gas pollution resistance of the drilling fluid can be improved by adding certain lime.
According to the invention, potassium formate is introduced as an inhibitor, a sulfonated and high-temperature resistant polymer drilling fluid material is preferably selected, barite is used as a weighting agent, a set of high-temperature and high-pressure water-based drilling fluid system is constructed, the density can reach 2.6g/cm3 at most, the high temperature resistance reaches 246 ℃, indoor research experiments show that the water-based drilling fluid has low high-temperature and high-pressure filtration loss, the formed filter cake is thin and tough, the rheological property is good, the reservoir protection effect is good, the difficult problem of drilling and the underground accident pre-control under high temperature and high pressure can be better solved in the drilling process, and certain reference significance and popularization value are provided for subsequent similar well operation.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly described below, it is obvious that the drawings in the following description are only some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to the drawings without creative efforts.
FIG. 1 is a statistical plot of the fluid loss rate of a base formulation drilling fluid of the present invention.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be obtained by a person skilled in the art without inventive effort based on the embodiments of the present invention, are within the scope of the present invention.
The embodiment provides an ocean high-temperature and high-pressure water-based drilling fluid which comprises the following components in percentage by weight: 2.5% of bentonite slurry, 0.6% of polyanionic cellulose, 2% of sulfonated asphalt, 2-3% of sulfonated resin, 3-4% of sulfonated polyfurnace, 2% of high temperature resistant polymer, 1-2% of high temperature resistant diluent, 0.5-0.9% of caustic soda, 7.5-8.2% of barite, 10% of potassium formate, 1.5% of lubricant and the balance of water, wherein the pH value of the drilling fluid is 10-11, the total filtration loss is less than 8mL/30min under the conditions of 150 ℃ and 100MPa, and the filtration loss after 15min is less than 0.7 mL/min. Among them, the preferable addition amount of the sulfonated resin is 2%, the preferable addition amount of the sulfonated polyfurnine is 3%, the preferable addition amount of the barite is 8%, the preferable addition amount of the high temperature resistant diluent is 0.8%, and the preferable addition amount of the caustic soda is 0.7%. In the tests described below, the preferred amounts of addition of the components were selected without further explanation.
Wherein the polyanionic cellulose is low viscosity polyanionic cellulose PF-PAC-LV.
Wherein the lubricant is a lubricating pellet, an oil lubricant or graphite.
Wherein the density of the barite is 4.5g/cm3。
Wherein the high temperature resistant polymer is a polymer of AA, AM and AMPS.
Wherein the high-temperature resistant diluent is sulfonated styrene maleic anhydride copolymer.
The marine high-temperature and high-pressure water-based drilling fluid system comprises a sulfonated material, a high-temperature resistant polymer, an inhibiting salt, a weighting agent and a high-temperature resistant diluent, and has good capability of inhibiting hydration and dispersion of clay minerals, strong high-temperature rheological property, excellent lubricity and rock debris suspension capability. In the aspect of reservoir protection effect, the invasion of drilling fluid and filtrate needs to be reduced, and the coring quality during cable logging coring operation is ensured.
The component screening process of the marine high-temperature high-pressure water-based drilling fluid comprises the following steps:
(1) selecting a basic formula: 2.5 percent of bentonite slurry, 0.6 percent of polyanionic cellulose, 2 percent of sulfonated asphalt, 2 to 3 percent of sulfonated resin, 3 to 4 percent of sulfonated polycoal, 2 percent of high temperature resistant polymer, 1 to 2 percent of high temperature resistant diluent, 0.5 to 0.9 percent of caustic soda and 7.5 to 8.2 percent of barite (4.5 g/cm)3) And the balance being water.
In the basic formula, the polyanionic cellulose is low-viscosity polyanionic cellulose PF-PAC-LV of Macoba (magcobar), the sulfonated asphalt is PF-GBL of the Macoba (magcobar), the sulfonated resin is PF-SHP of the Macoba (magcobar), the sulfonated polyfurnace is PF-SKCH of the Macoba (magcobar), the high-temperature resistant polymer is SL-HT-FL and is a polymer of AA, AM and AMPS, and the high-temperature resistant diluent Drillidillute is sulfonated styrene maleic anhydride copolymer. The properties of the base formulation drilling fluids at different densities are shown in Table 1
TABLE 1 basic formulation drilling fluid Performance at different densities
The experimental conditions were: the temperature is 240 ℃, and the aging time is 16 h.
(2) The inhibitor is preferably
The activity value of the salt solution in a saturated state is tested by an adsorption isothermal method, and the experimental result is shown in table 2
TABLE 2 Activity values of salt solutions in saturated state
The results show that the activity value of potassium formate is the lowest and is suitable for addition to drilling fluids as an inhibitor.
Stratum detritus of an oriole-qiong basin is selected in a laboratory to carry out mud shale expansion and detritus rolling recovery rate experiments, inhibitors are preferably selected and evaluated, equal amounts of sodium chloride and potassium formate are added into a basic formula, the measured linear expansion rate of a drilling fluid sample for 16h is shown in table 3, and the results of the experiments in table 2 show that potassium formate as the inhibitor of the drilling fluid can effectively reduce the activity of solution water and has an excellent effect of inhibiting mud shale hydration.
TABLE 3 evaluation of inhibition Properties
(3) The lubricant is preferably
The results of the coefficient of lubricity tests of the drilling fluid system, which were performed after adding different types of lubricants to the base formulation, are shown in table 4, wherein the lubricant pellets were selected from PF-BLAB of macmba (magcobar), the oil lubricant was selected from PF-LUBE of macmba (magcobar), and the graphite was selected from GRA of macmba (magcobar). Experimental results show that the lubricants can meet the requirement on lubricity under the working conditions of high temperature and high pressure, and can be used in a matched manner in the drilling process to achieve the best effect.
Table 4 drilling fluid lubricity test results
(4) Evaluation of high temperature Polymer and high temperature Diluent resistance
The drilling fluid uses high temperature resistant polymer and high temperature resistant diluent to effectively inhibit and reduce the high temperature dispersion of bentonite particles, and the content of the bentonite in the drilling fluid is controlled to be below 3 percent, so that the novel high temperature and high pressure water-based drilling fluid only undergoes high temperature thickening and is not gelled. A water-based drilling fluid A having a density of 2.5g/cm3 and a water-based drilling fluid B having a density of 2.3g/cm3 were evaluated. The drilling fluid A adopts a basic formula, the drilling fluid B removes the high-temperature resistant polymer SL-HT-FL on the basis of the basic formula, and the evaluation result is shown in Table 5.
TABLE 5 evaluation of the stability of Water-based drilling fluids A and B
Remarking: the experimental conditions of hot rolling of the formula A are 248 ℃ and 16 hours, and the experimental conditions of static aging are 248 ℃ and standing for 7 days. The experimental conditions of hot rolling of the formula B are 180 ℃ and 16h, and the experimental conditions of aging are 180 ℃ and standing for 7 d. A. Indoor evaluation of the formula B shows that no barite precipitate exists.
As can be seen from Table 5, the density was 2.50/cm3The performance change of the water-based drilling fluid A is relatively small at 240 ℃; and a density of 2.30g/cm3The performance of the water-based drilling fluid B at 180 ℃ is relatively greatly changed. Experimental results show that the stability of the drilling fluid under the high-temperature working condition can be obviously improved by adding 2% of high-temperature resistant polymer.
(5) Evaluation of plugging Properties
And (4) evaluating the plugging performance of the drilling fluid prepared by the basic formula. The sulfonated asphalt can well block sandstone pores and prevent drilling fluid filtrate from excessively invading the stratum. And (3) performing a leakage test by using a high-temperature high-pressure fluid loss instrument with openings at two ends, and performing the leakage test under the test conditions of the pressure of 10MPa and the temperature of 150 ℃ to evaluate the plugging performance. As can be seen from the statistics of the filtration rate (see figure 1), the total filtration loss is less than 8mL/30min, and the filtration rate of the drilling fluid system is nearly gentle after 15min and less than 0.7mL/min, which shows that effective plugging is formed on the end face of the rock core, so that the filtrate and solid phase can be prevented from entering the rock core, and a good plugging pressure-bearing effect is achieved.
(8) Evaluation of anti-debris contamination capability
On the basis of a basic formula, 10% by mass of potassium formate is added to evaluate the anti-debris pollution capacity of the rock debris composite material, and the potassium formate is added to serve as an inhibitor, so that the inhibition is determined by the low water activity and the mechanism of ion embedding and double electric layer compression. The strong inhibitive property makes the rock debris which pollutes the drilling fluid become inert, and has no great adverse effect on the performance. The debris of the oriole-qiong blocks are selected to be dried and then subjected to an anti-pollution experiment, and the experimental results are shown in table 6. The experimental result analysis can find that the drilling fluid system has good anti-debris pollution capacity, and the system still maintains stable rheological property after 10% of debris is added, so that the operation requirement of complex working conditions in the well is met.
TABLE 6 results of anti-debris contamination experiments
(9) Reservoir protection evaluation
And selecting a rock core of the oriole-qiong block to perform a permeability recovery value experiment, wherein the experimental result is shown in table 7, and the permeability recovery value is more than 90% as can be seen from table 7, which shows that the high-temperature high-pressure drilling fluid system has a good reservoir evaluation effect. The sulfonated asphalt and the potassium formate are added into the drilling fluid, so that the plugging and inhibiting performance under high temperature and high pressure can be improved. The high-temperature resistant polymer is added to control the high-temperature and high-pressure filtration loss, so that a large amount of drilling fluid filtrate is prevented from entering the pore throat of the reservoir, and the filtrate is prevented from causing physical and chemical reactions of reservoir sensitive minerals to damage the reservoir. The barite is selected, so that the content of bentonite in the drilling fluid can be controlled, a high-quality filter cake is formed, and the phenomenon that solid-phase particles of the drilling fluid enter a reservoir stratum to block a throat is reduced.
TABLE 7 reservoir protection evaluation results
(10) Evaluation of sedimentation stability
The high-temperature resistant polymer is added in the drilling process, so that the high-temperature and high-pressure water loss can be controlled within a design range, the drilling fluid is firstly prepared into a glue solution, and then the high-temperature resistant polymer is slowly and uniformly supplemented to a circulating system. The concentration of the high-temperature resistant material is increased along with the increase of the well temperature and the density, so that the drilling fluid is kept to have good sedimentation stability at high temperature and high density. Evaluating the sedimentation stability of a high-temperature and high-pressure drilling fluid system by using a static sedimentation method, wherein the sedimentation factor S of the drilling fluid systemfThe calculation was carried out using the formula (1), and the results are shown in Table 8. As can be seen from table 8, the settling factor of the drilling fluid system was maintained at 0.51, indicating that the system had good settling stability.
Sf＝ρbottom/(ρbottom+ρtop)
In the formula: sf-a sedimentation factor;
ρbottomdrilling fluid density at lower part after hot rolling, g/cm3；
ρtopUpper drilling fluid density after hot rolling, g/cm3。
TABLE 8 evaluation results of sedimentation stability
(11) Stability contrast experiment under high temperature conditions
X1, X2, X3 are three high temperature and high pressure wells drilled in the Oringa-Jongqin block. The formation pressure coefficients of X1, X2 and X3 are respectively 2.22, 2.21 and 2.37, and the formation temperatures are respectively 190 ℃, 210 ℃ and 220 ℃. The water-based drilling fluid with the basic formula of the X1 well is prepared by adding 10 mass percent of potassium formate into X2 and X3 on the basis of the basic formula, and the stability under the high-temperature working condition of field measurement and indoor evaluation is shown in Table 9. It can be seen from table 9 that the drilling fluid with potassium formate added has relatively small performance change and better stability under high temperature working conditions in the drilling process and indoor high temperature aging experiments.
TABLE 9 stability of water-based drilling fluids at high temperature
(12) Drilling fluid friction resistance data comparison
The lubricating globule, the oily lubricant and the graphite are good lubricants and can be adsorbed on the surface of metal or clay to form a lubricating film. The drilling fluid is matched with the lubricants, and the solid content is kept low, so that the friction coefficient is effectively reduced. 1.5 percent of lubricating pellets are added into the drilling fluid of the basic formula, and the drilling fluid friction resistance data of X1, X2 and X3 wells in the drilling process are shown in a table 10.
As can be seen from Table 10, the novel high-temperature high-pressure water-based drilling fluid has a friction resistance equivalent density of about 0.05-0.08g/cm in a slim hole of phi 149.22mm3(ii) a Compared with the conventional polysulfonate high-temperature and high-pressure water-based drilling fluid, the novel high-temperature and high-pressure water-based drilling fluid has the friction resistance equivalent density of 0.05-0.06g/cm lower in a phi 212.73mm well hole3Therefore, the water-based drilling fluid added with the lubricant has better rheological property and is more suitable for being applied to complex stratum with narrow density window.
TABLE 10 drilling fluid friction resistance data comparison table
From the above experiments, it can be seen that: by adding the potassium formate, the performance of the drilling fluid for inhibiting clay hydration expansion can be guaranteed, the viscosity of a liquid phase is controlled, and the invasion depth of filtrate is reduced. The high-temperature and high-pressure filtration loss of the drilling fluid is controlled to be less than 8mL/30min by adding the high-temperature resistant polymer and the sulfonated asphalt, and a high-quality mud cake is formed. The lubricity of the drilling fluid is improved by adding a lubricant. The high-temperature resistant diluent is used for adjusting the flow pattern of the drilling fluid and maintaining the rheological property of the drilling fluid; in order to prevent gelation under high-temperature working conditions and maintain a performance adjustment window for subsequent weight, the viscosity of the drilling fluid is as low as possible on the premise of ensuring the suspension of barite. The pH value of the drilling fluid is ensured to be 10-11 by adding caustic soda, and the acid gas pollution resistance of the drilling fluid can be improved by adding certain lime.
Although the present embodiment has been described in detail with respect to the above-mentioned embodiments, it should be understood by those skilled in the art that modifications or improvements based on the disclosure of the present embodiment can be made without departing from the spirit and scope of the present embodiment, and these modifications and improvements are within the spirit and scope of the present embodiment.
Claims (6)
1. The marine high-temperature and high-pressure water-based drilling fluid is characterized by comprising the following components in percentage by weight: 2.5% of bentonite slurry, 0.6% of polyanionic cellulose, 2% of sulfonated asphalt, 2-3% of sulfonated resin, 3-4% of sulfonated polyfurnace, 2% of high temperature resistant polymer, 1-2% of high temperature resistant diluent, 0.5-0.9% of caustic soda, 7.5-8.2% of barite, 10% of potassium formate, 1.5% of lubricant and the balance of water, wherein the pH value of the drilling fluid is 10-11, the total filtration loss is less than 8mL/30min under the conditions of 150 ℃ and 100MPa, and the filtration loss after 15min is less than 0.7 mL/min.
2. The marine high temperature and high pressure water based drilling fluid of claim 1, wherein the polyanionic cellulose is low viscosity polyanionic cellulose PF-PAC-LV.
3. The marine high temperature and high pressure water based drilling fluid of claim 1, wherein the lubricant is a lubricant pellet, an oil lubricant or graphite.
4. The marine high temperature and high pressure water based drilling fluid of claim 1, wherein the barite has a density of 4.5g/cm3。
5. The marine high temperature and high pressure water based drilling fluid of claim 1, wherein the high temperature resistant polymer is a polymer of AA, AM and AMPS.
6. The marine high temperature and high pressure water-based drilling fluid of claim 1, wherein the high temperature resistant diluent is a sulfonated styrene maleic anhydride copolymer.
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