CN117027745B - Method for strengthening thickened oil thermal recovery by using non-condensate gas composite aquathermolysis catalyst - Google Patents
Method for strengthening thickened oil thermal recovery by using non-condensate gas composite aquathermolysis catalyst Download PDFInfo
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/2406—Steam assisted gravity drainage [SAGD]
- E21B43/2408—SAGD in combination with other methods
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Catalysts (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
The invention relates to the technical field of thickened oil exploitation, in particular to a method for reinforcing thickened oil thermal exploitation by using a non-condensate gas composite aquathermolysis catalyst. The non-condensate gas inhibits steam condensation, can improve steam flow capacity and heat utilization rate, expands the heat action range of steam, and creates better heavy oil aquathermolysis reaction conditions for the catalyst. When the displacement liquid is injected, the precursor solution is pushed first, after the steam and the non-condensate gas are injected, the precursor is decomposed into the catalyst, and the drainage and carrying functions of the gas effectively improve the migration distance of the catalyst and the contact efficiency between the catalyst and the thick oil, so that the quality of the thick oil modification is improved.
Description
Technical Field
The invention relates to the technical field of thickened oil exploitation, in particular to a method for strengthening thickened oil thermal exploitation by using a non-condensate gas composite aquathermolysis catalyst.
Background
The thick oil has abundant reserves worldwide and wide distribution, is an important oil and gas resource, and has the global asphalt and thick oil resource quantity of 9380 multiplied by 10 according to statistics 8 t. With the increasingly outstanding contradiction between oil and gas supply and demand, the exploitation ratio of thick oil will be gradually increased, and the method has wide development prospect. The thick oil has extremely high molecular weight, the viscosity is generally more than 100 mPa.s, the thick oil is difficult to flow in a stratum, and the development difficulty is huge. Because the viscosity of the heavy oil has extremely strong sensitivity to temperature, the heavy oil reservoir is developed by adopting thermal modes such as steam huff and puff, SAGD, steam flooding, in-situ combustion and the like. The steam injection development process has obvious advantages in the initial exploitation of thick oil, but has poor long-term enhanced recovery effect in the development process; serious heat loss of steam and energyThe consumption is high; poor quality after exploitation, high post-processing cost and the like.
The thermal recovery and the hydrothermal cracking technology are combined, and the in-situ modification of the thick oil in the oil layer by utilizing heat energy is a research hot spot in the field of thick oil exploitation at present, and the working principle is as follows: the cracking catalyst injected into stratum catalyzes the cracking of C-S, C-N, C-H bonds and other heavy components in thick oil under the action of steam heat, can irreversibly reduce the viscosity of thick oil, and improves the mobility of crude oil in pores and the quality of produced oil. The technology not only ensures sustainable development of the thickened oil, but also reduces the processing cost of the thickened oil in the later stage. Chinese patent document CN 104695918A (application No. 201310646793. X) discloses a thickened oil low-down-modification viscosity-reduction oil extraction method, in which a hydrothermal cracking catalyst is dispersed in steam and then injected into a stratum, so that the extraction period is remarkably prolonged. Chinese patent CN 104314525A (application No. 201410475179.6) discloses a fire flooding oil recovery method using oleic acid for in-situ modification, and after oleic acid slugs are continuously injected into an oil layer through a gas injection well, in-situ combustion oil recovery is performed, so that the properties of the oil product and the recovery ratio of crude oil are improved. In the field of improvement of hydrothermal cracking, the important point is mainly to select or innovate the catalyst (Zhao Xiaoying, chen Yukun, etc.. Research progress of in situ hydrothermal cracking viscosity reduction of thickened oil [ J ]]30-35), such as Chinese patent document CN 115450597A (application No. 202211218711.7), discloses a composite catalyst technology for catalytic co-hydrothermal pyrolysis modification of thick oil lignin and an application method thereof, and provides a novel composite catalyst (Keggin type heteropolyacid catalyst and CeO) 2 A combination of catalysts) to enhance the upgrading effect of the thickened oil.
However, there are still several problems associated with the current methods of application of catalysts for hydrothermal cracking technology:
(1) Although a few aquathermolysis catalysts have good dispersing effect in stratum species, the heating range of pure steam is limited, so that the temperature of a considerable part of areas in the stratum cannot reach aquathermolysis conditions (generally more than 200 ℃), and crude oil modification is difficult to occur in the part of stratum areas containing the catalysts;
(2) The hydrothermal cracking catalyst in nano or particle form is easy to agglomerate and adsorb near the injection well under the influence of interfacial energy, so that the flowing distance of the catalyst in the stratum is limited, the catalyst is difficult to effectively migrate to the target stratum, and the utilization efficiency of the catalyst is low.
Accordingly, there is a need in the art for further research in improving the steam heat application range, hydrothermal cracking catalyst injection/transport capacity, and catalyst utilization efficiency.
Disclosure of Invention
The invention aims to overcome the defects of the prior art, and provides a method for reinforcing thick oil thermal recovery by using a non-condensate gas composite aquathermolysis catalyst, which is characterized in that a catalyst precursor solution and a mixed fluid of steam and non-condensate gas are sequentially injected into a stratum to ensure that the catalyst is generated in situ in the stratum, and the catalyst is utilized to crack and reduce viscosity of thick oil, so that the problems of catalyst migration and stratum temperature range are solved, and the thermal recovery efficiency of thick oil is greatly improved.
In order to achieve the technical effects, the invention adopts the following technical scheme:
a method for reinforcing thick oil exploitation by non-condensate gas composite aquathermolysis catalyst includes such steps as injecting the precursor solution of catalyst into stratum by well, injecting displacing liquid to push the precursor solution to flow deep in stratum, injecting the mixed fluid of steam and non-condensate gas, closing well, exploiting until the exploitation period is finished, and repeating said steps until the thick oil is recovered.
The method breaks through the limitation of the improvement direction in the prior art, is not entangled in the selection or innovation of the catalyst, and combines the defects existing in practical application, a brand-new exploitation method is provided pertinently, the defect that agglomeration or adsorption is generated by directly injecting the precursor solution of the existing catalyst is avoided by injecting the precursor solution of the nano or particle catalyst, then the precursor solution is transported to the deep part of the stratum rich in the thick oil by injecting the displacement liquid, after the precursor solution is transported to the deep part, high-temperature steam and non-condensate gas are injected, the precursor solution is subjected to in-situ generation of the target catalyst by utilizing thermal decomposition, then the well is closed for reaction, and the high Wen Cujin catalyst is utilized for in-situ aquathermolysis of the thick oil, so that the viscosity of the thick oil is effectively reduced.
Preferably, the solute of the precursor solution comprises a precursor of at least one of a molybdenum catalyst, a tungsten catalyst, a nickel catalyst, an iron catalyst, or a cobalt catalyst; the solvent is diesel oil or water.
For example, the precursor of the molybdenum catalyst is selected from one or more of ammonium tetrathiomolybdate, potassium tetrathiomolybdate, sodium tetrathiomolybdate, ammonium dodecathiomolybdate, sodium dodecathiomolybdate, potassium dodecathiomolybdate; the precursor of the tungsten catalyst is one or more selected from ammonium tetrathiotungstate, potassium tetrathiotungstate, sodium tetrathiotungstate, ammonium dodecathiotungstate, sodium dodecathiotungstate and potassium dodecathiotungstate; the precursor of the nickel catalyst is organic acid nickel, wherein the organic acid is one or more of C6-C20 primary acid or C6-C20 naphthenic acid.
The hydrophilic or lipophilic catalyst has poor dispersing effect in the stratum and lower utilization rate, so the application selects the transition metal catalyst, including transition metal simple substance and oxides, sulfides, carbides or supported particles thereof, in order to solve the injection problem of the existing catalyst and enable the injected catalyst to exert a catalytic effect at a target layer.
Further preferably, the mass concentration of the precursor in the precursor solution is 20-200 mug/g based on active metal simple substance, and the injection temperature of the precursor solution is required to be lower than the decomposition temperature of the precursor. Solves the problem of difficult injection of the catalyst into the stratum, and simultaneously prevents the early decomposition of the catalyst precursor before reaching the target stratum.
The precursor mass concentration calculation takes ammonium tetrathiomolybdate aqueous solution as an example, 50 mug of molybdenum is needed in 1g of aqueous solution when the active metal simple substance is 50 mug/g, and the mass and the concentration of the ammonium tetrathiomolybdate are calculated according to the mass of the molybdenum.
It is further preferred that the injection mass of the precursor solution is 0.4-1.5wt% of the mass of the heavy oil in the formation.
Preferably, the displacement liquid is hot water, and the injection mass of the hot water is 0.5-2 times of that of the precursor solution; it is further preferred that the injection mass of hot water is 1-2 times the injection mass of the precursor solution.
Preferably, the injection speed of the steam is 100-150t/d, the dryness of the steam is more than 0.9, and the accumulated injection amount of the steam is 1000-2000t; the injection speed of the non-condensate gas is 1-2 times of the injection speed of the steam, wherein the times are volume ratios, the volume flow of the steam is converted according to water, and the measurement condition of the injection speed of the gas is the volume of the stratum temperature and pressure.
Experimental study shows that when the accompanying injection proportion of the non-condensate gas is 2 times higher than the steam injection speed, the mixed fluid of the non-condensate gas and the steam is easy to generate channeling in the stratum, so that the heat loss of the steam is caused; when the concomitance injection proportion of the non-condensate gas is lower than 1 time of the steam injection speed, the generated drainage effect and the protection effect on the steam heat are poor.
Preferably, the non-condensable gas is co-injected with the steam into the formation in a satellite form.
Further preferably, the temperature of the mixed fluid of steam and non-condensate gas is in the range of 200-350 ℃; more preferably, the temperature of the mixed fluid ranges from 250 to 350 ℃.
Further preferably, the non-condensing gas is selected from N 2 、CO 2 、CH 4 And at least one of flue gas.
Preferably, the shut-in reaction time is 3-5 days. Considering the catalyst precursor decomposition process, below 3 days, crude oil in contact with the catalyst is not fully cracked, above 5 days, the formation temperature will be below the aquathermolysis temperature.
Preferably, the end of the recovery period is a recovery oil to gas ratio of less than 0.1.
Preferably, when the precursor solution of the catalyst is injected, the hydrogen donor is injected at the same time, and the ratio of the injection amount of the hydrogen donor to the precursor solution is adjusted according to the conventional amount.
Preferably, the well distribution mode of the thick oil thermal recovery is single well injection recovery of steam huff and puff.
The oil reservoir of the method provided by the invention meets the following conditions:
the average permeability of the oil reservoir is more than 300mD;
the depth of the oil reservoir is less than 2500m;
the saturation of initial oil content is more than 55%;
the formation temperature is 40-80 ℃;
the effective porosity of the oil reservoir is 20-40%.
Compared with the traditional method for exploiting thick oil by hydrothermal cracking, the enhanced thermal recovery method combines non-condensate gas with a catalytic modified yield increasing mechanism, utilizes the characteristic that the non-condensate gas has the capability of inhibiting steam condensation and high seepage, plays a role in drainage for migration of a catalyst precursor solution, improves the migration distance and the action range of the catalyst, effectively improves the utilization efficiency of the catalyst, and is widely applicable to heavy oil reservoirs or super/ultra heavy oil reservoirs developed by thermal recovery.
According to the invention, the whole thermal recovery displacement process is divided into five processes, and in the first stage, the catalyst precursor is injected into the stratum in a solution form, so that the problem of difficult catalyst injection is solved; in the second stage, displacing liquid is injected into the stratum, so that concentrated decomposition of a subsequent catalyst near an injection well is avoided, and the heavy oil modification range is effectively expanded; the third stage, injecting high-temperature steam and non-condensate gas into the stratum, creating reaction environment and condition for thermal decomposition of the catalyst precursor, and expanding the thermal action range of the steam by mixing and injecting the steam and the non-condensate gas; fourthly, shutting in the well to enable the catalyst to react with the thick oil; and fifthly, after the cracking reaction is completed, opening a well for production.
The beneficial effects of the invention are as follows:
(1) The non-condensate gas inhibits steam condensation, can improve steam flow capacity and heat utilization rate, expands the heat action range of steam, and creates better heavy oil aquathermolysis reaction conditions for the catalyst.
(2) When the displacement liquid is injected, the precursor solution is pushed first, after the steam and the non-condensate gas are injected, the precursor is decomposed into the catalyst, and the drainage and carrying functions of the gas effectively improve the migration distance of the catalyst and the contact efficiency between the catalyst and the thick oil, so that the quality of the thick oil modification is improved.
(3) The catalyst is injected into the stratum in the form of the active metal precursor solution, so that the injection of the catalyst is facilitated, and the target horizon of the modification reaction of the thick oil is easier to control.
(4) The dissolution of non-condensate gas in the thick oil reduces the viscosity of the crude oil, and can improve the fluidity of the crude oil and increase the output capacity of the crude oil.
(5) For the energy deficit stratum, the concomitant injection of non-condensate gas can effectively supplement stratum energy, avoid ineffective injection of steam and catalyst, and greatly improve the adaptability of the hydrothermal cracking enhanced heavy oil recovery technology.
Detailed Description
The invention is further illustrated below with reference to examples.
The invention provides a method for reinforcing thickened oil exploitation by a non-condensate gas composite aquathermolysis catalyst, which comprises the steps of injecting a precursor solution of the catalyst into a stratum from a shaft, injecting a displacement liquid to push the precursor solution to flow to the deep of the stratum, then injecting a mixed fluid of steam and non-condensate gas into the stratum, exploiting the mixed fluid until the exploitation period of the round is finished after well closing reaction, and repeating the steps until the extracted thickened oil reaches an expected value.
The solute of the precursor solution comprises a precursor of at least one of molybdenum catalyst, tungsten catalyst, nickel catalyst, iron catalyst or cobalt catalyst; the solvent is diesel oil or water. The solute of the precursor solution comprises a single-component molybdenum precursor solution, a tungsten precursor solution, a nickel precursor solution, an iron precursor solution, a cobalt precursor solution, or a composite catalyst precursor solution of two metals, three metals, four metals or five metals of the single-component precursor.
For example, the precursor of the molybdenum catalyst is selected from one or more of ammonium tetrathiomolybdate, potassium tetrathiomolybdate, sodium tetrathiomolybdate, ammonium dodecathiomolybdate, sodium dodecathiomolybdate, potassium dodecathiomolybdate; the precursor of the tungsten catalyst is one or more selected from ammonium tetrathiotungstate, potassium tetrathiotungstate, sodium tetrathiotungstate, ammonium dodecathiotungstate, sodium dodecathiotungstate and potassium dodecathiotungstate; the precursor of the nickel catalyst is organic acid nickel, wherein the organic acid is one or more of C6-C20 primary acid or C6-C20 naphthenic acid.
Further preferably, the mass concentration of the precursor in the precursor solution is 20-200 mug/g based on active metal simple substance, and the injection temperature of the precursor solution is required to be lower than the decomposition temperature of the precursor. Solves the problem of difficult injection of the catalyst into the stratum, and simultaneously prevents the early decomposition of the catalyst precursor before reaching the target stratum.
The precursor mass concentration calculation takes ammonium tetrathiomolybdate aqueous solution as an example, 50 mug of molybdenum is needed in 1g of aqueous solution when the active metal simple substance is 50 mug/g, and the mass and the concentration of the ammonium tetrathiomolybdate are calculated according to the mass of the molybdenum.
It is further preferred that the injection mass of the precursor solution is 0.4-1.5wt% of the mass of the heavy oil in the formation.
The displacement liquid is hot water, and the injection mass of the hot water is 0.5-2 times of the injection mass of the precursor solution; it is further preferred that the injection mass of hot water is 1-2 times the injection mass of the precursor solution.
Preferably, the injection speed of the steam is 100-150t/d, the dryness of the steam is more than 0.9, and the accumulated injection amount of the steam is 1000-2000t; the injection speed of the non-condensate gas is 1-2 times of the injection speed of the steam, wherein the times are volume ratios, the volume flow of the steam is converted according to water, and the measurement condition of the injection speed of the gas is the volume of the stratum temperature and pressure.
Experimental study shows that when the accompanying injection proportion of the non-condensate gas is 2 times higher than the steam injection speed, the mixed fluid of the non-condensate gas and the steam is easy to generate channeling in the stratum, so that the heat loss of the steam is caused; when the concomitance injection proportion of the non-condensate gas is lower than 1 time of the steam injection speed, the generated drainage effect and the protection effect on the steam heat are poor.
Preferably, the non-condensable gas is co-injected with the steam into the formation in a satellite form.
Further preferably, the temperature of the mixed fluid of steam and non-condensate gas is in the range of 200-350 ℃; more preferably, the temperature of the mixed fluid ranges from 250 to 350 ℃.
Further preferably, the non-condensing gas is selected from N 2 、CO 2 、CH 4 And at least one of flue gas.
The closing reaction time is 3-5 days. Considering the catalyst precursor decomposition process, below 3 days, crude oil in contact with the catalyst is not fully cracked, above 5 days, the formation temperature will be below the aquathermolysis temperature.
The end condition of the exploitation period is that the oil-gas ratio is smaller than 0.1.
The well distribution mode of the thick oil thermal recovery is single well injection recovery of steam huff and puff.
The oil reservoir of the method provided by the invention meets the following conditions:
the average permeability of the oil reservoir is more than 300mD;
the depth of the oil reservoir is less than 2500m;
the saturation of initial oil content is more than 55%;
the formation temperature is 40-80 ℃;
the effective porosity of the oil reservoir is 20-40%.
Example 1:
the method for reinforcing thickened oil exploitation by using the non-condensate gas composite aquathermolysis catalyst specifically comprises the following steps:
s1, a catalyst precursor injection stage: injecting a precursor solution accounting for 0.4% of the mass of thick oil in the stratum into the stratum from a shaft, wherein in the embodiment, the precursor in the precursor solution is specifically ammonium tetrathiomolybdate, and the mass concentration of the precursor is 20 mug/g calculated by active metal simple substance molybdenum, namely the mass concentration of the ammonium tetrathiomolybdate in the precursor solution is 54.2 mug/g;
s2, a displacement liquid injection stage: injecting hot water into the stratum, wherein the injection mass of the hot water is 0.5 times of that of the molybdenum precursor solution in the step S1, and the precursor solution is replaced by the hot water to flow to the deep part of the stratum;
s3, injecting a mixed fluid of steam and non-condensate gas: injecting mixed fluid of steam and non-condensate gas into stratum, wherein the injection speed of steam is 100t/d, and the steam isThe dryness is 0.92, the cumulative injection amount of the steam is 1000t, the injection speed of the non-condensed gas is 1 time of the injection speed of the steam, in the embodiment, the non-condensed gas is N 2 The temperature of the mixed fluid is 220 ℃;
s4, closing the well for 3 days, thermally decomposing the catalyst precursor by high-temperature steam, and providing a temperature environment for the hydrothermal cracking of the thick oil;
s5, well production is started until the ratio of oil to gas extracted is less than 0.1, and the round of exploitation is finished;
s6, repeating the steps S1-S5 until the extraction quantity reaches the expected value.
Example 2:
the method for reinforcing thickened oil exploitation by using the non-condensate gas composite aquathermolysis catalyst specifically comprises the following steps:
s1, a catalyst precursor injection stage: injecting a precursor solution accounting for 0.8% of the mass of thick oil in the stratum into the stratum from a shaft, wherein in the embodiment, the precursor specifically comprises ammonium tetrathiotungstate and nickel organic acid in equal proportion, wherein the organic acid is C12 primary acid, the dosage of the precursor is 110 mug/g based on active metal simple substance, namely the mass concentration of the ammonium tetrathiotungstate and the nickel organic acid in the precursor solution is 192.4 mug/g and 73.4 mug/g respectively;
s2, a displacement liquid injection stage: injecting hot water into the stratum, wherein the injection mass of the hot water is 1 time of that of the molybdenum precursor solution in the step S1, and the hot water is utilized to replace the precursor solution to flow to the deep part of the stratum;
s3, injecting a mixed fluid of steam and non-condensate gas: injecting mixed fluid of steam and non-condensate gas into stratum, wherein the injection speed of the steam is 120t/d, the steam dryness is 0.95, the accumulated injection amount of the steam is 1500t, and the injection speed of the non-condensate gas is 1.5 times of the injection speed of the steam, in the embodiment, the non-condensate gas is CO 2 The temperature of the mixed fluid is 250 ℃;
s4, closing the well for 4 days, thermally decomposing the catalyst precursor by high-temperature steam, and providing a temperature environment for the hydrothermal cracking of the thick oil;
s5, well production is started until the ratio of oil to gas extracted is less than 0.1, and the round of exploitation is finished;
s6, repeating the steps S1-S5 until the extraction quantity reaches the expected value.
Example 3:
the method for reinforcing thickened oil exploitation by using the non-condensate gas composite aquathermolysis catalyst specifically comprises the following steps:
s1, a catalyst precursor injection stage: injecting a precursor solution accounting for 1.2% of the mass of thick oil in the stratum into the stratum from a shaft, wherein the precursor specifically comprises ammonium dodecathiomolybdate, ammonium tetrathiotungstate and nickel organic acid in equal proportion, wherein the organic acid is C8 naphthenic acid, and the dosage of the precursor is 100 mug/g based on active metal molybdenum, tungsten and nickel, namely the mass concentration of the ammonium dodecathiomolybdate, the ammonium tetrathiotungstate and the nickel organic acid in the precursor solution is 59.5 mug/g, 36.7 mug/g and 189.2 mug/g respectively;
s2, a displacement liquid injection stage: injecting hot water into the stratum, wherein the injection mass of the hot water is 1.2 times of that of the molybdenum precursor solution in the step S1, and the precursor solution is replaced by the hot water to flow to the deep part of the stratum;
s3, injecting a mixed fluid of steam and non-condensate gas: injecting mixed fluid of steam and non-condensate gas into stratum, wherein the injection speed of the steam is 130t/d, the steam dryness is 0.95, the accumulated injection amount of the steam is 1800t, the injection speed of the non-condensate gas is 1.8 times of the injection speed of the steam, and in the embodiment, the non-condensate gas is equal volume of CH 4 And CO 2 The temperature of the mixed fluid is 290 ℃;
s4, closing the well for 4 days, thermally decomposing the catalyst precursor by high-temperature steam, and providing a temperature environment for the hydrothermal cracking of the thick oil;
s5, well production is started until the ratio of oil to gas extracted is less than 0.1, and the round of exploitation is finished;
s6, repeating the steps S1-S5 until the extraction quantity reaches the expected value.
Example 4:
the method for reinforcing thickened oil exploitation by using the non-condensate gas composite aquathermolysis catalyst specifically comprises the following steps:
s1, a catalyst precursor injection stage: injecting a precursor solution accounting for 1.5% of the mass of thick oil in the stratum into the stratum from a shaft, wherein in the embodiment, the precursor specifically comprises potassium dodecyl benzene sulfonate, the dosage of the catalyst is 200 mug/g calculated by active metal simple substance tungsten, namely the mass concentration of the potassium dodecyl benzene sulfonate in the precursor solution is 451.1 mug/g;
s2, a displacement liquid injection stage: injecting hot water into the stratum, wherein the injection mass of the hot water is 2 times of that of the molybdenum precursor solution in the step S1, and the precursor solution is replaced by the hot water to flow to the deep part of the stratum;
s3, injecting a mixed fluid of steam and non-condensate gas: injecting mixed fluid of steam and non-condensate gas into the stratum, wherein the injection speed of the steam is 150t/d, the steam dryness is 0.93, the accumulated injection amount of the steam is 2000t, the injection speed of the non-condensate gas is 2 times of the injection speed of the steam, in the embodiment, the non-condensate gas is flue gas, and the temperature of the mixed fluid is 350 ℃;
s4, closing the well for 5 days, thermally decomposing the catalyst precursor by high-temperature steam, and providing a temperature environment for the hydrothermal cracking of the thick oil;
s5, well production is started until the ratio of oil to gas extracted is less than 0.1, and the round of exploitation is finished;
s6, repeating the steps S1-S5 until the extraction quantity reaches the expected value.
Experimental example
Under the condition of a simulation experiment, different methods are used for displacing the heavy oil reservoir, wherein the heavy oil reservoir condition is the simulated heavy oil reservoir, the reservoir temperature is 60 ℃, the permeability is 2462mD, the oil saturation is 86%, the porosity is 28.55%, and the heavy oil viscosity is 5500 mPa.s at 60 ℃; the back pressure of the model outlet is set to be 1MPa, the inner diameter of the experimental oil displacement model is 2.54cm, the length is 60cm, temperature detection points are arranged at 5 positions of 10cm, 20cm, 30cm, 40cm and 50cm, and the specific displacement conditions of each experimental group are as follows:
experiment group 1:
s1, a catalyst injection stage: the catalyst solution is injected into the reservoir. The catalyst is MoS 3 The nano particles are calculated by active metal simple substance molybdenum, the concentration is 80 mug/g, the injection speed is 1mL/min, the injection time is 5min, and the injection temperature is 70 ℃.
S2, a displacement liquid injection stage: and injecting the displacement fluid into the reservoir. The displacement liquid is hot water, the injection speed is 1mL/min, the injection time is 6min, and the injection temperature is 70 ℃.
S3, steam injection stage: and (3) injecting steam into the stratum, wherein the injection speed of the steam is 1mL/min, the injection time is 15min, the injection temperature is 300 ℃, and the steam dryness is 0.9.
S4, closing the well for 4 days: after the mixed fluid is injected, the hydrothermal cracking catalyst fully reacts with the crude oil.
S5, crude oil exploitation stage: and (3) starting the well to produce, and stopping the production, wherein the cycle oil-gas ratio is 0.098.
Experiment group 2:
s1, a catalyst precursor injection stage: a catalyst precursor solution is injected into the reservoir. The catalyst is injected in the form of catalyst precursor solution, the solute is ammonium tetrathiomolybdate, the concentration is 80 mug/g based on active metal simple substance molybdenum, the injection speed is 1mL/min, the injection time is 5min, and the injection temperature is 70 ℃.
S2, a displacement liquid injection stage: and injecting the displacement fluid into the reservoir. The displacement liquid is hot water, the injection speed is 1mL/min, the injection time is 6min, and the injection temperature is 70 ℃.
S3, steam and injection stage: and (3) injecting steam into the stratum, wherein the injection speed of the steam is 1mL/min, the injection time is 15min, the injection temperature is 300 ℃, and the steam dryness is 0.9.
S4, closing the well for 4 days: after the mixed fluid is injected, the hydrothermal cracking catalyst fully reacts with the crude oil.
S5, crude oil exploitation stage: and (3) starting the well to produce, and stopping the production, wherein the cycle oil-gas ratio is 0.097.
Experiment group 3:
s1, a catalyst injection stage: the catalyst solution is injected into the reservoir. The catalyst is MoS 3 The nano particles are calculated by active metal simple substance molybdenum, the concentration is 80 mug/g, the injection speed is 1mL/min, the injection time is 5min, and the injection temperature is 70 ℃.
S2, a displacement liquid injection stage: and injecting the displacement fluid into the reservoir. The displacement liquid is hot water, the injection speed is 1mL/min, the injection time is 6min, and the injection temperature is 70 ℃.
S3, steamAnd a non-condensate gas injection stage: by combining steam with N 2 Injecting into stratum, wherein the injection speed of steam is 1mL/min, the injection time is 15min, the injection temperature is 300 ℃, and the steam dryness is 0.9; n (N) 2 The injection speed of (2) is 1mL/min, the injection time is 15min, and the injection temperature is 300 ℃.
S4, closing the well for 4 days: after the mixed fluid is injected, the hydrothermal cracking catalyst fully reacts with the crude oil.
S5, crude oil exploitation stage: and (3) starting the well to produce, and stopping the production, wherein the cycle oil-gas ratio is 0.097.
Experiment group 4:
s1, a catalyst precursor injection stage: a catalyst precursor solution is injected into the reservoir. The catalyst is injected in the form of catalyst precursor solution, the solute is ammonium tetrathiomolybdate, the concentration is 80 mug/g based on active metal simple substance molybdenum, the injection speed is 1mL/min, the injection time is 5min, and the injection temperature is 70 ℃.
S2, a displacement liquid injection stage: and injecting the displacement fluid into the reservoir. The displacement liquid is hot water, the injection speed is 1mL/min, the injection time is 6min, and the injection temperature is 70 ℃.
S3, steam and non-condensate gas injection stage: by combining steam with N 2 Injecting into stratum, wherein the injection speed of steam is 1mL/min, the injection time is 15min, the injection temperature is 300 ℃, and the steam dryness is 0.9; n (N) 2 The injection speed of (2) is 1mL/min, the injection time is 15min, and the injection temperature is 300 ℃.
S4, closing the well for 4 days: after the mixed fluid is injected, the hydrothermal cracking catalyst fully reacts with the crude oil.
S5, crude oil exploitation stage: and (3) starting the well to produce, and stopping the production, wherein the cycle oil-gas ratio is 0.099.
Experimental group 5:
s1, a catalyst precursor injection stage: a catalyst precursor solution is injected into the reservoir. The catalyst is injected in the form of catalyst precursor solution, the solute is ammonium tetrathiomolybdate, the concentration is 80 mug/g based on active metal simple substance molybdenum, the injection speed is 1mL/min, the injection time is 5min, and the injection temperature is 70 ℃.
S2, a displacement liquid injection stage: and injecting the displacement fluid into the reservoir. The displacement liquid is hot water, the injection speed is 1mL/min, the injection time is 6min, and the injection temperature is 70 ℃.
S3, steam and non-condensate gas injection stage: by combining steam with N 2 Injecting into stratum, wherein the injection speed of steam is 1mL/min, the injection time is 15min, the injection temperature is 300 ℃, and the steam dryness is 0.9; n (N) 2 The injection speed of (2) is 1mL/min, the injection time is 15min, and the injection temperature is 300 ℃.
S4, closing the well for 2 days: after the mixed fluid is injected, the hydrothermal cracking catalyst fully reacts with the crude oil.
S5, crude oil exploitation stage: and (3) starting the well to produce, and stopping the production, wherein the cycle oil-gas ratio is 0.096.
Experiment group 6
S1, a catalyst precursor injection stage: a catalyst precursor solution is injected into the reservoir. The catalyst is injected in the form of catalyst precursor solution, the solute is ammonium tetrathiomolybdate, the concentration is 80 mug/g based on active metal simple substance molybdenum, the injection speed is 1mL/min, the injection time is 5min, and the injection temperature is 70 ℃; and (3) mixing tetrahydronaphthalene with 8% of the mass of the thick oil in advance into the thick oil saturated in the model to serve as a hydrogen donor.
S2, a displacement liquid injection stage: and injecting the displacement fluid into the reservoir. The displacement liquid is hot water, the injection speed is 1mL/min, the injection time is 6min, and the injection temperature is 70 ℃.
S3, steam and non-condensate gas injection stage: by combining steam with N 2 Injecting into stratum, wherein the injection speed of steam is 1mL/min, the injection time is 15min, the injection temperature is 300 ℃, and the steam dryness is 0.9; n (N) 2 The injection speed of (2) is 1mL/min, the injection time is 15min, and the injection temperature is 300 ℃.
S4, closing the well for 4 days: after the mixed fluid is injected, the hydrothermal cracking catalyst fully reacts with the crude oil.
S5, crude oil exploitation stage: and (3) starting the well to produce, and stopping the production, wherein the cycle oil-gas ratio is 0.099.
The statistics of the results obtained for each experimental group are shown in the following table.
Table 1 results obtained for each experimental group
As can be seen from the comparison of the data of the experimental group 1 and the experimental group 2, the method provided by the invention effectively solves the problem of catalyst injection by using the injection of the catalyst precursor solution. Compared with injection of steam and nano catalyst solution, the catalyst precursor displacement solution has stronger fluidity, is easier to enter the deep part of the stratum, and the catalyst formed after thermal decomposition can play a role in a high oil saturation level, so that the viscosity of produced crude oil is obviously reduced.
As can be seen from the comparison of the data of the experimental group 1 and the experimental group 3, the method provided by the invention utilizes the characteristic of inhibiting the condensation and the high permeability of the steam of the non-condensate gas, and improves the thermal action range of the steam. Compared with the method for enhancing the steam flooding by using the catalyst alone, the recovery ratio is effectively improved, and the non-condensable gas can be found to have obvious enhancement effect on the deep heat transfer effect of the steam by comparing the temperature data of the temperature measuring points. However, the improvement of the recovery ratio and the reduction of the crude oil viscosity are not obvious, and the catalyst particles do not enter the deep stratum. The mixed fluid in which the non-condensed gas and the steam are mixed can improve the heat application area, but solves the problem of injection of the catalyst particles.
As can be seen from the comparison of the data of the experimental group 2 and the experimental group 4, the method provided by the invention has the advantages that the catalyst is injected into the stratum in the form of the precursor solution, the steam action range is enlarged by combining the non-condensate gas, the utilization efficiency of the catalyst is increased, and the recovery ratio and the crude oil modification effect are effectively improved. According to the data in the table, the crude oil recovery ratio, the temperature field development effect and the reduction degree of the viscosity of the produced crude oil measured by the experimental group 4 are all higher than those of the example 2, which shows that the addition of the non-condensate gas can further improve the heat application range of steam, the migration breadth of the catalyst and provide a better environment for the catalyst to act.
As can be seen from comparison of the data of the experimental group 4 and the experimental group 5, the method provided by the invention needs to consider the time for thermally decomposing the precursor into the catalyst, and the suitable well closing time is 3-5 days. The well closing time provided by the invention can realize a more beneficial development effect on the heavy oil reservoir.
The comparison of the data of the experiment group 4 and the experiment group 6 shows that the hydrogen supply agent is injected while the precursor solution is injected, so that the viscosity reduction of the thick oil can be promoted, the better hydrothermal cracking viscosity reduction effect is realized, and the recovery ratio of the thick oil is improved.
Claims (6)
1. A method for reinforcing thick oil exploitation by using a non-condensate gas composite aquathermolysis catalyst is characterized in that after a precursor solution of the catalyst is injected into a stratum from a shaft, a displacement liquid is injected to push the precursor solution to flow into the stratum, then a mixed fluid of steam and non-condensate gas is injected into the stratum, after a well closing reaction, the thick oil is exploited until the exploitation period of the current round is finished, and the steps are repeated until the thick oil is exploited to reach an expected value;
the solute of the precursor solution comprises a precursor of at least one of molybdenum catalyst, tungsten catalyst, nickel catalyst, iron catalyst or cobalt catalyst; the solvent is diesel oil or water;
the mass concentration of the precursor in the precursor solution is 20-200 mug/g calculated by active metal simple substance;
the injection mass of the precursor solution is 0.4-1.5wt% of the mass of the thick oil in the stratum;
the displacement liquid is hot water, and the injection mass of the hot water is 0.5-2 times of the injection mass of the precursor solution;
the injection speed of the non-condensed gas is 1-2 times of the injection speed of the steam, and the non-condensed gas and the steam are injected into the stratum together in a concomitant injection mode;
the non-condensable gas is selected from CO 2 Or flue gas or equivalent volumes of CH 4 And CO 2 。
2. The method of claim 1, wherein the steam is injected at a rate of 100-150t/d, a steam dryness > 0.9, and a cumulative steam injection of 1000-2000t;
the multiple of the injection speed of the non-condensate gas and the steam injection speed is the volume ratio, wherein the volume flow of the steam is converted according to water, and the measurement condition of the injection speed of the gas is the volume of the stratum temperature and pressure.
3. The method of claim 2, wherein,
the temperature of the mixed fluid of steam and non-condensate gas is in the range of 200-350 ℃.
4. The method of claim 1, wherein the shut-in reaction time is 3 to 5 days.
5. The method of claim 1 wherein the end of recovery period condition is a recovery oil to gas ratio of less than 0.1.
6. The method of claim 1, wherein the hydrogen donor is injected simultaneously with the injection of the precursor solution for the catalyst.
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