CN113444506A - Deep profile control channeling sealing agent and preparation method and application method thereof - Google Patents
Deep profile control channeling sealing agent and preparation method and application method thereof Download PDFInfo
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- 238000007789 sealing Methods 0.000 title claims abstract description 142
- 230000005465 channeling Effects 0.000 title claims abstract description 98
- 238000000034 method Methods 0.000 title claims abstract description 18
- 238000002360 preparation method Methods 0.000 title abstract description 8
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 133
- UMGDCJDMYOKAJW-UHFFFAOYSA-N thiourea Chemical compound NC(N)=S UMGDCJDMYOKAJW-UHFFFAOYSA-N 0.000 claims abstract description 38
- WHGYBXFWUBPSRW-FOUAGVGXSA-N beta-cyclodextrin Chemical compound OC[C@H]([C@H]([C@@H]([C@H]1O)O)O[C@H]2O[C@@H]([C@@H](O[C@H]3O[C@H](CO)[C@H]([C@@H]([C@H]3O)O)O[C@H]3O[C@H](CO)[C@H]([C@@H]([C@H]3O)O)O[C@H]3O[C@H](CO)[C@H]([C@@H]([C@H]3O)O)O[C@H]3O[C@H](CO)[C@H]([C@@H]([C@H]3O)O)O3)[C@H](O)[C@H]2O)CO)O[C@@H]1O[C@H]1[C@H](O)[C@@H](O)[C@@H]3O[C@@H]1CO WHGYBXFWUBPSRW-FOUAGVGXSA-N 0.000 claims abstract description 32
- 229920000858 Cyclodextrin Polymers 0.000 claims abstract description 19
- 239000001116 FEMA 4028 Substances 0.000 claims abstract description 19
- XSQUKJJJFZCRTK-UHFFFAOYSA-N Urea Natural products NC(N)=O XSQUKJJJFZCRTK-UHFFFAOYSA-N 0.000 claims abstract description 19
- 235000011175 beta-cyclodextrine Nutrition 0.000 claims abstract description 19
- 229960004853 betadex Drugs 0.000 claims abstract description 19
- ZLMJMSJWJFRBEC-UHFFFAOYSA-N Potassium Chemical compound [K] ZLMJMSJWJFRBEC-UHFFFAOYSA-N 0.000 claims abstract description 18
- 238000010795 Steam Flooding Methods 0.000 claims abstract description 18
- 229910052700 potassium Inorganic materials 0.000 claims abstract description 18
- 239000011591 potassium Substances 0.000 claims abstract description 18
- 229920002678 cellulose Polymers 0.000 claims abstract description 17
- 239000001913 cellulose Substances 0.000 claims abstract description 17
- VKYKSIONXSXAKP-UHFFFAOYSA-N hexamethylenetetramine Chemical compound C1N(C2)CN3CN1CN2C3 VKYKSIONXSXAKP-UHFFFAOYSA-N 0.000 claims abstract description 17
- 235000019832 sodium triphosphate Nutrition 0.000 claims abstract description 16
- ISWSIDIOOBJBQZ-UHFFFAOYSA-N Phenol Chemical compound OC1=CC=CC=C1 ISWSIDIOOBJBQZ-UHFFFAOYSA-N 0.000 claims abstract description 15
- 238000002347 injection Methods 0.000 claims abstract description 15
- 239000007924 injection Substances 0.000 claims abstract description 15
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 15
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 claims abstract description 13
- 229910052708 sodium Inorganic materials 0.000 claims abstract description 13
- 239000011734 sodium Substances 0.000 claims abstract description 13
- 150000003585 thioureas Chemical class 0.000 claims abstract description 13
- 239000002994 raw material Substances 0.000 claims abstract description 7
- 239000000203 mixture Substances 0.000 claims description 10
- 238000004519 manufacturing process Methods 0.000 claims description 6
- 238000002156 mixing Methods 0.000 claims description 5
- 230000033558 biomineral tissue development Effects 0.000 claims description 4
- 235000010299 hexamethylene tetramine Nutrition 0.000 claims description 4
- 239000011259 mixed solution Substances 0.000 claims 2
- DEUKGDDIXCQKES-UHFFFAOYSA-N phenol;sodium Chemical compound [Na].[Na].OC1=CC=CC=C1.OC1=CC=CC=C1 DEUKGDDIXCQKES-UHFFFAOYSA-N 0.000 claims 2
- 230000001965 increasing effect Effects 0.000 abstract description 12
- 238000010276 construction Methods 0.000 abstract description 11
- 238000005086 pumping Methods 0.000 abstract description 7
- 239000003921 oil Substances 0.000 description 21
- 230000035699 permeability Effects 0.000 description 14
- 238000012360 testing method Methods 0.000 description 14
- 230000000694 effects Effects 0.000 description 12
- 239000002981 blocking agent Substances 0.000 description 11
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 8
- 239000011435 rock Substances 0.000 description 8
- 238000003756 stirring Methods 0.000 description 8
- 238000011049 filling Methods 0.000 description 6
- 230000008569 process Effects 0.000 description 6
- 238000010793 Steam injection (oil industry) Methods 0.000 description 5
- 238000002474 experimental method Methods 0.000 description 5
- 239000006004 Quartz sand Substances 0.000 description 4
- 230000015572 biosynthetic process Effects 0.000 description 4
- 230000008859 change Effects 0.000 description 4
- 239000002131 composite material Substances 0.000 description 4
- 239000004576 sand Substances 0.000 description 4
- 238000005303 weighing Methods 0.000 description 4
- 238000010521 absorption reaction Methods 0.000 description 3
- 230000000903 blocking effect Effects 0.000 description 3
- 239000003431 cross linking reagent Substances 0.000 description 3
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- 238000011161 development Methods 0.000 description 3
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- 238000011056 performance test Methods 0.000 description 3
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- 238000006243 chemical reaction Methods 0.000 description 2
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- 239000007790 solid phase Substances 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 230000003313 weakening effect Effects 0.000 description 2
- KXGFMDJXCMQABM-UHFFFAOYSA-N 2-methoxy-6-methylphenol Chemical compound [CH]OC1=CC=CC([CH])=C1O KXGFMDJXCMQABM-UHFFFAOYSA-N 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- 229920006321 anionic cellulose Polymers 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
- 239000003814 drug Substances 0.000 description 1
- 239000000295 fuel oil Substances 0.000 description 1
- 238000001879 gelation Methods 0.000 description 1
- 239000012760 heat stabilizer Substances 0.000 description 1
- 230000007774 longterm Effects 0.000 description 1
- 230000005012 migration Effects 0.000 description 1
- 238000013508 migration Methods 0.000 description 1
- 239000005011 phenolic resin Substances 0.000 description 1
- 229920001568 phenolic resin Polymers 0.000 description 1
- 230000002035 prolonged effect Effects 0.000 description 1
- 238000010008 shearing Methods 0.000 description 1
- 230000007928 solubilization Effects 0.000 description 1
- 238000005063 solubilization Methods 0.000 description 1
- 230000000087 stabilizing effect Effects 0.000 description 1
- 239000000725 suspension Substances 0.000 description 1
- 238000010998 test method Methods 0.000 description 1
Classifications
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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
- C09K8/50—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
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- Life Sciences & Earth Sciences (AREA)
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Abstract
The invention provides a deep profile control channeling sealing agent, and a preparation method and an application method thereof. The deep profile control channeling sealing agent is prepared from raw materials including potassium humate and/or sodium humate, polyanionic cellulose, urotropine, phenol, sodium tripolyphosphate, beta-cyclodextrin and/or beta-cyclodextrin derivatives, thiourea and/or thiourea derivatives and water. The invention also provides an application method of the deep profile control channeling-sealing agent in the channeling-sealing measures of the steam-drive reservoir, which comprises the step of injecting the deep profile control channeling-sealing agent into a stratum at the temperature of 80-290 ℃, wherein the injection amount is 500m3The above. The deep profile control channeling sealing agent provided by the invention has good pumping performance and temperature resistance, long gelling time and high-temperature plugging rate, and has an obvious oil increasing effect when being applied to profile control channeling sealing construction.
Description
Technical Field
The invention relates to the technical field of oil extraction, in particular to a deep profile control channeling sealing agent and a preparation method and an application method thereof.
Background
Steam flooding and steam huff and puff are effective development modes of heavy oil reservoirs, and with continuous development of steam flooding and steam huff and puff, the main body part is high in extraction degree, residual oil is scattered, the potential digging difficulty is high, the side part steam flooding effect is poor, a large channel is formed between injection and production wells, and the effect improving difficulty is high. Aiming at the problem of uneven longitudinal and plane utilization in the development process, a solid-phase high-temperature profile control technology is implemented in recent years, a certain oil increasing effect is achieved, but the effective period of profile control is short, meanwhile, the technology can only be implemented in a general steam injection well, the problem of uneven utilization of a separate injection well cannot be solved, and therefore a solid-phase steam-drive profile control technology is not needed to be implemented urgently, and construction safety is guaranteed.
Influenced by factors such as heterogeneity of an oil layer, steam overburden and the like, large channels among injection wells and production wells are obvious after long-term steam flooding, the problem of uneven oil reservoir utilization is increasingly prominent, and a profile control agent needs to enter a deep part of a stratum to block a steam channeling channel, so that the profile control agent is required to have good deep part shearing resistance, and meanwhile, a steam flooding high-temperature area is 240-; in the past, profile control is better in pressure raising and stabilizing effects, but the oil increasing effect is general, the effective period is short, so that the requirements of steam drive profile control cannot be met by a profile control idea of improving steam injection pressure through simple plugging, and a profile control idea of combining deep profile control and strengthened plugging must be adopted to improve the measure effect.
Disclosure of Invention
In order to solve the problems, the invention aims to provide a deep profile control channeling-sealing agent and a preparation method and an application method thereof by adopting a profile control channeling-sealing thought of deep profile control and strengthened plugging. The deep profile control channeling sealing agent has the characteristics of long acting and deep plugging realization, and can realize long-acting plugging and safe construction when being applied to profile control channeling sealing of a steam-drive oil reservoir.
In order to achieve the purpose, the invention provides a deep profile control channeling sealing agent. The channeling sealing agent comprises the following raw materials by taking the total weight of the channeling sealing agent as 100 percent: 8-10% of potassium humate and/or sodium humate, 0.15-0.2% of polyanionic cellulose, 1-2% of urotropine, 0.1-0.2% of phenol, 0.03-0.05% of sodium tripolyphosphate, 0.02-0.05% of beta-cyclodextrin and/or beta-cyclodextrin derivatives, 0.05-0.08% of thiourea and/or thiourea derivatives and the balance of water.
In the deep profile control channeling-sealing agent, the deep profile control channeling-sealing agent preferably comprises the following raw materials by weight, based on 100% of the total weight of the channeling-sealing agent: 9 to 10% (more preferably 9% or 10%) of potassium humate and/or sodium humate, 0.16 to 0.2% (more preferably 0.16% or 0.2%) of polyanionic cellulose, 1.5 to 1.8% (more preferably 1.5% or 1.8%) of urotropin, 0.14 to 0.16% (more preferably 0.14% or 0.16%) of phenol, 0.04 to 0.045% (more preferably 0.04% or 0.045%) of sodium tripolyphosphate, 0.025 to 0.04% (more preferably 0.025% or 0.04%) of β -cyclodextrin and/or β -cyclodextrin derivatives, 0.06 to 0.08% (more preferably 0.06% or 0.08%) of thiourea and/or thiourea derivatives, and the balance of water.
In the deep profile control channeling sealing agent, the potassium humate and/or the sodium humate are/is used for reacting with other components in the deep part of the stratum, and the formed deep profile control channeling sealing agent has the advantages of good temperature resistance, long gelling time and outstanding plugging capability. In a specific embodiment, the potassium humate and/or sodium humate is preferably potassium humate.
In the deep profile control channeling sealing agent, the polyanionic cellulose has good thermal stability and dispersion suspension property, and mainly has the functions of improving the initial viscosity of a formula system, maintaining the overall stability of the formula system, ensuring the full reaction of the polyanionic cellulose in the deep part of a stratum, ensuring the performance of a medicament and improving the effective period of measures. Preferably, the viscosity of the polyanionic cellulose is > 50 mPas.
In the deep profile control channeling-sealing agent, urotropine and phenol are used as cross-linking agents and react with other components to generate the deep profile control channeling-sealing agent.
In the deep profile control channeling sealing agent, the sodium tripolyphosphate has a good solubilization effect, so that the components are fully mixed, and the stability of a formula system can be further improved due to the outstanding dispersing performance of the sodium tripolyphosphate.
In the deep profile control channeling sealing agent, the beta-cyclodextrin and/or the beta-cyclodextrin derivative can improve the solubility of each component and ensure the stability of a formula system. Preferably, the beta-cyclodextrin and/or beta-cyclodextrin derivative comprises beta-cyclodextrin.
In the deep profile control channeling sealing agent, the thiourea and/or the thiourea derivative is used as a heat stabilizer, so that the deep profile control channeling sealing agent still has good plugging performance in a high-temperature oil reservoir, and the effective period of measures is prolonged to more than one year. Preferably, the thiourea and/or thiourea derivative comprises thiourea.
In the deep profile control channeling sealing agent, the mineralization degree of water is preferably less than or equal to 5000 mg/L. The invention also provides a preparation method of the deep profile control channeling sealing agent, which comprises the following steps:
1. adding potassium humate and/or sodium humate, anionic cellulose and urotropine into water, mixing, and stirring to obtain a mixture;
2. and adding phenol, sodium tripolyphosphate, beta-cyclodextrin and/or beta-cyclodextrin derivatives, thiourea and/or thiourea derivatives into the mixture, and stirring to obtain the deep profile control channeling sealing agent.
According to a particular embodiment of the invention, the stirring time in step 1 is preferably 20 to 30 minutes.
According to a particular embodiment of the invention, the stirring time in step 2 is preferably 10 to 15 minutes.
According to the specific embodiment of the invention, the stability of the deep profile control channeling sealing agent can be improved by controlling the adding sequence of the components, and potassium humate and/or sodium humate, polyanionic cellulose and urotropine can be sequentially added in the step 1; in the step 2, phenol, sodium tripolyphosphate, beta-cyclodextrin and/or beta-cyclodextrin derivatives, and thiourea and/or thiourea derivatives can be added in sequence.
The invention also provides an application method of the deep profile control channeling-sealing agent in the profile control channeling-sealing measures of the gas drive oil reservoir, which comprises the step of injecting the deep profile control channeling-sealing agent into a stratum at the temperature of 80-290 ℃, wherein the injection amount of the profile control channeling-sealing agent is 500m3The above.
In a specific embodiment of the invention, after the deep profile control channeling-sealing agent is injected into a stratum with the temperature of 80-290 ℃, the reaction process of the deep profile control channeling-sealing agent under the stratum condition is as follows: the components are crosslinked between structural units under the action of a composite crosslinking agent (namely urotropine and phenol) in a stratum at the temperature of more than 80 ℃ to generate a compact three-dimensional space structure, and form phenolic resin at high temperature, so that the high-temperature-resistant composite material has excellent plugging strength and temperature-resistant stability.
According to the specific embodiment of the invention, when the deep profile control channeling-sealing agent is used for specific construction, a composite slug construction process can be adopted, namely, the deep profile control channeling-sealing agent with lower concentration is injected firstly, so that the deep profile control channeling-sealing agent enters the deep part of the stratum and is gradually gelled to form a first-stage slug; and injecting the deep profile control channeling sealing agent for multiple times, wherein the concentration of each component in the channeling sealing agent injected each time is gradually increased, and a multi-stage slug is formed in the deep part of the stratum, so that a step-by-step channeling sealing process is finally formed.
According to the specific embodiment of the invention, the concentration of each component in the deep profile control channeling-blocking agent and the dosage of the deep profile control channeling-blocking agent required for forming each stage of slug can be adjusted according to the field situation. Specifically, the gelling strength of the deep profile control channeling-sealing agent in the stratum can be adjusted by adjusting the dosage of sodium humate and/or potassium humate, and the gelling time of the deep profile control channeling-sealing agent in the stratum can be controlled by adjusting the concentration of a composite cross-linking agent (namely urotropine and phenol), so that the deep profile control channeling-sealing process with adjustable effective period and higher strength can be realized.
The beneficial effects of the invention include:
1. the deep profile control channeling sealing agent provided by the invention has good pumping performance, the initial viscosity of the deep profile control channeling sealing agent is low, the pumping performance is good, and the deep profile control channeling sealing agent can be injected by utilizing a steam injection pipe column for construction.
2. The deep profile control channeling sealing agent provided by the invention has long gelling time. Under the condition of high temperature, the gelling time of the temperature-resistant gel solution is adjustable, the requirement of long-distance migration in the stratum (generally more than 1 day) is met, and deep profile control can be realized.
3. The deep profile control channeling sealing agent provided by the invention has good temperature resistance. The gel formed by the deep profile control channeling sealing agent can better maintain the strength within a certain time and temperature range, and the requirement of controlling steam channeling by steam flooding is met.
4. The deep profile control channeling sealing agent provided by the invention has high-temperature sealing rate. The deep profile control channeling blocking agent has good blocking effect on rock cores with different permeability, the blocking rate reaches more than 85%, and the blocking agent shows better blocking effect on rock cores with high permeability.
5. The deep profile control channeling sealing agent provided by the invention is applied to the obvious oil increasing effect in the profile control channeling sealing construction. In the construction operation, the deep profile control channeling sealing agent has good temperature resistance and high plugging strength, can effectively seal channeling of high-permeability channels and large channels, and has obvious yield increasing effect.
Detailed Description
The technical solutions of the present invention will be described in detail below in order to clearly understand the technical features, objects, and advantages of the present invention, but the present invention is not limited to the practical scope of the present invention.
Example 1
The embodiment provides a deep profile control channeling sealing agent, which is prepared by the following steps:
step 1, weighing 9% of potassium humate, 0.16% of polyanionic cellulose (the viscosity is more than 50mPa & s), 1.5% of urotropine, 0.14% of phenol, 0.04% of sodium tripolyphosphate, 0.025% of beta-cyclodextrin and 0.06% of thiourea, and the balance being water with the mineralization degree of 4500mg/L, wherein the total weight of the deep profile control channeling sealing agent is 100%.
And 2, mixing the weighed potassium humate, polyanionic cellulose, urotropine and water in a liquid preparation tank, and stirring for 20 minutes at normal temperature to obtain a mixture.
And 3, sequentially adding the weighed phenol, sodium tripolyphosphate, beta-cyclodextrin and thiourea into the mixture, and stirring at normal temperature for 12 minutes to obtain the deep profile control channeling sealing agent.
Test example 1 Performance test
The deep profile control channeling sealing agent provided in example 1 was tested in terms of initial viscosity, gelling time, gelling strength, gelling speed, thermal stability and high-temperature plugging performance in this test example, respectively.
1.1 initial viscosity of deep Profile control channeling-blocking agent
And testing the on-site pumping performance of the deep profile control channeling-sealing agent. The viscosity of the deep profile control channeling-sealing agent is measured by a Brookfield viscometer, and the initial viscosity of the just-prepared deep profile control channeling-sealing agent is measured to be 115.6 mPas at 20 ℃ and 77.9 mPas at 90 ℃.
In field construction, the initial viscosity of the channeling sealing agent is generally less than 600mPa · s in order to ensure normal injection of the channeling sealing agent. From the above results, it can be seen that the deep profile control channeling sealing agent prepared on the ground has low initial viscosity, good pumpability and easy transportation and injection, and the viscosity of the deep profile control channeling sealing agent prepared in example 1 can further decrease in a high-temperature environment of the formation, so that the deep profile control channeling sealing agent prepared in example 1 can meet the requirements of oil field injection, and is suitable for steam flooding and steam huff and puff deep profile control operation.
1.2 gelling time and gelling strength of deep profile control channeling-sealing agent
And (3) testing the influence of the temperature on the gelling time and the gelling strength of the formulation of the deep profile control channeling sealing agent. The specific test method comprises the following steps: the deep profile control channeling-sealing agent prepared in example 1 is respectively placed in ovens at 260 ℃, 270 ℃, 280 ℃ and 290 ℃, taken out at intervals, and the gelling time and the gelling viscosity are measured, and the performance change of the profile control channeling-sealing agent at different temperatures is examined. Table 1 shows the results of experiments on the gelling time and gelling strength of the deep profile control channeling sealing agent at different temperatures.
TABLE 1
| Temperature/. degree.C | 260 | 270 | 280 | 290 |
| Gelling time/h | 70 | 65 | 53 | 49 |
| Gel viscosity/. times.104mPa·s | 7.1 | 6.9 | 6.1 | 4.8 |
As can be seen from Table 1, when the temperature is increased from 260 ℃ to 290 ℃, the gelling time of the deep profile control channeling sealing agent is reduced from 70h to 49h,meet the requirements of deep profile control. Meanwhile, the gelling viscosity is from 7.1X 10 along with the increase of the temperature4mPas to 4.8X 104mPa · s, the gelling strength gradually decreases. The above shows that the deep profile control channeling-sealing agent has little influence on the deep profile control channeling-sealing agent, and can meet the requirements of steam flooding and steam huff and puff profile control both for general high-temperature oil reservoirs above 80 ℃ and steam flooding oil reservoirs (the gelling viscosity is required to be above 20000mPa & s) developed for a long time above 200 ℃.
1.3 gelling speed of deep profile control channeling-sealing agent
And (3) testing the influence of the temperature on the gelling speed of the formula of the deep profile control channeling sealing agent. The deep profile control channeling-sealing agent is respectively placed in drying ovens at 150 ℃, 180 ℃, 220 ℃ and 260 ℃, the deep profile control channeling-sealing agent is taken out every 24 hours to measure the viscosity, the viscosity change of the gel at different temperatures is examined, and the change situation of the viscosity of the deep profile control channeling-sealing agent along with the time at different temperatures is summarized in table 2.
TABLE 2
The experimental results show that the gel viscosity increases with time at different temperatures. The higher the temperature, the faster the viscosity growth rate, and the maximum viscosity value was between 51000-70000 mPas. Within 72h, the gel viscosity of the deep profile control channeling sealing agent can meet the injection requirement (the general requirement is that the viscosity is 40000 mPas within 72h of injection).
1.4 evaluation of thermal stability of deep Profile control channeling-blocking agent
The thermal stability of the deep profile control channeling sealing agent is tested by the specific method: the deep profile control channeling sealing agent is kept warm in an oven at 260 ℃ for a long time, and the gel strength is tested periodically. The viscosity of the gel is 54000 mPas after aging for 14 days, the viscosity of the gel can still be kept above 45000 mPas after 30 days, and the viscosity of the gel is about 24000 mPas after 60 days, and experimental results show that the gel viscosity shows a general trend of gradually weakening with time under the condition of constant temperature of 260 ℃, but the reduction amplitude of the viscosity is gradually reduced and tends to be stable, the plugging capability is still strong, and the requirement of the field that the viscosity of the profile control channeling sealing agent is higher than 20000 mPas is met.
1.5 high-temperature plugging property of deep profile control channeling sealing agent
And testing the plugging performance of the deep profile control channeling sealing agent under a high-temperature condition. The experimental equipment used included: quartz sand (median particle size 0.15mm-0.30mm), sand filling pipe
A advection pump, a pressure gauge, an electronic balance and a deep profile control channeling sealing agent. The experimental method comprises the following steps: filling quartz sand into a sand filling pipe to prepare an artificial simulated core, measuring the pore volume of the core by a weighing method, and measuring the original permeability of the core; and connecting 3 groups of rock cores in parallel, introducing a 3PV deep profile control channeling sealing agent, waiting for setting at 260 ℃ for 72 hours, and respectively measuring the permeability of each rock core after plugging.
TABLE 3
Table 3 shows the results of the experiments for testing the high temperature plugging performance of the deep profile control channeling-blocking agent, wherein K is1、K2、FRRAnd E respectively represents the original permeability of the rock core, the permeability of the rock core after plugging, a resistance factor and the plugging rate of the channeling sealing agent. As can be seen from table 3, the plugging rate of the deep profile control channeling sealing agent prepared in example 1 can reach 85% or more at a high temperature of 260 ℃. And the original permeability, the permeability after plugging, the resistance factor and the plugging rate of the core 1 are higher than those of the core 2 and the core 3, and the corresponding plugging effect is better than those of the other two cores, which shows that the deep profile control channeling plugging agent has a better plugging effect on the high-permeability core.
Example 2
The embodiment provides a deep profile control channeling sealing agent, which is prepared by the following steps:
step 1, weighing 10% of potassium humate, 0.2% of polyanionic cellulose (the viscosity is more than 50mPa & s), 1.8% of urotropine, 0.16% of phenol, 0.045% of sodium tripolyphosphate, 0.04% of beta-cyclodextrin and 0.08% of thiourea, and taking the total weight of the deep profile control channeling sealing agent as 100%, wherein the balance is water with the mineralization degree of 3860 mg/L.
And 2, mixing the weighed potassium humate, polyanionic cellulose, urotropine and water in a liquid preparation tank in sequence, and stirring for 30 minutes at normal temperature to obtain a mixture.
And 3, sequentially adding the weighed phenol, sodium tripolyphosphate, beta-cyclodextrin and thiourea into the mixture, and stirring at normal temperature for 15 minutes to obtain the deep profile control channeling sealing agent.
Test example 2 Performance test
The deep profile control channeling sealing agent provided in example 2 was tested in terms of initial viscosity, gelling time, gelling strength, gelling speed, thermal stability and high-temperature plugging performance in this test example, respectively.
2.1 initial viscosity of deep Profile control channeling-blocking agent
And testing the on-site pumping performance of the deep profile control channeling-sealing agent. The viscosity of the deep profile control channeling-sealing agent is measured by a Brookfield viscometer, and the initial viscosity of the just-prepared deep profile control channeling-sealing agent is 129.2 mPas at 20 ℃ and 85.6 mPas at 90 ℃.
The results show that the deep profile control channeling sealing agent has low initial viscosity after being prepared on the ground, has good pumping performance, is easy to convey and inject, can further reduce the viscosity in the high-temperature environment of the stratum, can meet the requirement of oil field injection, and is suitable for steam flooding and steam huff and puff deep profile control operation.
2.2 gel formation time and gel formation strength of deep profile control channeling sealing agent
And (3) testing the influence of the temperature on the gelling time and the gelling strength of the formulation of the deep profile control channeling sealing agent. Table 4 shows the results of experiments on gelling time and gelling strength of the profile control channeling-sealing agent under different temperature conditions.
TABLE 4
| Temperature/. degree.C | 260 | 270 | 280 | 290 |
| Gelling time/h | 68 | 62 | 50 | 46 |
| Gel viscosity/. times.104mPa·s | 7.5 | 7.2 | 6.4 | 5.2 |
From table 4, it can be seen that when the temperature is increased from 260 ℃ to 290 ℃, the gelling time of the deep profile control channeling sealing agent is reduced from 68h to 46h, and the deep profile control requirement is met. Meanwhile, the gelling viscosity is from 7.5 multiplied by 10 along with the increase of the temperature4mPas to 5.2X 104mPa · s, the gelling strength gradually decreases. The above shows that the influence of temperature on the temperature-resistant gel is small, and the deep profile control channeling sealing agent can still meet the requirements of steam flooding and steam huff and puff profile control at high temperature.
2.3 Effect of temperature on gelation Rate
And (3) testing the influence of the temperature on the gelling speed of the deep profile control channeling sealing agent. The deep profile control channeling sealing agent is respectively placed in drying ovens of 150 ℃, 180 ℃, 220 ℃ and 260 ℃, the deep profile control channeling sealing agent is taken out every 24 hours to measure the viscosity, the viscosity change of the gel at different temperatures is examined, and the test results are summarized in table 5.
TABLE 5
The experimental results show that the gel viscosity increases with time at different temperatures. The higher the temperature, the faster the viscosity growth, with a maximum viscosity of 53000-71000 mPas. Within 72h, the gel viscosity can meet the injection requirement.
2.4 evaluation of thermal stability
The thermal stability of the deep profile control channeling sealing agent is tested by the specific method: the deep profile control channeling sealing agent is kept warm in an oven at 260 ℃ for a long time, and the gel strength is tested periodically. The viscosity of the gel is 57000 mPas after aging for 14 days, the viscosity of the gel can still be maintained above 48500 mPas after 30 days, and the viscosity of the gel is about 28600 mPas after 60 days, and experimental results show that under the condition of constant temperature of 260 ℃, the viscosity of the gel is in a general trend of gradually weakening along with time, but the reduction amplitude of the viscosity is gradually reduced and tends to be stable, the plugging capability is still strong, and the requirement of the field that the viscosity of a profile control channeling sealing agent is higher than 20000 mPas is met.
2.5 high temperature plugging Properties
And testing the plugging performance of the deep profile control channeling sealing agent under a high-temperature condition. The experimental equipment used included: quartz sand (median particle size 0.15mm-0.30mm), sand filling pipe
A advection pump, a pressure gauge, an electronic balance and a deep profile control channeling sealing agent. The experimental method comprises the following steps: filling quartz sand into a sand filling pipe to prepare an artificial simulated core, measuring the pore volume of the core by a weighing method, and measuring the original permeability of the core; and connecting 3 groups of rock cores in parallel, introducing a 3PV deep profile control channeling sealing agent, waiting for setting at 260 ℃ for 72 hours, and respectively measuring the permeability of each rock core after plugging.
TABLE 6
Table 6 shows the results of the high-temperature plugging performance test for the deep profile control channeling-blocking agent. As can be seen from table 6, the plugging rate of the profile control channeling-blocking agent prepared in example 2 can reach over 86% under the high-temperature condition of 260, the original permeability, the permeability after plugging, the resistance factor and the plugging rate of the core 1 are higher than those of the core 2 and the core 3, and the corresponding plugging effect is superior to those of the other two cores, which indicates that the deep profile control channeling-blocking agent has a better plugging effect on a high-permeability core.
Example 3
The embodiment provides the application of the deep profile control channeling-sealing agent in profile control channeling sealing of a thick oil steam flooding injection well. Take Liaohe oil field steam injection well Q20 well as an example. The well has uneven longitudinal steam absorption, high-permeability channels and large channels on the plane, and the production effect of corresponding well groups is poor. In order to effectively control the adverse effect caused by the steam channeling phenomenon, the deep profile control channeling sealing agent prepared in example 2 is used for implementing the profile control channeling sealing measures, so that the production effect is improved.
The concrete construction process is as follows: at the formation temperature of 240 ℃, 550m3The deep profile control channeling sealing agent is sequentially injected into the stratum through a 5-section plug injection process.
After the measures are taken, the steam injection pressure of the well rises by 2.1MPa, the steam absorption of a high permeability layer is reduced from 88.5 percent to 53.6 percent, the steam absorption of a medium and low permeability layer is improved from 11.5 percent to 46.4 percent, and the longitudinal utilization degree is obviously improved; the steam channeling channel on the plane is effectively blocked, 4 effective directions are newly added, the average daily oil production of the well group is increased to 30.6t from 24.2t of the last period, the measure validity period 385d is achieved, the oil is increased by 2464t, and the oil increasing effect is obvious.
The performance evaluation shows that the deep profile control channeling sealing agent provided by the invention has good pumping performance, long gelling time, good temperature resistance, high plugging rate under high temperature conditions, obvious oil increasing effect in profile control channeling sealing construction and can be applied to deep profile control channeling sealing of a steam-drive oil reservoir.
Claims (10)
1. The deep profile control channeling-sealing agent comprises the following raw materials by taking the total weight of the channeling-sealing agent as 100 percent:
8-10% of potassium humate and/or sodium humate; polyanionic cellulose 0.15-0.2%; 1-2% of urotropin; 0.1 to 0.2 percent of phenol; sodium tripolyphosphate, 0.03-0.05%; beta-cyclodextrin and/or beta-cyclodextrin derivatives, 0.02-0.05%; thiourea and/or thiourea derivatives, 0.05-0.08%; the balance being water.
2. The deep profile control channeling agent of claim 1, wherein the beta-cyclodextrin and/or beta-cyclodextrin derivative comprises beta-cyclodextrin.
3. The deep profile control channeling agent according to claim 1 or 2, wherein the thiourea and/or thiourea derivative comprises thiourea.
4. The deep profile control channeling sealing agent according to any one of claims 1 to 3, wherein the degree of mineralization of water is less than or equal to 5000 mg/L.
5. The deep profile control channeling agent according to any one of claims 1-4, wherein the polyanionic cellulose has a viscosity of > 50 mPa-s.
6. The deep profile control channeling sealing agent according to any one of claims 1 to 5, wherein the raw material composition of the deep profile control channeling sealing agent comprises, based on the total weight of the channeling sealing agent being 100%:
9-10% of potassium humate and/or sodium humate; polyanionic cellulose 0.16-0.2%; 1.5 to 1.8 percent of urotropine; 0.14 to 0.16 percent of phenol; 0.04-0.045% of sodium tripolyphosphate; beta-cyclodextrin and/or beta-cyclodextrin derivatives 0.025-0.04%; 0.06-0.08% of thiourea and/or thiourea derivative; the balance being water.
7. The deep profile control channeling-sealing agent according to claim 6, wherein the deep profile control channeling-sealing agent comprises the following raw materials by weight of 100% of the total weight of the channeling-sealing agent:
9% of potassium humate and/or sodium humate; polyanionic cellulose, 0.16%; 1.5 percent of urotropin; phenol, 0.14%; sodium tripolyphosphate, 0.04%; beta-cyclodextrin and/or beta-cyclodextrin derivatives 0.025%; 0.06% of thiourea and/or thiourea derivatives; the balance being water.
8. The deep profile control channeling-sealing agent according to claim 6, wherein the raw material composition of the deep profile control channeling-sealing agent comprises, based on the total weight of the channeling-sealing agent being 100%:
10% of potassium humate and/or sodium humate; polyanionic cellulose, 0.2%; 1.8 percent of urotropin; 0.16 percent of phenol; sodium tripolyphosphate, 0.045%; beta-cyclodextrin and/or beta-cyclodextrin derivatives, 0.04%; thiourea and/or thiourea derivatives, 0.08%; the balance being water.
9. The process for preparing the deep profile control channeling-sealing agent of any one of claims 1-8, comprising:
mixing potassium humate and/or sodium humate, polyanionic cellulose, urotropine and water to obtain a mixed solution;
and step two, adding phenol, sodium tripolyphosphate, beta-cyclodextrin and/or beta-cyclodextrin derivatives, thiourea and/or thiourea derivatives into the mixed solution, and mixing to obtain the deep profile control channeling-sealing agent.
10. The application method of the deep profile control channeling-sealing agent in the profile control channeling-sealing measures of the steam-flooding oil reservoir, which comprises the step of injecting the deep profile control channeling-sealing agent into a stratum at the temperature of 80-290 ℃, wherein the injection amount of the deep profile control channeling-sealing agent is 500m3The above.
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