CN113653475A - Treatment and utilization method of foam gas-displacement channel - Google Patents
Treatment and utilization method of foam gas-displacement channel Download PDFInfo
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- 239000006260 foam Substances 0.000 title claims abstract description 91
- 238000000034 method Methods 0.000 title claims abstract description 47
- 238000006073 displacement reaction Methods 0.000 title claims abstract description 13
- 238000011282 treatment Methods 0.000 title description 21
- 238000004519 manufacturing process Methods 0.000 claims abstract description 151
- 239000007789 gas Substances 0.000 claims abstract description 144
- 238000002347 injection Methods 0.000 claims abstract description 118
- 239000007924 injection Substances 0.000 claims abstract description 118
- 230000005465 channeling Effects 0.000 claims abstract description 115
- 239000000243 solution Substances 0.000 claims abstract description 56
- 239000004094 surface-active agent Substances 0.000 claims abstract description 27
- 239000007788 liquid Substances 0.000 claims abstract description 16
- 230000008569 process Effects 0.000 claims abstract description 9
- 239000000700 radioactive tracer Substances 0.000 claims description 78
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 43
- 238000010790 dilution Methods 0.000 claims description 19
- 239000012895 dilution Substances 0.000 claims description 19
- DBMJMQXJHONAFJ-UHFFFAOYSA-M Sodium laurylsulphate Chemical compound [Na+].CCCCCCCCCCCCOS([O-])(=O)=O DBMJMQXJHONAFJ-UHFFFAOYSA-M 0.000 claims description 16
- 230000015572 biosynthetic process Effects 0.000 claims description 12
- 238000002791 soaking Methods 0.000 claims description 12
- 239000003129 oil well Substances 0.000 claims description 11
- 229940083575 sodium dodecyl sulfate Drugs 0.000 claims description 7
- 235000019333 sodium laurylsulphate Nutrition 0.000 claims description 7
- 239000003546 flue gas Substances 0.000 claims description 4
- 238000012544 monitoring process Methods 0.000 claims description 4
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 claims description 3
- 238000004364 calculation method Methods 0.000 claims description 3
- 239000000203 mixture Substances 0.000 claims description 3
- NSTREUWFTAOOKS-UHFFFAOYSA-N 2-fluorobenzoic acid Chemical compound OC(=O)C1=CC=CC=C1F NSTREUWFTAOOKS-UHFFFAOYSA-N 0.000 claims description 2
- GVGUFUZHNYFZLC-UHFFFAOYSA-N dodecyl benzenesulfonate;sodium Chemical compound [Na].CCCCCCCCCCCCOS(=O)(=O)C1=CC=CC=C1 GVGUFUZHNYFZLC-UHFFFAOYSA-N 0.000 claims description 2
- 229940080264 sodium dodecylbenzenesulfonate Drugs 0.000 claims description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 abstract description 8
- 239000003345 natural gas Substances 0.000 abstract description 3
- 238000009491 slugging Methods 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 83
- 239000000295 fuel oil Substances 0.000 description 24
- 239000003795 chemical substances by application Substances 0.000 description 14
- 230000033558 biomineral tissue development Effects 0.000 description 12
- 230000000052 comparative effect Effects 0.000 description 11
- 238000011084 recovery Methods 0.000 description 9
- 238000000605 extraction Methods 0.000 description 8
- 230000035699 permeability Effects 0.000 description 7
- WPYMKLBDIGXBTP-UHFFFAOYSA-N benzoic acid Chemical compound OC(=O)C1=CC=CC=C1 WPYMKLBDIGXBTP-UHFFFAOYSA-N 0.000 description 6
- 238000009933 burial Methods 0.000 description 6
- 239000010779 crude oil Substances 0.000 description 6
- 238000011161 development Methods 0.000 description 6
- 230000018109 developmental process Effects 0.000 description 6
- 239000012530 fluid Substances 0.000 description 6
- 239000008398 formation water Substances 0.000 description 6
- 230000000903 blocking effect Effects 0.000 description 5
- 230000008859 change Effects 0.000 description 5
- 230000037361 pathway Effects 0.000 description 5
- JLZVIWSFUPLSOR-UHFFFAOYSA-N 2,3-difluorobenzoic acid Chemical compound OC(=O)C1=CC=CC(F)=C1F JLZVIWSFUPLSOR-UHFFFAOYSA-N 0.000 description 4
- 229910052708 sodium Inorganic materials 0.000 description 4
- 239000011734 sodium Substances 0.000 description 4
- 239000002131 composite material Substances 0.000 description 3
- 238000009792 diffusion process Methods 0.000 description 3
- 230000000694 effects Effects 0.000 description 3
- 238000005516 engineering process Methods 0.000 description 2
- 238000005065 mining Methods 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 230000001186 cumulative effect Effects 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 230000009969 flowable effect Effects 0.000 description 1
- 239000004088 foaming agent Substances 0.000 description 1
- 230000002401 inhibitory effect Effects 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 238000005067 remediation Methods 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 239000007790 solid phase Substances 0.000 description 1
- 239000013589 supplement Substances 0.000 description 1
- 238000002834 transmittance Methods 0.000 description 1
- 238000005406 washing Methods 0.000 description 1
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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
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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
- E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium
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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
- E21B47/00—Survey of boreholes or wells
- E21B47/10—Locating fluid leaks, intrusions or movements
- E21B47/11—Locating fluid leaks, intrusions or movements using tracers; using radioactivity
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Abstract
The invention relates to the technical field of oil and natural gas exploitation, in particular to a method for treating and utilizing a foam gas-displacement channel, which comprises the following steps: s1, judging the position of a gas channeling channel and calculating the volume; s2, injecting foam, namely simultaneously injecting a surfactant solution into an injection well and a production well of a well group with gas channeling to form a liquid slug, then simultaneously injecting gas into the injection well and the production well, and alternately slugging the surfactant solution and the gas to form a foam system underground; s3, stewing, namely closing the well mouths of the injection well and the production well simultaneously to conduct stewing operation after the step S2 is completed; and S4, well opening production. The invention adopts the method of synchronously injecting foam into the injection well and the production well for huff and puff, and because the injection and production relationship of the injection well and the production well does not exist, the foam can not directly reach the production well from the injection well along the gas channeling channel in the injection process, and the gas channeling channel is effectively treated.
Description
Technical Field
The invention relates to the technical field of oil and natural gas exploitation, in particular to a method for treating and utilizing a foam gas-displacement channel.
Background
With the continuous development of oil and gas fields, secondary oil recovery and even tertiary oil recovery are in operationThe proportion occupied in mining is getting bigger and bigger. The foam flooding is used as one of tertiary oil recovery modes, and has excellent plugging performance and oil-water selectivity. Foam flooding refers to the reaction of N2、CO2And natural gas, etc. are mixed with a foaming agent solution to form foam, and the foam is used as a displacement medium in oil extraction to perform oil extraction. Foam flooding is an important development direction for oil and gas field development at present. The foam fluid can enter the pores of the low permeable layer and various structures to improve the swept area of oil displacement and improve the microscopic swept efficiency of the foam fluid. Meanwhile, the foam can effectively reduce the tension of an oil-water interface, so that the contact angle of oil to the surface of the rock is increased, and the oil displacement efficiency of the oil displacement agent is improved. In addition, the injected foam can increase formation pressure and supplement formation energy. The above is the main mechanism for enhanced oil recovery by foam flooding. Meanwhile, the foam has the characteristics of selective water blocking, no oil blocking during water blocking and low blocking height, and is generally accepted by technical personnel and management personnel engaged in foam flooding research. The foam flooding technology has very wide prospect for oil field development. For air foam flooding, N in recent years2Foam flooding, CO2The theoretical researches of foam flooding, flue gas foam flooding and the like are gradually and deeply researched.
The foam flooding agent not only has a high-strength profile control function, but also has an oil washing function. The oil displacement agent can greatly improve the swept volume and the oil displacement efficiency of the oil reservoir while protecting the oil reservoir, and the recovery ratio is improved accordingly. However, the gas channeling phenomenon during the production method adopting foam flooding can affect the production effect. When specific gas is injected in the oilfield development process, due to the heterogeneity of the stratum, the advance of oil-gas interfaces between layers and planes is usually uneven, which often causes a gas channeling channel to be generated in a hypertonic layer, namely a gas channeling phenomenon. This results in the injected gas seeping directly along the blow-by gas channel and thus reducing swept volume. The problem of gas channeling is common in practical applications, which results in reduced flooding efficiency and sweep efficiency. The gas channeling phenomenon in the foam flooding process not only reduces the sweep coefficient of foam flooding, but also causes the gas-oil ratio at the outlet of the produced well to be too high, thereby affecting the pump efficiency, even generating gas lock in serious conditions, causing the well pump to be incapable of normally operating, and causing the oil field to be incapable of normally producing.
Chinese patent document CN105781512A (application No. 201610243248X) discloses a method for inhibiting huff and puff gas channeling of composite thermal fluid by using a foam-assisted temperature-sensitive phase-change system, which mainly utilizes a temperature-sensitive phase-change system. The system has the characteristic of enabling the system to be transformed from a liquid phase flowable system to a solid phase system along with the high energy of the temperature. And the foam fluid can assist in blocking the gas channeling in the composite hot fluid. The method can effectively improve the single well recovery rate of the oil field and provide technical support for prolonging the throughout life. However, the anti-channeling method has limited effect and can only be used for plugging a near wellbore zone. In addition, the oilfield gas channeling conflicts become more severe as the oil well's composite thermal fluid throughput rounds increase.
Disclosure of Invention
Aiming at the defects of the prior art, the invention provides a method for treating and utilizing a foam gas-displacement channel.
The invention adopts the mining method that the injection well and the extraction well are integrally injected with foam for huff and puff, and the injection well and the extraction well are simultaneously injected and simultaneously extracted in the process of treating the gas channeling channel, thereby improving the stratum energy of an oil reservoir and the recovery ratio of subsequent oil reservoir extraction and finally treating the gas channeling channel.
In order to achieve the purpose, the invention adopts the following technical scheme:
a method for treating and utilizing a foam gas-displacement channel comprises the following steps:
s1, judging the position of a gas channeling channel and calculating the volume,
in the foam flooding process, after a mixed tracer is injected into an injection well into a foam system, in a monitoring period, a production well with the detected tracer is found, namely, the fact that a gas channeling channel exists between the production well and the injection well is explained, the tracer concentration of the production well with the gas channeling channel is detected to obtain the output condition of the tracer, and the volume of the gas channeling channel is calculated according to the detected tracer concentration and well bore parameters;
s2, injecting foam into the mixture,
firstly, simultaneously injecting surfactant solution into an injection well and a production well of a well group with gas channeling to form a liquid slug, then simultaneously injecting gas into the injection well and the production well, and alternately injecting surfactant solution and gas of the slug to form foam underground;
s3, stewing the well,
after the step S2 is completed, closing the well heads of the injection well and the production well at the same time for soaking operation;
s4, opening a well to produce,
and after the pressure difference between the injection well and the production well is minimum, namely the wellhead pressure is stable, simultaneously opening the injection well and the production well for well opening production, when the total oil production of the injection well and the production well is lower than 2t/d, ending the huff and puff round, restoring the balance of the stratum at the moment, and repeating the steps S2 and S3 to perform the huff and puff of the next round.
The tracer in the step S1 is a fluorobenzoic acid tracer, the injection concentration range of the tracer is 350 mg/L-550 mg/L, and the injection speed of the tracer solution is 5 multiplied by 103-10×103L/h, injecting the tracer solution until the tracer is detected in the monitoring period.
The method of calculating the volume of the gas channeling passage in step S1 is specifically as follows:
fitting the actual output curve peak concentration of the tracer by adjusting the dilution coefficient alpha of the shaft to obtain the dilution coefficient alpha of the shaft of the gas channeling channel of the target well group, and obtaining the water yield Q of the target oil well according to the water yield Q of the target oil wellwAnd calculating the dilution coefficient alpha of the shaft to obtain the water yield Q of the gas channeling channel between the wellscI.e. Qc＝Qw×α，QwAnd QcAll units of (are m)3D, the volume V of the gas channeling channel is V ═ Qc×tpWherein t ispIs the peak time of the tracer, and has the unit of d, and the unit of V is m3。
In step S2, the surfactant is one or more selected from sodium dodecylbenzene sulfonate, sodium dodecylsulfate, etc.
In the step S2, the total volume of injected foam, that is, the total volume of injected gas and surfactant solution, is 1.2 to 1.5 times the volume of the gas channeling passage calculated in the step S1, and the volume of injected foam is more than the volume of the gas channeling passage, so that the formation pressure can be increased, the formation energy can be increased, and the oil recovery efficiency can be improved.
In the step S2, the injected gas is CO2、CH4、N2And flue gas.
In the step S2, the injection speed of the surfactant solution is 10t/d to 100t/d, and the gas injection speed is 2 x 104sm3/d～10×104sm3/d，sm3Is the gas volume unit under standard conditions; the volume ratio of the surfactant solution injected in each time to the gas injected is 1: 500-1: 5000.
In step S2, controlling the foam mass of the foam under the formation condition to be 60-80%, wherein the calculation formula of the foam mass is as follows:
in the formula: r is the foam quality; vGIs the volume of gas, m3；VLVolume of surfactant solution, m3；VFM is the total volume of the solution3. When the injected foam mass is 60-80%, the foam is dense, the friction resistance is large, the viscosity is high, and the foam is more stable. This enables better diffusion of the foam all around, and thus better utilization of the gas channeling path.
The invention has the beneficial effects that:
1) the invention adopts the treatment method of synchronously injecting foam into the injection well and the production well for huff and puff, and because the injection and production relationship of the injection well and the production well does not exist, the foam can not directly reach the production well from the injection well along the gas channeling channel in the injection process, and the gas channeling channel is effectively treated;
2) according to the invention, by adopting the treatment method of synchronously injecting the foam into the injection well and the extraction well, the pressure of the oil reservoir is increased in the foam injection process, so that the foam in the gas channeling channel is expanded outwards, and the swept range is increased, thereby improving the recovery ratio, and effectively utilizing the gas channeling channel while treating the gas channeling channel so as to improve the exploitation efficiency;
3) compared with the prior art that high-viscosity plugging agents are injected into a near wellbore zone to plug a gas channeling channel, the technology adjusts the injection-production relationship of a well group, and can fundamentally solve the problem of foam gas channeling.
Drawings
FIG. 1 is a schematic view of an embodiment of the present invention, in which arrows indicate the direction of diffusion of the foam;
wherein, 1, an injection well; 2. a production well; 3. a gas channeling channel.
Detailed Description
The invention is further illustrated with reference to the following figures and examples.
As shown in fig. 1, the present invention provides a method for treating and utilizing a blow-by gas passage of foam, wherein arrows in the figure indicate the direction of diffusion of foam, the method specifically comprises the steps of,
s1, judging the position of a gas channeling channel and calculating the volume,
in the foam flooding process, tracer solution is mixed in a foam system and injected into an injection well 1, the injection concentration of the tracer solution ranges from 350mg/L to 550mg/L, and the injection flow rate of the tracer solution is 5 multiplied by 103～10×103L/h, in a monitoring period after tracer solution is injected, finding a production well 2 with detected tracer, namely, indicating that a gas channeling channel 3 exists between the production well 2 and an injection well 1, detecting the concentration of the tracer in the production well 2 with the gas channeling channel 3 and obtaining the output condition of the tracer, calculating the volume of the gas channeling channel according to the detected concentration of the tracer and wellbore parameters, wherein the specific volume calculation method comprises the steps of fitting the actual peak concentration of a production curve of the tracer by adjusting the dilution coefficient alpha of the wellbore to obtain the wellbore dilution coefficient alpha of the gas channeling channel 3 of a target well group, and obtaining the water yield Q of the target oil wellwAnd calculating the dilution coefficient alpha of the shaft to obtain the water yield Q of the gas channeling passage 3 between the wellscI.e. Qc＝Qw×α，QwAnd QcAll units of (are m)3D, the volume V of the gas channeling channel 3 is V ═ Qc×tpWherein t ispIs the peak time of the tracer, and has the unit of d, and the unit of V is m3；
S2, injecting foam into the mixture,
injection well in gas channeling first group of wellsSimultaneously injecting a surfactant solution into the production well to form a liquid slug, wherein the mass concentration of the surfactant in the injected surfactant solution is 0.1-0.5%, the injection speed of the surfactant solution is 10-100 t/d, and then simultaneously injecting gas into the injection well and the production well, wherein the gas is selected from CO2、CH4、N2One of the flue gases, the gas injection speed is 2 x 104sm3/d～10×104sm3/d，sm3Is the gas volume unit under standard conditions; the volume ratio of the surfactant solution injected each time to the gas injected is 1: 500-1: 5000; the injected surfactant solution and gas are collectively called as foam, and the total amount of the injected foam is 1.2 to 1.5 times the volume of the gas channeling passage 3 calculated in step S1, while controlling the foam mass under the formation conditions to be 60 to 80%, wherein the foam mass is calculated by the formula
In the formula: r is the foam quality; vGIs the volume of gas, m3；VLIs the volume of liquid, m3；VFM is the total volume of the solution3；
S3, stewing the well,
after the step S2 is completed, closing the well heads of the injection well 1 and the production well 2 at the same time for stewing operation;
s4, opening a well to produce,
and after the pressure of the well head is stabilized, simultaneously opening the injection well and the extraction well for well opening production, ending the huffing and puff round when the oil production of the two wells is lower than 2t/d, restoring the balance of the stratum at the moment, and repeating the steps S2 and S3 to perform the huffing and puff of the next round.
Application example:
the experimental oil field of the application example is a certain common heavy oil reservoir, has the characteristics of deep burial, medium and low permeability, serious heterogeneity, heavy oil and high mineralization degree, and is a deep common heavy oil reservoir. The average reservoir temperature was 78 ℃. The oil saturation of the reservoir is 58.6 percent, the reservoir depth is 2700-Transmittance 205 mD. The oil reservoir pressure is 27-31MPa, and the heavy oil density is 0.966g/cm3The viscosity of the thickened oil at 50 ℃ is 286 mPa.s, and the mineralization degree of the formation water is 8-9 multiplied by 104mg/L. For the presence of gas channeling between injection wells a2-203 and production wells a 2-121. The distance between the injection well and the production well is 125 m. The daily injection amount of A2-203 was 137m3The daily liquid yield of A2-121 is 124m3(d) the average water content was 88.0%.
The treatment method of the gas channeling channel comprises the following steps:
s1, judging the position of a gas channeling channel and calculating the volume: preparing 2, 6-sodium difluorobenzoate solution with water, injecting 2, 6-sodium difluorobenzoate into injection well (A2-203) at tracer solution injection concentration of 480mg/L and injection flow rate of 7 × 103L/h, and the injection time is 1 d. The tracer concentration of each production well was monitored in real time and it was found that the production wells (i.e., a2-121) were detected with the tracer, indicating that a gas channeling pathway existed between the injection well and the production well. And then detecting the concentration of the tracer agent of the production well and obtaining the actual output condition of the tracer agent. The peak time of the tracer is 52d according to the actual production condition of the concentration of the tracer. Firstly, fitting the actual production curve peak concentration of the tracer by adjusting the dilution coefficient of the shaft. Thereby obtaining a wellbore dilution factor alpha of 0.35 for the target well group blow-by passage. Thereby calculating and obtaining the water yield Q in the cross flow channel between the wellscIs 38.192m3And d. The volume V of the channeling channel is 1985.98m by multiplying the water yield in the channeling channel by the peak time of the tracer3；
1. And (3) calculating the water yield of the target oil well: qw＝124×88.0％＝109.12m3/d
2. Calculating the water production in the gas channeling channel between wells: qc＝109.12×0.35＝38.19m3/d
3. Calculating the volume of the gas channeling channel: v38.192 × 52 m 1985.98m3
S2, injecting foam, simultaneously injecting Sodium Dodecyl Sulfate (SDS) solution with the mass concentration of 0.3% into an injection well and a production well of the gas channeling well group to form a liquid slug, and simultaneously injecting N2Total amount of SDS solution injected 774.54m3The injection speed is 65t/d, N2Total amount of 2204.44m under formation conditions3And the injection speed is 7 x 104sm3The ratio of the volume of the surfactant solution injected to the volume of the gas injected per time was 1: 2500. The total amount of foam injected was 2978.98m31.5 times the volume of the gas channeling passage, wherein the mass of the foam is
S3, soaking: after the step S2 is completed, closing the wellhead of the injection well and the production well at the same time to carry out soaking operation;
s4, well opening production: and when the change rate of the wellhead pressure is 0.01MPa/d, simultaneously opening the injection well and the production well for well opening production, ending the huff and puff round when the oil production of the two wells is lower than 2t/d, restoring the balance of the stratum at the moment, and repeating the steps S2 and S3 for huff and puff of the next round.
Before the gas channeling channel is treated, the average daily oil production of the produced wells is only 3.27t/d due to the gas channeling channel between the two wells, and effective production cannot be carried out. After the treatment method is adopted, the total daily oil yield of the injection well and the production well reaches 19.18t/d to the maximum, the production is carried out for 103 days in the effective throughput period, and the yield increase crude oil is 1966.52t in an accumulated mode, so that a better development effect is achieved.
Comparative example 1:
the experimental oil field of the comparative example is a certain common heavy oil reservoir, has the characteristics of deep burial, medium and low permeability, serious heterogeneity, heavy oil and high mineralization degree, and is a deep common heavy oil reservoir. The average reservoir temperature was 78 ℃. The oil saturation of the reservoir is 58.6 percent, the reservoir depth is 2700-. The oil reservoir pressure is 27-31MPa, and the heavy oil density is 0.966g/cm3The viscosity of the thickened oil at 50 ℃ is 286 mPa.s, and the mineralization degree of the formation water is 8-9 multiplied by 104mg/L. For the presence of gas channeling between injection wells a2-42 and production wells a 2-113. The distance between the injection well and the production well is 113 m. The daily injection amount of A2-42 was 129m3Daily output of/d, A2-113The liquid volume is 114m3(d) the average water content was 90.0%.
The treatment method of the gas channeling channel comprises the following steps:
s1, judging the position of a gas channeling channel and calculating the volume: preparing 2, 6-difluorosodium benzoate solution with water, injecting 2, 6-difluorosodium benzoate into injection well (A2-42) at tracer solution injection concentration of 465mg/L and injection flow rate of 7.5 × 103L/h, and the injection time is 1 d. The tracer concentration of each production well was monitored in real time and it was found that the production wells (i.e., a2-113) were detected with the tracer, indicating that a gas channeling pathway existed between the injection well and the production well. And then detecting the concentration of the tracer agent of the production well and obtaining the actual output condition of the tracer agent. And according to the actual production condition of the concentration of the tracer, the peak time of the tracer is 46 d. Firstly, fitting the actual production curve peak concentration of the tracer by adjusting the dilution coefficient of the shaft. Thereby obtaining a wellbore dilution factor alpha of 0.32 for the target well group blow-by passage. Thereby calculating and obtaining the water yield Q in the cross flow channel between the wellscIs 32.83m3And d. The volume V of the channeling channel is 1510.27m by multiplying the water yield in the channeling channel by the peak time of the tracer3；
1. And (3) calculating the water yield of the target oil well: qw＝114×90.0％＝102.60m3/d
2. Calculating the water production in the gas channeling channel between wells: qc＝102.60×0.32＝32.83m3/d
3. Calculating the volume of the gas channeling channel: v32.832 × 46 m 1510.27m3
S2, injecting foam, injecting a Sodium Dodecyl Sulfate (SDS) solution with the mass concentration of 0.3% into an injection well of the gas channeling well group to form a liquid slug, and then injecting N2Total amount of SDS solution injected 702.28m3The injection speed is 65t/d, N2Total amount of 1563.13m under formation conditions3And the injection speed is 7 x 104sm3The ratio of the volume of the surfactant solution injected to the volume of the gas injected per time was 1: 2500. The total amount of foam injected was 2265.41m31.5 times of the volume of the gas channeling passage, wherein the mass of the foam is 69.0%,
s3, soaking: after the step S2 is completed, closing the wellhead of the injection well and the production well at the same time to carry out soaking operation;
s4, well opening production: and when the change rate of the wellhead pressure is 0.01MPa/d, simultaneously opening the injection well and the production well for well opening production, ending the huff and puff round when the oil production of the two wells is lower than 2t/d, restoring the balance of the stratum at the moment, and repeating the steps S2 and S3 for huff and puff of the next round.
Before the gas channeling channel is treated, the average daily oil production of the produced well is only 3.86t/d due to the gas channeling channel between the two wells, and effective production cannot be carried out. After the treatment method is adopted, the total daily oil yield of the injection well and the production well reaches 16.23t/d at most, 98 days are produced in the effective throughput period, and the increased crude oil is 1352.43t in an accumulated mode.
Comparative example 2:
the experimental oil field of the comparative example is a certain common heavy oil reservoir, has the characteristics of deep burial, medium and low permeability, serious heterogeneity, heavy oil and high mineralization degree, and is a deep common heavy oil reservoir. The average reservoir temperature was 78 ℃. The oil saturation of the reservoir is 58.6 percent, the reservoir depth is 2700-. The oil reservoir pressure is 27-31MPa, and the heavy oil density is 0.966g/cm3The viscosity of the thickened oil at 50 ℃ is 286 mPa.s, and the mineralization degree of the formation water is 8-9 multiplied by 104mg/L. For the case of gas channeling between injection wells a204-19 and production wells a 204-32. The distance between the injection well and the production well is 134 m. The daily injection amount of A204-19 is 147m3The daily liquid yield of A204-32 is 129m3(d) the average water content was 89.5%.
The treatment method of the gas channeling channel comprises the following steps:
s1, judging the position of a gas channeling channel and calculating the volume: preparing 2, 6-difluorosodium benzoate solution with water, injecting 2, 6-difluorosodium benzoate into injection well (A204-19) at tracer solution injection concentration of 470mg/L and injection flow rate of 7.8 × 103L/h, and the injection time is 1 d. To pairThe tracer concentration of each production well is monitored in real time and it is found that the production well (i.e., a204-32) is detected with the tracer, indicating that a gas channeling pathway exists between the injection well and the production well. And then detecting the concentration of the tracer agent of the production well and obtaining the actual output condition of the tracer agent. According to the actual production condition of the concentration of the tracer, the peak time of the tracer is 47 d. Firstly, fitting the actual production curve peak concentration of the tracer by adjusting the dilution coefficient of the shaft. Thereby obtaining a wellbore dilution factor alpha of 0.32 for the target well group blow-by passage. Thereby calculating and obtaining the water yield Q in the cross flow channel between the wellscIs 36.9456m3And d. The volume V of the channeling channel is 2007.762m by multiplying the water yield in the channeling channel by the peak time of the tracer3；
1. And (3) calculating the water yield of the target oil well: qw＝129×89.5％＝115.46m3/d
2. Calculating the water production in the gas channeling channel between wells: qc＝115.455×0.32＝36.94m3/d
3. Calculating the volume of the gas channeling channel: v36.9456 × 47 ═ 1736.44m3
S2, injecting foam, injecting a Sodium Dodecyl Sulfate (SDS) solution with the mass concentration of 0.3% into a production well of the gas channeling well group to form a liquid slug, and then injecting N2Total amount of SDS solution injected 764.56m3The injection speed is 65t/d, N2Total amount of 2046.31m under formation conditions3And the injection speed is 7 x 104sm3The ratio of the volume of the surfactant solution injected to the volume of the gas injected per time was 1: 2500. The total amount of foam injected was 2431.02m31.4 times of the volume of the gas channeling passage, wherein the mass of the foam is 72.8 percent,
s3, soaking: after the step S2 is completed, closing the wellhead of the injection well and the production well at the same time to carry out soaking operation;
s4, well opening production: and when the change rate of the wellhead pressure is 0.01MPa/d, simultaneously opening the injection well and the production well for well opening production, ending the huff and puff round when the oil production of the two wells is lower than 2t/d, restoring the balance of the stratum at the moment, and repeating the steps S2 and S3 for huff and puff of the next round.
Before the gas channeling channel is treated, the average daily oil production of the produced well is only 3.12t/d due to the gas channeling channel between the two wells, and effective production cannot be carried out. After the treatment method is adopted, the total daily oil yield of the injection well and the production well reaches up to 13.56t/d, and the production is carried out for 109 days in the effective throughput period, and the increased crude oil is 1269.85 t.
Comparative example 3:
the experimental oil field of the comparative example is a certain common heavy oil reservoir, has the characteristics of deep burial, medium and low permeability, serious heterogeneity, heavy oil and high mineralization degree, and is a deep common heavy oil reservoir. The average reservoir temperature was 78 ℃. The oil saturation of the reservoir is 58.6 percent, the reservoir depth is 2700-. The oil reservoir pressure is 27-31MPa, and the heavy oil density is 0.966g/cm3The viscosity of the thickened oil at 50 ℃ is 286 mPa.s, and the mineralization degree of the formation water is 8-9 multiplied by 104mg/L. For the case of gas channeling between injection wells a204-19 and production wells A2-41. The distance between the injection well and the production well is 125 m. The daily injection amount of A204-19 is 137m3The daily liquid yield of A2-41 is 124m3(d) the average water content was 88.0%.
The treatment method of the gas channeling channel is carried out according to the method provided by Chinese patent document CN105781512A, and the oil reservoir extraction conditions before and after treatment are recorded. Before the gas channeling channel is treated, the average daily oil production of the produced wells is only 5.35t/d due to the gas channeling channel between the two wells, and effective production cannot be carried out. After the treatment method is adopted, the total daily oil yield reaches 15.41t/d at most, 101 days are produced in the effective throughput period, and 1402.53t of crude oil is increased in cumulative mode.
Comparative example 4:
the experimental oil field of the comparative example is a certain common heavy oil reservoir, has the characteristics of deep burial, medium and low permeability, serious heterogeneity, heavy oil and high mineralization degree, and is a deep common heavy oil reservoir. The average reservoir temperature was 78 ℃. The oil saturation of the reservoir is 58.6 percent, and the depth of the reservoir is 2700-The oil layer thickness was 34.1m, the porosity 23.6%, and the permeability 205 mD. The oil reservoir pressure is 27-31MPa, and the heavy oil density is 0.966g/cm3The viscosity of the thickened oil at 50 ℃ is 286 mPa.s, and the mineralization degree of the formation water is 8-9 multiplied by 104mg/L. For the presence of gas channeling between injection wells a2-42 and production wells a 2-123. The distance between the injection well and the production well is 125 m. The daily injection amount of A2-203 is 112m3The daily liquid yield of A2-121 is 103m3(ii)/d, average water content was 87.0%.
The treatment method of the gas channeling channel comprises the following steps:
s1, judging the position of a gas channeling channel and calculating the volume: preparing 2, 6-sodium difluorobenzoate solution with water, injecting 2, 6-sodium difluorobenzoate into injection well (A2-42) at 494mg/L tracer solution injection rate of 6.5 × 103L/h, and the injection time is 1 d. The tracer concentration of each production well was monitored in real time and it was found that the production wells (i.e., a2-123) were detected tracer indicating the presence of a gas channeling pathway from the injection well to the production wells. And then detecting the concentration of the tracer agent of the production well and obtaining the actual output condition of the tracer agent. According to the actual production condition of the concentration of the tracer, the peak time of the tracer is 49 d. Firstly, fitting the actual production curve peak concentration of the tracer by adjusting the dilution coefficient of the shaft. Thereby obtaining a wellbore dilution factor alpha of 0.4 for the target well group cross-flow channel. Thereby calculating and obtaining the water yield Q in the cross flow channel between the wellscIs 35.84m3And d. The volume V of the channeling channel is 1756.36m by multiplying the water yield in the channeling channel by the peak time of the tracer3；
1. And (3) calculating the water yield of the target oil well: qw＝103×87.0％＝89.61m3/d
2. Calculating the water production in the gas channeling channel between wells: qc＝89.61×0.4＝35.84m3/d
3. Calculating the volume of the gas channeling channel: v35.844 × 49 1756.36m3
S2, injecting foam, injecting a Sodium Dodecyl Sulfate (SDS) solution with the mass concentration of 0.3% into a production well of the gas channeling well group to form a liquid slug, and then injecting N2Injected SDSTotal amount of solution 1146.02m3The injection speed is 65t/d, N2Total amount of 1488.51m under formation conditions3And the injection speed is 7 x 104sm3The ratio of the volume of the surfactant solution injected to the volume of the gas injected per time was 1: 2500. The total amount of foam injected was 2634.53m3Is 1.5 times of the volume of the gas channeling channel, wherein the mass of foam is less than 60 percent,
s3, soaking: after the step S2 is completed, closing the wellhead of the injection well and the production well at the same time to carry out soaking operation;
s4, well opening production: and when the change rate of the wellhead pressure is 0.01MPa/d, simultaneously opening the injection well and the production well for well opening production, ending the huff and puff round when the oil production of the two wells is lower than 2t/d, restoring the balance of the stratum at the moment, and repeating the steps S2 and S3 for huff and puff of the next round.
Before the gas channeling channel is treated, the average daily oil production of the produced well is only 4.12t/d due to the gas channeling channel between the two wells, and effective production cannot be carried out. After the treatment method is adopted, the total daily oil yield of the injection well and the production well reaches up to 15.21t/d, 89 days of production is carried out in the effective throughput period, and 1035.96t of crude oil is increased in an accumulated mode.
Comparative example 5:
the experimental oil field of the comparative example is a certain common heavy oil reservoir, has the characteristics of deep burial, medium and low permeability, serious heterogeneity, heavy oil and high mineralization degree, and is a deep common heavy oil reservoir. The average reservoir temperature was 78 ℃. The oil saturation of the reservoir is 58.6 percent, the reservoir depth is 2700-. The oil reservoir pressure is 27-31MPa, and the heavy oil density is 0.966g/cm3The viscosity of the thickened oil at 50 ℃ is 286 mPa.s, and the mineralization degree of the formation water is 8-9 multiplied by 104mg/L. For the case of gas breakthrough between injection well a new 3-3 and production well a 2-122. The well spacing between the injection well and the production well is 102 m. The daily injection amount of A2-203 is 135m3The daily liquid yield of A2-121 is 118m3(d) average water content of 91.0％。
The treatment method of the gas channeling channel comprises the following steps:
s1, judging the position of a cross flow channel and calculating the volume: preparing 2, 6-difluorosodium benzoate solution with water, injecting 2, 6-difluorosodium benzoate into injection well (i.e. A new 3-3), wherein the injection concentration of tracer solution is 480mg/L, and the injection flow rate is 7 × 103L/h, and the injection time is 1 d. The tracer concentration of each production well was monitored in real time and it was found that the production wells (i.e., a2-122) were detected with the tracer, indicating that a gas channeling pathway existed between the injection well and the production well. And then detecting the concentration of the tracer agent of the production well and obtaining the actual output condition of the tracer agent. And the peak time of the tracer is 56d according to the actual production condition of the concentration of the tracer. Firstly, fitting the actual production curve peak concentration of the tracer by adjusting the dilution coefficient of the shaft. Thereby achieving a wellbore dilution factor alpha of 0.39 for the target well group blow-by passage. Thereby calculating and obtaining the water yield Q in the cross flow channel between the wellscIs 41.878m3And d. The volume V of the channeling channel is 2345.18m by multiplying the water yield in the channeling channel by the peak time of the tracer3；
1. And (3) calculating the water yield of the target oil well: qw＝118×91.0％＝107.38m3/d
2. Calculating the water production in the gas channeling channel between wells: qc＝107.38×0.39＝41.88m3/d
3. Calculating the volume of the gas channeling channel: v41.878 × 56 2345.18m3
S2, injecting foam, injecting a Sodium Dodecyl Sulfate (SDS) solution with the mass concentration of 0.3% into a production well of the gas channeling well group to form a liquid slug, and then injecting N2Total amount of SDS solution injected 492.49m3The injection speed is 65t/d, N2Total amount of 2790.76m under formation conditions3And the injection speed is 7 x 104sm3The ratio of the volume of the surfactant solution injected to the volume of the gas injected per time was 1: 2500. The total amount of foam injected was 3283.25m31.4 times the volume of the gas channeling passage, wherein the mass of the foam is more than 80%,
s3, soaking: after the step S2 is completed, closing the wellhead of the injection well and the production well at the same time to carry out soaking operation;
s4, well opening production: and when the change rate of the wellhead pressure is 0.01MPa/d, simultaneously opening the injection well and the production well for well opening production, ending the huff and puff round when the oil production of the two wells is lower than 2t/d, restoring the balance of the stratum at the moment, and repeating the steps S2 and S3 for huff and puff of the next round.
Before the gas channeling channel is treated, the average daily oil production of the produced well is only 3.12t/d due to the gas channeling channel between the two wells, and effective production cannot be carried out. After the treatment method is adopted, the total daily oil yield of the injection well and the production well reaches 16.14t/d at most, 105 days are produced in the effective throughput period, and the increased crude oil is 1423.82 t.
The statistics of the oil reservoir output before and after the application examples and the comparative treatments and the increase percentage after the treatments are shown in the following table.
TABLE 1 reservoir production before and after remediation and percent increase
In the table, the oil yield (t) in the effective period of the untreated measure is the daily average oil yield (t/d) of the production well before treatment multiplied by the number of production days (d) in the effective throughout period; the oil yield (t) in the effective period of the measure is the accumulated oil yield (t) in the effective throughout period; the percentage (%) of increase in oil production in the effective period after treatment is equal to (oil production in the effective period of the measures (t) -oil production in the effective period of the untreated measures (t))/oil production in the effective period of the untreated measures (t) × 100%.
According to the table data, the method provided by the invention not only can effectively diffuse the foam injected into the stratum to block the gas channeling channel, but also effectively improves the oil production of the treated oil reservoir.
Although the embodiments of the present invention have been described with reference to the accompanying drawings, it is not intended to limit the scope of the present invention, and it should be understood by those skilled in the art that various modifications and variations can be made without inventive efforts by those skilled in the art based on the technical solution of the present invention.
Claims (8)
1. A method for treating and utilizing a foam gas-displacement channel is characterized by comprising the following steps:
s1, judging the position of a gas channeling channel and calculating the volume,
in the foam flooding process, after a mixed tracer is injected into an injection well into a foam system, in a monitoring period, a production well with the detected tracer is found, namely, the fact that a gas channeling channel exists between the production well and the injection well is explained, the tracer concentration of the production well with the gas channeling channel is detected to obtain the output condition of the tracer, and the volume of the gas channeling channel is calculated according to the detected tracer concentration and well bore parameters;
s2, injecting foam into the mixture,
firstly, simultaneously injecting surfactant solution into an injection well and a production well of a well group with gas channeling to form a liquid slug, then simultaneously injecting gas into the injection well and the production well, and alternately injecting surfactant solution and gas of the slug to form foam underground;
s3, stewing the well,
after the step S2 is completed, closing the well heads of the injection well and the production well at the same time for soaking operation;
s4, opening a well to produce,
and after the pressure difference between the injection well and the production well is minimum, namely the wellhead pressure is stable, simultaneously opening the injection well and the production well for well opening production, when the total oil production of the injection well and the production well is lower than 2t/d, ending the huff and puff round, restoring the balance of the stratum at the moment, and repeating the steps S3 and S4 to perform the huff and puff of the next round.
2. The method as claimed in claim 1, wherein the tracer in step S1 is a fluorobenzoic acid tracer, which is injected at a concentration ranging from 350mg/L to 550mg/L, and the injection rate of the tracer solution is set to be in the range of5×103-10×103L/h。
3. The method as set forth in claim 1, wherein the calculation method of the blow-by passage volume in the step S1 is specifically as follows:
fitting the actual output curve peak concentration of the tracer by adjusting the dilution coefficient alpha of the shaft to obtain the dilution coefficient alpha of the shaft of the gas channeling channel of the target well group, and obtaining the water yield Q of the target oil well according to the water yield Q of the target oil wellwAnd calculating the dilution coefficient alpha of the shaft to obtain the water yield Q of the gas channeling channel between the wellscI.e. Qc＝Qw×α，QwAnd QcAll units of (are m)3D, the volume V of the gas channeling channel is V ═ Qc×tpWherein t ispIs the peak time of the tracer, and has the unit of d, and the unit of V is m3。
4. The method of claim 1, wherein in step S2, the surfactant is selected from one or more of sodium dodecylbenzene sulfonate, sodium dodecylsulfate, etc.
5. The method of claim 3, wherein the total volume of the injected foam, i.e., the total volume of the injected gas and the surfactant solution, is 1.2 to 1.5 times the volume of the gas channeling path calculated in the step S1 in the step S2.
6. The method of claim 1, wherein the injected gas is CO 22、CH4、N2And flue gas.
7. The method of claim 1, wherein in the step S2, the surfactant solution is injected at a rate of 10t/d to 100t/d, and the gas is injected at a rate of 2 x 104sm3/d～10×104sm3/d，sm3Is the gas volume unit under standard conditions; the volume of surfactant solution injected per time and the gas injectedThe volume ratio of (A) to (B) is 1: 500-1: 5000.
8. The method of claim 1, wherein in step S2, the foam is controlled to have a foam mass of 60-80% at formation conditions, wherein the foam mass is calculated by the formula:
in the formula: r is the foam quality; vGIs the volume of gas, m3；VLVolume of surfactant solution, m3；VFM is the total volume of the solution3。
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