CN113887088A - Method for determining dosage of blocking remover for removing reservoir barite pollution - Google Patents

Method for determining dosage of blocking remover for removing reservoir barite pollution Download PDF

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Publication number
CN113887088A
CN113887088A CN202111312450.0A CN202111312450A CN113887088A CN 113887088 A CN113887088 A CN 113887088A CN 202111312450 A CN202111312450 A CN 202111312450A CN 113887088 A CN113887088 A CN 113887088A
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barite
crack
fracture
blocking remover
amount
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罗志锋
黄家洪
谢耀增
吴林
张楠林
陈翔
程龙
曾秀权
李建斌
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Southwest Petroleum University
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    • G06—COMPUTING; CALCULATING OR COUNTING
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    • G06F30/00—Computer-aided design [CAD]
    • G06F30/20—Design optimisation, verification or simulation
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06F—ELECTRIC DIGITAL DATA PROCESSING
    • G06F17/00—Digital computing or data processing equipment or methods, specially adapted for specific functions
    • G06F17/10—Complex mathematical operations
    • G06F17/11—Complex mathematical operations for solving equations, e.g. nonlinear equations, general mathematical optimization problems
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    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06F—ELECTRIC DIGITAL DATA PROCESSING
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    • G06F2119/14—Force analysis or force optimisation, e.g. static or dynamic forces

Abstract

The invention discloses a method for determining the dosage of a blocking remover for removing reservoir barite pollution, which mainly comprises the following steps: acquiring oil reservoir geological parameters of a target well; acquiring well-periphery natural fracture parameters; calculating the invasion depth of the drilling fluid; calculating the amount of the blockage removing barite in the matrix; calculating the amount of the blockage removing barite in the crack; and calculating the total dosage of the blocking remover. The method increases the determination of the usage amount of the barite pollution blocking remover from subjective judgment to quantitative calculation, and fully considers the usage amounts of matrix pores and fracture reservoirs aiming at the characteristics of the barite blocking remover, so that the calculation result is more accurate; meanwhile, on the premise of ensuring successful implementation of blockage removal, the invention not only can realize high-efficiency blockage removal of the oil-gas well and improve the yield of a target stratum, but also can effectively control the cost of the blockage removal agent and realize cost reduction and efficiency improvement.

Description

Method for determining dosage of blocking remover for removing reservoir barite pollution
Technical Field
The invention relates to the technical field of oil and gas field development, in particular to a method for determining the dosage of a blocking remover for removing reservoir barite pollution.
Background
In recent years, with the increase of the difficulty of oil-gas exploration and development in China, the number of drilling of more and more deep wells and ultra-deep wells is increased. In the drilling process, along with formation high pressure, barite is adopted to increase the weight of the drilling fluid in order to balance the formation pressure, and solid-phase particles such as barite can be transported to the deep part of a crack to cause blockage, pollute a production layer and are extremely difficult to remove, so that the productivity is greatly reduced.
The removal of reservoir heavy gold stone pollution is necessary work for oil gas production increase, but because the barite (barium sulfate) is a mineral substance with very stable chemical property and is very difficult to dissolve in strong acid and strong base, the solid-phase blockage of the barite is difficult to effectively remove in the acidification (pressing) operation. Aiming at the blocking mechanism, the chelating blocking remover is adopted by combining with the characteristics of the reservoir, so that the solid-phase blocking of the barite in the natural fracture can be fully dissolved, the damage of the reservoir can be removed, the modification volume of the reservoir can be enlarged, and the productivity of the high-temperature and high-pressure oil-gas well can be improved.
The key point is the dosage of the blocking remover by removing the pollution of the barite, communicating oil and gas layers and enlarging seepage channels. At present, the dosage of the blocking remover is mainly determined by experience, and a stage of fixing the volume and quantifying is not increased, so that certain blindness is realized. In view of the above, a relatively precise method for determining the amount of the blocking remover for the barite pollution is urgently needed.
Disclosure of Invention
The invention aims to provide a method for determining the using amount of a blocking remover for removing reservoir barite pollution, aiming at the defects of the prior art, not only can solve the problems of inaccurate using amount and the like caused by subjective judgment of the using amount of the barite pollution blocking remover, but also can reasonably control the blocking removal cost.
The technical scheme adopted by the invention for solving the technical problems comprises the following contents:
a method for determining the dosage of a blocking remover for removing reservoir barite pollution comprises the following steps:
s1, acquiring oil reservoir geological parameters of a target well;
s2, acquiring well-surrounding natural fracture parameters;
s3, calculating the invasion depth of the drilling fluid;
s4, calculating the amount of the blockage removing barite in the matrix;
s5, calculating the amount of the blockage removing barite in the crack;
and S6, calculating the total dosage of the blocking remover.
Further, the geological parameters of the oil reservoir in the step S1 include porosity, permeability, reservoir thickness, oil saturation, formation temperature, formation pressure, ground stress parameters, fluid property parameters, rock mechanics parameters, and viscosity of drilling fluid.
Further, the method for acquiring the well-surrounding natural fracture parameters in the step S2 includes:
(1) reading FMI (imaging logging) data, identifying the low-resistance black sinusoidal curve displayed on the image as an opening crack, and reading the trend and inclination angle parameters of the opening crack;
(2) reading FMI data, identifying a light color or bright color sinusoidal curve displayed on an image as a filling crack, and reading the trend and inclination angle parameters of the filling crack;
(3) reading FMI (imaging logging) data, identifying black lines which are displayed on an image and symmetrically appear along a well wall as induced cracks, and reading the trend and inclination angle parameters of the induced cracks;
(4) calculating natural fracture density, namely the total number of fractures on the well wall per unit length, wherein the equation for calculating the natural fracture density is as follows:
Figure BDA0003342195670000021
wherein, FdIs the crack density, bars/m; n1 is the number of the opening slots,(ii) a strip; n2 is the number of filling seams; n3 is the number of the induction seams; hdIs the log section thickness, m.
Further, the definition of the drilling fluid invasion depth calculated in the step S3 is as follows:
under the condition of a certain pressure difference, after the drilling fluid is lost for a certain time, when the drilling fluid pressure in the fracture is balanced with the formation pressure, the loss of the drilling fluid is finished, and the time when the drilling fluid flows through the distance along the fracture is the invasion depth L, m of the lost drilling fluid in the fracture in the time; the calculation of the drilling fluid invasion depth comprises the following calculation formula:
continuity equation in fracture:
Figure BDA0003342195670000022
continuity equation in matrix:
Figure BDA0003342195670000023
the cross flow equation:
Figure BDA0003342195670000031
fluid flow rate equation within the slot:
Figure BDA0003342195670000032
wherein phi isfFracture porosity,%; phi is amFracture porosity,%; cfIs a crack compression factor, Pa-1；pfIs the pressure within the fracture, Pa; t is time, s; x is the abscissa, m; p is a radical ofmIs the pressure within the matrix, Pa; μ is the fluid viscosity, pas; alpha is a shape factor, has no dimension, and is generally 0.5; kfCrack permeability, D; kmAs the matrix permeability, D; cmIs pressed into a substrateCoefficient of contraction, Pa-1(ii) a q is the fluid flow rate, m3S; p is the pressure within the fracture, Pa; w is the crack width, m; v is the flow velocity of the drilling fluid in the fracture, m/s.
Further, the calculation formula for calculating the amount of the deblocking barite in the matrix in step S4 is as follows:
Figure BDA0003342195670000033
wherein, VSubstrateThe amount of the pore blocking remover used as the matrix m3(ii) a R is the unblocking radius and generally takes a value of 2 m; h is the length of the modified section, m;
Figure BDA0003342195670000034
is the average porosity of the crack,%.
Further, the calculation formula for calculating the amount of the blockage relieving barite in the fracture in the step S5 is as follows:
Vcrack (crack)＝(N·L·H·w·η)·ρBarite·β·c
Wherein, VCrack (crack)The dosage of the blocking remover for reservoir fractures, m3N is the number of cracks of the blockage removing section; l is the invasion depth of the drilling fluid in the fracture, m; h is the crack height, m; w is the crack width, m; eta is the blocking volume correction coefficient of the barite, and is taken as 0.4; rhoBariteIs barite density, g/cm3(ii) a Beta is a safety coefficient, and 1.6 is taken; c is the consumption unblocking dosage of unit weight barite, m3/t。
Further, the calculation formula of the total usage amount of the blocking remover in the step S6 is as follows:
V＝Vsubstrate+VCrack (crack)
Wherein V is the total dosage of the blocking remover, m3，VSubstrateThe amount of the pore blocking remover used as the matrix m3；VCrack (crack)The dosage of the blocking remover for reservoir fractures, m3。
The invention has the beneficial effects that:
the method increases the determination of the using amount of the reservoir barite pollution blocking remover from subjective judgment to quantitative calculation, and fully considers the using amounts of matrix pores and fractured reservoirs aiming at the characteristics of the barite blocking remover, so that the calculation result is more accurate; meanwhile, on the premise of ensuring successful implementation of blockage removal, the invention not only can realize high-efficiency blockage removal of the oil-gas well and improve the yield of a target stratum, but also can effectively control the cost of the blockage removal agent and realize cost reduction and efficiency improvement.
Drawings
Fig. 1 is a schematic view of the overall process of the present invention.
FIG. 2 is a graph of the imaging log results of W12-21 wells 7860-7875 m.
FIG. 3 is a periwell pressure cloud.
FIG. 4 is a graph of drilling fluid invasion depth versus pressure within the fracture at different leak-off times.
Detailed Description
The present invention will be described in detail with reference to the following examples, which should be construed as merely illustrative and explanatory of the present invention and not restrictive thereof.
A method for determining the dosage of a blocking remover for removing reservoir barite pollution comprises the following steps:
s1, acquiring oil reservoir geological parameters of a target well;
s2, acquiring well-surrounding natural fracture parameters;
s3, calculating the invasion depth of the drilling fluid;
s4, calculating the amount of the blockage removing barite in the matrix;
s5, calculating the amount of the blockage removing barite in the crack;
and S6, calculating the total dosage of the blocking remover.
The overall process of the invention is shown in figure 1.
The geological parameters of the oil reservoir in the step S1 include porosity, permeability, reservoir thickness, oil saturation, formation temperature, formation pressure, ground stress parameters, fluid property parameters, rock mechanics parameters and drilling fluid viscosity.
The method for acquiring the well periphery natural fracture parameters in the step S2 comprises the following steps:
(1) reading FMI (imaging logging) data, identifying the low-resistance black sinusoidal curve displayed on the image as an opening crack, and reading the trend and inclination angle parameters of the opening crack;
(2) reading FMI data, identifying a light color or bright color sinusoidal curve displayed on an image as a filling crack, and reading the trend and inclination angle parameters of the filling crack;
(3) reading FMI (imaging logging) data, identifying black lines which are displayed on an image and symmetrically appear along a well wall as induced cracks, and reading the trend and inclination angle parameters of the induced cracks;
(4) calculating the natural fracture density, namely the total number of the fractures on the well wall in unit length, wherein the equation for calculating the natural fracture density is as follows:
Figure BDA0003342195670000051
wherein, FdIs the crack density, bars/m; n1 is the number of opening seams; n2 is the number of filling seams; n3 is the number of the induction seams; hdIs the reservoir thickness, m.
The definition of the drilling fluid invasion depth calculated in step S3 is:
under the condition of a certain pressure difference, after the drilling fluid is lost for a certain time, when the drilling fluid pressure in the fracture is balanced with the formation pressure, the loss of the drilling fluid is finished, and the time when the drilling fluid flows through the distance along the fracture is the invasion depth L, m of the lost drilling fluid in the fracture in the time; the calculation of the drilling fluid invasion depth comprises the following calculation formula:
continuity equation in fracture:
Figure BDA0003342195670000052
continuity equation in matrix:
Figure BDA0003342195670000053
the cross flow equation:
Figure BDA0003342195670000054
fluid flow rate equation within the slot:
Figure BDA0003342195670000055
wherein phi isfFracture porosity,%; phi is amFracture porosity,%; cfIs a crack compression factor, Pa-1；pfIs the pressure within the fracture, Pa; t is time, s; x is the abscissa, m; p is a radical ofmIs the pressure within the matrix, Pa; μ is the fluid viscosity, pas; alpha is a shape factor, has no dimension, and is generally 0.5; kfCrack permeability, D; kmAs the matrix permeability, D; cmIs the compression coefficient of the matrix, Pa-1(ii) a q is the fluid flow rate, m3S; p is the pressure within the fracture, Pa; w is the width of the crack, mm; v is the flow velocity of the drilling fluid in the fracture, m/s.
In step S4, the calculation formula for the amount of the deblocking barite in the matrix is:
Figure BDA0003342195670000061
wherein, VSubstrateThe amount of the pore blocking remover used as the matrix m3(ii) a R is the unblocking radius and generally takes a value of 2 m; h is the effective segment length of the target layer, m;
Figure BDA0003342195670000062
is the average porosity of the crack,%.
In the step S5, the calculation formula for calculating the amount of the blockage relieving barite in the crack is as follows:
Vcrack (crack)＝(N·L·H·w·η)·ρBarite·β·c
Wherein, VCrack (crack)The dosage of the blocking remover for reservoir fractures, m3N is solutionThe number of the cracks of the plugging section is large; l is the invasion depth of the drilling fluid in the fracture, m; h is the crack height, m; w is the width of the crack, mm; eta is the blocking volume correction coefficient of the barite, and is taken as 0.4; rhoBariteIs barite density, g/cm3(ii) a Beta is a safety coefficient, and 1.6 is taken; c is the consumption unblocking dosage of unit weight barite, m3/t。
The calculation formula of the total dosage of the blocking remover in the step S6 is as follows:
V＝Vsubstrate+VCrack (crack)
Wherein V is the total dosage of the blocking remover, m3，VSubstrateThe amount of the pore blocking remover used as the matrix m3；VCrack (crack)The dosage of the blocking remover for reservoir fractures, m3。
In a specific embodiment, the target well is a W12-21 well, belongs to a fractured tight sandstone gas well, has serious leakage in the 7860-7875 m drilling process, has the accumulated leakage time of 0.4h, and is analyzed to determine that the well has a serious barite blocking phenomenon, so that in order to improve the productivity of a single well, the blocking removal and the production increase of a reservoir layer are needed. The well construction adopts GT-BS-2 barite blocking remover, and the amount of the barite blocking remover is calculated.
S1, acquiring oil reservoir geological parameters of a target well
The thickness of a target interval is 157m, the average porosity of a reservoir is 6.93%, the average permeability is 2.1mD, the average oil saturation is 64%, the original pressure of a formation is 137.9MPa, the original temperature of the formation is 159.1 ℃, the maximum horizontal principal stress is 167MPa, the minimum horizontal principal stress is 145MPa, the Poisson ratio is 0.21, the Young modulus is 29GPa, and the viscosity of drilling fluid is 0.1 Pa.s.
S2, acquiring well-surrounding natural fracture parameters
The imaging logging result of the target well W12-21 well 7860-7875 m is shown in figure 2, the FMI (imaging logging) data is used for identifying 7 well section development filling cracks of the well 7860-7875 m, 11 cracks are opened, 1 crack is induced, the height of a natural crack is 3m, the width of the natural crack is 200 mu m, and the density of the well cracks is calculated to be 1.3 cracks/m.
S3, calculating the invasion depth of the drilling fluid
Based on the identification result of the well-surrounding imaging logging cracks, a 300m multiplied by 300m well-surrounding geological model is established, the size of a grid is 3m multiplied by 3m, and 10000 grids are used in total. The resulting pressure cloud is shown in FIG. 3. And (4) performing discrete solution on the equation by adopting an extended finite element method. The relationship between the drilling fluid invasion depth and the fracture internal pressure at the formation initial pressure of 137.9MPa, the bottom hole pressure of 140MPa, the fracture initial width of 200 μm and the loss time of 0.1, 0.2, 0.3, 0.4 and 0.5h is calculated, and the result is shown in FIG. 4. The accumulated loss time of the W12-21 well in the 7860-7875 m drilling process is 0.4h, and the calculation result shows that when the length of the seam exceeds 87.5m, the drilling fluid pressure in the seam is equal to the formation pressure, so that the invasion depth of the drilling fluid of the well is 87.5m (the loss time 0.4h curve in FIG. 4).
S4, calculating the amount of the blockage-removing barite in the matrix
Determining the blockage removal radius to be 2m according to the pollution radius, performing weighted average processing on the porosity of different fractured reservoirs explained by the logging of the target layer to obtain the weighted average porosity of the target layer to be 5.5%, and calculating the dosage of blockage removal barite in the matrix:
Vsubstrate＝π×22×15×5.5％＝28.2m3。
S5, calculating the amount of the blockage removing barite in the crack
According to the natural fracture parameters, calculating the amount of the blockage removing barite in the fracture:
Vcrack (crack)＝(19×87.5×3×200×10-6×0.4)×4.5×1.6×82＝235.5m3。
S6, calculating the total dosage of the blocking remover
Calculating the total dosage of the blocking remover: 28.2+ 235.5-263.7 m3。
Through summation calculation, the total usage of the barite blocking remover is determined to be 263.7m3, the blocking remover is pumped into a shaft according to corresponding construction parameters, the expected effect of removing the blockage of the barite blocking plug is achieved, the yield of a single well is improved, and stable production is realized.
The method increases the determination of the usage amount of the barite pollution blocking remover from subjective judgment to quantitative calculation, and fully considers the usage amounts of matrix pores and fracture reservoirs aiming at the characteristics of the barite blocking remover, so that the calculation result is more accurate; meanwhile, on the premise of ensuring successful implementation of blockage removal, the invention not only can realize high-efficiency blockage removal of the oil-gas well and improve the yield of a target stratum, but also can effectively control the cost of the blockage removal agent and realize cost reduction and efficiency improvement.
Although the present invention has been described with reference to a preferred embodiment, it should be understood that various changes, substitutions and alterations can be made herein without departing from the spirit and scope of the invention as defined by the appended claims.

Claims (7)

1. The method for determining the amount of the blocking remover for removing reservoir barite pollution is characterized by comprising the following steps of:
s1, acquiring oil reservoir geological parameters of a target well;
s2, acquiring well-surrounding natural fracture parameters;
s3, calculating the invasion depth of the drilling fluid;
s4, calculating the amount of the blockage removing barite in the matrix;
s5, calculating the amount of the blockage removing barite in the crack;
and S6, calculating the total dosage of the blocking remover.
2. The method as claimed in claim 1, wherein the geological parameters of reservoir in step S1 include porosity, permeability, reservoir thickness, oil saturation, formation temperature, formation pressure, ground stress parameter, fluid property parameter, rock mechanics parameter, and viscosity of drilling fluid.
3. The method for determining the amount of the blocking remover for removing reservoir barite pollution according to claim 1, wherein the method for acquiring the periwellbore natural fracture parameters in the step S2 is as follows:
(1) reading FMI (imaging logging) data, identifying the low-resistance black sinusoidal curve displayed on the image as an opening crack, and reading the trend and inclination angle parameters of the opening crack;
(2) reading FMI data, identifying a light color or bright color sinusoidal curve displayed on an image as a filling crack, and reading the trend and inclination angle parameters of the filling crack;
(3) reading FMI (imaging logging) data, identifying black lines which are displayed on an image and symmetrically appear along a well wall as induced cracks, and reading the trend and inclination angle parameters of the induced cracks;
(4) calculating the natural fracture density, namely the total number of the fractures on the well wall in unit length, wherein the equation for calculating the natural fracture density is as follows:
Figure FDA0003342195660000011
wherein, FdIs the crack density, bars/m; n1 is the number of opening seams; n2 is the number of filling seams; n3 is the number of the induction seams; hdIs the log section thickness, m.
4. The method for determining the amount of the blocking remover for removing reservoir barite pollution according to claim 1, wherein the calculation of the invasion depth of the drilling fluid in the step S3 is defined as:
under the condition of a certain pressure difference, after the drilling fluid is lost for a certain time, when the drilling fluid pressure in the fracture is balanced with the formation pressure, the loss of the drilling fluid is finished, and the time when the drilling fluid flows through the distance along the fracture is the invasion depth L, m of the lost drilling fluid in the fracture in the time; the calculation of the drilling fluid invasion depth comprises the following calculation formula:
continuity equation in fracture:
Figure FDA0003342195660000021
continuity equation in matrix:
Figure FDA0003342195660000022
the cross flow equation:
Figure FDA0003342195660000023
fluid flow rate equation within the slot:
Figure FDA0003342195660000024
wherein phi isfFracture porosity,%; phi is amFracture porosity,%; cfIs a crack compression factor, Pa-1；pfIs the pressure within the fracture, Pa; t is time, s; x is the abscissa, m; p is a radical ofmIs the pressure within the matrix, Pa; μ is the fluid viscosity, pas; alpha is a shape factor, has no dimension, and is generally 0.5; kfCrack permeability, D; kmAs the matrix permeability, D; cmIs the compression coefficient of the matrix, Pa-1(ii) a q is the fluid flow rate, m3S; p is the pressure within the fracture, Pa; w is the crack width, m; v is the flow velocity of the drilling fluid in the fracture, m/s.
5. The method for determining the amount of the blocking remover for removing the reservoir barite pollution according to claim 1, wherein the calculation formula of the amount of the blocking remover for the intramatrix blocking barite in the step S4 is as follows:
Figure FDA0003342195660000025
wherein, VSubstrateThe amount of the pore blocking remover used as the matrix m3(ii) a R is the unblocking radius and generally takes a value of 2 m; h is the length of the modified section, m;
Figure FDA0003342195660000026
is the average porosity of the crack,%.
6. The method for determining the amount of the blocking remover for removing the reservoir barite pollution according to claim 1, wherein the calculation formula of the amount of the blocking remover for the fracture in the step S5 is as follows:
Vcrack (crack)＝(N·L·H·w·η)·ρBarite·β·c
Wherein, VCrack (crack)The dosage of the blocking remover for reservoir fractures, m3N is the number of cracks of the blockage removing section; l is the invasion depth of the drilling fluid in the fracture, m; h is the crack height, m; w is the crack width, m; eta is the blocking volume correction coefficient of the barite, and is taken as 0.4; rhoBariteIs barite density, g/cm3(ii) a Beta is a safety coefficient, and 1.6 is taken; c is the consumption unblocking dosage of unit weight barite, m3/t。
7. The method for determining the amount of the blocking remover for removing reservoir barite pollution according to claim 1, wherein the calculation formula of the total amount of the blocking remover in the step S6 is as follows:
V＝Vsubstrate+VCrack (crack)
Wherein V is the total dosage of the blocking remover, m3，VSubstrateThe amount of the pore blocking remover used as the matrix m3；VCrack (crack)The dosage of the blocking remover for reservoir fractures, m3。
CN202111312450.0A 2021-11-08 2021-11-08 Method for determining dosage of blocking remover for removing reservoir barite pollution Pending CN113887088A (en)

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Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN116612388A (en) * 2023-07-17 2023-08-18 新疆华屹能源发展有限公司 Blocking removing method and system for oil production well

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN116612388A (en) * 2023-07-17 2023-08-18 新疆华屹能源发展有限公司 Blocking removing method and system for oil production well
CN116612388B (en) * 2023-07-17 2023-09-19 新疆华屹能源发展有限公司 Blocking removing method and system for oil production well

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