CN108343426B - Simulation method for water content output of fracture-cavity type oil reservoir oil well - Google Patents
Simulation method for water content output of fracture-cavity type oil reservoir oil well Download PDFInfo
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 310
- 239000003129 oil well Substances 0.000 title claims abstract description 49
- 238000000034 method Methods 0.000 title claims abstract description 43
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- 239000008398 formation water Substances 0.000 claims description 26
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- 238000007906 compression Methods 0.000 claims description 11
- 230000006835 compression Effects 0.000 claims description 10
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Abstract
The invention discloses a simulation method of water content output by a fracture-cavity type oil reservoir oil well, which comprises the following steps: s1, firstly, establishing a description structure and description parameters of the multi-fracture-cavity unit oil reservoir; s2, simulating and calculating the oil yield and the water yield of each fracture-cavity unit stage by utilizing the fracture-cavity unit description structure and description parameters established in S1, combining the elastic driving stage material balance relation and the water content model in the oil reservoir development process and using elastic expansion energy as the virtual injection quantity of the fracture-cavity unit, so as to obtain the oil yield, the water yield and the accumulated water yield of the oil well; and S3, finally, calculating the change of the water content of the oil well along with the accumulated liquid production according to the obtained oil production, water production and accumulated liquid production of the oil well. The method provided by the invention contributes a new idea for analyzing the dynamic water content of the production and recognizing the fracture-cavity structure in the elastic driving stage of the fracture-cavity oil reservoir.
Description
Technical Field
The invention relates to the field of oil and gas field development, in particular to a method for simulating the water content of a fracture-cavity oil reservoir oil well.
Background
For a carbonate fracture-cavity type oil reservoir, the storage and seepage space is a corrosion pore, a corrosion pore and a crack, the fracture-cavity flow conductivity is strong, the karst cavity is a main storage space, the oil-water gravity difference in the karst cavity is obvious, the crack is a main flow channel, the water content of an oil well rises quickly after water breakthrough, the natural water flooding reserve utilization degree is poor, and the recovery ratio is low. According to production data, a multifilar form of a cumulative water-cumulative liquid curve produced by an oil well is found, as shown in figure 1, the water content change of the oil well in the figure is divided into four stages of a, b, c and d, two general forms of water content rising and falling are included, and three karst cave unit models can be used for simulation combination when the water content of the oil well changes in three steps: supposing that an oil well is put into production through a No. 1 karst cave, the No. 2 karst cave and the No. 3 karst cave respectively supply liquid to the No. 1 karst cave, the outlet ends of the No. 1 karst cave and the No. 2 karst cave are positioned above an original oil-water interface, the karst cave produces oil firstly and then produces water, the fluid composition in the karst cave is that water is rich and oil is little, the outlet end of the No. 3 karst cave is positioned below the original oil-water interface, the karst cave produces oil firstly and then produces water, and the fluid composition in the karst cave is that; in the stage a, the oil well does not produce water, the 1# karst cave water does not overflow, the 2# karst cave water does not overflow, the 3# karst cave oil does not overflow, and the oil yield of the oil well is equal to the oil expansion amount of the 1# karst cave plus the total oil-water expansion amount of the 2# karst cave; in the stage b, oil and water are produced simultaneously, 1# karst cave water overflows, 2# karst cave water does not overflow, 3# karst cave oil does not overflow, the stage water yield is equal to the water expansion amount of the 1# karst cave plus the total oil and water expansion amount of the 3# karst cave, the stage oil yield is equal to the oil expansion amount of the 1# karst cave plus the total oil and water expansion amount of the 2# karst cave, and the water content of the oil well rises by one step due to the water production of the 1# karst cave; co-production of oil and water in stage c; 1# karst cave water overflows, 2# karst cave water overflows, 3# karst cave oil does not overflow, the stage water yield is equal to the water expansion amount of the 1# karst cave plus the water expansion amount of the 2# karst cave plus the total oil-water expansion amount of the 3# karst cave, the stage oil yield is equal to the oil expansion amount of the 1# karst cave plus the oil expansion amount of the 2# karst cave, and the water content of the oil well rises by one step due to the water production of the 2# karst cave; and (3) in the stage d, oil and water are produced simultaneously, 1# karst cave water overflows, 2# karst cave water overflows, 3# karst cave oil overflows, the stage water yield is equal to the water expansion amount of the 1# karst cave plus the water expansion amount of the 2# karst cave plus the water expansion amount of the 3# karst cave, and the stage oil yield is equal to the oil expansion amount of the 1# karst cave plus the oil expansion amount of the 2# karst cave plus the oil expansion amount of the 3# karst cave, so that the water content of the oil well is reduced by one step due to the oil production of the 3# karst cave. Through the analysis of the production dynamics of the three karst cave units, a certain relation between the fracture-cave structure in the oil reservoir and the change form of the water content can be deduced, so that the invention provides a new method for simulating the production dynamic water content in the elastic driving stage of the oil reservoir, thereby analyzing and knowing the fracture-cave structure.
Disclosure of Invention
The invention aims to overcome the defects of the prior art and provides a method for simulating the water content generated by a fracture-cavity type oil reservoir oil well, which contributes a new idea for analyzing the production dynamic water content and recognizing the fracture-cavity structure in the elastic driving stage of the fracture-cavity type oil reservoir.
The purpose of the invention is realized by the following technical scheme: a simulation method for water content output by a fracture-cavity oil reservoir oil well comprises the following steps: s1, firstly, establishing a description structure and description parameters of the multi-fracture-cavity unit oil reservoir; s2, simulating and calculating the stage oil yield and water yield of each fracture-cavity unit by using the fracture-cavity unit description structure and description parameters established in the step S1, combining the elastic driving stage material balance relation and the water content model in the oil reservoir development process and using the elastic expansion amount as the virtual injection amount of the fracture-cavity unit, so as to obtain the oil yield, the water yield and the accumulated water yield of the oil well; and S3, finally, calculating the change of the water content of the oil well along with the accumulated liquid production according to the obtained oil production, water production and accumulated liquid production of the oil well.
Preferably, the description structure of the fracture-cavity unit in step S1 is mainly represented by a tree structure, the solution cavity in the fracture-cavity unit is represented by a node, the crack in the fracture-cavity unit is represented by a connecting path, and the tree structure is constructed in a manner that child nodes are associated and point to the root node in a reverse order.
Preferably, the description parameters of the slot-hole unit in step S1 include a common attribute parameter of the slot-hole unit, a static attribute parameter of the karst-cave node unit, and a dynamic attribute parameter of the karst-cave node; the common attribute parameters of the fracture-cavity unit comprise a pressure parameter, a volume coefficient, a compression coefficient and a fluid viscosity:
the pressure parameter includes formation pressure PiCurrent formation pressure P and crude oil saturation pressure Pb，MPa，
The volume coefficient comprises the original volume coefficient B of the crude oiloiAnd the original volume coefficient B of formation waterwiThe method has the advantages of no dimension,
the compressibility comprises crude oil compressibility CoFormation water compression coefficient CwAnd the compression coefficient of rock Cf，MPa-1，
Fluid viscosity includes crude oil viscosity μoAnd formation water viscosity muw，mPa.s；
The static attribute parameters of the karst cave node unit comprise the original fluid reserves and the outlet positions of the karst caves, wherein j represents the jth node;
the original fluid reserves of the caverns include the reserves N of crude oiljReservoir of formation water WjAnd the total volume V of the karst cavejIn which V isj＝Nj+Wj，m3；
The outlet position including the underflow coefficient Cd,jAnd the overflow coefficient Cu,jSaid underflow coefficient Cd,jThe ratio of water volume to total volume when formation water overflows due to rise of an oil-water interface, and the overflow coefficient Cu,jThe ratio of the volume of water to the total volume when crude oil overflows due to the reduction of the oil-water interface;
the dynamic attribute parameters of the karst cave nodes comprise node oil-water interface coefficients CjNode time step inflow oil volume Vio,jNode time step inflow water volume Viw,jVolume V of oil and water flowing out of node in time stepow,jTime step outflow water content f of sum nodew,jWherein the node oil-water interface system CjThe number is the ratio of the volume of water to the total volume at the oil-water interface.
Preferably, in the step S2, the multi-fracture-hole unit tree-shaped structure model established in the step S1 is utilized, a numerical simulation method is adopted, a pressure drop step Δ p is used as a time step, the karst cave inflow is equal to the outflow according to the material balance relationship, the virtual oil-water inflow amount and the outflow water content of the node are calculated from the bottom leaf node of the tree-shaped structure, the node is scanned and calculated layer by layer until the root node is traced back, the outflow liquid amount and the outflow water content of the oil well are obtained, the node is scanned repeatedly until the total pressure drop reaches a target value, and the calculation is finished; the specific method comprises the following steps: s21, scanning from the bottom of the tree structure by taking a pressure drop step as a time step, and calculating the virtual oil-water inflow liquid quantity and the inflow water content of the node, wherein the virtual oil-water inflow liquid quantity of the node comprises the external inflow quantity generated by the front terminal node and the volume expansion quantity of the residual fluid of the node; s22, judging the relation between the oil-water interface position of the node and the upper and lower overflow points in the processes before and after the node flows in, and under different conditions, calculating the submergence and the outflow water content by combining the seam hole structure of the node to obtain the outflow oil-water volume of the node; s23, updating the interface coefficient of the node and the stage inflow of the rear-end father node; s24, scanning upwards, executing the step S21 and the step S22 on the upper parent node, and then executing the step S23 until the root node is traced back to obtain the outflow liquid volume and outflow water content of the oil well; s25, when the pressure drop does not reach the target value, repeating the steps S21 to S24, when the pressure drop reaches the set value, executing the step S26; and S26, finishing the calculation.
Preferably, the oil virtual inflow at the node j in the step S21 is: v. ofo,j＝vio,j+(1-Cj)Vj(Co+Cf)Δp，
Virtual inflow of water to node j: v. ofw,j＝viw,j+CjVj(Cw+Cf)Δp，
Influent flow at node j: v. ofow,j＝vo,j+vw,j，
Inflow water content of node j: f. ofiw,j＝vw,j/vow,jWhere j represents the jth node.
Preferably, the step S22 of calculating the outflow water content of the node needs to determine the relationship between the oil-water interface and the upper and lower overflow points of the node before and after the inflow liquid amount flows, where j represents the jth node:
(a) if the crude oil water interface is below the underflow point and the interface after addition of influent water is below the underflow point, Cj＜Cd,jAnd is
The node only produces oil and does not produceWater, outflow water content fw,jWhen it is 0, step S23 is executed;
(b) if the crude oil water interface is above the overflow point and the interface minus the incoming oil is above the overflow point, Cj＞Cu,jAnd is
The node only produces water and does not produce oil, and the water content of the outflow is fw,jStep S23 is executed as 1;
(c) if the water interface of the crude oil is between the upper and lower overflow points, i.e. Cd,j≤Cj≤Cu,jIf so, performing joint oil-water co-production, calculating the outflow water content by using the submergence degree model, and executing the step S23;
(d) if the crude oil water interface is below the underflow point and the interface after addition of influent water is above the underflow point, Cj＜Cd,jAnd is
The oil-water interface of the node rises over the lower overflow point, only oil is produced and water is not produced at the front stage of the pressure time step, the oil and water are produced at the rear stage of the pressure time step simultaneously, the inflow can be divided into two parts, the first part is that the oil-water interface rises to the lower overflow point, the second part enters between the upper overflow point and the lower overflow point, the outflow water content of the node j after the inflow of the first part of the node j is calculated according to the condition (a), then the outflow water content of the node j after the inflow of the second part of the node j is calculated according to the condition (c), and after the outflow water content of the node j is obtained, the step S23 is executed;
calculating the water inflow amount of the first part of the oil-water interface rising to the underflow point: v. ofw1＝Vj(Cj-Cd,j) Calculating the energy consumption proportion of the first part according to the inflow amount of water: k is vw1/vw,jTherefore, the node input parameters of the first part are:
virtual inflow volume of crude oil at node j: v. ofo,j'＝kvo,j，
Formation water virtual inflow volume at node j: v. ofw,j'＝kvw,j，
Inflow of node jLiquid amount: v. ofow,j'＝kvow,j
Inflow water content of node j: f. ofiw,j'＝vw,j'/vow,j；
The node input parameters of the second part are as follows:
virtual inflow volume of crude oil at node j: v. ofo,j'＝(1-k)vo,j，
Formation water virtual inflow volume at node j: v. ofw,j'＝(1-k)vw,j，
Influent flow at node j: v. ofow,j'＝(1-k)vow,j，
Inflow water content of node j: f. ofiw,j'＝vw,j'/vow,j；
(e) If the crude oil water interface is above the overflow point and the interface minus the incoming oil is below the overflow point, Cj＞Cu,jAnd is
The oil-water interface of the node falls to cross the upper overflow point, only water is produced and oil is not produced at the front stage of the pressure time step, oil and water are produced at the rear stage of the pressure time step simultaneously, the inflow can be divided into two parts, the first part is that the oil-water interface falls to the upper overflow point, the second part enters between the upper overflow point and the lower overflow point, the outflow water content of the inflow of the first part of the node j is calculated according to the condition of (b), then the outflow water content of the inflow of the second part of the node j is calculated according to the condition of (c), and after the outflow water content of the node j is obtained, the step S23 is executed;
calculating the oil inflow amount of the first part of oil-water interface rising to the underflow point: v. ofo1＝Vj(Cj-Cu,j) Calculating the energy consumption ratio of the first part according to the oil inflow: k is vo1/vo,jTherefore, the node input parameters of the first part are:
virtual inflow volume of crude oil at node j: v. ofo,j'＝kvo,j，
Formation water virtual inflow volume at node j: v. ofw,j'＝kvw,j，
Influent flow at node j: v. ofow,j'＝kvow,j
Inflow water content of node j: f. ofiw,j'＝vw,j'/vow,j；
The node input parameters of the second part are as follows:
virtual inflow volume of crude oil at node j: v. ofo,j'＝(1-k)vo,j，
Formation water virtual inflow volume at node j: v. ofw,j'＝(1-k)vw,j，
Influent flow at node j: v. ofow,j'＝(1-k)vow,j，
Inflow water content of node j: f. ofiw,j'＝vw,j'/vow,j；
Preferably, in the step S22, the specific method for calculating the effluent water content by using the submergence model is as follows:
(1) calculating the initial value of the pressure drop time step of the node j submergence: sj＝(Cj-Cd,j)/(Cu,j-Cd,j)；
(2) Solving the model of the sinking degree to obtain the sinking degree of the node
New value:
(3) by using the value of submergence
Calculating the pressure drop time step outflow water content of the node according to the new value:
wherein f isiwJ is the inflow water content of the node j, and a is muw/μo，b＝VA,j/vow,j，VA,jVolume of oil-water co-production zone, V, of node jA,j＝Vj(Cu,j-Cd,j)。
Preferably, the step S23 updates the interface coefficients of the nodes and the stage inflow amount of the rear parent node, where j represents the jth node, and k represents the rear parent node of the node j, and the specific method thereof is as follows:
node j original oil volume: vo,j＝Vj(1-Cj)，
Original water volume of node j: vw,j＝VjCj，
Remaining oil volume at node j:
remaining water volume at node j:
and updating the interface coefficient of the node j:
update rear parent node k oil inflow: v. ofio,k *＝vio,k+vow,j(1-fw,j)。
The invention has the following advantages:
the fracture-cavity structure of the oil reservoir is recognized through production dynamic analysis, which is one of the main targets of dynamic monitoring of the fracture-cavity oil reservoir, the space structure of the fracture-cavity oil reservoir is extremely complex, and the conventional oil reservoir simulation technology is difficult to depict and describe. The invention adopts a volume equivalent mode to describe the size of a karst cave reservoir body to eliminate the influence of the karst cave form, adopts overflow points and an oil-water interface mode to describe the change of the karst cave output constitution, adopts a tree structure to describe the communication mode between a plurality of karst caves and a production well, and quickly calculates the accumulated liquid production amount and the change of the water content under specific pressure drop based on the material balance relation. The invention provides a quantitative analysis approach for identifying the incidence relation between the water content change mode and the fracture-cavity unit structure mode of the fracture-cavity oil reservoir, detecting the fracture-cavity unit structure of oil well communication and evaluating and controlling reserves.
Drawings
FIG. 1 is a schematic diagram of multi-step water content of a multi-karst-cave water-producing synthetic oil well;
FIG. 2 is a simulation result of the water content of the double-slit-hole unit;
FIG. 3 is a simulation result of water accumulation of a double-slot-hole unit;
FIG. 4 is a water content simulation result of a three-slot-hole unit;
FIG. 5 shows the simulation result of water accumulation of a three-slot hole unit.
Detailed Description
The invention will be further described with reference to the accompanying drawings, but the scope of the invention is not limited to the following.
A simulation method for water content output by a fracture-cavity oil reservoir oil well comprises the following steps: s1, firstly, establishing a description structure and description parameters of the multi-fracture-cavity unit oil reservoir; s2, simulating and calculating oil yield and water yield of each fracture-cavity unit stage by using the fracture-cavity unit description structure and description parameters established in S1, combining the elastic driving stage material balance relation and the water content model in the oil reservoir development process and using elastic energy as the virtual injection quantity of the fracture-cavity unit, so as to obtain the oil yield, the water yield and the accumulated water yield of the oil well; and S3, finally, calculating the change of the water content of the oil well along with the accumulated liquid production according to the obtained oil production, water production and accumulated liquid production of the oil well.
Preferably, the description structure of the fracture-cavity unit in step S1 is mainly represented by a tree structure, the solution cavity in the fracture-cavity unit is represented by a node, the crack in the fracture-cavity unit is represented by a connecting path, and the tree structure is constructed in a manner that child nodes are associated and point to the root node in a reverse order.
Preferably, the description parameters of the slot-hole unit in step S1 include a common attribute parameter of the slot-hole unit, a static attribute parameter of the karst-cave node unit, and a dynamic attribute parameter of the karst-cave node; the common attribute parameters of the fracture-cavity unit comprise a pressure parameter, a volume coefficient, a compression coefficient and a fluid viscosity:
the pressure parameter includes formation pressure PiCurrent formation pressure P and crude oil saturation pressure Pb，MPa，
Volume factor packageOriginal volume coefficient B of crude oiloiAnd the original volume coefficient B of formation waterwiThe method has the advantages of no dimension,
the compressibility comprises crude oil compressibility CoFormation water compression coefficient CwAnd the compression coefficient of rock Cf，MPa-1，
Fluid viscosity includes crude oil viscosity μoAnd formation water viscosity muw，mPa.s；
The static attribute parameters of the karst cave node unit comprise the original fluid reserves and the outlet positions of the karst cave, wherein j represents the jth node,
the original fluid reserves of the caverns include the reserves N of crude oiljReservoir of formation water WjAnd the total volume V of the karst cavejIn which V isj＝Nj+Wj，m3，
The outlet position including the underflow coefficient Cd,jAnd the overflow coefficient Cu,jSaid underflow coefficient Cd,jThe ratio of water volume to total volume when formation water overflows due to rise of an oil-water interface, and the overflow coefficient Cu,jThe ratio of the volume of water to the total volume when crude oil overflows due to the reduction of the oil-water interface;
the dynamic attribute parameters of the karst cave nodes comprise node oil-water interface coefficients CjNode time step inflow oil volume Vio,jNode time step inflow water volume Viw,jVolume V of oil and water flowing out of node in time stepow,jTime step outflow water content f of sum nodew,jWherein the node oil-water interface system CjThe number is the ratio of the volume of water to the total volume at the oil-water interface.
Preferably, in the step S2, the multi-fracture-cavity unit tree-shaped structure model established in the step S1 is utilized, a numerical simulation method is adopted, a pressure drop step length is used as a time step, the karst cave inflow rate is equal to the outflow rate according to the material balance relationship, the virtual oil-water inflow amount and the outflow water content of the node are calculated from the bottom leaf node of the tree-shaped structure, the node is scanned and calculated layer by layer until the root node is traced back, the outflow liquid amount and the outflow water content of the oil well are obtained, the node is scanned repeatedly until the total pressure drop reaches a target value, and the calculation is finished; the specific method comprises the following steps: s21, scanning from the bottom of the tree structure by taking a pressure drop step delta p as a time step, and calculating the oil-water virtual inflow and the inflow water content of the node, wherein the node oil-water virtual inflow comprises the external inflow generated by the front terminal node and the volume expansion of the residual fluid of the node; s22, judging the relation between the oil-water interface of the node and the upper and lower overflow points in the processes before and after the inflow liquid amount flows into the node, and calculating the submergence and the outflow water content by combining the seam hole structure of the node under different conditions to obtain the outflow oil-water volume of the node; s23, updating the interface coefficient of the node and the stage inflow of the rear-end father node; s24, scanning upwards, executing the steps S21 and S22 on the upper parent node, and then executing the step S23 until the root node is traced back, so as to obtain the outflow liquid amount and accumulate the numerical value; s25, when the pressure drop does not reach the target value, the step S21 is repeatedly executed, and when the pressure drop reaches the set value, the step S26 is executed; and S26, finishing the calculation.
Preferably, the oil virtual inflow at the node j in the step S21 is: v. ofo,j＝vio,j+(1-Cj)Vj(Co+Cf)Δp，
Virtual inflow of water to node j: v. ofw,j＝viw,j+CjVj(Cw+Cf)Δp，
Influent flow at node j: v. ofow,j＝vo,j+vw,j，
Inflow water content of node j: f. ofiw,j＝vw,j/vow,jWhere j represents the jth node.
Preferably, the step S22 of calculating the outflow water content of the node needs to determine the relationship between the oil-water interface and the upper and lower overflow points of the node before and after the inflow liquid amount flows, where j represents the jth node:
(a) if the crude oil water interface is below the underflow point and the interface after addition of influent water is below the underflow point, Cj＜Cd,jAnd is
The node only produces oilNo water production and outflow water content fw,jWhen it is 0, step S23 is executed;
(b) if the crude oil water interface is above the overflow point and the interface minus the incoming oil is above the overflow point, Cj＞Cu,jAnd is
The node only produces water and does not produce oil, and the water content of the outflow is fw,jStep S23 is executed as 1;
(c) if the water interface of the crude oil is between the upper and lower overflow points, i.e. Cd,j≤Cj≤Cu,jIf so, performing joint oil-water co-production, calculating the outflow water content by using the submergence degree model, and executing the step S23;
(d) if the crude oil water interface is below the underflow point and the interface after addition of influent water is above the underflow point, Cj＜Cd,jAnd is
The oil-water interface of the node rises over the lower overflow point, only oil is produced and water is not produced at the front stage of the pressure time step, the oil and water are produced at the rear stage of the pressure time step simultaneously, the inflow can be divided into two parts, the first part is that the oil-water interface rises to the lower overflow point, the second part enters between the upper overflow point and the lower overflow point, the outflow water content of the node j after the inflow of the first part of the node j is calculated according to the condition (a), then the outflow water content of the node j after the inflow of the second part of the node j is calculated according to the condition (c), and after the outflow water content of the node j is obtained, the step S23 is executed;
calculating the water inflow amount of the first part of the oil-water interface rising to the underflow point: v. ofw1＝Vj(Cj-Cd,j) Calculating the energy consumption proportion of the first part according to the inflow amount of water: k is vw1/vw,jTherefore, the node input parameters of the first part are:
virtual inflow volume of crude oil at node j: v. ofo,j'＝kvo,j，
Formation water virtual inflow volume at node j: v. ofw,j'＝kvw,j，
Of node jThe amount of the influent liquid: v. ofow,j'＝kvow,j
Inflow water content of node j: f. ofiw,j'＝vw,j'/vow,j；
The node input parameters of the second part are as follows:
virtual inflow volume of crude oil at node j: v. ofo,j'＝(1-k)vo,j，
Formation water virtual inflow volume at node j: v. ofw,j'＝(1-k)vw,j，
Influent flow at node j: v. ofow,j'＝(1-k)vow,j，
Inflow water content of node j: f. ofiw,j'＝vw,j'/vow,j；
(e) If the crude oil water interface is above the overflow point and the interface minus the incoming oil is below the overflow point, Cj＞Cu,jAnd is
The oil-water interface of the node falls to cross the upper overflow point, only water is produced and oil is not produced at the front stage of the pressure time step, oil and water are produced at the rear stage of the pressure time step simultaneously, the inflow can be divided into two parts, the first part is that the oil-water interface falls to the upper overflow point, the second part enters between the upper overflow point and the lower overflow point, the outflow water content of the inflow of the first part of the node j is calculated according to the condition of (b), then the outflow water content of the inflow of the second part of the node j is calculated according to the condition of (c), and after the outflow water content of the node j is obtained, the step S23 is executed;
calculating the oil inflow amount of the first part of oil-water interface rising to the underflow point: v. ofo1＝Vj(Cj-Cu,j) Calculating the energy consumption ratio of the first part according to the oil inflow: k is vo1/vo,jTherefore, the node input parameters of the first part are:
virtual inflow volume of crude oil at node j: v. ofo,j'＝kvo,j，
Formation water virtual inflow volume at node j: v. ofw,j'＝kvw,j，
Influent flow at node j: v. ofow,j'＝kvow,j
Inflow water content of node j: f. ofiw,j'＝vw,j'/vow,j；
The node input parameters of the second part are as follows:
virtual inflow volume of crude oil at node j: v. ofo,j'＝(1-k)vo,j，
Formation water virtual inflow volume at node j: v. ofw,j'＝(1-k)vw,j，
Influent flow at node j: v. ofow,j'＝(1-k)vow,j，
Inflow water content of node j: f. ofiw,j'＝vw,j'/vow,j；
Preferably, in the step S22, the specific method for calculating the effluent water content by using the submergence model is as follows:
(1) calculating the initial value of the pressure drop time step of the node j submergence: sj＝(Cj-Cd,j)/(Cu,j-Cd,j)；
(2) Solving the model of the sinking degree to obtain the sinking degree of the node
New value:
(3) by using the value of submergence
Calculating the pressure drop time step outflow water content of the node according to the new value:
wherein f isiw,jIs the inflow water ratio of the node j, and a is ═ muw/μo，b＝VA,j/vow,j，VA,jCalculating V from the overflow coefficient for the volume of oil-water co-production zone at node jA,j＝Vj(Cu,j-Cd,j)。
Preferably, the step S23 updates the interface coefficients of the nodes and the stage inflow amount of the rear parent node, where j represents the jth node, and k represents the rear parent node of the node j, and the specific method thereof is as follows:
node j original oil volume: vo,j＝Vj(1-Cj)，
Original water volume of node j: vw,j＝VjCj，
Remaining oil volume at node j:
remaining water volume at node j:
and updating the interface coefficient of the node j:
update rear parent node k oil inflow: v. ofio,k *＝vio,k+vow,j(1-fw,j)。
Example analysis:
setting basic parameters: the volume coefficient of crude oil is 1.05, the volume coefficient of formation water is 1.02, and the compression coefficient of crude oil is 0.0015MPa-1Formation water compressibility factor of 0.0005MPa-1Compression coefficient of rock 0.0004MPa-1Crude oil viscosity of 25mPa.s, formation water viscosity of 0.25mPa.s, original formation pressure of 55MPa, and current formation pressure of 40 MPa.
As shown in figures 2 and 3, the structure and oil-water reserves of a double-fracture-cavity unit are defined in a table 1, an oil well is communicated with the fracture-cavity unit 1, the water content of the unit 1 is the output water content of the oil well, the fracture-cavity unit 2 supplies liquid to the unit 1, the water content change and the accumulated water production change of each fracture-cavity unit are calculated in a simulation mode, and the step-type change process of the water content of the fracture-cavity oil reservoir oil well is reflected. The original oil-water interface of the slotted hole unit 1 is lower than a lower overflow point, and oil production is performed firstly and then water is obtained after production; the original oil-water interface in the slotted hole unit 2 is lower than the upper overflow point and higher than the lower overflow point, water production starts when the slotted hole unit 2 is put into production, the water content is reduced along with the reduction of the oil-water interface, and the water content of the slotted hole unit 2 is reduced to cause the reduction of the water content of the unit 1.
TABLE 1 definition of two slot unit structures and oil-water reserves
As shown in figures 4 and 5, the structure and oil-water reserves of three fracture-cavity units are defined in a table 2, an oil well is communicated with the fracture-cavity unit 1, the fracture-cavity unit 2 and the unit 3 supply liquid to the unit 1, and the water content change and the accumulated water production change of each fracture-cavity unit are simulated and calculated to reflect the step-type change process of the water content of the fracture-cavity type oil reservoir oil well. The original oil-water interfaces of the slotted hole unit 2 and the slotted hole unit 3 are lower than a lower overflow point, oil production is performed firstly after production, and then water breakthrough is performed, and the water breakthrough time of the unit 2 is inconsistent with that of the unit 3 due to different relative positions of oil-water reserves and the overflow points; the original oil-water interface of the slotted hole unit 1 is higher than the underflow point, water production starts when the slotted hole unit is put into operation, but the water content of the unit 1 is reduced to a lower level after oil injection along with the units 2 and 3, and the water content of the unit 1 is increased due to the water production of the units 2 and 3 in the later period.
TABLE 2 Structure and oil-water reserves definition of three slotted-hole units
While the invention has been described with respect to a preferred embodiment, it will be understood by those skilled in the art that various changes and modifications may be made without departing from the spirit and scope of the invention.
Claims (8)
1. A simulation method for water content output by a fracture-cavity oil reservoir oil well is characterized by comprising the following steps: the method comprises the following steps:
s1, firstly, establishing a description structure and description parameters of the multi-fracture-cavity unit oil reservoir;
s2, simulating and calculating the oil yield and the water yield of each fracture-cavity unit stage by utilizing the fracture-cavity unit description structure and description parameters established in the step S1, combining the elastic driving stage material balance relation and the water content model in the oil reservoir development process and using the volume elastic expansion amount as the virtual injection amount of the fracture-cavity unit, so as to obtain the oil yield, the water yield and the accumulated water yield of the oil well;
and S3, finally, calculating the change of the water content of the oil well along with the accumulated liquid production according to the obtained oil production, water production and accumulated liquid production of the oil well.
2. The method for simulating the water content of the fracture-cavity oil reservoir oil well as claimed in claim 1, wherein: the description structure of the fracture-cavity unit in the step S1 is mainly represented by a tree structure, the karst cavity in the fracture-cavity unit is represented by nodes, the cracks in the fracture-cavity unit are represented by connecting paths, and the tree structure is constructed in a manner that child nodes are associated in a reverse order and point to root nodes.
3. The method for simulating the water content of the fracture-cavity oil reservoir oil well as claimed in claim 2, wherein: the description parameters of the slot hole unit in the step S1 include a common attribute parameter of the slot hole unit, a static attribute parameter of the karst cave node unit, and a dynamic attribute parameter of the karst cave node;
the common attribute parameters of the fracture-cavity unit comprise a pressure parameter, a volume coefficient, a compression coefficient and fluid viscosity, and the pressure parameter comprises formation pressure PiCurrent formation pressure P and crude oil saturation pressure Pb，MPa，
The volume coefficient comprises the original volume coefficient B of the crude oiloiAnd the original volume coefficient B of formation waterwiThe method has the advantages of no dimension,
the compressibility comprises crude oil compressibility CoFormation water compression coefficient CwAnd the compression coefficient of rock Cf，MPa-1，
Fluid viscosity includes crude oil viscosity μoAnd formation water viscosity muw，mPa.s；
The static attribute parameters of the karst cave node unit comprise the original fluid reserves and the outlet positions of the karst cave, wherein j represents the jth node,
the original fluid reserves of the caverns include the reserves N of crude oiljReservoir of formation water WjAnd the total volume V of the karst cavejIn which V isj＝Nj+Wj，m3；
The outlet position including the underflow coefficient Cd,jAnd the overflow coefficient Cu,jSaid underflow coefficient Cd,jThe ratio of water volume to total volume when formation water overflows due to rise of an oil-water interface, and the overflow coefficient Cu,jThe ratio of the volume of water to the total volume when crude oil overflows due to the reduction of the oil-water interface;
the dynamic attribute parameters of the karst cave nodes comprise node oil-water interface coefficients CjNode time step inflow oil volume Vio,jNode time step inflow water volume Viw,jVolume V of oil and water flowing out of node in time stepow,jTime step outflow water content f of sum nodew,jWherein the node oil-water interface system CjThe number is the ratio of the volume of water to the total volume at the oil-water interface.
4. The method for simulating the water content of the fracture-cavity oil reservoir oil well as claimed in claim 3, wherein: step S2 is to use the multi-fracture-cavity unit tree structure model established in step S1, to use a numerical simulation method, to take a pressure drop step Δ p as a time step, and according to a material balance relationship, the karst cave inflow is equal to the outflow, to calculate the virtual oil-water inflow and outflow water content of the node from the bottom leaf node of the tree structure, to perform scanning calculation layer by layer until the root node is traced back, to obtain the outflow liquid amount and outflow water content of the oil well, to repeat scanning the node until the total pressure drop reaches a target value, to end the calculation; the specific method comprises the following steps:
s21, scanning from the bottom of the tree structure by taking a pressure drop step delta p as a time step, and calculating the virtual oil-water inflow liquid quantity and the inflow water content of the node, wherein the virtual oil-water inflow liquid quantity of the node comprises the external inflow quantity generated by the front terminal node and the volume expansion quantity of the residual fluid of the node;
s22, judging the relation between the oil-water interface position of the node and the upper and lower overflow points in the processes before and after the node flows in, and under different conditions, calculating the submergence and the outflow water content by combining the seam hole structure of the node to obtain the outflow oil-water volume of the node;
s23, updating the interface coefficient of the node and the stage inflow of the rear-end father node;
s24, scanning upwards, executing the step S21 and the step S22 on the upper parent node, and then executing the step S23 until the root node is traced back to obtain the outflow liquid volume and outflow water content of the oil well;
s25, when the pressure drop does not reach the target value, repeating the steps S21 to S24, when the pressure drop reaches the set value, executing the step S26;
and S26, finishing the calculation.
5. The method for simulating the water content of the fracture-cavity oil reservoir oil well as claimed in claim 4, wherein: virtual inflow of oil to the node j in the step S21: v. ofo,j＝vio,j+(1-Cj)Vj(Co+Cf)Δp，
Virtual inflow of water to node j: v. ofw,j＝viw,j+CjVj(Cw+Cf)Δp，
Influent flow at node j: v. ofow,j＝vo,j+vw,j，
Inflow water content of node j: f. ofiw,j＝vw,j/vow,jWhere j represents the jth node.
6. The method for simulating the water content of the fracture-cavity oil reservoir oil well as claimed in claim 5, wherein: in the step S22, calculating the outflow water content of the node requires determining the relationship between the oil-water interface position of the node and the upper and lower overflow points in the processes before and after the node flows into the node, where j represents the jth node:
(a) if the crude oil water interface is lower than the underflow overflowAt a point and the interface after the addition of influent water is below the lower overflow point, i.e. Cj＜Cd,jAnd is
The node only produces oil and does not produce water, and the water content f flows outw,jWhen it is 0, step S23 is executed;
(b) if the crude oil water interface is above the overflow point and the interface minus the incoming oil is above the overflow point, Cj＞Cu,jAnd is
The node only produces water and does not produce oil, and the water content of the outflow is fw,jStep S23 is executed as 1;
(c) if the water interface of the crude oil is between the upper and lower overflow points, i.e. Cd,j≤Cj≤Cu,jIf so, performing joint oil-water co-production, calculating the outflow water content by using the submergence degree model, and executing the step S23;
(d) if the crude oil water interface is below the underflow point and the interface after addition of influent water is above the underflow point, Cj＜Cd,jAnd is
The oil-water interface of the node rises over the lower overflow point, only oil is produced and water is not produced at the front stage of the pressure time step, the oil and water are produced at the rear stage of the pressure time step simultaneously, the inflow can be divided into two parts, the first part is that the oil-water interface rises to the lower overflow point, the second part enters between the upper overflow point and the lower overflow point, the outflow water content of the node j after the inflow of the first part of the node j is calculated according to the condition (a), then the outflow water content of the node j after the inflow of the second part of the node j is calculated according to the condition (c), and after the outflow water content of the node j is obtained, the step S23 is executed;
(e) if the crude oil water interface is above the overflow point and the interface minus the incoming oil is below the overflow point, Cj＞Cu,jAnd is
And (3) the oil-water interface of the node falls to cross the upper overflow point, only water is produced and oil is not produced at the front stage of the pressure time step, oil and water are produced at the rear stage of the pressure time step simultaneously, the inflow can be divided into two parts, the first part is that the oil-water interface falls to the upper overflow point, the second part enters between the upper overflow point and the lower overflow point, the outflow water content of the inflow of the first part of the node j is calculated according to the condition (b), the outflow water content of the inflow of the second part of the node j is calculated according to the condition (c), and the step S23 is executed after the outflow water content of the node j is obtained.
7. The method for simulating the water content of the fracture-cavity oil reservoir oil well as claimed in claim 6, wherein: in the step S22, a specific method for calculating the outflow water content by using the submergence model is as follows:
(1) calculating the initial value of the pressure drop time step of the node j submergence: sj＝(Cj-Cd,j)/(Cu,j-Cd,j)；
(2) Solving the model of sinking to obtain nodes
New value of submergence degree:
(3) by using the value of submergence
Calculating the pressure drop time step outflow water content of the node according to the new value:
wherein f isiw,jIs the inflow water ratio of the node j, and a is ═ muw/μo，b＝VA,j/vow,j，VA,jVolume of oil-water co-production zone, V, of node jA,j＝Vj(Cu,j-Cd,j)。
8. The method for simulating the water content of the fracture-cavity oil reservoir oil well as claimed in claim 7, wherein: step S23 is to update the interface coefficients of the nodes and the stage inflow of the rear parent node, where j represents the jth node, and k represents the rear parent node of the node j, and the specific method is as follows:
node j original oil volume: vo,j＝Vj(1-Cj)，
Original water volume of node j: vw,j＝VjCj，
Remaining oil volume at node j:
remaining water volume at node j:
and updating the interface coefficient of the node j:
update rear parent node k oil inflow: v. ofio,k*＝vio,k+vow,j(1-fw,j)。
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