CN113356842B - Method for measuring wellbore oil reservoir parameter distribution based on packing particle accumulation - Google Patents
Method for measuring wellbore oil reservoir parameter distribution based on packing particle accumulation Download PDFInfo
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- 238000012856 packing Methods 0.000 title claims abstract description 124
- 239000002245 particle Substances 0.000 title claims abstract description 111
- 238000000034 method Methods 0.000 title claims abstract description 89
- 238000009826 distribution Methods 0.000 title claims abstract description 42
- 238000009825 accumulation Methods 0.000 title claims description 19
- 239000007788 liquid Substances 0.000 claims abstract description 81
- 238000012360 testing method Methods 0.000 claims abstract description 53
- 238000010521 absorption reaction Methods 0.000 claims abstract description 45
- 239000012530 fluid Substances 0.000 claims abstract description 43
- 238000011049 filling Methods 0.000 claims abstract description 40
- 230000035699 permeability Effects 0.000 claims abstract description 39
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 37
- 238000005213 imbibition Methods 0.000 claims abstract description 36
- 238000005259 measurement Methods 0.000 claims abstract description 28
- 230000008569 process Effects 0.000 claims abstract description 28
- 239000003129 oil well Substances 0.000 claims abstract description 6
- 238000010992 reflux Methods 0.000 claims description 20
- 238000011010 flushing procedure Methods 0.000 claims description 12
- 238000002347 injection Methods 0.000 claims description 7
- 239000007924 injection Substances 0.000 claims description 7
- 230000008859 change Effects 0.000 claims description 4
- 125000006850 spacer group Chemical group 0.000 claims 1
- 238000004519 manufacturing process Methods 0.000 abstract description 12
- 238000004364 calculation method Methods 0.000 description 16
- 239000010410 layer Substances 0.000 description 9
- 238000005086 pumping Methods 0.000 description 9
- 238000005516 engineering process Methods 0.000 description 5
- 238000005429 filling process Methods 0.000 description 5
- 238000010276 construction Methods 0.000 description 4
- 238000011161 development Methods 0.000 description 4
- 238000000691 measurement method Methods 0.000 description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 3
- 230000003247 decreasing effect Effects 0.000 description 2
- 230000009467 reduction Effects 0.000 description 2
- 239000004576 sand Substances 0.000 description 2
- 230000003068 static effect Effects 0.000 description 2
- 238000012795 verification Methods 0.000 description 2
- 239000004927 clay Substances 0.000 description 1
- 230000001186 cumulative effect Effects 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 238000003384 imaging method Methods 0.000 description 1
- 239000011229 interlayer Substances 0.000 description 1
- 238000011068 loading method Methods 0.000 description 1
- 239000011236 particulate material Substances 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 238000005325 percolation Methods 0.000 description 1
- 239000012466 permeate Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 230000002265 prevention Effects 0.000 description 1
- 230000005855 radiation Effects 0.000 description 1
- 230000008439 repair process Effects 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
Abstract
A method for measuring wellbore reservoir parameter distribution based on packing particle packing, comprising the steps of: filling liquid or flowback liquid is injected into the well bore, and the length of a submerged section of packing particles accumulated in the well bore is changed; measuring and calculating the bottom hole pressure difference of an unsubmerged section in the shaft and the stratum liquid absorption amount; the imbibition index per meter in the wellbore and the distribution of formation permeability along the wellbore are calculated. The invention can directly and continuously measure the parameters of stratum such as imbibition index, stratum permeability and the like of each meter of the imbibition stratum by continuously changing the length of the submerged section of the packing particles in the well bore, and has the following advantages: firstly, the flow of the production fluid in the stratum in the underground actual exploitation process is directly simulated, so that stratum parameters can be directly and continuously measured, and the measurement result is greatly improved in the aspects of resolution, accuracy, precision and the like; secondly, the testing process is simple, the time consumption is less, and the cost is low; the adaptability is strong, and the stratum parameter measurement requirements of various oil wells such as open hole wells, cased hole wells and the like can be met.
Description
Technical Field
The invention belongs to the technical field of oil and gas exploitation, relates to a shaft, in particular to a method for measuring oil reservoir parameter distribution, and particularly relates to a method for measuring the oil reservoir parameter distribution of the shaft based on packing particle accumulation.
Background
In the development of oil fields, physical parameters of oil reservoirs along a shaft are required to be known, and the development and well repair design of the oil fields are facilitated, wherein the physical parameters comprise permeability, porosity, well diameter, fracture volume and the like, and in the actual oil field development process, the measurement of the permeability is crucial, the productivity of each layer is related, and the physical parameters are key parameters for dividing the layers.
However, the existing logging technology generally adopts an indirect measurement method to measure, for example, underground electric, magnetic, neutron radiation and other parameters are measured through a cable and a measuring instrument, and underground stratum parameters are indirectly measured by changing the running length of the cable. For stratum parameter measurement of a horizontal well, a logging tool is difficult to run into the horizontal section by gravity, the measurement while drilling precision is low, and the cost is high; the clay content is measured by natural gamma, the water saturation is measured by resistivity, the porosity is measured by neutron density radioactivity curve, and the permeability is measured inaccurately. Static data are measured with natural gamma logging, while permeability is a dynamic parameter. The error in calculating the permeability using static parameters is large, sometimes up to about 10 times. For a fractured reservoir, GVR imaging logging can measure the width of a fracture, but the accuracy is not high, and meanwhile, the logging cost is high, and the volume and the conductivity of the fracture cannot be measured. Well logging techniques do not meet the development requirements.
In order to make up for the shortages of logging technology, an oil field adopts an oil testing technology to measure formation parameters, the oil testing is to clamp a production end through two packers to measure the liquid production amount, and the formation parameters of other production sections are gradually clamped and tested. Because the formation permeability difference is large, the measurement result cannot be distinguished into each small layer; even if the measurement areas are the same large layer, there is a large difference in the in-layer permeability distribution, and the measurement result still cannot accurately reflect the actual stratum state.
Disclosure of Invention
The invention aims to overcome the defects of the prior art and provide the method for measuring the oil reservoir parameter distribution of the shaft based on packing particle accumulation, which can directly and continuously measure the stratum parameters, has simple measurement process, saves time and labor and has accurate result.
In order to achieve the above purpose, the invention adopts the following technical scheme:
a method for measuring wellbore reservoir parameter distribution based on packing particle packing, comprising the steps of: filling liquid or flowback liquid is injected into the well bore, and the length of a submerged section of packing particles accumulated in the well bore is changed; measuring and calculating the bottom hole pressure difference of an unsubmerged section in the shaft and the stratum liquid absorption amount; the imbibition index per meter in the wellbore and the distribution of formation permeability along the wellbore are calculated.
Further, the method for changing the length of the submerged section of packing particle accumulation in the well bore comprises the following steps: a packing fluid containing packing particles is injected into the wellbore, the packing particles accumulate from the distal end to the proximal end in the wellbore, and the submerged section increases in length.
Further, the wellbore is an open hole wellbore; in the process of filling the filling liquid, the length of a submerged section of packing particles accumulated in the well bore at any moment is obtained by dividing the accumulated volume of the packing particles (accumulated volume) in the well bore by the sectional area of the well bore.
Further, a seepage test tubular column is arranged in the shaft; filling liquid containing packing particles is injected into an annulus between the seepage testing tubular column and the well wall, and the packing particles are accumulated from inside to outside in the annulus; and obtaining the length of the submerged section of packing particle accumulation in the well bore at any moment through the reflux quantity of the wellhead filling liquid and the lateral pressure difference inside and outside the seepage test pipe column.
Further, for a wellbore filled with packing particles, the method for changing the length of a submerged section of packing particles accumulated in the wellbore is as follows: and (3) flowback the packed packing particles in the well bore to the well head, so that the length of the submerged section is reduced.
Further, the wellbore is an open hole wellbore; and (3) returning the packed packing particles in the well bore to the wellhead by lowering a coiled tubing flushing pipe into the well bore, so that the length of the submerged section is reduced.
Further, the length of the submerged section of the packing particle accumulation in the well bore at any moment is obtained by calculating the length of the coiled tubing flushing pipe.
Further, a seepage test tubular column is arranged in the shaft; packing particles are filled in the outer ring air between the seepage test pipe column and the well wall; and injecting flowback fluid into the annulus between the seepage test tubular column and the well wall, and after the flowback fluid enters the annulus through the seepage hole, flowback the packing particles fully accumulated in the annulus to the well head, so that the length of the submerged section is reduced.
Further, the length of the submerged section of packing particles accumulated in the well bore at any moment is obtained through the reflux quantity of wellhead flowback fluid and the pressure drop of the inner side and the outer side of the seepage test pipe column.
Further toThe density of the packing particles is 0.95 to 1.05g/cm 3 (true density rather than bulk density) with a particle size of 40-70 mesh; the packing particles form submerged sections in the wellbore stack that impede seepage from the walls of the submerged sections.
Further, the method for measuring the bottom hole differential pressure comprises the following steps: the injection pressure of the fluid/flowback fluid through the wellhead minus the edge Cheng Mazu; alternatively, the measurement is made directly by a downhole pressure gauge mounted on the seepage test string.
Further, the method for measuring the stratum liquid absorption amount comprises the following steps: and subtracting the reflux quantity of the wellhead filling liquid or the flowback liquid from the injection quantity of the wellhead filling liquid or the flowback liquid.
Further, the method of calculating the fluid absorption index per meter and the distribution of formation permeability along the wellbore comprises the steps of: calculating to obtain a stratum imbibition index according to the ratio of the stratum imbibition amount to the bottom hole pressure difference; calculating the ratio of the accumulated liquid absorption amount of the stratum in a period of time to the length change value of the submerged section and the bottom hole pressure difference in the period of time to obtain a liquid absorption index per meter; calculating to obtain the permeability of the liquid absorption layer section through a steady-state yield formula of a vertical well or a horizontal well; and drawing a distribution curve of the imbibition index per meter and the stratum permeability in the well bore along the well bore.
Further, the method for calculating and obtaining the permeability of the liquid absorption layer section through the steady-state yield formula of the vertical well or the horizontal well comprises the following steps: assuming that the stratum participating in imbibition is homogeneous and has equal thickness, and is a plane radial flow with a circular supply boundary, and the stratum with submerged section length participates in seepage within a period of time; and (3) through a steady-state yield formula of the vertical well or the horizontal well, the stratum liquid absorption amount is the oil well yield in the period, and the permeability of the liquid absorption layer section in the period is reversely calculated.
According to the method for measuring the oil reservoir parameter distribution of the shaft based on packing particle accumulation, the length of the submerged section of the packing particles in the shaft is continuously changed under different well conditions, so that stratum parameters such as the imbibition index and the stratum permeability of each meter of participating in imbibition stratum can be directly and continuously measured. Compared with the traditional indirect measurement method (the measurement method which indirectly reflects the stratum parameters through electromagnetism and the like), the method directly simulates the flow (reverse flow) of the production fluid in the stratum in the underground actual exploitation process, so that the stratum parameters can be measured directly and continuously, and the measurement result is greatly improved in the aspects of resolution, accuracy, precision and the like; secondly, the testing process is simple, the time consumption is less, and the cost is low; the adaptability is strong, and the stratum parameter measurement requirements of various oil wells such as open hole wells, cased hole wells and the like can be met.
Drawings
FIG. 1 is a schematic illustration of wellbore construction of a method for measuring wellbore reservoir parameter distribution based on packing particle accumulation in examples 1 and 3;
FIG. 2 is a schematic illustration of wellbore construction of one method of measuring wellbore reservoir parameter distribution based on packing particle accumulation in examples 2 and 4;
FIG. 3 is a schematic illustration of a wellbore construction of a method for measuring wellbore reservoir parameter distribution based on packing particle accumulation in example 5;
FIG. 4 is a graph of the results of the liquid absorption index per meter in example 5;
FIG. 5 is a graph of formation permeability results for example 5.
Detailed Description
An embodiment of a method for measuring wellbore reservoir parameter distribution based on packing particle accumulation according to the present invention is further described below with reference to fig. 1 to 5. The method for measuring the wellbore oil reservoir parameter distribution based on packing particle accumulation is not limited to the description of the following embodiments.
The term is used herein as defined below:
and (3) sealing particles: a round or other irregularly shaped particulate material, having a density approaching that of water, may be injected into the wellbore by a packing fluid or removed from the wellbore by a flowback fluid; the specific structure and the filling and flowback methods thereof refer to International patent application (application No. PCT/CN 2010/002014) oil and gas well production section channeling-preventing packing particles, a well completion method and an oil extraction method using the particles, and related technologies for oil and gas auxiliary exploitation by using the packing particles provided by Andongberlin Petroleum technology (Beijing) Limited.
Seepage test tubular column: the whole body is of a tube cavity structure, seepage holes are circumferentially arranged, and the diameters of the seepage holes are smaller than the diameters of the packing particles; the imbibition index of the seepage test pipe column is constant under the unit pressure difference (namely, the liquid flow rate of liquid flowing out of the pipe cavity or flowing into the pipe cavity from the outside is constant under the condition that the unit pressure difference exists inside and outside for the seepage test pipe column with the unit length). Specifically, the seepage test pipe column can be composed of a plurality of pipe columns with flow control devices, sand prevention filter screens are attached to the outer walls of the pipe columns, and the seepage test pipe column has the functions of controlling water, preventing sand and the like.
The meanings of the symbols used in the following text are as follows:
q is delta t The stratum liquid absorption in time, K is the permeability, mu is the viscosity of filling liquid, B 0 For the volume coefficient of the filling liquid, deltaP is the bottom hole pressure difference, a is the half length of the elliptic long axis, and L is DeltaP t Submerged segment length in time, h is reservoir thickness, r w For the radius of the well bore, r eh To drive radius, L 1 At t 1 Length of submerged segment at moment, L 2 At t 2 The length of the submerged section at moment, R is stratum imbibition index, P is wellhead pressure, P 1 For edge Cheng Mazu, P 0 Is the formation pressure, Q 1 For pumping into well head, Q 2 For reflux quantity, q is delta t Accumulating the filling and packing particle amount in the time, wherein S is the sectional area of the shaft, and l 1 At t 1 The running depth of the coiled tubing flushing pipe at moment, l 2 At t 1 The running depth of the coiled tubing flushing pipe is at the moment,at t 1 Seepage test pipe column length participating in flow at any time, < + >>At t 2 And the seepage test pipe column length which participates in the flow at any time. />At t 1 Pressure drop inside and outside the flow control device at moment +.>At t 2 The pressure drop inside and outside the flow control device at the moment.
Example 1:
the embodiment provides a specific method for measuring the oil reservoir parameter distribution of a shaft based on packing particle accumulation.
As shown in fig. 1, the well bore 1 is composed of a vertical well section 6 and a horizontal well section 3, and a packer 4 is arranged inside the well bore. The horizontal well section 3 is an open hole well, and is not cased or otherwise provided with a production string.
A packing fluid containing packing particles 5 is injected into the open hole wellbore through a surface equipment run-in, a portion of the packing fluid returning to the surface along the wellbore and a portion of the packing fluid penetrating the formation. Preferably, as much of the packing fluid as possible is lost through the formation by controlling the injection flow rate and injection pressure. Along with the leakage of filling liquid, the packing particles are deposited and accumulated continuously from the far end to the near end in the open hole shaft, and a submerged section is formed gradually. In the submerged section of the accumulated packing particles, the packing particles can effectively prevent formation fluid and injection fluid from flowing in the well space along the axial direction of the well or being absorbed by the well wall. As the filling continues, the distance of the submerged sections increases and the non-submerged sections decrease, and the formation fluid absorption capacity will gradually decrease under the same bottom hole pressure differential. In the filling process, the pumping quantity and the reflux quantity of the filling liquid are recorded in real time through a wellhead flowmeter, so that the stratum liquid absorption quantity can be calculated; recording pressure by a wellhead pressure gauge or a bottom hole pressure gauge, and further obtaining bottom hole pressure difference; the distribution of well diameters (i.e., wellbore diameters) is obtained by pre-logging.
The specific calculation process and principle are as follows:
in the filling process, the wellhead pressure, the pumping quantity and the reflux quantity at different moments are recorded, and the bottom hole pressure difference and the submerged stratum liquid absorption quantity are calculated. The bottom hole pressure difference can be obtained by subtracting the along-distance friction from the wellhead pressure.
ΔP＝P-P 1 -P 0
Similarly, the bottom hole pressure difference can be obtained by measuring the pressure gauge in the well in real time.
ΔP＝P 2 -P 0
Wherein: p is wellhead pressure, P 1 For edge Cheng Mazu, P 0 Is the formation pressure, P 2 Is the pressure of the downhole pressure gauge.
Q＝Q 01 -Q 02
Wherein: q (Q) 01 For pumping into well head, Q 02 For reflux, Q is the formation fluid absorption.
By delta t And calculating the accumulated filling amount of the packing particles by using the concentration of the packing particles of the filling liquid. The cumulative packing particle loading divided by the wellbore cross-sectional area gives delta t The length of the submerged segment is increased by a value.
Assuming a constant radius r, delta for the wellbore t The accumulated filling and packing particle quantity in the time is q, and the length of a shaft is L 0 Then
The shaft cross-sectional area is s=pi r 2
Particle submerged segment length l=q/pi r 2
Assuming a wellbore radius r (L), Δ t The accumulated filling and packing particle quantity in the time is q
The shaft cross-sectional area is s=pi r (L) 2
Particle submerged segment length l=q/pi r (L) 2
Stratum liquid absorption amount divided by stratum liquid absorption index of participation seepage at different moments by using delta t Accumulated fluid uptake of the formation over time divided by delta t And obtaining the imbibition index per meter by adding the length increment value of the submerged section and the bottom hole pressure difference in time.
Using the calculated formation fluid absorption and bottom hole pressure difference at different moments, the fluid absorption index of the seepage section of the stratum=fluid absorption/bottom hole pressure difference, i.e.
Wherein: r is stratum imbibition index
The liquid absorption index per meter is equal to delta t Accumulated fluid uptake of the formation over time divided by delta t Length of submerged segment in timeIncrease value and bottom hole pressure differential.
Open hole well with constant radius for well bore
Open hole for wellbore radius variation
Wherein:the liquid absorption index per meter.
Calculating delta by using steady-state yield formulas of the vertical well and the horizontal well t The time is related to the formation permeability of the imbibition.
The steady-state yield formula of the vertical well is utilized to obtain:
the steady-state yield formula of the horizontal well is utilized to obtain:
wherein,
wherein: ΔQ is Δ t The stratum liquid absorption in time, K is the permeability, mu is the viscosity of filling liquid, B 0 For the volume coefficient of the filling liquid, deltaP is the bottom hole pressure difference, a is the half length of the elliptic long axis, and L is DeltaP t Submerged segment length in time, h is reservoir thickness, r w For the radius of the well bore, r eh Is the driving radius.
And drawing a relation curve of the imbibition index and the permeability of each meter and the wellbore distribution by taking the length of the wellbore as an abscissa and the imbibition index and the permeability of each meter as an ordinate.
Aiming at a bare well, the embodiment adopts the technical scheme of directly filling packing particles, has simple testing process and low construction cost, and can realize continuous measurement of the liquid absorption index and the stratum permeability of each meter of stratum in the whole well section. By measuring the liquid absorption amount of the stratum, the liquid production capacity of the stratum after the production of the oil well can be accurately reflected.
Example 2:
the embodiment provides another specific method for measuring the wellbore oil reservoir parameter distribution based on packing particle accumulation.
As shown in fig. 2, the well bore 1 is composed of a vertical well section 6 and a horizontal well section 3, and a seepage test pipe column 2 and a hanging packer 4 are arranged in the well bore 1. And firstly, a seepage test pipe column is put into the underground production section, and the seepage test pipe column divides the shaft into two parts, namely a pipe column inner space and an outer annulus formed between the pipe column and the well wall. Filling liquid containing packing particles 5 is injected into the annular space through ground equipment, and a part of filling liquid enters the inner space of the pipe column through a seepage hole of the seepage test pipe column and returns to the ground; a portion of the packing fluid directly penetrates the formation. Because the particle size of the packing particles is larger than the diameter of the seepage holes, the filling liquid can smoothly pass through the seepage test pipe column, but the packing particles carried by the filling liquid cannot enter the seepage test pipe column, so that the packing particles are continuously deposited and piled up from the far end to the near end in an annulus between the pipe column and a well wall to form a submerged section. In the packed-formed flooding section, the packing particles can impede the axial flow of formation fluid and injected packing fluid along the wellbore or be absorbed by the formation. In the filling process, the pumping quantity and the reflux quantity are recorded in real time through a wellhead flowmeter, so that the stratum liquid absorption quantity is calculated; and recording the pressure by a wellhead pressure gauge or a bottom hole pressure gauge, and further obtaining the bottom hole pressure difference.
The specific calculation process and principle are as follows:
the well head pressure, pumping quantity and reflux quantity at different moments are recorded in the filling process, and the well bottom differential pressure and the liquid absorption quantity of the seepage section are measured and calculated, and the calculation method and the calculation process are the same as those in the embodiment 1.
Through the reflux quantity of the seepage test pipe column, participation can be calculatedThe length of the liquid suction test column is measured to obtain delta t Length of submerged segment in time
Reflux quantity Q passing through seepage test pipe column 02 Calculating the length of a seepage test pipe column participating in imbibition
Wherein: l (L) 0 And a is the flow control device coefficient, which is the length of a single flow control device.
Wherein:at t 1 Seepage test pipe column length participating in flow at any time, < + >>At t 2 And the seepage test pipe column length which participates in the flow at any time.
The method and process for calculating the formation imbibition index, which is the formation imbibition amount divided by the bottom hole differential pressure, at different times involved in seepage, was the same as in example 1. The liquid absorption index per meter is equal to delta t Accumulated fluid uptake of the formation over time divided by delta t The length increasing value of submerged section and the bottom hole pressure difference in time
Wherein: q (Q) 021 At t 1 Return amount of time, Q 022 At t 2 The amount of reflux at the moment of time,at t 1 Pressure drop inside and outside the flow control device at moment +.>At t 2 Internal and external pressure of flow control device at momentDescending.
Calculating delta by using steady-state yield formulas of the vertical well and the horizontal well t The specific calculation method and process for the formation permeability of the reference imbibition over time are the same as in example 1.
The imbibition index and permeability per meter were plotted against wellbore profile, with the specific plot method and procedure being the same as in example 1.
In the embodiment, the length of the submerged section can be calculated more accurately by arranging the seepage test pipe column and taking the seepage test pipe column as the scale for calculating the submerged section, so that the stratum parameters obtained by calculation have higher precision. Meanwhile, the packing particles filled in the well bore are easier to discharge through the seepage test pipe column, and the well bore is not damaged.
Example 3:
the embodiment provides another specific method for measuring the wellbore oil reservoir parameter distribution based on packing particle accumulation.
The wellbore configuration in this example is the same as in example 1. After filling the wellbore with packing particles by surface equipment, an entire submerged section is formed in the wellbore. And (3) feeding a coiled tubing flushing pipe, injecting flowback fluid, gradually stripping filled packing particles in the well bore from outside to inside, and discharging the filled packing particles back to the well head, so that the length of a submerged section of the packing particles is changed.
The specific calculation process and principle are as follows:
the specific calculation method and process for calculating the bottom hole pressure difference and participating in the liquid suction amount of the liquid suction section by recording the wellhead pressure, the pumping-in amount and the reflux amount at different moments in the flowback process are the same as those of the embodiment 1.
The running position of the coiled tubing can represent the stacking position of the packing particles by using the packing particles in the coiled tubing flushing pipe flowback shaft, thus passing delta t The change value of the running depth of the coiled tubing flushing pipe in the shaft in time is obtained to obtain delta t The length of the submerged segment is over time.
Through the running depth of the coiled tubing flushing pipe, delta is calculated t The submerged length L in time.
L＝l 2 -l 1
Wherein: l (L) 1 At t 1 The running depth of the coiled tubing flushing pipe at moment, l 2 At t 2 The running depth of the coiled tubing flushing pipe is measured at any time.
The method and process for calculating the formation fluid absorption divided by the fluid absorption index of the formation involved in seepage at different times by the bottom hole pressure difference are the same as in example 1. The liquid absorption index per meter is equal to delta t Accumulated fluid uptake of the formation over time divided by delta t Reduction in submerged segment length and bottom hole pressure differential over time
Calculating delta by using steady-state yield formulas of the vertical well and the horizontal well t The specific calculation method and process of the formation permeability of the reference seepage flow in time are the same as in example 1.
The imbibition index and permeability per meter were plotted against wellbore profile, with the specific plot method and procedure being the same as in example 1.
This embodiment can be regarded as the inverse of embodiment 1, i.e. the parameter distribution measurement is done by stepwise decreasing the submerged segments. In a specific application, the method described in example 1 may be used to perform a first measurement, after which the wellbore is filled with the packer particles; then, the method in this embodiment is used to perform the second measurement, so that not only the measurement result can be used as the verification for the first measurement, but also the well bore after the measurement is completed can directly have the production condition.
Example 4:
the embodiment provides another specific method for measuring the wellbore oil reservoir parameter distribution based on packing particle accumulation.
In this example, the wellbore structure was the same as in example 2, and the packing particles were packed into the inner space and the outer annulus of the percolation test string by the process of example 2. And injecting flowback fluid into the annulus through flowback holes of the seepage test pipe column by the flowback process of the seepage test pipe column, wherein a part of the flowback fluid flows out of a wellhead through a shaft, and a part of the flowback fluid is absorbed by the stratum. The flowback fluid gradually strips and carries the packer particles fully accumulated in the well bore out of the well bore, so that the submerged section formed by accumulating the packer particles is continuously shortened from outside to inside.
The specific calculation process and principle are as follows:
in the flowback process, the pumping quantity and the reflux quantity are recorded in real time through a wellhead flowmeter, so that the stratum liquid absorption quantity is calculated; and recording the pressure by a wellhead pressure gauge or a bottom hole pressure gauge, and further obtaining the bottom hole pressure difference.
The well head pressure, the pumping quantity and the reflux quantity at different moments are recorded in the flowback process, the bottom hole pressure difference and the stratum liquid absorption quantity participating in the seepage section are calculated, and the specific calculation method and the specific calculation process are the same as those in the embodiment 1
Reflux quantity Q passing through seepage test pipe column 02 The length of the test pipe column participating in the flowing can be calculatedTo obtain delta t The length L of the submerged segment in time.
Wherein: l (L) 0 For the length of a single flow control device, a is the coefficient of the flow control device
Wherein:at t 1 Length of the seepage column involved in the flow, +.>At t 2 The calculation method and process of the formation imbibition index of the seepage pipe column length of the participated flow are the same as that of the example 1, wherein the formation imbibition index at different moments is obtained by dividing the formation imbibition amount of the seepage pipe column length participated in the flow by the bottom hole pressure difference. The liquid absorption index per meter is equal to delta t Accumulated fluid uptake of the formation over time divided by delta t Submerged segment length reduction value and bottom hole pressure differential in time
Calculating delta by using steady-state yield formulas of the vertical well and the horizontal well t The specific calculation method and process of the formation permeability of reference and seepage flow in time are the same as those of the embodiment 1
The imbibition index and permeability per meter were plotted against wellbore profile, with the specific plot method and procedure being the same as in example 1.
This embodiment can be regarded as the inverse of embodiment 2, i.e. the parameter distribution measurement is done by stepwise decreasing the submerged segments. In a specific application, the method described in example 2 may be used to perform a first measurement, after which the wellbore is filled with the packer particles; then, the method in this embodiment is used to perform the second measurement, so that not only the measurement result can be used as the verification for the first measurement, but also the well bore after the measurement is completed can directly have the production condition.
Example 5:
this example shows the results of a specific implementation of measurements performed on a well using the method described in example 2.
As shown in fig. 3, a well bore structure of a certain oil well is schematically shown, the depth of the well is 2015 m, and the length D of the open hole horizontal segment 3 is as follows L The diameter r of the open hole is 8-1/2in, the packing particles 5 are 50 meshes, and the outer diameter of the seepage test pipe column is 172 mm. The effective thickness h of the oil reservoir is 19 meters, and the volume coefficient B of the filling liquid 0 A viscosity μ of 1.0, a driving radius r, and a viscosity μ of 1 mPa.s eh Is 30 meters.
The operation steps are as follows:
firstly, a seepage test pipe column with the length of 5-1/2 of an inch is put into a downhole horizontal section, and the seepage test pipe column divides a shaft into an inner annular space of the pipe column and an outer annular space between the pipe column and a well wall. And injecting filling liquid containing the packing particles into the well bore through surface equipment, wherein a part of the filling liquid returns out of the surface through the seepage test tubular column, and a part of the filling liquid permeates into the stratum. The filling liquid can smoothly pass through the seepage test pipe column, and the packing particles cannot pass through the pipe column, so that the packing particles are deposited and piled up continuously from the far end to the near end in the annular space of the pipe column and the well wall, and a submerged section is formed.
In the filling process, the pumping quantity and the reflux quantity are recorded in real time through a wellhead flowmeter, and then the liquid absorption quantity is calculated; and recording the pressure by a wellhead pressure gauge or a bottom hole pressure gauge, and further obtaining the bottom hole pressure difference. According to the measurement result, a change curve chart of the liquid suction amount and the bottom hole pressure difference along with the filling time can be drawn.
The method and process for calculating the liquid absorption index per meter are the same as those of example 2, and the calculation result is shown in fig. 4; the formation permeability was calculated in the same manner as in example 1 and the calculation result is shown in fig. 5.
By analyzing fig. 4 and 5, it can be determined that the reservoir has heterogeneity with a large variation in the imbibition index per meter and the formation permeability. The layers of 158-191 m and 442-475 m are strong imbibition sections, the permeability is high, and the reservoir is primarily judged to be cracked; the weak imbibition section is at 310-380 m interval, the permeability is low, which indicates that the reservoir has no crack and possibly a interlayer.
The foregoing is a further detailed description of the invention in connection with the preferred embodiments, and it is not intended that the invention be limited to the specific embodiments described. It will be apparent to those skilled in the art that several simple deductions or substitutions may be made without departing from the spirit of the invention, and these should be considered to be within the scope of the invention.
Claims (13)
1. In a method for measuring wellbore reservoir parameter distribution based on packing particle packing, the improvement comprising: the method comprises the following steps:
filling liquid or flowback liquid is injected into the well bore, and the length of a submerged section of packing particles accumulated in the well bore is changed;
measuring and calculating the bottom hole pressure difference of an unsubmerged section in the shaft and the stratum liquid absorption amount;
calculating the imbibition index per meter in the well bore and the distribution of stratum permeability along the well bore;
wherein the method of calculating the imbibition index per meter and the distribution of formation permeability in the wellbore along the wellbore comprises the steps of:
calculating to obtain a stratum imbibition index according to the ratio of the stratum imbibition amount to the bottom hole pressure difference;
calculating to obtain a liquid absorption index per meter according to the ratio of the accumulated liquid absorption amount of the stratum in a period of time to the length change value of the submerged section and the bottom hole pressure difference in the period of time;
calculating to obtain the permeability of the liquid absorption layer section through a steady-state yield formula of a vertical well or a horizontal well;
and drawing a distribution curve of the imbibition index per meter and the stratum permeability in the well bore along the well bore.
2. The method of measuring wellbore reservoir parameter distribution based on packing particle packing of claim 1, wherein: the method for changing the length of the submerged section of packing particle accumulation in the well bore comprises the following steps: a packing fluid containing packing particles is injected into the wellbore, the packing particles accumulate from the distal end to the proximal end in the wellbore, and the submerged section increases in length.
3. The method of measuring wellbore reservoir parameter distribution based on packing particle packing of claim 2, wherein: and in the process of filling the filling liquid, dividing the accumulated volume of the packing particles injected into the well bore by the sectional area of the well bore to obtain the length of the submerged section of the packing particles accumulated in the well bore at any moment.
4. The method of measuring wellbore reservoir parameter distribution based on packing particle packing of claim 2, wherein: a seepage test pipe column is arranged in the shaft; filling liquid containing packing particles is injected into an annulus between the seepage testing tubular column and the well wall, and the packing particles are accumulated from inside to outside in the annulus; and obtaining the length of the submerged section of packing particle accumulation in the well bore at any moment through the reflux quantity of the wellhead filling liquid and the lateral pressure difference inside and outside the seepage test pipe column.
5. The method of measuring wellbore reservoir parameter distribution based on packing particle packing of claim 1, wherein: for a wellbore filled with packing particles, the method for changing the length of a submerged section of packing particles accumulated in the wellbore is as follows: and (3) flowback the packed packing particles in the well bore to the well head, so that the length of the submerged section is reduced.
6. The method of measuring wellbore reservoir parameter distribution based on packing particle packing of claim 5, wherein: the shaft is an open hole well; and (3) returning the packed packing particles in the well bore to the wellhead by lowering a coiled tubing flushing pipe into the well bore, so that the length of the submerged section is reduced.
7. The method of measuring wellbore reservoir parameter distribution based on packing particle packing of claim 6, wherein: and calculating the length of a flushing pipe of the coiled tubing, and obtaining the length of a submerged section of packing particles accumulated in the well bore at any moment.
8. The method of measuring wellbore reservoir parameter distribution based on packing particle packing of claim 5, wherein: a seepage test pipe column is arranged in the shaft; packing particles are filled in the outer ring air between the seepage test pipe column and the well wall; and injecting flowback fluid into the annulus between the seepage test tubular column and the well wall, and after the flowback fluid enters the annulus through the seepage hole, flowback the packing particles fully accumulated in the annulus to the well head, so that the length of the submerged section is reduced.
9. The method of measuring wellbore reservoir parameter distribution based on packing particle packing of claim 8, wherein: and obtaining the length of the submerged section of packing particles accumulated in the well bore at any moment through the reflux quantity of the wellhead flowback fluid and the pressure drop of the inner side and the outer side of the seepage test pipe column.
10. The method of measuring wellbore reservoir parameter distribution based on packing particle packing of claim 1, wherein: the sealThe true density of the spacer particles is 0.95 to 1.05g/cm 3 The grain diameter is 40-70 meshes; the packing particles form submerged sections in the wellbore stack that impede seepage from the walls of the submerged sections.
11. The method of measuring wellbore reservoir parameter distribution based on packing particle packing of claim 1, wherein: the method for measuring the bottom hole pressure difference comprises the following steps: the injection pressure of the fluid/flowback fluid through the wellhead minus the edge Cheng Mazu; alternatively, the measurement is made directly by a downhole pressure gauge mounted on the seepage test string.
12. The method of measuring wellbore reservoir parameter distribution based on packing particle packing of claim 1, wherein: the method for measuring the stratum liquid absorption amount comprises the following steps: and subtracting the reflux quantity of the wellhead filling liquid or the flowback liquid from the injection quantity of the wellhead filling liquid or the flowback liquid.
13. The method of measuring wellbore reservoir parameter distribution based on packing particle packing of claim 1, wherein: the method for calculating and obtaining the permeability of the liquid absorption layer section through the steady-state yield formula of the vertical well or the horizontal well comprises the following steps:
assuming that the stratum participating in imbibition is homogeneous and has equal thickness, and is a plane radial flow with a circular supply boundary, and the stratum with submerged section length participates in seepage within a period of time;
and (3) through a steady-state yield formula of the vertical well or the horizontal well, the stratum liquid absorption amount is the oil well yield in the period, and the permeability of the liquid absorption layer section in the period is reversely calculated.
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