CN110541704A - method for evaluating staged water yield of compact oil multi-stage fracturing well by using tracer - Google Patents
method for evaluating staged water yield of compact oil multi-stage fracturing well by using tracer Download PDFInfo
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
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- E21B47/00—Survey of boreholes or wells
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- E—FIXED CONSTRUCTIONS
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- E21B—EARTH OR ROCK 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
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- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
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Abstract
the invention relates to a correlation technique in the field of dense oil fracturing fluid flowback tracing, in particular to a method for evaluating the staged water yield of a dense oil multi-stage fracturing well by using a tracer, which comprises the following steps: in the process of dense staged fracturing, injecting different types of trace element tracers into each stage of fracturing layer section according to the designed concentration and dosage, continuously monitoring a construction curve of the fracturing process, and obtaining the original formation pressure, the total dosage of fracturing fluid and the pump-stopping pressure of each stage; in the process of fracturing fluid flowback, continuously sampling and testing the concentration of different trace element tracers, the yield of wellhead flowback fluid and the wellhead pressure in the flowback fluid by adopting a 'density first and then sparse' strategy; and according to the monitoring data, drawing concentration curves of different tracers relative to the whole well liquid amount, selecting concentration values capable of representing the segmented liquid production capacity, calculating the formation pressure, the bottom hole pressure, the segmented flow-back liquid amount, the formation water yield and the water content of each fracturing segment at different time, and evaluating the fracturing effect.
Description
Technical Field
The invention relates to the related technology in the field of tight oil fracturing fluid flowback tracing, in particular to a method for evaluating the staged water yield of a tight oil multi-stage fracturing well by using a tracer.
background
at present, with the increasing of the oil-gas exploration and development strength, the large-scale volume fracturing of the horizontal well becomes the most effective technical means for developing unconventional reservoirs such as compact oil, and the number of fracturing sections of the horizontal well also tends to rise year by year. In order to achieve the optimal fracturing effect, the interval between the sections, fracturing construction parameters and the like are optimized. Therefore, the effect analysis of each fractured section after fracturing is very important.
in the prior art, the staged fracturing effect can be monitored by an interwell microseism, a potential method and the like, but the method has the defects of complex process, high cost and the like, the condition of each layer is difficult to accurately explain, and the effluent condition of each layer after fracturing cannot be evaluated; the optical fiber liquid production profile logging can be used for monitoring the liquid production profile in a segmented and clustered mode, but has the defects of high cost and incapability of evaluating the formation water yield.
Regarding the tracer monitoring technology, in the conventional horizontal well stratified fracturing, only the discharged fluid volume of fracturing returns can be explained by the technology, but the stratum water yield and the crude oil yield of each section cannot be specifically judged, and the staged returned fracturing fluid, the stratum water yield and the water content cannot be effectively evaluated. The existing evaluation method is only suitable for the condition that each section does not produce stratum water in the evaluation period. In practical situations, formation water is produced in each fracturing section to different degrees, so that evaluation errors are caused, and reasonable explanation cannot be made. Reports of monitoring the segmented formation water yield and segmented water content by using a tracer monitoring technology are not found.
therefore, a monitoring method for evaluating the segmental water yield and contribution rate in the tight oil multi-segment fracturing well by using a tracer is still one of the problems to be solved in the field.
Disclosure of Invention
in order to solve the technical problems, the invention aims to provide a monitoring method for evaluating the segmental water yield and contribution rate in a compact oil multi-segment fracturing well by using a tracer. The method can quantitatively monitor and draw the segmented liquid production contribution, the segmented fracturing liquid return displacement, the segmented formation water yield, the segmented crude oil yield, the segmented water content and the like of the compact oil multi-segment fracturing level at different time, has small error and convenient application, and plays an important guiding role in the subsequent fracturing work of similar well layers.
In order to achieve the aim, the invention provides a monitoring method for evaluating the segmental water yield and contribution rate in a compact oil multi-segment fracturing well by using a tracer, which comprises the following steps:
(1) preference of the tracer: the tracer comprises a water-based tracer and an oil-based tracer, wherein the water-based tracer selects trace elements with low background concentration as the water-based tracer according to a water sample detection result of the same layer of a target well facing the well, the oil-based tracer does not have the problem of a bottom sample and can be directly selected, the quantity of the tracer is determined according to the number of fracturing sections, and one tracer is selected for each section;
(2) Design concentration of tracer: for trace element tracers, the maximum detected background concentration is Cmax, and in order to control the influence of the background concentration within 3 per thousand, the concentration of each tracer section is not lower than Cmax/3 per thousand. And setting the well to co-fracture N sections, wherein each fracturing section can uniformly discharge liquid, and the concentration required by each section of tracer entering the stratum is not less than N x Cmax/3 per mill. The field application shows that the volume ratio of the tracer mother liquor to the fracturing fluid is 1:10000 hours, the requirement of pump injection equipment precision and uniform addition can be well met. Therefore, the concentration of the prepared mother liquor is not less than 10000 × N × Cmax/3 ‰;
(3) uniformly adding the water-based tracer into the pad fluid and the sand-carrying fluid in proportion in the fracturing process and injecting the water-based tracer and the sand-carrying fluid together, wherein the water-based tracer is not added in the fluid squeezing process, and the oil-based tracer is added in the initial stage of the sand-carrying fluid; adding different tracers into different intervals;
(4) Continuously monitoring a construction curve of the fracturing process, and obtaining the original formation pressure, the fracturing fluid consumption and the pump stopping pressure of each section;
(5) In the process of fracturing fluid flowback, continuously sampling and testing different tracer agent concentrations, wellhead flowback fluid yield and wellhead pressure in flowback fluid by adopting a 'density first and then sparse' strategy;
(6) according to the monitoring data, concentration curves of different tracers relative to the whole well fluid volume are drawn, water-based tracer concentration values capable of representing the segmented fluid production capacity are selected, the segmented fluid production capacity proportion, the flow-back fluid volume, the stratum oil production volume, the stratum water yield, the water content and the yield contribution rate of each fracturing section are explained and calculated, and the fracturing effect is evaluated;
a. the change in formation pressure per volume of fracturing fluid is calculated by the following equation:
in the formula: delta Pi0 is the change in formation pressure caused by the unit volume of the ith section of fracturing fluid, MPa/m 3;
pist is the pump stopping pressure after the i-th stage fracturing, and is MPa;
Piepf is the formation pressure before the i-th stage fracturing, MPa;
Qif is the volume of the i stage fracturing fluid containing the fracturing proppant under formation conditions, m 3.
b. The formation pressures at different times for each fracture zone are calculated by the following formula:
P＝P-△P·Q
In the formula: the Pist is the formation pressure, MPa,
qisum is the volume of flowback fluid under formation conditions at the i-th cut-off evaluation time, m 3.
c. the bottom hole pressure at different times for each fracture zone is calculated by the following formula:
P＝P+ρ·g·h×10
in the formula: piwf is the bottom hole pressure of the ith section at the evaluation moment, MPa;
pwell is the wellhead pressure of the current evaluation well at the evaluation moment, MPa;
rho is the density of the flowback liquid, kg/m 3;
g is a gravity acceleration constant, 9.8N/kg;
hi is the ith segment vertical depth, m.
d. The flow-back liquid amount of each fracturing section at different time is calculated by the following formula:
In the formula: virf is the underground volume flow-back liquid quantity of the i-th section at the evaluation moment, and m 3/d;
Vwell is the well head liquid production amount of the current evaluation well at the evaluation moment, m 3/d;
Ci is the wellhead monitoring concentration of the water-based tracer in the ith section, ppb;
ci0 designed concentration, ppb, for the water-based tracer in stage i;
Gamma i is a loss proportion coefficient and decimal number of the ith section of water-based tracer agent caused by adsorption, interference and the like, and is measured by experiments;
and Bw is the volume coefficient and decimal of the fracturing flow-back fluid (water).
e. the oil production at different times of each fracturing segment is calculated by the following formula:
in the formula: vio is the underground volume oil production at the evaluation time of the ith section, m 3/d;
vowell is the wellhead oil production of the current evaluation well at the evaluation moment, m 3/d;
cio and Cjo are respectively the i-th and j-th section oil-based tracer wellhead monitoring concentration, ppb;
Gamma io and gamma jo are loss proportion coefficients and decimal numbers of the oil-based tracers in the sections i and j respectively, which are caused by adsorption, interference and the like and are measured by experiments;
Bo is the volume coefficient and decimal of the crude oil;
And N is the number of fracturing stages.
f. the liquid production capacity ratio of each fracturing section is calculated by the following formula:
in the formula: lambdai is the liquid production capacity proportion of the ith section, and the decimal number;
virf max and Vjrf max are respectively the underground volume flow of the flowback liquid corresponding to the ith and jth maximum flowback concentration, and m 3/d;
g. The yield contribution rate of each fracturing stage at different time is calculated by the following formula:
in the formula: eta i is the yield contribution rate of the ith section at the evaluation moment, and the decimal number;
Pjst is the pressure of the fracturing pump stop of the jth section, and is MPa;
piwf0 and Pjwf0 are respectively the subsection bottom hole pressure, MPa, corresponding to the maximum flow-back concentration.
h. The formation water production at different times for each fracture zone is calculated by the following formula:
In the formula: qiw is the formation water production of the underground volume at the evaluation time of section i, m 3/d;
Qw and Qo are respectively the water and oil production at the well head at the evaluation time, m 3/d.
i. The water content of each fracturing section at different time is calculated by the following formula:
In the formula: fiw is the water content, decimal fraction of the ith section at the evaluation time;
ρ w and ρ o yield water, oil density, kg/m3, respectively.
the tracer is a rare element or a metal element complex.
the rare elements comprise one or more of lithium, rubidium, cesium, titanium, zirconium, gallium, indium, scandium, yttrium, lanthanum, cerium, praseodymium, neodymium, samarium, europium, gadolinium, terbium, dysprosium, holmium, erbium, thulium, ytterbium and lutetium; the metal element forming the complex comprises one or more of manganese, silver, strontium, bismuth, cobalt, chromium, nickel, copper, zinc, cadmium, lead and tin.
the detection period of 'dense before sparse' in the step (5) is specifically as follows: day 1-10, 12 samples/day; day 11-20, 8 samples/day; day 21-30, 6 samples/day; day 31-50, 4 samples/day; days 51-70, 2 samples/day; day 71-90, 1 sample/day; days 91-120, 1 sample/2 day; 180 days 111-; day 181-; day 241 later, 1 sample/10 days.
The water-based tracer concentration value Cimax which can represent the segmented liquid production capacity in the step (6) can be selected by two methods: firstly, the concentration at the initial stage of flowback is low, the concentration rapidly rises, the concentration slowly falls after reaching the maximum concentration value, and the maximum concentration value is taken as the productivity evaluation reference value of the layer section; and secondly, the concentration value at the initial flowback stage is stable and slowly reduced, and the maximum value at the initial stage is taken as the productivity evaluation reference value of the interval.
the invention has the beneficial effects that: the evaluation method of the invention considers the conditions of stratum water production of different degrees of each stratum, can quantitatively calculate the information such as the liquid production capacity proportion, the flow back liquid amount, the stratum oil production amount, the stratum water yield, the water content, the yield contribution rate of each fracturing section and the like of the compact oil multi-section fracturing, has small error and convenient application, and plays an important guiding role in the subsequent fracturing work of similar well layers. By utilizing the method, the fracturing schemes of different stratums can be further optimized, so that the design of each stage of fracturing scheme is more pertinent, and the method has significance in multi-stage fracturing transformation of compact oil and shale oil long-water wells.
drawings
FIG. 1 is a monitoring concentration curve of the tracer of the flowback fluid of each fracturing segment in the invention.
FIG. 2 is a 2 nd stage fracture profile for a typical well of the present invention.
FIG. 3 is a plot of the flowback rate of fracturing fluids from each fracture zone of an exemplary well of the present invention.
FIG. 4 is a stacked plot of typical well 1 stage fracturing fluid and formation water production in accordance with the present invention.
FIG. 5 is a stacked plot of typical well 2 stage fracturing fluid and formation water production in accordance with the present invention.
FIG. 6 is a stacked plot of typical well 3 fracturing fluid and formation water production in accordance with the present invention.
FIG. 7 is a stacked plot of production contribution from each fracture zone of an exemplary well of the present invention.
Detailed Description
technical features, effects, and embodiments of the present invention will be described in detail below in order to better understand them.
the embodiment provides a tracer evaluation method for the segmental water yield and the contribution rate in a tight oil multi-segment fracturing well. The method is implemented by 3-level fracturing of a certain compact oil horizontal well in Daqing oil field, and comprehensive evaluation is carried out on the flowback rate, the liquid production contribution rate and the stratum water yield of each fracturing section by adopting the tracer monitoring and evaluating method of the implementation example.
The tracer is a rare element or a metal element complex; the rare elements comprise one or more of lithium, rubidium, cesium, titanium, zirconium, gallium, indium, scandium, yttrium, lanthanum, cerium, praseodymium, neodymium, samarium, europium, gadolinium, terbium, dysprosium, holmium, erbium, thulium, ytterbium and lutetium; the metal element forming the complex comprises one or more of manganese, silver, strontium, bismuth, cobalt, chromium, nickel, copper, zinc, cadmium, lead and tin.
The implementation of this example includes the following steps:
(1) Optimization and dosage design of tracer
for optimizing a proper water-based trace element tracer, sampling the same well-facing position of a well to be implemented for 3 times, and performing background value analysis on 5 trace elements by using inductively coupled plasma mass spectrometry (ICP-MS), wherein the results are as follows:
The concentration values of the selected 5 trace element bottom samples are all lower than 0.1ppb, and the maximum background value Cmax is understood to be 0.1ppb, which shows that the background value has little or no influence on the tracer, so that 5 tracers can be used. Because the well is designed to fracture 3 sections, 3 tracers need to be added, and the former 3 tracers with lower cost are preferably used.
in order to eliminate the influence of the background value as much as possible, the background value of the stratum is controlled within 3 per thousand of the designed concentration, namely the designed concentration of the water-based tracer is 0.1ppb/3 per thousand to 33.3 ppb. Since 3 sections of the well are fractured, assuming equal production from each section, the tracer addition concentration from each section should be 33.3 x 3 to 99.9ppb, which equals to about 100 ppb. Meanwhile, considering that the injection ratio of the tracer solution to the fracturing fluid is generally 1:10000, the preparation concentration of the single-stage tracer is 100ppb by 10000 to 1000 ppm. When the tracer is configured, a safety margin of 1.1 is considered, and the actual tracer design is shown in the following table.
the oil-based tracer does not have the problem of bottom sample, 3 types can be directly selected, and the dosage of the oil-based tracer does not have a specific range.
(2) In situ injection of tracer
The water-based tracer is injected together with the pad fluid and the sand-carrying fluid by using an electronic peristaltic pump in the fracturing process, the fluid is not added in the squeezing process, and different tracers are added into different intervals. Before fracturing construction, the electronic peristaltic pump needs to be debugged and corrected according to standard operation specifications of instruments. And (3) starting fracturing construction, injecting the mixture on a sand mixing truck by using an electronic peristaltic pump by an on-site engineer, communicating with an instrument truck engineer, and regulating and controlling the adding speed in real time. In the adding process, an operator on the sand mixing truck keeps communication with a fracturing commander on the fracturing instrument truck, and the adding scheme is adjusted at any time to ensure that the tracer is uniformly added in proportion.
the oil-based tracer needs to be added into a sand mixing truck at one time in the initial stage of sand carrying liquid, the oil-based tracer can be directly poured in during adding, and different tracers are added into different intervals.
(3) Continuously monitoring a construction curve of the fracturing process, and obtaining the original formation pressure, the fracturing fluid consumption and the pump stopping pressure of each section;
(4) flowback fluid tracer concentration detection
In the process of fracturing fluid flowback, a 'density before sparse' strategy is adopted to continuously sample and test the concentration of different types of tracers in flowback fluid, the yield of wellhead flowback fluid and the wellhead pressure.
For a water sample, in the process of back-flowing of fracturing fluid, sampling at the outlet of a liquid discharge pipeline according to the design frequency by using a 100ml standard container; for oil samples, the oil samples need to be sampled together with water samples after oil is seen at a wellhead.
| Timing of sampling | Working time | Sampling frequency | number of samples (number) |
| 1-10 days of flowback | 10 days | 12 pieces per day | 120 |
| the 11 th to 20 th days of the return discharge | 10 days | 8 pieces per day | 80 |
| The 21 st to 30 th days of the return row | 10 days | 6 per day | 60 |
| Total up to | 30 days | 260 |
After sampling, the samples were sent to a laboratory for pretreatment, and then the concentration of each tracer in the samples, i.e., the detected concentration of each tracer relative to the production fluid at the well head, was detected using inductively coupled plasma mass spectrometry (ICP-MS). The concentration monitoring curve is shown in figure 1.
(5) Fracture construction data analysis
And (3) drawing concentration curves of different tracers relative to the whole well fluid volume, selecting a water-based tracer concentration value capable of representing the segmented fluid production capacity, explaining and calculating the segmented fluid production capacity proportion, the flow-back fluid volume, the formation oil production, the formation water yield, the water content and the yield contribution rate of each fracturing section, and evaluating the fracturing effect. The concentration value selection method of the water-based tracer which can represent the segmented liquid production capacity comprises two methods: firstly, the concentration at the initial stage of flowback is low, the concentration rapidly rises, the concentration slowly falls after reaching the maximum concentration value, and the maximum concentration value is taken as the productivity evaluation reference value of the layer section; and secondly, the concentration value at the initial flowback stage is stable and slowly reduced, and the maximum value at the initial stage is taken as the productivity evaluation reference value of the interval.
In the fracturing process, the system is communicated with a field fracturing engineer in real time to know the fracturing condition in time. And after fracturing construction is finished, collecting fracturing construction curves of all the sections, and determining the volume of the working fluid of all the sections, the formation pressure before fracturing and the formation pressure after fracturing. Taking section 2 as an example, this section is actually run into the well guanidine gum fracturing fluid 642m 3. The fracturing construction curve shown in the attached figure 2 shows that the formation pressure before fracturing is 25.4MPa, the formation pressure after fracturing is 28.2MPa, and the formation pressure is increased by 2.8 MPa.
Similarly, the volume of the fracturing fluid entering the well at the 1 st section is 378m3, the pressure of the formation before pressing is 25.8MPa, the pressure of the formation after pressing is 27.5MPa, and the pressure of the formation is increased by 1.7 MPa; the volume of the 3 rd section well-entering fracturing fluid is 942m3, the formation pressure before the fracturing is 25.0MPa, the formation pressure after the fracturing is 29.0MPa, and the formation pressure is increased by 4.0 MPa.
The change of the stratum pressure caused by the unit volume of the fracturing fluid of each fracturing section is calculated by the following formula:
in the formula: delta Pi0 is the change in formation pressure caused by the unit volume of the ith section of fracturing fluid, MPa/m 3;
pist is the pump stopping pressure after the i-th stage fracturing, and is MPa;
piepf is the formation pressure before the i-th stage fracturing, MPa;
qif is the volume of the i stage fracturing fluid containing the fracturing proppant under formation conditions, m 3.
Taking section 2 as an example, the change in formation pressure per unit volume of fracturing fluid is:
similarly, the stratum pressure changes caused by the unit volume of the 1 st and 3 rd sections of fracturing fluid are 0.004497 and 0.004246MPa/m3 respectively.
(6) evaluation of flowback rate, contribution rate and stratum water yield of each fracturing segment
calculating the flow-back rate of the fracturing fluid of each fracturing section
In the formula: virf is the underground volume flow-back liquid quantity of the i-th section at the evaluation moment, and m 3/d;
Vwell is the well head liquid production amount of the current evaluation well at the evaluation moment, m 3/d;
Ci is the wellhead monitoring concentration of the water-based tracer in the ith section, ppb;
ci0 designed concentration, ppb, for the water-based tracer in stage i;
Gamma i is a loss proportion coefficient and decimal number of the ith section of water-based tracer agent caused by adsorption, interference and the like, and is measured by experiments;
and Bw is the volume coefficient and decimal of the fracturing flow-back fluid (water).
Taking the fracturing fluid flowback day 2 as an example, the wellhead concentration of the tracer in the 3 rd section is 33.66ppb, the daily liquid production of the wellhead is 117.2m3/d, the gamma i is 0.81 measured by a laboratory, and the volume coefficient of the fracturing flowback fluid (water) is 1.0, so that the flowback fracturing fluid in the 3 rd section on the day is as follows:
Similarly, the flow-back liquid amounts of the 1 st section and the 2 nd section on the flow-back day 2 can be calculated as follows: 12.1m3/d and 24.3m 3/d.
In the well construction process, the fracturing fluid volumes of the sections 1 to 3 in the well are 340, 600 and 904m3 respectively. Accordingly, the fracturing fluid flowback volume and the flowback rate of each fracturing section at different stages can be calculated and given, and the figure 3 shows.
② calculating the liquid production capacity proportion of each fracturing section
By monitoring and analyzing the concentration of the tracer in the fracturing flowback fluid, the concentration of the flowback fluid reaches the maximum value in day 2, and the method can be used as the basis for calculating the fluid production capacity. And (4) calculating the liquid production capacity proportion of each fracturing section by using the calculation result of the first step as follows:
In the formula: lambdai is the liquid production capacity proportion of the ith section, and the decimal number;
Virf max and Vjrf max are respectively the underground volume flow of the i-th and j-th maximum flowback concentration corresponding flowback liquid, and m 3/d.
the liquid production capacity ratios of the three fracturing stages are calculated to be 0.142, 0.286 and 0.572 respectively.
Thirdly, calculating the yield contribution rate of each fracturing segment at different time
The yield contribution rate of each fracturing stage at different time is calculated by the following formula:
in the formula: eta i is the yield contribution rate of the ith section at the evaluation moment, and the decimal number;
Pjst is the pressure of the fracturing pump stop of the jth section, and is MPa;
piwf0 and Pjwf0 are respectively the subsection bottom hole pressure, MPa, corresponding to the maximum flow-back concentration.
because the horizontal well has only 3 sections of fracturing, the bottom hole flow pressure can be approximately equal, and the production contribution rate at different time is only determined by the formation pressure of each section. Taking day 1 as an example, the formation pressure is the pump stopping pressure, the bottom hole flow pressure of the 1 st to 3 rd sections is the same and is 15.2MPa, and the yield contribution rate of the 1 st section is as follows:
Similarly, the yield contribution rates of the 2 nd and 3 rd sections are 0.286 and 0.572.
fourthly, calculating the stratum water yield of each fracturing stage at different time
The formation water production at different times for each fracture zone is calculated by the following formula:
in the formula: qiw is the formation water production of the underground volume at the evaluation time of section i, m 3/d;
Qw and Qo are respectively the water and oil production at the well head at the evaluation time, m 3/d.
taking section 1 and day 1 as examples, if the oil production is 0, then:
similarly, the water production of the stratum in the 2 nd section and the 3 rd section is respectively 8.45 m3/d and 9.05m 3/d.
fifthly, calculating the stratum pressure of each fracturing section at different time
the formation pressure at different times for each fracture zone is calculated by:
P＝P-△P·Q
in the formula: the Pist is the stratum pressure of the ith section at the evaluation moment, namely MPa;
Qisum is the volume of flowback fluid under formation conditions at the i-th cut-off evaluation time, m 3.
taking section 1 and day 2 as examples, the formation pressure is:
P＝27.50-0.004497*8.37＝27.46MPa
similarly, the stratum pressures of the 2 nd and 3 rd sections can be obtained to be 28.13 MPa and 28.86 MPa.
and (4) repeatedly calculating the second to fourth steps according to the flow-back time to obtain the sectional contribution rate, the sectional flow-back fracturing fluid quantity and the sectional flow-back stratum water quantity at each flow-back moment, and obtaining the result shown in the attached figures 4 to 7.
Compared with the prior art, the evaluation method provided by the invention considers the stratum water producing conditions of different degrees of each stratum, can quantitatively calculate the information such as the compact oil multi-section fracturing horizontal subsection liquid production capacity proportion, the flow-back liquid quantity, the stratum oil production quantity, the stratum water yield, the water content and the yield contribution rate of each fracturing section, and has the advantages of small error, convenience in application and important guidance effect on the subsequent fracturing work of similar well layers. By utilizing the method, the fracturing schemes of different stratums can be further optimized, so that the design of each stage of fracturing scheme is more pertinent, and the method has significance in multi-stage fracturing transformation of compact oil and shale oil long-water wells.
Claims (5)
1. a method for evaluating the staged water production of a compact oil multi-stage fractured well by using a tracer is characterized by comprising the following steps of:
(1) preference of the tracer: the tracer comprises a water-based tracer and an oil-based tracer, wherein the water-based tracer selects trace elements with low background concentration as the water-based tracer according to a water sample detection result of the same layer of a target well facing the well, the oil-based tracer does not have the problem of a bottom sample and can be directly selected, the quantity of the tracer is determined according to the number of fracturing sections, and one tracer is selected for each section;
(2) Design concentration of tracer: for trace element tracers, the maximum detected background concentration is Cmax, and in order to control the influence of the background concentration within 3 per thousand, the concentration of each tracer section is not lower than Cmax/3 per thousand. And setting the well to co-fracture N sections, wherein each fracturing section can uniformly discharge liquid, and the concentration required by each section of tracer entering the stratum is not less than N x Cmax/3 per mill. The field application shows that the volume ratio of the tracer mother liquor to the fracturing fluid is 1:10000 hours, the requirement of pump injection equipment precision and uniform addition can be well met. Therefore, the concentration of the prepared mother liquor is not less than 10000 × N × Cmax/3 ‰;
(3) uniformly adding the water-based tracer into the pad fluid and the sand-carrying fluid in proportion in the fracturing process and injecting the water-based tracer and the sand-carrying fluid together, wherein the water-based tracer is not added in the fluid squeezing process, and the oil-based tracer is added in the initial stage of the sand-carrying fluid; adding different tracers into different intervals;
(4) Continuously monitoring a construction curve of the fracturing process, and obtaining the original formation pressure, the fracturing fluid consumption and the pump stopping pressure of each section;
(5) in the process of fracturing fluid flowback, continuously sampling and testing different tracer agent concentrations, wellhead flowback fluid yield and wellhead pressure in flowback fluid by adopting a 'density first and then sparse' strategy;
(6) according to the monitoring data, concentration curves of different tracers relative to the whole well fluid volume are drawn, water-based tracer concentration values capable of representing the segmented fluid production capacity are selected, the segmented fluid production capacity proportion, the flow-back fluid volume, the stratum oil production volume, the stratum water yield, the water content and the yield contribution rate of each fracturing section are explained and calculated, and the fracturing effect is evaluated;
a. The change in formation pressure per volume of fracturing fluid is calculated by the following equation:
In the formula: delta Pi0 is the change in formation pressure caused by the unit volume of the ith section of fracturing fluid, MPa/m 3;
Pist is the pump stopping pressure after the i-th stage fracturing, and is MPa;
piepf is the formation pressure before the i-th stage fracturing, MPa;
qif is the volume of the i stage fracturing fluid containing the fracturing proppant under formation conditions, m 3.
b. The formation pressures at different times for each fracture zone are calculated by the following formula:
P＝P-△P·Q
in the formula: the Pist is the formation pressure, MPa,
qisum is the volume of flowback fluid under formation conditions at the i-th cut-off evaluation time, m 3.
c. the bottom hole pressure at different times for each fracture zone is calculated by the following formula:
P＝P+ρ·g·h×10
in the formula: piwf is the bottom hole pressure of the ith section at the evaluation moment, MPa;
Pwell is the wellhead pressure of the current evaluation well at the evaluation moment, MPa;
rho is the density of the flowback liquid, kg/m 3;
g is a gravity acceleration constant, 9.8N/kg;
hi is the ith segment vertical depth, m.
d. The flow-back liquid amount of each fracturing section at different time is calculated by the following formula:
In the formula: virf is the underground volume flow-back liquid quantity of the i-th section at the evaluation moment, and m 3/d;
Vwell is the well head liquid production amount of the current evaluation well at the evaluation moment, m 3/d;
ci is the wellhead monitoring concentration of the water-based tracer in the ith section, ppb;
ci0 designed concentration, ppb, for the water-based tracer in stage i;
gamma i is a loss proportion coefficient and decimal number of the ith section of water-based tracer agent caused by adsorption, interference and the like, and is measured by experiments;
And Bw is the volume coefficient and decimal of the fracturing flow-back fluid (water).
e. the oil production at different times of each fracturing segment is calculated by the following formula:
In the formula: vio is the underground volume oil production at the evaluation time of the ith section, m 3/d;
vowell is the wellhead oil production of the current evaluation well at the evaluation moment, m 3/d;
cio and Cjo are respectively the i-th and j-th section oil-based tracer wellhead monitoring concentration, ppb;
gamma io and gamma jo are loss proportion coefficients and decimal numbers of the oil-based tracers in the sections i and j respectively, which are caused by adsorption, interference and the like and are measured by experiments;
bo is the volume coefficient and decimal of the crude oil;
And N is the number of fracturing stages.
f. the liquid production capacity ratio of each fracturing section is calculated by the following formula:
In the formula: lambdai is the liquid production capacity proportion of the ith section, and the decimal number;
Virfmax and Vjrfmax are respectively the underground volume flow of the flowback liquid corresponding to the ith and jth maximum flowback concentration, and m 3/d;
g. the yield contribution rate of each fracturing stage at different time is calculated by the following formula:
in the formula: eta i is the yield contribution rate of the ith section at the evaluation moment, and the decimal number;
Pjst is the pressure of the fracturing pump stop of the jth section, and is MPa;
Piwf0 and Pjwf0 are the staged bottom hole pressures, MPa, respectively, corresponding to the maximum flowback concentration.
h. The formation water production at different times for each fracture zone is calculated by the following formula:
in the formula: qiw is the formation water production of the underground volume at the evaluation time of section i, m 3/d;
Qw and Qo are respectively the water and oil production at the well head at the evaluation time, m 3/d.
i. the water content of each fracturing section at different time is calculated by the following formula:
In the formula: fiw is the water content, decimal fraction of the ith section at the evaluation time;
ρ w and ρ o yield water, oil density, kg/m3, respectively.
2. the trace element tracer evaluation method according to claim 1, characterized in that: the tracer is a rare element or a metal element complex.
3. The trace element tracer evaluation method according to claim 2, characterized in that: the rare elements comprise one or more of lithium, rubidium, cesium, titanium, zirconium, gallium, indium, scandium, yttrium, lanthanum, cerium, praseodymium, neodymium, samarium, europium, gadolinium, terbium, dysprosium, holmium, erbium, thulium, ytterbium and lutetium; the metal element forming the complex comprises one or more of manganese, silver, strontium, bismuth, cobalt, chromium, nickel, copper, zinc, cadmium, lead and tin.
4. the trace element tracer evaluation method according to claim 1, characterized in that: the detection period of 'dense before sparse' in the step (5) is specifically as follows: day 1-10, 12 samples/day; day 11-20, 8 samples/day; day 21-30, 6 samples/day; day 31-50, 4 samples/day; days 51-70, 2 samples/day; day 71-90, 1 sample/day; days 91-120, 1 sample/2 day; 180 days 111-; day 181-; day 241 later, 1 sample/10 days.
5. tracer-evaluation method according to claim 1, characterized in that: the water-based tracer concentration value Cimax which can represent the segmented liquid production capacity in the step (6) can be selected by two methods: firstly, the concentration at the initial stage of flowback is low, the concentration rapidly rises, the concentration slowly falls after reaching the maximum concentration value, and the maximum concentration value is taken as the productivity evaluation reference value of the layer section; and secondly, the concentration value at the initial flowback stage is stable and slowly reduced, and the maximum value at the initial stage is taken as the productivity evaluation reference value of the interval.
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| CN113756802B (en) * | 2021-09-28 | 2024-02-23 | 平安煤矿瓦斯治理国家工程研究中心有限责任公司 | Method for investigating fracturing drainage effect of coal bed gas horizontal well |
| CN113931626A (en) * | 2021-10-13 | 2022-01-14 | 陕西延长石油（集团）有限责任公司 | Method for monitoring stratum buried amount after carbon dioxide fracturing |
| CN113931626B (en) * | 2021-10-13 | 2023-11-28 | 陕西延长石油（集团）有限责任公司 | Stratum buried quantity monitoring method after carbon dioxide fracturing |
| CN115288649A (en) * | 2022-05-10 | 2022-11-04 | 西安石油大学 | Tracer system for coal bed gas reservoir and coal bed gas horizontal well fracturing monitoring method |
| CN115288649B (en) * | 2022-05-10 | 2024-04-16 | 西安石油大学 | Tracer system for coalbed methane reservoir and coalbed methane horizontal well fracturing monitoring method |
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