CN111911128A - High-tectonic stress normal-pressure shale gas-reservoir fracturing method - Google Patents
High-tectonic stress normal-pressure shale gas-reservoir fracturing method Download PDFInfo
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Abstract
The invention discloses a high-tectonic stress normal-pressure shale gas-reservoir fracturing method. The method comprises the following steps: 1) evaluating shale key reservoir parameters; 2) evaluating geological engineering double desserts and determining perforation positions; 3) optimizing a crack parameter system; 4) optimizing fracturing construction parameters; 5) performing shower hole operation; 6) acid pretreatment operation; 7) high-viscosity glue liquid high-displacement splitting vertical main crack construction; 8) the low-viscosity slick water variable-displacement communication extension branch seam system and the horizontal layer seam management system; 9) small-grain-size long slugs or continuous sand adding construction; 10) sand adding construction is carried out on a first high-viscosity glue solution slug; 11) construction with small particle size and medium sand-liquid ratio and medium discharge capacity of slickwater; 12) a second high-viscosity glue liquid slug sand adding construction; 13) construction with small grain size and high sand-liquid ratio and high discharge capacity of the slickwater; 14) and (5) carrying sand with high-viscosity glue liquid to fill the vertical main crack for construction. The post-pressing modification volume of the normal-pressure shale gas well can be increased, and therefore the economic development effect of the normal-pressure shale gas well is improved.
Description
Technical Field
The invention belongs to the technical field of oil exploitation, and particularly relates to a high-tectonic stress normal-pressure shale gas-reservoir fracturing method.
Background
At present, the recoverable resource amount of normal pressure shale gas is huge, but because its structure is complicated, especially most are in stress extrusion state's syncline, minimum horizontal principal stress is close to with vertical stress even is higher than vertical stress sometimes, consequently, probably be existing horizontal layer reason seam and have vertical joint when fracturing makes the seam, and, the effect of induced stress in fracturing process, minimum horizontal principal stress can continue to increase, has further increased the possibility that a plurality of horizontal layer reason seams extend simultaneously. Although a certain induced stress is generated during the extension of the horizontal lamellar seams, the induced stress of each lamellar seam is relatively small due to the plurality of horizontal lamellar seams, and the induced stress is also relatively small and cannot be compared with the induced stress of a single vertical crack at all. Although the induced stress superposition effect of a plurality of horizontal layer seams exists, firstly, the induced stress is relatively small, and secondly, the distance between every two adjacent horizontal layer seams is small, so that in case that the induced stress is transmitted to the adjacent layer seams, the induced stress can be absorbed by the adjacent layer seams and is mostly consumed. In other words, the induced stress superimposed by multiple horizontal lamellar seams is relatively small, much less than the induced stress of a single vertical seam. Therefore, the combined effect of the induced stresses should be to further exacerbate the spread of multiple horizontal lamellar seams. The expansion of a plurality of horizontal layer reason seams has absorbed discharge capacity and liquid measure of very big proportion for vertical fissured net pressure reduces by a wide margin, and consequently, vertical fissured height also receives the restriction greatly, leads to final crack to reform transform the volume and receives the influence greatly, has seriously restricted the output after the pressure of ordinary pressure shale gas.
The literature, "application analysis of ball-throwing steering fracturing process in normal-pressure shale gas horizontal well section" (petroleum knowledge) mainly explains the field test application of ball-throwing steering fracturing process in normal-pressure shale gas horizontal well section and the use effect thereof. The process is applied to LY2HF wells, and the influence effect of the process on fracturing modification construction in normal-pressure shale gas wells is analyzed through the research on the construction modification conditions of all sections. Meanwhile, the influence factors of the process in the application process are analyzed, and the factors influencing the temporary blocking and transforming effect of the shot are analyzed from two aspects of geology and engineering. The process is a feasible and effective measure for improving the fracturing improvement perfection and the improvement effect of the normal-pressure shale gas well. The application condition of the temporary plugging ball in the normal-pressure shale gas well is only briefly elucidated and analyzed in the literature, and the fracturing construction parameters of the application well are listed, and detailed analysis and effective measures are not carried out in the aspect of the main synergistic process of the fracturing reformation of the normal-pressure shale gas well.
Therefore, there is a need to develop a new atmospheric shale gas-reservoir fracturing technology that can be adapted to high tectonic stresses.
Disclosure of Invention
In order to solve the problems in the prior art, the invention provides a high-tectonic stress normal-pressure shale gas reservoir fracturing method. The post-pressing modification volume of the normal-pressure shale gas well can be increased, and therefore the economic development effect of the normal-pressure shale gas well is improved.
The invention aims to provide a high-tectonic stress normal-pressure shale gas reservoir fracturing method.
The method comprises the following steps:
step 1) evaluation of shale key reservoir parameters;
step 2), geological engineering double-dessert evaluation and perforation position determination;
step 3), optimizing a fracture parameter system;
step 4), optimizing fracturing construction parameters;
step 5), performing shower hole operation;
the length of a single cluster is 1-1.5m, and the pore density is 16-20 pores/m; the number of clusters in a single hole is 4-6 clusters;
step 6) acid pretreatment operation;
step 7), high-viscosity glue liquid high-discharge splitting vertical main crack construction;
step 8), communicating an extended branch seam system and a horizontal layer seam system by low-viscosity slick water with variable displacement;
step 9), constructing small-particle-size long slugs or continuously adding sand;
step 10), sand adding construction is carried out on a first high-viscosity glue liquid slug;
step 11), construction of medium-discharge capacity of small-grain-size medium sand-liquid ratio of slickwater;
step 12) second high-viscosity glue liquid slug sand adding construction;
step 13), construction with high sand-liquid ratio and high discharge capacity of small grain size of slickwater;
step 14), high-viscosity glue liquid high-discharge sand-carrying filling vertical main crack construction;
step 15) replacement work.
Wherein the content of the first and second substances,
in the step 6), the step of,
the dosage of each acid is 20-30m3The discharge capacity of the acid injection is 1-1.5m3Min, the displacement of the acid is 4-6m3Min; when acid enters a first perforation cluster close to the heel, the displacement of the acid is reduced to the original displacement of the acid;
and after 18-22% of the using amount of the acid liquor enters the first cluster of perforations, dividing the first cluster of perforations for 2-3 times, uniformly dividing the rest acid, and gradually increasing the displacement of the acid replacement, wherein the final displacement of the acid replacement is the optimized highest displacement.
In the step 7), the step of,
using glue solution with viscosity of 60-70mPa.s, the discharge capacity is increased to the optimized maximum value within 1-2min, and the liquid amount is 50-60m3。
In the step 8), the step of carrying out the,
taking low-viscosity slick water with viscosity of 1-3mPa.s and drag reduction rate of more than 70%, and taking 5-6m at initial discharge3And/min, the liquid volume accounts for 20-30% of the total liquid volume of the section, when the liquid volume of the section is injected into the section by 50-60%, the residual liquid volume is uniformly divided into 2-3 parts, and the discharge capacity is correspondingly and gradually increased to the optimized maximum discharge capacity.
In the step 9), the step (c),
using slickwater with viscosity of 1-3mPa.s to carry 70-140 meshes of propping agent, wherein the sand-liquid ratio is 1-3-5-7-9%; the first three sand-liquid ratios adopt continuous sand adding, the liquid amount of each section is 100% -150% of the volume of the current section of the shaft, the last two sand-liquid ratios are slug sand adding, and the volume of each sand-liquid ratio is 50% -60% of the volume of the shaft; the discharge capacity is 50-60% of the optimized maximum discharge capacity;
if the sand-liquid ratio slug type sand adding does not cause obvious change of the wellhead stress, the continuous sand adding construction of the two sand-liquid ratios is carried out again until the wellhead stress is caused to rise by 4-8 Mpa.
In the step 10), the step of processing the raw material,
using glue solution with viscosity of 60-70mPa.s and liquid quantity of 40-50m3The discharge capacity is the optimized maximum discharge capacity and carries 40-70 meshes of propping agent, the sand-liquid ratio is 10-13%, and the liquid amount with the sand-liquid ratio of 10% accounts for 50% -60% of the total liquid amount of each construction section.
In the step 11), the step of processing the raw material,
the method adopts slickwater with the viscosity of 1-3mPa.s and 70-140 meshes of small-particle size propping agent, the sand-liquid ratio is 11-13-15%, the sand is added in a slug type manner, the liquid amount of each sand-liquid ratio is 40-50% of the volume of the current section of a well bore, and the discharge capacity is 70-80% of the optimized maximum discharge capacity.
In the step 12), the step of processing the raw material,
using glue solution with viscosity of 70-80mPa.s and liquid quantity of 50-60m3The discharge capacity is the optimized maximum discharge capacity, 40-70 meshes of propping agent are carried, the sand-liquid ratio is 16-19%, and the liquid amount with the sand-liquid ratio of 16% accounts for 50% -60% of the total liquid amount of each construction section.
In the step 13), the step of carrying out the,
the method adopts slickwater with viscosity of 1-3mPa.s and 70-140 meshes of small-particle size propping agent, the sand-liquid ratio is 17-19%, the sand is added in a slug type manner, the liquid amount of each sand-liquid ratio is 30-40% of the volume of the well bore of the current section, and the discharge capacity is the optimized highest discharge capacity.
In the step 14), the step of,
cleaning again by using glue solution with the viscosity of 80-90mPa.s, wherein the discharge capacity is the optimized highest discharge capacity, and the liquid quantity is designed according to 110-120% of the expected volume of the vertical main crack; 70-140 meshes of small-particle-size proppant with a sand-liquid ratio of 21-23-25% and then 40-70 meshes of proppant with a sand-liquid ratio of 18-21-24%, wherein the liquid amount of each sand-liquid ratio is evenly divided according to the step number of the sand-liquid ratio; or the liquid amount in the high sand-liquid ratio stage is reduced by 5-10%, and the reduced amount is supplied to the low sand-liquid ratio stage, so that the construction safety is ensured;
in the step 15), the step of carrying out the,
the displacement liquid amount is 105-110% of the volume of the current section of the well bore; the displacement is the optimized maximum displacement;
the former 30-40% displacement liquid adopts glue solution with viscosity of 50-60mPa.s, and then adopts slickwater with viscosity of 1-3mPa.s for displacement.
The invention can adopt the following technical scheme:
1) evaluation of shale key reservoir parameters
Including the development conditions of structures, faults and various fractures, lithology and sensitivity, physical properties and gas content (including the proportion of adsorbed gas), rock mechanics parameters (including the fracture toughness of the horizontal direction of a reservoir and the vertical direction of the reservoir and an upper interlayer and a lower interlayer), three-dimensional ground stress parameters, temperature and pressure and the like.
The method can be carried out by adopting the methods of earthquake, well logging, core indoor test of pilot hole wells and the like. Conversion of the logging dynamic values into core static test results is considered. Therefore, the dynamic and static conversion relation of various parameters in the pilot hole is established. And (3) solving various static parameters of the horizontal section by considering the corresponding relation between the horizontal section and the logging parameters of the pilot hole well and referring to the dynamic and static parameter conversion relation of the pilot hole well.
2) Geological engineering dual-dessert evaluation and perforation location determination
On the basis of the step 1), respectively calculating a geological dessert and an engineering dessert according to a conventional multi-parameter dessert evaluation model, and calculating final comprehensive dessert data according to an equal weight method. And (3) determining the positions of the shower holes by combining the optimized total number of the cracks (obtained by the crack spacing) in the step 3) and combining the casing cementing quality and the avoided coupling position. Regarding the division of the segments, the lithology and the ground stress are equivalent, and the synthetic sweet spots are equivalent or close to each other to be divided into one segment.
Considering that the brittleness of the normal-pressure shale gas is relatively good and the urgent need of reducing the cost of engineering is met, a method with few sections and multiple clusters is adopted, and the number of single-section perforation clusters can reach 4-6 clusters.
3) Optimization of fracture parameter system
On the basis of the step 1), a fine geological model is established by applying the common geological modeling commercial software PETROL. Then, introducing the geological model into commercial simulation software ECLIPSE commonly used for shale gas fracturing yield dynamic prediction, and setting different hydraulic fractures including a vertical main fracture, a branch fracture and a horizontal bedding fracture according to a method of equivalent conductivity (after the width of the fracture is amplified by a certain multiple, the permeability of the proppant in the fracture is proportionally reduced, and the product of the permeability and the conductivity of the fracture is kept unchanged). And finally, simulating the dynamic yield of the pressed steel sheet after different vertical main crack lengths, flow conductivity, crack spacing and crack length distribution forms (equal crack length distribution, U-shaped distribution with long ends and short middle, W-shaped distribution with long and short alternately distributed seams, spindle-shaped distribution and the like) according to an orthogonal design method. The branch crack simulation refers to the method of main cracks, and for the sake of simplicity, 1/10 of main cracks are selected as the length, the flow conductivity, the distance and the like of the branch cracks; the arrangement of the horizontal lamellar gaps is similar to an ellipsoid type gap, and for the sake of simplicity, a series of cylindrical stacks can be assumed. However, the height of the cylinder, i.e. the width of the horizontal lamellar gaps, is set in the same way as described above for the equivalent flow conductivity. But at a magnification such that the height of the cylinder does not exceed the position of the adjacent horizontal lamellar gap.
After the three fractures are comprehensively considered, the fracture parameter system corresponding to the predicted relatively highest post-pressure yield or the maximum economic net present value is the optimal fracture parameter system.
4) Optimization of fracturing construction parameters
In order to obtain the fracture parameter system optimized in the step 3), shale gas fracture expansion simulation is applied to a common commercial software MEYER, and fracture expansion dynamics under different fracture construction parameters are simulated. The specific fracturing construction parameters comprise discharge capacity, viscosity, liquid amount, the proportion of liquids with different viscosities, the proppant amount, the proportion of proppants with different particle sizes, construction sand-liquid ratio, corresponding pumping and injecting procedures and the like. And simulating the fracturing construction parameters of the branch joint system and the horizontal bedding joint system according to the method. The horizontal layer seam simulation is usually carried out by using a horizontal seam model, and a vertical main seam and branch seam system adopts a vertical seam model. Considering that the horizontal layer seam has a narrow width, the lower limit of the liquid viscosity set in the corresponding simulation is properly reduced. The final total fracturing construction parameters except that the liquid viscosity cannot be superposed, other discharge capacity, liquid quantity, sand-liquid ratio and the like can be obtained by adding and summing.
It is worth pointing out that, in order to reduce low-efficiency construction, based on the actual conditions that the three-dimensional geometric dimension of the early-stage fracture in the fracture expansion has the fastest extension speed, the middle-stage fracture is slowed down and the later-stage fracture is slower, more importantly, in order to reduce the cost requirement, the later-stage fracture construction time is properly compressed by 10-20%, at the moment, the three-dimensional geometric dimension of the fracture is reduced by at most 3-5%, and the yield simulation result proves that the influence on the final fracture modification volume and the post-compression effect is very limited and can be basically ignored.
5) Cluster perforation operation
According to the conventional perforation parameters, such as the length of a single cluster is 1-1.5m, the hole density is 16-20 holes/m, the phase is 60 degrees, and the hole diameter is 9.5 mm. The number of clusters in a single hole is 4-6, if the brittleness index is more than 60%, a single-section 6-cluster perforation can be considered, and if the brittleness index is lower than 55%, a single-section 4-cluster perforation can be considered.
The conventional bridge plug perforation combined tool is adopted, a continuous oil pipe is adopted in the first section to carry a perforating gun, and the other sections carry a perforating tool string by adopting a pumping method. After the bridge plug is in place, setting, releasing, lifting the perforating gun to a preset position step by step, perforating, and finally lifting all the pipe strings together.
6) Acid pretreatment operation
And (3) applying the rock core in the step 1) to carry out compatibility and acid dissolution rate experiments of different hydrochloric acid, earth acid and the like, and preferably selecting an acid type and a formula with good compatibility and relatively highest acid dissolution rate.
Considering the number of single-stage perforation clusters is large, the dosage of each stage of acid can be 20-30m3The discharge capacity of the acid injection is generally 1-1.5m3Permin, the displacement of the acid is generally 4-6m3And/min, when the acid enters the first perforation cluster close to the heel, reducing the displacement of the acid to the original displacement of the acid injection so as to increase the contact time of the acid rock and the pressure drop effect.
In order to increase the probability of uniform acid feeding and synchronous crack initiation and extension of each cluster of perforation, after 20% of acid enters the first cluster of perforation, the acid is divided for 2-3 times, the rest acid is uniformly divided, the displacement of the acid replacement is gradually increased, and the final displacement of the acid replacement can be the highest displacement optimized in the step 4).
7) High-viscosity glue liquid high-displacement splitting vertical main crack construction
The discharge capacity of the glue solution with the viscosity of 60-70mPa.s is increased to the highest value designed in the step 4) within 1-2min as soon as possible, and the liquid quantity is generally 50-60m according to the height requirement of the expected pressed crack3。
8) The low-viscosity slick water variable-displacement communication extended branch seam system and the horizontal layer seam system.
The low-viscosity low-friction slick water system with the viscosity of 1-3mPa.s and the resistance reduction rate of more than 70 percent is adopted, the low viscosity is convenient for communicating various small-scale branch seam systems and horizontal layer seam systems, and the low friction is convenient for further extending the branch seam systems and the horizontal layer seam systems after communication. Measuring the initial discharge amount to 5-6m3And/min, the liquid amount accounts for 20-30% of the total liquid amount in the section, after the liquid amount in the section is injected to 60%, the residual liquid amount is uniformly divided into 2-3 parts, and the discharge capacity is correspondingly and gradually increased to the maximum discharge capacity optimized in the step 4).
9) Small grain size long slug or continuous sand adding construction (low discharge capacity)
On the basis of fully forming the seams in the step 8), carrying 70-140 meshes of propping agent by 1-3mPa.s slickwater, wherein the sand-liquid ratio is 1-3-5-7-9%. The first three sand-liquid ratios can be used for continuously adding sand, the liquid amount of each section is about 100% -150% of the volume of the current section of the well shaft, the second two sand-liquid ratios can be used for trying to add sand in a slug mode, and the volume of each sand-liquid ratio can be 50% -60% of the volume of the well shaft. The displacement of the section is 50-60% of the optimized maximum displacement of the step 4). If the sand-liquid ratio is smoother than the section plug type sand adding, and the severe change of the stress of the well mouth is not caused, the continuous sand adding construction of the two sand-liquid ratios can be carried out again until the obvious change of the pressure of the well mouth is caused;
10) first high viscosity glue slug sanding construction
Based on the step 9), using glue solution with viscosity of 60-70mPa.s and liquid amount of 40-50m3The discharge capacity is the optimized maximum discharge capacity in the step 4), 40-70 meshes of propping agent are carried, the sand-liquid ratio is 10-13%, and the preposed liquid amount accounts for 50% -60% of the total liquid amount of each construction section.
11) Construction of small-grain-size medium sand-liquid ratio medium discharge capacity of slickwater
The specific process refers to step 9), slick water with the viscosity of 1-3mPa.s and 70-140 meshes of small-particle size propping agent are also adopted, the sand-liquid ratio is higher, the sand-liquid ratio can be 11-13-15%, the sand-liquid ratio is mainly added in a slug mode, the liquid amount of each sand-liquid ratio is 40-50% of the volume of the current section of the well bore, and the discharge capacity is 70-80% of the optimized maximum discharge capacity in the step 4).
12) Second high viscosity glue slug sanding construction
Based on the step 9), using glue solution with the viscosity of 70-80mPa.s and the liquid amount of 50-60m3The discharge capacity is the optimized maximum discharge capacity in the step 4), 40-70 meshes of propping agent are carried, the sand-liquid ratio is 16-19%, and the sand-liquid ratio accounts for about 60%.
13) Construction of small-grain-size high sand-liquid ratio and high discharge capacity of slickwater
The specific flow refers to step 9), slick water with the viscosity of 1-3mPa.s and 70-140 meshes of small-particle size propping agent are also adopted, the sand-liquid ratio is higher, the sand-liquid ratio can be 17-19%, the sand is mainly added in a slug mode, the liquid amount of each sand-liquid ratio is 30-40% of the volume of the current section of the well bore, and the discharge capacity is the highest discharge capacity optimized in the step 4).
14) Construction of high-viscosity glue liquid high-displacement sand-carrying filling vertical main crack
The small-particle size propping agent in the construction process may be retained in the vertical main fracture, and can be cleaned again by using glue solution with viscosity of 80-90mPa.s, wherein the discharge capacity is the highest discharge capacity optimized in the step 4), and the liquid capacity is designed according to 120% of the expected volume of the vertical main fracture, namely 110-120%. The sand-liquid ratio of 70-140 meshes of small-particle size proppant is 21-23-25%, the sand-liquid ratio of 40-70 meshes of proppant is 18-21-24%, the liquid amount of each sand-liquid ratio is equal to the liquid amount according to the number of steps of the sand-liquid ratio, or the liquid amount is properly reduced in the high sand-liquid ratio stage, and the reduced amount is given to the front low sand-liquid ratio stage, so that the construction safety is ensured.
15) Replacement work
And designing the displacement liquid amount of the section according to 105-110% of the volume of the current section of the well shaft, and taking the optimized maximum displacement in the step 4). The former 30-40% displacing liquid adopts glue solution with viscosity of 50-60mPa.s to ensure no sand setting phenomenon in the horizontal shaft. Then, the mixture is replaced by slickwater with the viscosity of 1-3 mPa.s.
16) And (5) repeating the steps 5) to 15) for the construction of other sections until all the sections are constructed.
17) Drilling, testing and production, performed according to conventional procedures, are not cumbersome here.
ADVANTAGEOUS EFFECTS OF INVENTION
The invention has the following technical characteristics and excellent effects:
the method has the advantages of reasonable design, simple process and convenient operation, optimizes the parameters from the aspects of pre-fracturing evaluation, main construction parameter optimization and the like, and provides a set of process measures for effectively improving the fracturing transformation effect aiming at the normal pressure shale gas well under the condition of high structural stress, thereby improving the economic development effect of the normal pressure shale gas well.
Detailed Description
The present invention will be further described with reference to the following examples.
Example 1:
the well A is an atmospheric shale gas horizontal well, the depth of a target layer of the well is 2505.7-2638m, the pressure coefficient is 1.08, and the porosity of the well is 4.96%, the average quartz content is 56.6%, the clay content is 25.8%, and the total gas content is 4.6m through logging3T, adsorbed gas content 1.65m3T, free gas content 4.35m3And/t, the horizontal maximum principal stress is 62MPa, the horizontal minimum principal stress is 58MPa, the vertical principal stress is 50MPa, the Young modulus is 38GPa, the Poisson ratio is 0.23, horizontal bedding cracks develop in the well target layer, and part of the bedding cracks are filled with calcite. The method is used for implementing low-viscosity variable-displacement fracturing construction on the well, and comprises the following specific implementation steps of:
1) determining the perforation position of the whole well through analyzing the geological characteristic parameters of the well;
2) a numerical model of the well is established by using geological and engineering commercial simulation software, and the half length of a crack of the well is optimized to be 300m, a W-shaped crack distribution mode is optimized, the crack spacing is 20m, and the flow conductivity is 3dc cm through simulation.
3) According to the optimal artificial crack optimized in the step 2), the optimal construction parameters obtained by optimizing with commercial software MEYER are as follows: single stage liquid volume 2200-2400 m3Comprehensive sand ratio of 3-5%, single-stage cluster number of 3-4 and construction discharge capacity of 12-16m3/min。
4) Performing a first stage of fracturing construction according to the analysis and optimization results of the steps 1) to 3), wherein the first stage of perforation adopts a continuous oil pipe with a perforating gun, the length of a single cluster is 1m, the hole density is 16 holes/m, and the number of the single-hole clusters is 4; phase 60 degree, aperture 9.5 mm.
5) The total amount of acid is 20m3The discharge capacity of acid injection is 1m3Min, after pumping for 3min, the discharge capacity is increased by 4m3Replacing acid in min, and reducing the displacement of the acid to 1m when the acid enters the first perforation cluster close to the heel3Min, equal to 4m3When the acid enters the first perforation cluster close to the heel, the remaining acid liquid is divided into two times of 1m3The volume of the discharge per minute is finished.
6) Using a glue solution with the viscosity of 60 mPas of 50m3And the discharge capacity is increased to 16m within 2min3/min。
7) Adopts a low-viscosity low-friction slick water system with viscosity of 1mPa & s and drag reduction rate of more than 70 percent and has initial discharge capacity of 5m3Min, after the liquid quantity of the section is injected to 60%, the residual liquid quantity is uniformly injected in 2 portions, and the discharge quantity is gradually increased to 16m3Min (i.e. optimized maximum displacement).
8) On the basis of fully sewing in the step 7), 1mPa.s slickwater is adopted for 10m3620m liquid injection quantity of displacement pump per min3Continuously adding 70-140 meshes of propping agent with the sand ratio of 1-3-5-7-9%. The first three sand ratios are 1-3-5%, a continuous sand adding mode is adopted, and the sand carrying liquid amount of each sand ratio is 50m3Two sand ratios of 7% and 9% are added in a plug mode, and the liquid amount of each sand ratio can be 25m3The liquid amount of each section is 100 percent of the volume of the current section of the well bore.
The pressure of the well head rises by 4 Mpa;
9) using glue solution with viscosity of 60mPa.s and liquid quantity of 40m on the basis of the step 8)3The discharge capacity is 16m3Min, carrying 40-70 mesh proppant with a sand ratio of 10-13% and a liquid amount of 24m for 10% sand ratio3。
10) And continuing to carry out slick water construction: adopts slickwater with viscosity of 3mPa.s and 70-140 meshes of small-particle size propping agent to be 12m3The proppant with the grain diameter is added into the sand-liquid ratio of 11-13% in a segmented filling manner, and the liquid amount of each sand-liquid ratio is 20m3(ii) a Is composed ofWhen the volume of the section of the well bore is 40%, the displacement is 70% of the optimized maximum displacement.
11) And carrying out second-stage high-viscosity glue construction: with optimized maximum construction displacement of 16m3Injecting 70 Pa.s glue solution at min for 60m3In the glue solution injection process, the proppant with 40-70 meshes is injected in a plug-type carrying mode according to two sand-liquid ratios of 16% and 18%, wherein the liquid amount is 36m when the sand-liquid ratio is 16%3。
12) And (3) construction in a slick water stage again: injecting 70-140 mesh small-particle size proppant by adopting a slick water section with viscosity of 3mPa.s, wherein the sand-liquid ratio can be 17-19%, and the liquid amount of each sand-liquid ratio is 20m3The liquid amount of each sand-liquid ratio is 30 percent of the volume of the current section of the well bore, and the discharge capacity is the highest discharge capacity of 16m3/min。
13) The small-particle size propping agent in the construction can possibly stay in the vertical main crack and can be cleaned again by glue solution with viscosity of 80mPa.s and discharge capacity of 16m3And/min, firstly 70-140 meshes of small-particle-size proppant with the sand-liquid ratio of 21-23-25%, then 40-70 meshes of proppant with the sand-liquid ratio of 18-21-24%, and equally dividing the liquid amount of each sand-liquid ratio by 3.
14) Replacement operation: the displacement liquid volume of the section is 45m according to the design of 110 percent of the volume of the section of the well bore3At 16m3Displacement injection per min. 13.5m3And adopting glue solution with the viscosity of 50mPa & s to ensure that the horizontal shaft has no sand setting phenomenon. Then, the mixture was replaced with slickwater having a viscosity of 3 mPas.
15) And (5) constructing other sections, and repeating the steps 4) to 14), and correspondingly adjusting the construction parameters of each section according to the patent design until all sections are constructed.
16) Drilling plug, testing and producing, and executing according to the conventional flow.
Example 2
The well B is an atmospheric shale gas horizontal well, the depth of a target layer of the well is 2375.4-2516.8m, the pressure coefficient is 1.01, the porosity of the well is 4.21%, the average quartz content is 52.3%, the clay content is 30.1%, and the total gas content is 3.87m3T, adsorbed gas content 1.25m3T, free gas content 2.62m3T, maximum principal stress in horizontal58MPa, the horizontal minimum principal stress is 53MPa, the vertical principal stress is 50MPa, the Young modulus is 36.4GPa, the Poisson ratio is 0.22, a horizontal bedding gap develops in the well target layer, and part of the bedding gap is filled with calcite. And performing low-viscosity variable-displacement fracturing construction on the well.
The specific implementation steps are as follows:
1) determining the perforation position of the whole well through analyzing the geological characteristic parameters of the well;
2) a numerical model of the well is established by using geological and engineering commercial simulation software, and the half length of a crack of the well is optimized to be 300m, a W-shaped crack distribution mode is optimized, the crack spacing is 20m, and the flow conductivity is 3dc cm through simulation.
3) According to the optimal artificial crack optimized in the step 2), the optimal construction parameters obtained by optimizing with commercial software MEYER are as follows: single stage liquid volume 2200-2400 m3Comprehensive sand ratio of 3-5%, single-stage cluster number of 3-4 and construction discharge capacity of 12-16m3/min。
4) Performing a first stage of fracturing construction according to the analysis and optimization results of the steps 1) to 3), wherein the first stage of perforation adopts a continuous oil pipe with a perforating gun, the length of a single cluster is 1m, the hole density is 20 holes/m, and the number of the single-hole clusters is 6; phase 60 degree, aperture 9.5 mm.
5) The total amount of acid is 30m3The discharge capacity of acid injection is 1.5m3Min, after pumping for 3min, the discharge capacity is increased by 6m3Replacing acid in min, and reducing the displacement of the acid to 1.5m when the acid enters the first perforation cluster close to the heel3Min; wait for 6m3When the acid enters the first perforation cluster close to the heel, the remaining acid liquid is divided into 3 times equally and 1m3The volume of the discharge per minute is finished.
6) Using a glue solution with the viscosity of 70 mPas of 60m3And the discharge capacity is increased to 16m within 2min3/min。
7) Adopts a low-viscosity low-friction slick water system with the viscosity of 3mPa & s and the resistance reduction rate of more than 70 percent, and the initial discharge capacity is 6m3Min, after 50% of the liquid volume in the section is injected, the residual liquid volume is evenly injected in 3 parts, and the discharge volume is gradually increased to 16m3Min (i.e. optimized maximum displacement).
8) On the basis of fully sewing in the step 7), 3mPa.s slickwater is adopted for 10m3620m liquid injection quantity of displacement pump per min3Continuously adding 70-140 meshes of propping agent with the sand ratio of 1-3-5-7-9%. The first three sand ratios are 1-3-5%, a continuous sand adding mode is adopted, and the sand carrying liquid amount of each sand ratio is 50m3Two sand ratios of 7% and 9% are added in a plug mode, and the liquid amount of each sand ratio can be 25m3The liquid amount of each section is 150% of the volume of the current section of the well bore. The sand liquid is added with sand in a section plug mode, the stress of a wellhead is not obviously changed, and the pressure of the wellhead is increased by 8Mpa.
9) Based on the step 8), using glue solution with the viscosity of 70mPa.s and the liquid amount of 50m3The discharge capacity is 16m3Min, carrying 40-70 mesh proppant with a sand ratio of 10-13% and a liquid amount of 24m for 10% sand ratio3。
10) And continuing to carry out slick water construction: adopts slickwater with viscosity of 1mPa.s and 70-140 meshes of small-particle size propping agent to be 12m3The proppant with the grain diameter is added into the sand-liquid ratio of 11 to 13 percent in a segmented filling manner at a displacement of/min, and the liquid amount of each sand-liquid ratio is 25m3(ii) a The displacement is 80% of the optimized maximum displacement, which is 50% of the volume of the current section of the well bore.
11) And carrying out second-stage high-viscosity glue construction: with optimized maximum construction displacement of 16m3Injecting 70 Pa.s glue solution at min for 60m3In the glue solution injection process, the proppant with 40-70 meshes is injected in a plug-type carrying mode according to two sand-liquid ratios of 16% and 18%, wherein the liquid amount of the 16% sand-liquid ratio is 36m3。
12) And (3) construction in a slick water stage again: injecting 70-140 mesh small-particle size proppant by adopting a slick water section with viscosity of 1mPa.s in a plug mode, wherein the sand-liquid ratio can be 17-19%, and the liquid amount of each sand-liquid ratio is 25m3The liquid amount of each sand-liquid ratio is 40 percent of the volume of the current section of the well bore, and the discharge capacity is the highest discharge capacity of 16m3/min。
13) The small-particle size propping agent in the construction can possibly stay in the vertical main crack and can be cleaned again by glue solution with the viscosity of 90mPa.s and the discharge capacity of 16m3And/min, firstly 70-140 meshes of small-particle-size proppant with the sand-liquid ratio of 21-23-25%, then 40-70 meshes of proppant with the sand-liquid ratio of 18-21-24%, and equally dividing the liquid amount of each sand-liquid ratio by 3.
14) Replacement operation: according to the current sectionThe volume of the well bore is 105 percent of the design, and the displacement liquid volume of the section is 45m3At 16m3Displacement injection per min. 13.5m3And glue solution with the viscosity of 60mPa & s is adopted to ensure that the horizontal shaft has no sand setting phenomenon. Then, the mixture was replaced with slickwater having a viscosity of 1 mPas.
15) And (5) constructing other sections, and repeating the steps 4) to 14), and correspondingly adjusting the construction parameters of each section according to the patent design until all sections are constructed.
16) Drilling plug, testing and producing, and executing according to the conventional flow.
Claims (10)
1. A high tectonic stress normal pressure shale gas reservoir fracturing method is characterized by comprising the following steps:
step 1) evaluation of shale key reservoir parameters;
step 2), geological engineering double-dessert evaluation and perforation position determination;
step 3), optimizing a fracture parameter system;
step 4), optimizing fracturing construction parameters;
step 5), performing shower hole operation;
the length of a single cluster is 1-1.5m, and the pore density is 16-20 pores/m; the number of clusters in a single hole is 4-6 clusters;
step 6) acid pretreatment operation;
step 7), high-viscosity glue liquid high-discharge splitting vertical main crack construction;
step 8), communicating an extended branch seam system and a horizontal layer seam system by low-viscosity slick water with variable displacement;
step 9), constructing small-particle-size long slugs or continuously adding sand;
step 10), sand adding construction is carried out on a first high-viscosity glue liquid slug;
step 11), construction of medium-discharge capacity of small-grain-size medium sand-liquid ratio of slickwater;
step 12) second high-viscosity glue liquid slug sand adding construction;
step 13), construction with high sand-liquid ratio and high discharge capacity of small grain size of slickwater;
step 14), high-viscosity glue liquid high-discharge sand-carrying filling vertical main crack construction;
step 15) replacement work.
2. The high tectonic stress atmospheric pressure shale gas reservoir fracturing method of claim 1, wherein:
in the step 6), the step of,
the dosage of each acid is 20-30m3The discharge capacity of the acid injection is 1-1.5m3Min, the displacement of the acid is 4-6m3Min; when acid enters a first perforation cluster close to the heel, the displacement of the acid is reduced to the original displacement of the acid;
after 18-22% of the using amount of the acid liquor enters the first cluster of perforations, the first cluster of perforations is divided into 2-3 times, the rest acid is evenly injected, the displacement of the acid replacement is gradually increased, and the final displacement of the acid replacement is the optimized highest displacement.
3. The high tectonic stress atmospheric pressure shale gas reservoir fracturing method of claim 1, wherein:
in the step 7), the step of,
using glue solution with viscosity of 60-70mPa.s, the discharge capacity is increased to the optimized maximum value within 1-2min, and the liquid amount is 50-60m3。
4. The high tectonic stress atmospheric pressure shale gas reservoir fracturing method of claim 1, wherein:
in the step 8), the step of carrying out the,
taking low-viscosity slick water with viscosity of 1-3mPa.s and drag reduction rate of more than 70%, and taking 5-6m at initial discharge3And/min, the liquid volume accounts for 20-30% of the total liquid volume of the section, when the liquid volume of the section is injected into the section by 50-60%, the residual liquid volume is uniformly injected into the section by 2-3 parts, and the discharge capacity is correspondingly and gradually increased to the optimized maximum discharge capacity.
5. The high tectonic stress atmospheric pressure shale gas reservoir fracturing method of claim 1, wherein:
in the step 9), the step (c),
using slickwater with viscosity of 1-3mPa.s to carry 70-140 meshes of propping agent, wherein the sand-liquid ratio is 1-3-5-7-9%; the first three sand-liquid ratios adopt continuous sand adding, the liquid amount of each section is 100% -150% of the volume of the current section of the shaft, the last two sand-liquid ratios are slug sand adding, and the volume of each sand-liquid ratio is 50% -60% of the volume of the shaft; the discharge capacity is 50-60% of the optimized maximum discharge capacity;
if the sand-liquid ratio slug type sand adding does not cause obvious change of the wellhead stress, the continuous sand adding construction of the two sand-liquid ratios is carried out again until the wellhead stress is caused to rise by 4-8 Mpa.
6. The high tectonic stress atmospheric pressure shale gas reservoir fracturing method of claim 1, wherein:
in the step 10), the step of processing the raw material,
using glue solution with viscosity of 60-70mPa.s and liquid quantity of 40-50m3The discharge capacity is the optimized maximum discharge capacity and carries 40-70 meshes of propping agent, the sand-liquid ratio is 10-13%, and the liquid amount with the sand-liquid ratio of 10% accounts for 50% -60% of the total liquid amount of each construction section.
7. The high tectonic stress atmospheric pressure shale gas reservoir fracturing method of claim 1, wherein:
in the step 11), the step of processing the raw material,
the method adopts slickwater with the viscosity of 1-3mPa.s and 70-140 meshes of small-particle size propping agent, the sand-liquid ratio is 11-13-15%, the sand is added in a slug type manner, the liquid amount of each sand-liquid ratio is 40-50% of the volume of the current section of a well bore, and the discharge capacity is 70-80% of the optimized maximum discharge capacity.
8. The high tectonic stress atmospheric pressure shale gas reservoir fracturing method of claim 1, wherein:
in the step 12), the step of processing the raw material,
using glue solution with viscosity of 70-80mPa.s and liquid quantity of 50-60m3The discharge capacity is the optimized maximum discharge capacity, 40-70 meshes of propping agent are carried, the sand-liquid ratio is 16-19%, and the liquid amount with the sand-liquid ratio of 16% accounts for 50% -60% of the total liquid amount of each construction section.
9. The high tectonic stress atmospheric pressure shale gas reservoir fracturing method of claim 1, wherein:
in step 13)
The method adopts slickwater with viscosity of 1-3mPa.s and 70-140 meshes of small-particle size propping agent, the sand-liquid ratio is 17-19%, the sand is added in a slug type manner, the liquid amount of each sand-liquid ratio is 30-40% of the volume of the well bore of the current section, and the discharge capacity is the optimized highest discharge capacity.
10. The high tectonic stress atmospheric pressure shale gas reservoir fracturing method of claim 1, wherein:
in the step 14), the step of,
cleaning again by using glue solution with the viscosity of 80-90mPa.s, wherein the discharge capacity is the optimized highest discharge capacity, and the liquid quantity is designed according to 110-120% of the expected volume of the vertical main crack; 70-140 meshes of small-particle-size proppant with a sand-liquid ratio of 21-23-25% and then 40-70 meshes of proppant with a sand-liquid ratio of 18-21-24%, wherein the liquid amount of each sand-liquid ratio is evenly divided according to the step number of the sand-liquid ratio; or the liquid amount in the high sand-liquid ratio stage is reduced by 5-10%, and the reduced amount is supplied to the low sand-liquid ratio stage, so that the construction safety is ensured;
in the step 15), the step of carrying out the,
the displacement liquid amount is 105-110% of the volume of the current section of the well bore; the displacement is the optimized maximum displacement;
the former 30-40% displacement liquid adopts glue solution with viscosity of 50-60mPa.s, and then adopts slickwater with viscosity of 1-3mPa.s for displacement.
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