CN111287720A - Compact oil and gas reservoir hydraulic fracturing optimization design method based on compressibility evaluation - Google Patents
Compact oil and gas reservoir hydraulic fracturing optimization design method based on compressibility evaluation Download PDFInfo
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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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
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Abstract
The invention discloses a compact oil and gas reservoir hydraulic fracturing optimization design method based on compressibility evaluation, which comprises the following steps: acquiring basic geological parameters of a reservoir fracturing interval; performing compressibility index calculation on the reservoir according to the basic geological parameters; optimizing a perforation position according to the calculation result of the compressibility index; and adjusting the viscosity of the fracturing fluid and the density of the proppant, and optimizing the laying form of the proppant in the fracture. The method can effectively improve the complexity of a fracture network, finely adjust the viscosity of the fracturing fluid and the density of the proppant based on reservoir parameters to control the conveying distance of the proppant, improve the laying form of the proppant in a near-wellbore zone and a far-end fracture, effectively improve the seepage capability of the reservoir and improve the hydraulic fracturing effect.
Description
Technical Field
The invention relates to the technical field of oil and gas reservoir development, in particular to a compact oil and gas reservoir hydraulic fracturing optimization design method based on compressibility evaluation in yield increase transformation of an oil and gas reservoir.
Background
The hydraulic fracturing is an important measure for increasing production and improving a compact oil and gas reservoir, and is mainly characterized in that a ground high-pressure pump set is utilized to inject high-pressure liquid (pad fluid) into a reservoir under the condition that the fracture pressure of the reservoir or the closing pressure of natural fractures is higher than the fracture pressure of the reservoir, artificial fractures and natural fractures are opened in the reservoir and communicated to form a complex fracture network, then fracturing fluid (sand carrying fluid) with propping agents (sand grains) is continuously injected, and the propping agents are moved and settled in the fractures to form a sand bank. After the fracturing fluid is drained back, the propping agent left in the fracture can play a role of preventing the fracture from being completely closed, so that the fracture still keeps a certain opening degree under the closing pressure, and a sand-filled fracture which has a certain length and allows fluid to flow is formed in the stratum, thereby achieving the purposes of improving the oil-gas seepage condition and increasing the yield of an oil-gas well. Thus, the key to hydraulic fracturing of tight reservoirs is the formation of a complex fracture network and good proppant placement morphology in the fracture network.
The preferred reservoir perforation location is a key factor in creating a complex network of seams. The conventional method for selecting the perforation position does not consider the influences of factors such as rock brittleness, ground stress, natural fractures and the like, and cannot ensure that a reservoir stratum forms a complex fracture network. In addition, in a complex fracture network, the accurate control of the migration and sedimentation of the propping agent by optimizing construction parameters is the key for improving the laying efficiency of the propping agent.
At present, a plurality of methods for optimizing hydraulic fracturing construction parameters at home and abroad exist, but aiming at compact oil and gas reservoirs, researches on improving the complexity of fractures and the laying efficiency of a propping agent are few, the current on-site fracturing construction design requirements cannot be met, the operability of the fracturing construction process is poor, and effective guidance cannot be provided for fracturing construction.
Disclosure of Invention
Aiming at the problems, the invention aims to provide a compact oil and gas reservoir hydraulic fracturing optimization design method based on compressibility evaluation, a complex fracture network can be formed in the hydraulic fracturing process according to the design of parameters, a propping agent is effectively laid in the fracture, and the hydraulic fracturing effect is improved.
The technical scheme of the invention is as follows:
a compact oil and gas reservoir hydraulic fracturing optimization design method based on compressibility evaluation comprises the following steps:
acquiring basic geological parameters of a reservoir fracturing interval;
performing compressibility index calculation on the reservoir according to the basic geological parameters;
optimizing a perforation position according to the calculation result of the compressibility index;
and adjusting the viscosity of the fracturing fluid and the density of the proppant, and optimizing the laying form of the proppant in the fracture.
Preferably, the basic geological parameters of the reservoir fracturing interval comprise rock mechanical parameters, an approach angle, a ground stress difference coefficient, reservoir fracture closing pressure and temperature, and the rock mechanical parameters comprise Young modulus, shear expansion angle and peak strain.
Preferably, the compressibility index is calculated as follows:
dividing a reservoir fracturing layer into N fracturing small layers, wherein the thickness of each layer is 1m, calculating the average value of basic parameters of each small layer, and then carrying out normalization treatment on the Young modulus, the shear expansion angle and the peak strain according to the following formula:
in the formula: xnIs a normalized value of the parameter X; x is a rock mechanical parameter; xminIs the minimum value of the parameter X in the N layers; xmaxThe maximum value of the parameter X in the N layers;
the compressibility index was calculated according to the following formula:
in the formula: fIIs the compressibility index;Ennormalized value for young's modulus; psinIs a normalized value of the shear expansion angle; epsilonpnNormalized value for peak strain; theta is an approach angle; thetamaxThe maximum value of the approach angle in the N layers is obtained; khIs the ground stress difference coefficient.
Preferably, the preferred principle of the preferred perforation locations is as follows: when the compressibility index is greater than or equal to the compressibility index threshold value, perforating; and when the compressibility index is smaller than the compressibility index threshold value, no perforation is performed.
Preferably, the compressibility index threshold value is determined according to the whole compressibility condition of the reservoir and the length of the construction perforation.
Preferably, the method of adjusting the viscosity of the fracturing fluid and the density of the proppant is as follows:
the fracturing fluid viscosity and proppant density were designed according to the formation fracture closure pressure P and formation temperature T of the fractured interval as shown in table 1:
table 1 fracturing fluid viscosity and proppant density
| Formation temperature | Viscosity of first stage fracturing fluid | Second stage fracturing fluid viscosity |
| T≤90℃ | 20mPa·s | 5mPa· |
| 90℃＜T＜120℃ | 30mPa·s | 10mPa·s |
| T≥120℃ | 40mPa·s | 20mPa·s |
| Closing pressure | First stage proppant Density | Second stage proppant Density |
| P≤50MPa | 1300kg/m3 | 1500kg/m3 |
| 50MPa＜P＜70MPa | 1500kg/m3 | 1700kg/m3 |
| P≥70MPa | 1700kg/m3 | 1830kg/m3 |
When the sand liquid consumption is within one half or three fifths of the total sand liquid consumption, the first stage is obtained, and the rest sand liquid consumption is the second stage.
Compared with the prior art, the invention has the following advantages:
according to the method, the influences of stratum rock mechanical parameters, ground stress and natural fractures are considered, the compressibility index of the fracturing layer section is calculated according to the influences, then the perforation position is optimized based on the calculation result of the compressibility index, and the complexity of the fracture network can be effectively improved. In addition, the viscosity of the fracturing fluid and the density of the propping agent are finely adjusted based on reservoir parameters, so that the conveying distance of the propping agent can be controlled, the laying form of the propping agent in a near-wellbore zone and a far-end fracture is improved, the seepage capability of the reservoir is effectively improved, and the hydraulic fracturing effect is improved.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly described below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to these drawings without creative efforts.
FIG. 1 is a schematic diagram showing the comparison of construction pressures of a W1 well and a W2 well in an example;
FIG. 2 is a graph showing the production curves of wells W1 and W2 in comparison in the example.
Detailed Description
The invention is further illustrated with reference to the following figures and examples. It should be noted that, in the present application, the embodiments and the technical features of the embodiments may be combined with each other without conflict.
The invention provides a compact oil and gas reservoir hydraulic fracturing optimization design method based on compressibility evaluation, which comprises the following steps:
firstly, obtaining basic geological parameters of a reservoir fractured interval, wherein the basic geological parameters of the reservoir fractured interval comprise rock mechanical parameters, an approach angle, a ground stress difference coefficient, reservoir fracture closing pressure and temperature, the rock mechanical parameters comprise Young modulus, a shear expansion angle and peak strain, and the approach angle is an included angle between a natural fracture and the maximum horizontal principal stress of a stratum.
Secondly, calculating a compressibility index of the reservoir according to the basic geological parameters, wherein the calculation method of the compressibility index comprises the following steps:
dividing a reservoir fracturing layer into N fracturing small layers, wherein the thickness of each layer is 1m, calculating the average value of basic parameters of each small layer, and then carrying out normalization treatment on the Young modulus, the shear expansion angle and the peak strain according to the following formula:
in the formula: xnIs a normalized value of the parameter X; x is a rock mechanical parameter; xminIs the minimum value of the parameter X in the N layers; xmaxThe maximum value of the parameter X in the N layers;
the compressibility index was calculated according to the following formula:
in the formula: fIIs the compressibility index; enNormalized value for young's modulus; psinIs a normalized value of the shear expansion angle; epsilonpnNormalized value for peak strain; theta is an approach angle; thetamaxThe maximum value of the approach angle in the N layers is obtained; khIs the ground stress difference coefficient.
Then, the perforation position is optimized according to the calculation result of the compressibility index, and the optimization principle of the optimized perforation position is as follows: when the compressibility index is greater than or equal to the compressibility index threshold value, perforating; and when the compressibility index is smaller than the compressibility index threshold value, no perforation is performed. And the compressibility index threshold value is determined according to factors such as the whole compressibility condition of the reservoir, the construction perforation length and the like.
And finally, adjusting the viscosity of the fracturing fluid and the density of the proppant, optimizing the laying form of the proppant in the fracture, and adjusting according to the stratum fracture closing pressure P and the stratum temperature T of the fractured interval as shown in the table 1:
table 1 fracturing fluid viscosity and proppant density
| Formation temperature | Viscosity of first stage fracturing fluid | Second stage fracturing fluid viscosity |
| T≤90℃ | 20mPa·s | 5mPa· |
| 90℃＜T＜120℃ | 30mPa·s | 10mPa·s |
| T≥120℃ | 40mPa·s | 20mPa·s |
| Closing pressure | First stage proppant Density | Second stage proppant Density |
| P≤50MPa | 1300kg/m3 | 1500kg/m3 |
| 50MPa＜P＜70MPa | 1500kg/m3 | 1700kg/m3 |
| P≥70MPa | 1700kg/m3 | 1830kg/m3 |
When the sand liquid consumption is within one half or three fifths of the total sand liquid consumption, the first stage is obtained, and the rest sand liquid consumption is the second stage.
The design of the first stage can enable the high-viscosity fracturing fluid to carry the low-density propping agent, the low-density propping agent is slow to settle and is conveyed to the far end of the fracture, the laying distance of the propping agent is increased, and the area of the supported fracture is effectively increased. Meanwhile, the accumulation of the propping agent at the crack inlet of the near-well zone is reduced, the static pressure at the crack inlet end is reduced, and the fracturing construction success rate is improved.
The design of the second stage can enable the low-viscosity fracturing fluid to carry high-density propping agent, the high-density propping agent has high settling speed, is settled and accumulated at the seam opening, fills a sand-free area formed at the early stage, and forms a high-conductivity fracture in a near-well zone. The fracturing fluid and the propping agent are used in combination in the two stages, so that an ideal propping agent laying form can be formed in the fracture, the seepage capability of the reservoir is effectively improved, and the hydraulic fracturing effect is improved.
In a specific embodiment, a certain block of oil well W1 is taken as an example, the oil well is a deep tight oil reservoir, the stratum fracture closing pressure is 52MPa, the reservoir temperature is 136 ℃, natural fractures develop, and the ground stress difference coefficient is large. The length of the fracturing section is 60m, and the perforation position and related fracturing construction parameters are optimally designed according to the length.
A compact oil and gas reservoir hydraulic fracturing optimization design method based on compressibility evaluation comprises the following steps:
(1) collecting basic parameters of the target interval needing fracturing modification, including rock mechanical parameters (Young modulus, shear expansion angle and peak strain), approximation angle, ground stress difference coefficient, reservoir fracture closing pressure and temperature data.
(2) Dividing the target interval into 60 small fracturing layers, wherein the thickness of each layer is 1m, calculating the average value of basic parameters of each small layer, and then carrying out normalization treatment on the Young modulus, the shear expansion angle and the peak strain according to the formula (1).
(3) The compressibility index of the target interval is calculated according to the formula (2), and the calculation result is shown in table 2:
TABLE 2 compressibility index calculation results
(4) And (3) preferably selecting a perforation position according to the compressibility index, wherein the whole compressibility index of the well reservoir is 0.1-0.6, and the threshold value of the compressibility index is determined to be 0.4 by combining the perforation length requirement, and then selecting the perforation position as a small layer with the compressibility index larger than 0.4, wherein the preferable results are shown in Table 3:
TABLE 3 perforation optimization results
(5) The viscosity of the fracturing fluid and the density of the proppant are finely regulated and controlled by the method shown in table 1, so that the laying form of the proppant in the fracture is optimized, and the construction parameters are specifically as follows:
① the stratum fracture closing pressure P is 52MPa, the stratum temperature T is 136 ℃, therefore, the viscosity of the fracturing fluid pumped in the first stage is determined to be 40 mPa.s, and the density of the propping agent is determined to be 1500kg/m3。
② the viscosity of the fracturing fluid pumped in the second stage is 20 mPa.s, and the density of the propping agent is 1700kg/m3。
The W2 well and the W1 well are adjacent wells located in the same block and the same reservoir, the W2 well selects a perforation position, fracturing fluid viscosity and proppant density by a conventional method, the two wells are fractured by the same construction scale, and then the pressure change in the fracturing construction process and the yield result of the fractured oil well are compared. The construction pressure curves of the W1 well and the W2 well are shown in fig. 1, and it can be seen from fig. 1 that the fracture pressure of the W1 well at the preferred perforation position is lower according to the compressibility index because the interval with higher compressibility index is more brittle and the natural fracture develops. In the whole construction process, the construction pressure can be obviously reduced by 5-10 MPa after the position of the jetting hole is optimized. Under the same construction conditions, the later construction pressure of the W1 well rises to a certain extent, and the fluid friction resistance is increased because a complex seam network is formed by communicating natural fractures. As shown in FIG. 2, the production curves of the two wells are shown in FIG. 2, and it is understood from FIG. 2 that about 17.6t of daily oil production in the initial stage of the W1 well is increased by about 5.6t compared with the W2 well, and the production of the well is stabilized by about 15t for a long time.
In another specific embodiment, the invention is applied to more than 10 compact oil wells in the Bohai Bay basin, the average daily yield of a single well is increased by about 4.8t, and the fracturing modification effect is greatly improved.
In conclusion, the invention can effectively reduce the construction pressure, improve the complexity of the fracture network, improve the laying form of the propping agent in the near-wellbore zone and the far-end fracture and improve the hydraulic fracturing effect.
Although the present invention has been described with reference to a preferred embodiment, it should be understood that various changes, substitutions and alterations can be made herein without departing from the spirit and scope of the invention as defined by the appended claims.
Claims (6)
1. A compact oil and gas reservoir hydraulic fracturing optimization design method based on compressibility evaluation is characterized by comprising the following steps:
acquiring basic geological parameters of a reservoir fracturing interval;
performing compressibility index calculation on the reservoir according to the basic geological parameters;
optimizing a perforation position according to the calculation result of the compressibility index;
and adjusting the viscosity of the fracturing fluid and the density of the proppant, and optimizing the laying form of the proppant in the fracture.
2. The tight hydrocarbon reservoir hydraulic fracturing optimization design method based on compressibility evaluation of claim 1, wherein the basic geological parameters of the reservoir fracturing interval comprise rock mechanics parameters, including young's modulus, shear expansion angle, peak strain, approach angle, geostress difference coefficient, reservoir fracture closure pressure and temperature.
3. The design method for hydraulic fracturing optimization of tight oil and gas reservoirs based on compressibility evaluation as claimed in claim 2, wherein the compressibility index is calculated as follows:
dividing a reservoir fracturing layer into N fracturing small layers, wherein the thickness of each layer is 1m, calculating the average value of basic parameters of each small layer, and then carrying out normalization treatment on the Young modulus, the shear expansion angle and the peak strain according to the following formula:
in the formula: xnIs a normalized value of the parameter X; x is a rock mechanical parameter; xminIs the minimum value of the parameter X in the N layers; xmaxThe maximum value of the parameter X in the N layers;
the compressibility index was calculated according to the following formula:
in the formula: fIIs the compressibility index; enNormalized value for young's modulus; psinIs a normalized value of the shear expansion angle; epsilonpnNormalized value for peak strain; theta is an approach angle; thetamaxThe maximum value of the approach angle in the N layers is obtained; khIs the ground stress difference coefficient.
4. The method for optimally designing the hydraulic fracturing of the tight hydrocarbon reservoir based on the compressibility evaluation as claimed in any one of claims 1-3, wherein the optimization principle of the optimized perforation positions is as follows: when the compressibility index is greater than or equal to the compressibility index threshold value, perforating; and when the compressibility index is smaller than the compressibility index threshold value, no perforation is performed.
5. The method for designing and optimizing the hydraulic fracturing of the tight oil and gas reservoir based on the compressibility evaluation as claimed in claim 4, wherein the compressibility index threshold value is determined according to the overall compressibility of the reservoir and the length of the construction perforation.
6. The method for designing the hydraulic fracturing optimization of the tight oil and gas reservoir based on the compressibility evaluation as claimed in claim 1, wherein the method for adjusting the viscosity of the fracturing fluid and the density of the proppant comprises the following steps:
the fracturing fluid viscosity and proppant density were designed according to the formation fracture closure pressure P and formation temperature T of the fractured interval as shown in table 1:
table 1 fracturing fluid viscosity and proppant density
When the sand liquid consumption is within one half or three fifths of the total sand liquid consumption, the first stage is obtained, and the rest sand liquid consumption is the second stage.
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