CN113221227B - Horizontal well azimuth optimization method comprehensively considering drilling and hydraulic fracturing - Google Patents

Horizontal well azimuth optimization method comprehensively considering drilling and hydraulic fracturing Download PDF

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CN113221227B
CN113221227B CN202110604335.4A CN202110604335A CN113221227B CN 113221227 B CN113221227 B CN 113221227B CN 202110604335 A CN202110604335 A CN 202110604335A CN 113221227 B CN113221227 B CN 113221227B
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马天寿
王浩男
付建红
白杨
吴鹏程
钟成旭
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Abstract

The invention discloses a horizontal well azimuth optimization method comprehensively considering well drilling and hydraulic fracturing, which comprises the following steps of: collecting the stratum vertical depth, the rock mechanical parameters, the pore pressure parameters and the ground stress parameters of a work area, designing a well body structure, designing a drilling tool structure, designing drilling fluid performance parameters and tripping speed of a to-be-drilled well in the work area; building a horizontal well collapse pressure and fracture pressure calculation model, and calculating the collapse pressure equivalent density and the fracture pressure equivalent density of horizontal well bores in different directions; calculating the fluctuating pressure of a design horizontal wellAn equivalent density; drawing collapse pressure equivalent density, fracture pressure equivalent density and designed drilling fluid density rhomAnd determining the optimal drilling direction of the horizontal well according to the relation chart of the equivalent density of the fluctuation pressure. The method comprehensively considers the influences of borehole wall collapse pressure, borehole wall fracture pressure and drilling operation, and can provide a basis for unconventional oil and gas horizontal well design, drilling optimization and hydraulic fracturing optimization of shale oil and gas, dense oil and gas, coal bed gas and the like.

Description

Horizontal well azimuth optimization method comprehensively considering drilling and hydraulic fracturing
Technical Field
The invention relates to a horizontal well azimuth optimization method comprehensively considering well drilling and hydraulic fracturing.
Background
Along with the exhaustion of conventional oil and gas resources, unconventional oil and gas such as shale oil and gas, dense oil and gas, coal bed gas and the like are gradually paid attention. The horizontal well and hydraulic fracturing are key technologies for developing the unconventional oil and gas, firstly, the contact area of a shaft and a production layer is increased by drilling the horizontal well, and then, the permeability of a reservoir stratum around the well is increased and an oil and gas seepage channel is pressed out by means of staged hydraulic fracturing, so that the oil and gas recovery rate is improved. For unconventional oil and gas development, recovery and economics are always the goals sought by the industry, which requires that recovery and economics be targeted from development, drilling, fracturing to production. A great deal of research has shown that the drilling direction of the horizontal well affects not only the construction difficulty of drilling and fracturing (i.e. affects the economy), but also the oil and gas recovery rate, mainly because the drilling direction of the horizontal well needs to be along the direction of the minimum horizontal ground stress as much as possible, and the actual drilling operation is often difficult to realize, and deviates from the direction, but at the end, how to design the deviating direction, or how to optimize the drilling direction of the horizontal well, is always the focus of the industry's debate.
For the design and optimization of the optimal azimuth of the horizontal well, from the perspective of the stability of the well wall of the well, the optimal drilling azimuth of the horizontal well in the normal fault stress state is the direction of the minimum horizontal ground stress, the optimal drilling azimuth of the horizontal well in the walk-slip fault stress state is the direction with the included angle of 30-45 degrees with the direction of the maximum horizontal ground stress, the optimal drilling azimuth of the horizontal well in the reverse thrust fault stress state is the direction of the maximum horizontal ground stress, and the well wall stability in the directions is better; however, due to the influence of the stratigraphic weak plane, the optimal drilling direction of the horizontal well which is beneficial to the well wall stability is influenced to a certain extent, which needs to be considered. From a hydraulic fracturing perspective, it is generally desirable to drill along the least horizontal geostress azimuth, i.e., the optimal drilling azimuth of the horizontal well is the least horizontal geostress direction, as this facilitates hydraulic fracturing to form vertical fractures perpendicular to the wellbore axis, which facilitates enhanced oil and gas recovery. Therefore, the optimal orientation of the drilling of unconventional oil and gas horizontal wells such as shale oil and gas, dense oil and gas, coal bed gas and the like needs to be designed by comprehensively considering the requirements of drilling and hydraulic fracturing, and meanwhile, in order to ensure safe and efficient drilling, the comprehensive influence of drilling operation on well wall stability and well leakage in the drilling process needs to be comprehensively considered, so that the orientation of the horizontal well is optimized. However, at present, a horizontal well azimuth optimization method comprehensively considering the factors is still unavailable. Therefore, the horizontal well azimuth optimization method comprehensively considering well drilling and fracturing is invented to guide the azimuth selection and design of unconventional oil and gas horizontal wells such as shale oil and gas, compact oil and gas, coal bed gas and the like.
Disclosure of Invention
The invention mainly overcomes the defects in the prior art and provides a horizontal well azimuth optimization method comprehensively considering drilling and hydraulic fracturing.
The technical scheme provided by the invention for solving the technical problems is as follows: a horizontal well azimuth optimization method comprehensively considering drilling and hydraulic fracturing comprises the following steps:
s10, collecting TVD of the vertical depth of the stratum of the work area, rock mechanics parameters, pore pressure parameters, ground stress parameters, well body design structure of the well to be drilled in the work area, drilling tool design structure, drilling fluid performance parameters and tripping speed vp；
Step S20, building a horizontal well collapse pressure and rupture pressure calculation model and calculating the collapse pressure and rupture pressure of the horizontal well according to the work areaCalculating collapse pressure equivalent density rho of boreholes at different azimuth levels by using the stratum vertical depth TVD, the rock mechanics parameter, the pore pressure parameter and the ground stress parametercAnd fracture pressure equivalent density ρf；
S30, designing a well structure, a drilling tool structure, drilling fluid performance parameters and a tripping speed v according to the to-be-drilled well in the work areapCalculating the fluctuation pressure equivalent density rho of the designed horizontal wellsw；
Step S40, drawing collapse pressure equivalent density rhocFracture pressure equivalent density ρfDesign drilling fluid density rhomAnd fluctuating pressure equivalent density ρswAnd determining the optimal drilling direction of the horizontal well by using the relation chart.
The further technical scheme is that the rock mechanical parameters comprise rock Poisson ratio mu and rock cohesion C0Internal angle of friction of rock
Figure BDA0003093847260000021
Tensile strength S of rocktAnd the rock Biot coefficient αp(ii) a The pore pressure parameter comprises formation pore pressure Pp(ii) a The ground stress parameter comprises a vertical ground stress sigmavMaximum horizontal ground stress σHMinimum level of ground stress σh(ii) a The designed well body structure comprises a well depth H and a well bore diameter Dw(ii) a The designed drilling tool structure comprises a drill collar outer diameter ddcLength L of drill collardcOuter diameter d of drill roddpLength L of drill roddp(ii) a The design drilling fluid performance parameters include a design drilling fluid density ρmA fluidity index n and a consistency factor K.
The further technical scheme is that the calculation model of the collapse pressure and the rupture pressure of the horizontal well in the step S20 is as follows:
Figure BDA0003093847260000031
Figure BDA0003093847260000032
in the formula: sigmar、σθ、σz、τθzRespectively the borehole wall stress under the cylindrical coordinates of the borehole, MPa; sigmaHHorizontal maximum ground stress, MPa; sigmahHorizontal minimum ground stress, MPa; sigmavIs vertical ground stress, MPa; pwThe drilling fluid column pressure is MPa; theta is the well angle, °; psi is the borehole azimuth (borehole axis included angle with maximum horizontal geostress azimuth), °; mu is Poisson's ratio and has no dimension; sigmai、σj、σkRespectively is a main stress component of the well wall, namely MPa; ppPore pressure, MPa; alpha is alphapBiot coefficient, no dimension.
Further technical solution is that the collapse pressure equivalent density ρ in the step S20cThe calculation formula is as follows:
Figure BDA0003093847260000033
Figure BDA0003093847260000034
wherein the content of the first and second substances,
Figure BDA0003093847260000035
Figure BDA0003093847260000036
Figure BDA0003093847260000041
Figure BDA0003093847260000042
in the formula: c. CwThe cohesive force of the bedding surface is MPa;
Figure BDA0003093847260000043
the angle of the inner friction of the bedding plane is degree; beta is the included angle between the normal of the weak surface and the direction of the maximum main stress; c. C0Bulk cohesion, MPa;
Figure BDA0003093847260000044
is the internal friction angle of the body, degree; beta is a0Shearing the fracture surface angle for the body; beta is a1、β2Angle range of damage for bedding shearing slippage; f. ofcIs a borehole wall collapse damage function; gamma is the included angle between the maximum main stress of the well wall and the axis of the well; lp、mp、npThe direction cosine of the normal of the bedding surface under the geodetic coordinate system; lm、mm、nmThe direction cosine of the maximum main stress of the well wall under a coordinate system; DIP is the angle of inclination of the plane; TR is the direction of the bedding plane, degree; pcCollapse pressure, MPa; rhocIn terms of collapse pressure equivalent density, g/cm3(ii) a TVD is the vertical depth of the stratum, m;
fracture pressure equivalent density ρfThe calculation formula of (2) is as follows:
Figure BDA0003093847260000045
Figure BDA0003093847260000046
in the formula: stRock tensile strength, MPa; f. offAs a function of borehole wall fracture; pfRupture pressure, MPa; rhofFor burst pressure equivalent Density, g/cm3。
The further technical scheme is that the specific process of the step S30 is as follows:
step S31, according to the diameter ratio d of the drill collar annulusdc/DwAnd a fluidity index n to obtain a fluid adhesion systemNumber Kc；
Step S32, calculating the annular flow velocity v of the drill collardcAnd the annular flow velocity v of the drill pipedp：
Step S33, according to the annular flow velocity v of the drill collardcAnd the annular flow velocity v of the drill pipedpCalculating the Reynolds number Re of the drill collar annulusdcAnd annular Reynolds number Re of drill roddp；
Step S34, judging the annular fluid state of the drill collar and the drill pipe, and determining the Reynolds number Re of the annular fluid of the drill collardcAnd annular Reynolds number Re of drill roddpCalculating the friction coefficient f of drill collar annulusdcAnd annular friction coefficient f of drill pipedp：
For a collar annulus:
when Redc<(3470-dc：
fdc＝24/Redc
In the formula: f. ofdcThe friction coefficient of the drill collar annulus is; redcThe annular Reynolds number of the drill collar is a dimensionless number;
when RedcWhen the pressure is not less than 3470-dc：
Figure BDA0003093847260000051
In the formula: f. ofdcThe friction coefficient of the drill collar annulus is; redcThe annular Reynolds number of the drill collar is a dimensionless number;
for a drill pipe annulus:
when Redp<(3470 1370n), the drill pipe annulus is laminar flow, and the drill pipe annulus friction coefficient fdp：
fdp＝24/Redp
In the formula: f. ofdpThe annular friction coefficient of the drill pipe is obtained; redpThe Reynolds number of the drill pipe annulus;
when RedpWhen the pressure is not less than 3470-dp：
Figure BDA0003093847260000052
In the formula: f. ofdpThe annular friction coefficient of the drill pipe is obtained; redpThe Reynolds number of the drill pipe annulus;
step S35, according to the annular flow velocity v of the drill collardcDrill pipe annulus flow velocity vdpAnnular friction coefficient f of drill collardcAnnular friction coefficient f of drill pipedpCalculating the fluctuation pressure equivalent density rhosw。
The further technical proposal is that the annular flow velocity v of the drill collardcAnd the annular flow velocity v of the drill pipedpThe calculation formula of (a) is as follows:
Figure BDA0003093847260000053
Figure BDA0003093847260000054
in the formula: v. ofdcThe annular flow velocity of the drill collar is m/s; ddcIs the outer diameter of the drill collar, cm; v. ofdpThe annular flow velocity of the drill rod is m/s; ddpIs the outer diameter of the drill rod in cm; v. ofpThe tripping speed is m/s; dwIs the wellbore diameter, cm.
The further technical scheme is that the annular Reynolds number Re of the drill collardcAnd annular Reynolds number Re of drill roddpThe calculation formula of (a) is as follows:
Figure BDA0003093847260000055
Figure BDA0003093847260000061
in the formula: redcThe annular Reynolds number of the drill collar is a dimensionless number; redpFor drillingThe rod ring hollow Reynolds number has no dimension; rhomIs density, g/cm3(ii) a n is a fluidity index and has no dimension; k is the consistency coefficient and has no dimension.
The further technical proposal is that the fluctuation pressure equivalent density rhoswThe calculation formula of (a) is as follows:
Figure BDA0003093847260000062
in the formula: l isdcIs the drill collar length, m; redpIs the length of the drill rod, m; rhoswFor fluctuating pressure equivalent density, g/cm3。
Further technical solution is that, in step S40: when collapsed pressure equivalent density ρcFracture pressure equivalent density ρfThe safe density window in between, i.e. the collapse pressure equivalent density ρcFracture pressure equivalent density ρfThe drilling fluid density rho is designed under the condition that the area between the two is widemAnd fluctuating pressure equivalent density ρswThe formed drilling operation density fluctuation range does not exceed a safe density window, and well wall collapse and well wall fracture do not occur during drilling along any direction, and at the moment, the optimized horizontal well direction is the direction of minimum horizontal ground stress in view of being beneficial to hydraulic fracturing.
Further technical solution is that, in step S40: when collapsed pressure equivalent density ρcFracture pressure equivalent density ρfThe safe density window in between, i.e. the collapse pressure equivalent density ρcFracture pressure equivalent density ρfThe drilling fluid density rho is designed under the condition that the area between the two is not widemAnd fluctuating pressure equivalent density ρswThe fluctuation range of the drilling operation density is formed to exceed the safe density window, namely an overlapping area exists between the fluctuation range of the drilling operation density and the safe density window, the overlapping area is shown as a dotted frame shadow area in figure 4, and an included angle psi between the boundary point of the overlapping area and the direction of the minimum horizontal ground stress can be obtained1And psi2At this time, the water is optimized from the viewpoint of facilitating hydraulic fracturingThe azimuth of the horizontal well is an included angle min { psi [ phi ] of the direction close to the minimum horizontal ground stress1,ψ2}。
The invention has the following beneficial effects: the invention comprehensively considers the comprehensive influence of the drilling operation on the well wall stability and the well leakage in the drilling process, and can provide a basis for unconventional oil and gas horizontal well design, drilling optimization and hydraulic fracturing optimization of shale oil and gas, compact oil and gas, coal bed gas and the like.
Drawings
FIG. 1 is a flow chart of the present invention;
FIG. 2 is a graph showing the fluid adhesion coefficient KcChecking a value chart;
FIG. 3 is a first horizontal well drilling azimuth optimization chart;
fig. 4 is a second horizontal well drilling azimuth optimization chart.
Detailed Description
The present invention will be further described with reference to the following examples and the accompanying drawings.
As shown in FIG. 1, the horizontal well azimuth optimization method comprehensively considering drilling and hydraulic fracturing comprises the following steps:
s1, collecting TVD of the vertical depth of the stratum of the work area, rock mechanics parameters, pore pressure parameters and ground stress parameters, and collecting the designed well body structure, the designed drilling tool structure, the designed drilling fluid performance parameters and the tripping speed v of the work area to be drilledp；
Wherein the rock mechanics parameters comprise rock Poisson ratio mu and rock cohesion C0Internal angle of friction of rock
Figure BDA0003093847260000071
Tensile strength S of rocktAnd the rock Biot coefficient αp(ii) a The pore pressure parameter comprises formation pore pressure Pp(ii) a The ground stress parameter comprises a vertical ground stress sigmavMaximum horizontal ground stress σHMinimum level of ground stress σh(ii) a The designed well body structure comprises a well depth H and a well bore diameter Dw(ii) a The designed drilling tool structure comprises a drill collar outer diameter ddcLength L of drill collardcOuter diameter d of drill roddpLength L of drill roddp(ii) a The design drilling fluid performance parameters include density ρmA fluidity index n and a consistency coefficient K;
s2, establishing a calculation model of horizontal well collapse pressure and fracture pressure, and calculating collapse pressure equivalent density rho of boreholes at different azimuth levels according to the vertical depth TVD of the stratum of the work area, rock mechanical parameters, stratum pore pressure parameters and stratum ground stress parameterscAnd fracture pressure equivalent density ρf；
Establishing a horizontal well collapse pressure and fracture pressure calculation model:
firstly, calculating the horizontal well wall stress:
Figure BDA0003093847260000081
in the formula: sigmar,σθ,σz,τθzRespectively the borehole wall stress under the cylindrical coordinates of the borehole, MPa; sigmaHHorizontal maximum ground stress, MPa; sigmahHorizontal minimum ground stress, MPa; sigmavIs vertical ground stress, MPa; pwThe drilling fluid column pressure is MPa; theta is the well angle, °; psi is the borehole azimuth (borehole axis included angle with maximum horizontal geostress azimuth), °; mu is Poisson's ratio and has no dimension;
then, calculating the main stress of the horizontal well wall:
Figure BDA0003093847260000082
in the formula: sigmai,σj,σkRespectively is a main stress component of the well wall, namely MPa; ppPore pressure, MPa; alpha is alphapBiot coefficient, no dimension.
Then the main stress sigma of the well wall of the horizontal welliAnd σkSubstituting into the criterion of borehole wall collapse, calculating the nonlinear equation shown in the formula (3), and obtaining the critical borehole pressure P for preventing borehole wall collapsewThe critical wellbore pressure PwNamely waterCollapse pressure P of horizontal wellcThen collapse pressure PcAnd corresponding collapse pressure equivalent density ρcRespectively as follows:
Figure BDA0003093847260000083
Figure BDA0003093847260000084
wherein the content of the first and second substances,
Figure BDA0003093847260000085
Figure BDA0003093847260000086
Figure BDA0003093847260000087
Figure BDA0003093847260000088
in the formula: c. CwThe cohesive force of the bedding surface is MPa;
Figure BDA0003093847260000091
the angle of the inner friction of the bedding plane is degree; beta is the included angle between the normal of the weak surface and the direction of the maximum main stress; c. C0Bulk cohesion, MPa;
Figure BDA0003093847260000092
is the internal friction angle of the body, degree; beta is a0To shear the fracture surface angle of the body,
Figure BDA0003093847260000093
β1,β2shear slip for beddingShift the destruction angle range (fig. 2), deg.; f. ofcAs a function of borehole wall collapse damage, fc<0 will collapse and destabilize, fcWhen 0 is in the limit equilibrium state, fc>0, collapse and instability can not occur; gamma is the included angle between the maximum main stress of the well wall and the axis of the well; lp,mp,npThe direction cosine of the normal of the bedding surface under the geodetic coordinate system; (ii) a lm,mm,nmThe direction cosine of the maximum main stress of the well wall under a coordinate system; DIP is the angle of inclination of the plane; TR is the direction of the bedding plane, degree; pcCollapse pressure, MPa; rhocIn terms of collapse pressure equivalent density, g/cm3(ii) a TVD is the formation vertical depth, m.
Then the main stress sigma of the well wall of the horizontal welljSubstituting into the criterion of borehole wall fracture, calculating the nonlinear equation shown in the formula (8), and obtaining the critical borehole pressure P for preventing borehole wall fracturewThe critical wellbore pressure PwNamely the fracture pressure P of the horizontal wellfThen breaking pressure PfAnd corresponding burst pressure equivalent density ρfRespectively as follows:
Figure BDA0003093847260000094
Figure BDA0003093847260000095
in the formula: stRock tensile strength, MPa; f. offAs a function of borehole wall fracture ff<0 will break, ffWhen 0 is in the limit equilibrium state, ff>0, no crack occurs; pfRupture pressure, MPa; rhofFor burst pressure equivalent Density, g/cm3；
S3, designing a well structure, a drilling tool structure, drilling fluid performance parameters and a tripping speed v according to the to-be-drilled well in the work areapCalculating the fluctuation pressure equivalent density rho of the designed horizontal wellsw；
Step (ii) ofS31, according to the diameter ratio d of the drill collar annulusdc/DwAnd a fluidity index n, and obtaining a fluid adhesion coefficient K by examining the graph 2c；
Step S32, calculating the annular flow velocity v of the drill collardcAnd the annular flow velocity v of the drill pipedp：
Figure BDA0003093847260000096
Figure BDA0003093847260000097
In the formula: v. ofdcThe annular flow velocity of the drill collar is m/s; ddcIs the outer diameter of the drill collar, cm; v. ofdpThe annular flow velocity of the drill rod is m/s; ddpIs the outer diameter of the drill rod in cm; v. ofpThe tripping speed is m/s; dwIs the wellbore diameter, cm.
Step S33, calculating annular Reynolds number Re of drill collardcAnd annular Reynolds number Re of drill roddp；
Figure BDA0003093847260000101
Figure BDA0003093847260000102
In the formula: redcThe annular Reynolds number of the drill collar is a dimensionless number; redpThe Reynolds number of the drill pipe annulus is zero; rhomIs density, g/cm3(ii) a n is a fluidity index and has no dimension; k is the consistency coefficient and has no dimension.
Step S34, judging the annular fluid state of the drill collar and the drill pipe, and calculating the annular friction coefficient f of the drill collardcAnd annular friction coefficient f of drill pipedp：
For a collar annulus:
when Redc<(3470-dc：
fdc＝24/Redc-------------------------------------(15)
When RedcWhen the pressure is not less than 3470-dc：
Figure BDA0003093847260000103
For a drill pipe annulus:
when Redp<(3470 1370n), the drill pipe annulus is laminar flow, and the drill pipe annulus friction coefficient fdp：
fdp＝24/Redp--------------------------------------(17)
When RedpWhen the pressure is not less than 3470-dp：
Figure BDA0003093847260000104
Step S35, calculating the fluctuation pressure equivalent density rhosw；
Figure BDA0003093847260000105
In the formula: l isdcIs the drill collar length, m; redpIs the length of the drill rod, m; rhoswFor fluctuating pressure equivalent density, g/cm3；
Step S4, drawing collapse pressure equivalent density rhocFracture pressure equivalent density ρfDesign drilling fluid density rhomAnd fluctuating pressure equivalent density ρswDetermining the optimal drilling direction of the horizontal well by using a relation chart;
first type of plate: collapse pressure equivalent density ρcFracture pressure equivalent density ρfDesign drilling fluid density rhomAnd fluctuating pressure equivalent density ρswThe relationship is shown in FIG. 3, when collapsed, the equivalent density ρcFracture pressure equivalent density ρfThe safe density window in between (i.e., the collapse pressure equivalent density ρ)cFracture pressure equivalent density ρfArea between the two) is wide enough, the drilling fluid density ρ is designedmAnd fluctuating pressure equivalent density ρswThe formed drilling operation density fluctuation range does not exceed a safe density window, and well wall collapse and well wall fracture do not occur during drilling along any direction, and at the moment, the optimized horizontal well direction is the direction of minimum horizontal ground stress in view of being beneficial to hydraulic fracturing.
Second type of plate: collapse pressure equivalent density ρcFracture pressure equivalent density ρfDesign drilling fluid density rhomAnd fluctuating pressure equivalent density ρswThe relationship is shown in FIG. 4, when collapsed, the equivalent density ρcFracture pressure equivalent density ρfThe safe density window in between (i.e., the collapse pressure equivalent density ρ)cFracture pressure equivalent density ρfArea between the two) is not wide enough, the drilling fluid density ρ is designedmAnd fluctuating pressure equivalent density ρswThe fluctuation range of the drilling operation density is formed to exceed the safe density window, namely an overlapping area exists between the fluctuation range of the drilling operation density and the safe density window, the overlapping area is shown as a dotted frame shadow area in figure 4, and an included angle psi between the boundary point of the overlapping area and the direction of the minimum horizontal ground stress can be obtained1And psi2At this time, from the viewpoint of facilitating hydraulic fracturing, the horizontal well azimuth optimized is the angle min { ψ ] near the direction of minimum horizontal ground stress1,ψ2}。
Although the present invention has been described with reference to the above embodiments, it should be understood that the present invention is not limited to the above embodiments, and those skilled in the art can make various changes and modifications without departing from the scope of the present invention.

Claims (8)

1. A horizontal well azimuth optimization method comprehensively considering drilling and hydraulic fracturing is characterized by comprising the following steps:
s10, collecting TVD of the vertical depth of the stratum of the work area, rock mechanics parameters, pore pressure parameters, ground stress parameters, well body design structure of the well to be drilled in the work area, drilling tool design structure, drilling fluid performance parameters and tripping speed vp；
S20, establishing a calculation model of horizontal well collapse pressure and fracture pressure, and calculating the collapse pressure equivalent density rho of the boreholes at different azimuth levels according to the formation vertical depth TVD, rock mechanical parameters, pore pressure parameters and ground stress parameters of the work areacAnd fracture pressure equivalent density ρf；
S30, designing a well structure, a drilling tool structure, drilling fluid performance parameters and a tripping speed v according to the to-be-drilled well in the work areapCalculating the fluctuation pressure equivalent density rho of the designed horizontal wellsw；
Step S40, drawing collapse pressure equivalent density rhocFracture pressure equivalent density ρfDesign drilling fluid density rhomAnd fluctuating pressure equivalent density ρswDetermining the optimal drilling direction of the horizontal well by using a relation chart;
when collapsed pressure equivalent density ρcFracture pressure equivalent density ρfThe safe density window in between, i.e. the collapse pressure equivalent density ρcFracture pressure equivalent density ρfThe drilling fluid density rho is designed under the condition that the area between the two is widemAnd fluctuating pressure equivalent density ρswThe formed drilling operation density fluctuation range does not exceed a safe density window, and well wall collapse and well wall fracture do not occur during drilling along any direction, and at the moment, the optimized horizontal well orientation is the direction of the minimum horizontal ground stress in view of being beneficial to hydraulic fracturing;
when collapsed pressure equivalent density ρcFracture pressure equivalent density ρfThe safe density window in between, i.e. the collapse pressure equivalent density ρcFracture pressure equivalent density ρfThe drilling fluid density rho is designed under the condition that the area between the two is not widemAnd fluctuating pressure equivalent density ρswThe fluctuation range of the formed drilling operation density exceeds the safe density window, namely an overlapping area exists between the fluctuation range of the drilling operation density and the safe density window, and an included angle psi between the boundary point of the overlapping area and the direction of the minimum horizontal ground stress can be obtained by a shadow area of a virtual frame of the overlapping area1And psi2At this time, from the viewpoint of facilitating hydraulic fracturing, the horizontal well azimuth optimized is the angle min { ψ ] near the direction of minimum horizontal ground stress1,ψ2}。
2. The horizontal well azimuth optimization method comprehensively considering drilling and hydraulic fracturing, according to claim 1, characterized in that the rock mechanical parameters comprise rock Poisson ratio mu and rock cohesion C0Internal angle of friction of rock
Figure FDA0003370379010000021
Tensile strength S of rocktAnd the rock Biot coefficient αp(ii) a The pore pressure parameter comprises formation pore pressure Pp(ii) a The ground stress parameter comprises a vertical ground stress sigmavMaximum horizontal ground stress σHMinimum level of ground stress σh(ii) a The designed well body structure comprises a well depth H and a well bore diameter Dw(ii) a The designed drilling tool structure comprises a drill collar outer diameter ddcLength L of drill collardcOuter diameter d of drill roddpLength L of drill roddp(ii) a The design drilling fluid performance parameters include a design drilling fluid density ρmA fluidity index n and a consistency factor K.
3. The horizontal well azimuth optimization method comprehensively considering drilling and hydraulic fracturing, according to claim 1, characterized in that the calculation model of the collapse pressure and the fracture pressure of the horizontal well in the step S20 is as follows:
Figure FDA0003370379010000022
Figure FDA0003370379010000023
in the formula: sigmar、σθ、σz、τθzRespectively the borehole wall stress under the cylindrical coordinates of the borehole, MPa; sigmaHHorizontal maximum ground stress, MPa; sigmahHorizontal minimum ground stress, MPa; sigmavIs vertical ground stress, MPa; pwThe drilling fluid column pressure is MPa; theta is the well angle, °; ψ is the borehole azimuth, °; mu is Poisson's ratio and has no dimension; sigmai、σj、σkRespectively is a main stress component of the well wall, namely MPa; ppPore pressure, MPa; alpha is alphapBiot coefficient, no dimension.
4. The horizontal well azimuth optimization method comprehensively considering drilling and hydraulic fracturing, according to claim 3, characterized in that the collapse pressure equivalent density p in the step S20cThe calculation formula is as follows:
Figure FDA0003370379010000024
Figure FDA0003370379010000025
wherein the content of the first and second substances,
Figure FDA0003370379010000031
Figure FDA0003370379010000032
Figure FDA0003370379010000033
Figure FDA0003370379010000034
in the formula: c. CwThe cohesive force of the bedding surface is MPa;
Figure FDA0003370379010000035
the angle of the inner friction of the bedding plane is degree; beta is the included angle between the normal of the weak surface and the direction of the maximum main stress; c. C0Bulk cohesion, MPa;
Figure FDA0003370379010000036
is the internal friction angle of the body, degree; beta is a0Shearing the fracture surface angle for the body; beta is a1、β2Angle range of damage for bedding shearing slippage; f. ofcIs a borehole wall collapse damage function; gamma is the included angle between the maximum main stress of the well wall and the axis of the well; lp、mp、npThe direction cosine of the normal of the bedding surface under the geodetic coordinate system; lm、mm、nmThe direction cosine of the maximum main stress of the well wall under a coordinate system; DIP is the angle of inclination of the plane; TR is the direction of the bedding plane, degree; pcCollapse pressure, MPa; rhocIn terms of collapse pressure equivalent density, g/cm3(ii) a TVD is the vertical depth of the stratum, m;
fracture pressure equivalent density ρfThe calculation formula of (2) is as follows:
Figure FDA0003370379010000037
Figure FDA0003370379010000038
in the formula: stRock tensile strength, MPa; f. offAs a function of borehole wall fracture; pfRupture pressure, MPa; rhofFor burst pressure equivalent Density, g/cm3。
5. The horizontal well azimuth optimization method comprehensively considering drilling and hydraulic fracturing as claimed in claim 1, wherein the specific process of the step S30 is as follows:
step S31, according to the diameter ratio d of the drill collar annulusdc/DwAnd the fluidity index n to obtain the fluid adhesion coefficient Kc；
Step S32, calculating the annular flow velocity v of the drill collardcAnd the annular flow velocity v of the drill pipedp：
Step S33, according to the annular flow velocity v of the drill collardcAnd the annular flow velocity v of the drill pipedpCalculating the Reynolds number Re of the drill collar annulusdcAnd annular Reynolds number Re of drill roddp；
Step S34, judging the annular fluid state of the drill collar and the drill pipe, and determining the Reynolds number Re of the annular fluid of the drill collardcAnd annular Reynolds number Re of drill roddpCalculating the friction coefficient f of drill collar annulusdcAnd annular friction coefficient f of drill pipedp：
For a collar annulus:
when Redc<(3470-dc：
fdc＝24/Redc
In the formula: f. ofdcThe friction coefficient of the drill collar annulus is; redcThe annular Reynolds number of the drill collar is a dimensionless number;
when RedcWhen the pressure is not less than 3470-dc：
Figure FDA0003370379010000041
In the formula: f. ofdcThe friction coefficient of the drill collar annulus is; redcThe annular Reynolds number of the drill collar is a dimensionless number;
for a drill pipe annulus:
when Redp<(3470 1370n), the drill pipe annulus is laminar flow, and the drill pipe annulus friction coefficient fdp：
fdp＝24/Redp
In the formula: f. ofdpThe annular friction coefficient of the drill pipe is obtained; redpThe Reynolds number of the drill pipe annulus;
when RedpWhen the pressure is not less than 3470-dp：
Figure FDA0003370379010000042
In the formula: f. ofdpThe annular friction coefficient of the drill pipe is obtained; redpThe Reynolds number of the drill pipe annulus;
step S35, according to the annular flow velocity v of the drill collardcDrill pipe annulus flow velocity vdpAnnular friction coefficient f of drill collardcAnnular friction coefficient f of drill pipedpCalculating the fluctuation pressure equivalent density rhosw。
6. The horizontal well azimuth optimization method comprehensively considering drilling and hydraulic fracturing, characterized in that the annular flow velocity v of the drill collar isdcAnd the annular flow velocity v of the drill pipedpThe calculation formula of (a) is as follows:
Figure FDA0003370379010000043
Figure FDA0003370379010000044
in the formula: v. ofdcAs drill collarsAnnular flow velocity, m/s; ddcIs the outer diameter of the drill collar, cm; v. ofdpThe annular flow velocity of the drill rod is m/s; ddpIs the outer diameter of the drill rod in cm; v. ofpThe tripping speed is m/s; dwIs the wellbore diameter, cm.
7. The horizontal well azimuth optimization method comprehensively considering drilling and hydraulic fracturing, characterized in that the Reynolds number Re of the drill collar annulus isdcAnd annular Reynolds number Re of drill roddpThe calculation formula of (a) is as follows:
Figure FDA0003370379010000051
Figure FDA0003370379010000052
in the formula: redcThe annular Reynolds number of the drill collar is a dimensionless number; redpThe Reynolds number of the drill pipe annulus is zero; rhomIs density, g/cm3(ii) a n is a fluidity index and has no dimension; k is the consistency coefficient and has no dimension.
8. The horizontal well azimuth optimization method comprehensively considering drilling and hydraulic fracturing, as claimed in claim 5, wherein the fluctuating pressure equivalent density p isswThe calculation formula of (a) is as follows:
Figure FDA0003370379010000053
in the formula: l isdcIs the drill collar length, m; redpIs the length of the drill rod, m; rhoswFor fluctuating pressure equivalent density, g/cm3。
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