CN107609214B - Borehole tortuosity control method capable of improving horizontal section composite drilling effect - Google Patents
Borehole tortuosity control method capable of improving horizontal section composite drilling effect Download PDFInfo
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Abstract
The invention discloses a borehole tortuosity control method capable of improving horizontal section composite drilling effect, which comprises a horizontal section borehole tortuosity description method, a horizontal section borehole tortuosity control method, a key parameter calculation method, a horizontal section composite drilling proportion prediction method, a plurality of strategies for improving the horizontal section composite drilling proportion, a horizontal section borehole tortuosity control flow and the like. The key steps of regulation and control are as follows: determining the slip drilling build-up rate, the composite drilling deviation and the azimuth change rate according to the actual drilling data, calculating the allowed maximum deviation of the well deviation angle, the maximum deviation of the azimuth angle, the composite drilling section length and the slip drilling section length according to a formula, and regulating and controlling the well track of the horizontal section according to the calculation result. Under given conditions, the method can calculate the allowable composite drilling section length, the sliding drilling section length, the maximum deviation of the well inclination angle and the azimuth angle, the expected composite drilling proportion and the like. The method is applied to establish a horizontal section borehole tortuosity regulation scheme, and is beneficial to improving the composite drilling proportion and the drilling speed.
Description
Technical Field
The invention relates to the field of petroleum drilling engineering, in particular to the field of research and application of sliding guide drilling technology, and specifically relates to a borehole tortuosity regulation and control method capable of improving horizontal section composite drilling effect.
Background
The horizontal section of the planned wellbore trajectory (referred to as the wellbore axis) is typically horizontal or nearly horizontal and straight. Currently, sliding guide or rotary guide drilling technology is mostly adopted to drill a horizontal section. When the sliding guide drilling technology is adopted, a sliding drilling mode (large borehole curvature) and a rotary drilling mode (small borehole curvature) need to be alternately adopted. When using rotary steerable drilling techniques, it is also necessary to alternate between high build rate commands (large wellbore curvature) and low build rate commands (small wellbore curvature). No matter what kind of guide drilling technology is adopted, the track of the horizontal section real drilling hole is not a horizontal or approximately horizontal straight line any more, but a complex curve with the fluctuation change characteristic and taking the axis of the designed hole as the center. In the field of petroleum drilling, the bending characteristic and the twisting characteristic of a real drilling track are usually described by using borehole tortuosity, but the traditional borehole tortuosity description method is not comprehensive enough, so that the bending characteristic and the twisting characteristic of the horizontal section real drilling track, the volatility and the periodic variation characteristic of the horizontal section real drilling track are difficult to accurately describe, and the traditional borehole tortuosity description method is difficult to apply to guide borehole track control.
When the sliding guide drilling technology is adopted to drill the horizontal section, a sliding drilling mode and a rotary drilling mode need to be alternately adopted. Because the tool surface needs to be swung during sliding drilling, the pressure supporting phenomenon also commonly exists, so that the sliding drilling speed is generally lower than the composite drilling speed. In order to reduce the difficulty of horizontal section drilling and improve the drilling speed, the composite drilling proportion is urgently needed to be improved by reasonably regulating and controlling the tortuosity of a horizontal section well hole in a drilling site, and the switching times of the drilling mode is reduced as far as possible.
Disclosure of Invention
Based on the technical problems, the invention provides a borehole tortuosity control method capable of improving the horizontal section composite drilling effect.
The technical solution adopted by the invention is as follows:
a wellbore tortuosity control method capable of improving horizontal section composite drilling effect comprises the following steps:
(1) determining horizontal wellbore tortuosity description parameters
the design well inclination angle corresponding to the horizontal section is set as alphaTAzimuthal angle of phiTAdopting a rectangular columnar target, the target half width is a, the target half height is b, and the borehole tortuosity description parameter includes composite drilling section length delta LrWell deviation rate of change KiAzimuth change rate Ka(ii) a Sliding drilling section length Δ LsSlip drilling build-up rate Ksmaximum deviation of inclination angle delta alphaTMaximum deviation of azimuth angle delta phiT；
(2) establishing a maximum deviation Delta alpha of the well inclination angleTMaximum deviation of azimuth angle delta phiTFormula for calculation
In a half of the adjusting period, the longitudinal and transverse fluctuation amplitudes of the actual drilling track satisfy the following relations:
cosγ＝cosΔαTcosΔφT(1.c)
the maximum deviation Delta α of the well inclination angle can be obtained by the formulaTMaximum deviation from azimuth angle delta phiT；
deviation of maximum angle of inclination of well delta alphaTMaximum deviation from azimuth angle delta phiTConversion into composite drilling section length DeltaL within half of the adjustment periodrAnd sliding drilling section length Δ LsThe form is as follows:
cos(ΔLs·Ks)＝cos(ΔLr·Ki)cos(ΔLr·Ka) (2.c)
the slip drilling build-up rate K can be obtained by the formulasComposite drilling well deviation rate KiAnd rate of change of azimuth KaLength of composite drilling section DeltaL in corresponding half regulation periodrAnd sliding drilling section length Δ Ls；
(3) Carry out the adjustment and control of the tortuosity of the horizontal section of the well
firstly, determining a sliding drilling build-up rate, a well inclination change rate and an azimuth change rate of a composite drilling section according to actual drilling data;
secondly, calculating the allowed maximum deviation of the well inclination angle and the maximum deviation of the azimuth angle according to the formulas (1.a), (1.b) and (1. c);
③, calculating the length of the composite drilling section and the length of the sliding drilling section according to the formulas (2.a), (2.b) and (2. c);
and fourthly, regulating and controlling the horizontal section well track according to the calculation results of the maximum deviation of the inclination angle, the maximum deviation of the azimuth angle, the composite drilling section length and the sliding drilling section length.
Preferably, the method further comprises the following steps: using R as the proportion of the composite drilling well sectionrDenotes, set up RrBuild-up rate K with sliding drillingsComposite drilling well deviation rate KiAnd rate of change of azimuth KaThe relation between
In the above steps, the means for improving the composite drilling effect of the horizontal section comprises optimizing the design of the drilling tool assembly and optimizing the drilling parameters, properly improving the slip drilling build-up rate, and reducing the inclination change rate and the azimuth change rate of the composite drilling well.
The beneficial technical effects of the invention are as follows:
(1) the method for describing the tortuosity of the horizontal section of the well is given for the first time; the corresponding key parameters comprise the change rate and the azimuth change rate of the composite drilling well deviation, the slip drilling build-up rate, the length of a composite drilling section, the length of a slip drilling section, the maximum deviation of the well deviation angle and the azimuth angle, the longitudinal deviation (vertical depth difference) of the well track, the transverse deviation and the like.
(2) Firstly, a horizontal section borehole tortuosity regulation method and a key parameter calculation method are provided; when the fluctuation amplitude (longitudinal deviation and transverse deviation) of the well track is limited, the method can calculate the allowable composite drilling section length, the sliding drilling section length, the maximum deviation of the well inclination angle and the azimuth angle and the like, and can improve the composite drilling effect and the drilling speed of the horizontal section.
(3) A horizontal section composite drilling proportion prediction method is provided for the first time, and a plurality of strategies capable of improving the horizontal section composite drilling proportion are provided based on the method. For example, the design of the drilling tool assembly and the optimized drilling parameters are optimized, the slip drilling build rate is properly improved, and the composite drilling well slope change rate and the azimuth change rate are reduced.
Drawings
FIG. 1 is a schematic illustration depicting the tortuosity of a horizontal section of a wellbore;
FIG. 2 is a flow chart of horizontal wellbore tortuosity control.
Detailed Description
The invention provides a borehole tortuosity description method and a key parameter regulation and control method suitable for horizontal section characteristics aiming at the technical problems that a horizontal section alternately adopts a composite drilling and sliding drilling mode and the drilling speed needs to be improved, wherein the borehole tortuosity description method and the key parameter regulation and control method comprise the composite drilling section length, the sliding drilling section length, the maximum deviation of a well inclination angle and an azimuth angle and the like allowed by horizontal section track control, and a complete and practical borehole tortuosity regulation and control method capable of improving the composite drilling effect of the horizontal section is formed.
(1) Horizontal section borehole tortuosity description method
"wellbore tortuosity" shall include the degree of deviation of the actual wellbore trajectory from the designed wellbore trajectory, as well as the degree of curvature or distortion of the designed wellbore trajectory and the actual wellbore trajectory, among other critical parameters. The description of the tortuosity of the horizontal section of the well bore comprises key parameters such as well bore curvature, well deviation change rate, azimuth change rate, well deviation angle, azimuth deviation, length of a sliding drilling section and a composite drilling section, longitudinal deviation (vertical depth difference) of a real drilling well bore track, transverse deviation and the like.
when the horizontal section is drilled by combining the composite drilling mode and the sliding drilling mode, the actual drilling track is shown in figure 1, wherein the composite drilling starting point is 0 point and 4 points, the middle point is 1 point and 5 points, the tail point is 2 points and 6 points, the sliding drilling starting point is 2 points and 6 points, the middle point is 3 points, and the tail point is 4 points, the corresponding design inclination angle of the horizontal section is αTAzimuthal angle of phiTA rectangular columnar target is adopted, the target half width is a, and the target half height is b. Wellbore tortuosity key parameters includeCombined drilling section length delta LrWell deviation rate of change KiAzimuth change rate Ka(ii) a Sliding drilling section length Δ LsAnd build-up rate Ksmaximum deviation delta α of inclination angle and azimuth angleT、ΔφTAnd the like. The basic parameters corresponding to each node on the actual wellbore trajectory are shown in table 1.
TABLE 1
According to the basic parameters of each node set in the table 1, the composite drilling well section adopts a cylindrical spiral method (curvature radius method) to calculate the well track parameters, the sliding drilling well section adopts a slope arc method (minimum curvature method) to calculate the well track parameters, and the vertical depth increment delta H corresponding to each well section can be calculatediAnd north-south coordinate increment Δ Ni(i＝1～6)。
cosγ3＝cos(αT+ΔαT)cosαT+sin(αT+ΔαT)sinαTcosΔφT(1.i)
cosγ4＝cosαTcos(αT-ΔαT)+sinαTsin(αT-ΔαT)cosΔφT(1.j)
considering that the target plane is vertical to the axis of the target frame, no matter what the design inclination angle and azimuth angle of the target section are, the inclination angle alpha can be designed according to the coordinate rotation transformationTAngle phi of 90 DEGTThis special case was analyzed at 90 °.
cosγ3＝cosγ4＝cosΔαTcosΔφT(2.e)
(2) Horizontal section borehole tortuosity control method
In order to reduce the number of times of alternation of sliding drilling and composite drilling, it is usually agreed that the drilling mode is switched when the fluctuation amplitude of the sliding drilling and composite drilling well sections in a design target frame reaches a given value. In a half of the adjusting period, the longitudinal fluctuation amplitude (delta H) and the transverse fluctuation amplitude (delta N) of the actual drilling track satisfy the following relations:
ΔH＝ΔH1+ΔH4＝-(ΔH2+ΔH3)≤2b (3.a)
ΔN＝ΔN1+ΔN4＝-(ΔN2+ΔN3)≤2a (3.b)
substituting formula (2.a) -formula (2.e) into the above formula, the following form can be obtained:
cosγ＝cosΔαTcosΔφT(4.c)
it can be seen that given target half-width a and target half-height b, the slip drilling build-up rate Ksthen, the deviation delta α of the deviation angle allowed by the actual drilling trackTAnd the azimuth angle deviation delta phiTDependent on the rate of change of the composite drilling well inclination KiAzimuth change rate Ka。
determining deviation of well inclination angle delta alphaTAnd the azimuth angle deviation delta phiTThe composite drilling step length Δ L can then be determined for half the adjustment periodrAnd sliding drilling section length Δ Lsthe deviation of the angle of inclination Δ α can also be calculatedTAnd the azimuth angle deviation delta phiTConversion into composite drilling section length DeltaL within half of the adjustment periodrAnd sliding drilling section length Δ LsThe form is as follows:
cos(ΔLs·Ks)＝cos(ΔLr·Ki)cos(ΔLr·Ka) (5.c)
the slip drilling build-up rate K can be obtained by the formulasComposite drilling well deviation rate KiAnd rate of change of azimuth KaMaximum length of composite drilling segment DeltaL in corresponding half of adjusting periodrMaximum length of sliding drilling section DeltaLs。
In actual conditions, in order to ensure that the borehole trajectory is always positioned in the target frame, the borehole trajectory fluctuation amplitude should comprehensively consider the borehole trajectory regulation and control capability of the guide drilling tool and the parameter limitation of the target frame, and a certain safety margin is reserved. If the safety margin is large, the fluctuation range of the well track is small, the drilling mode needs to be frequently adjusted, and the drilling speed is influenced; if the safety margin is small, the fluctuation range of the well track is large, so that the friction torque may be increased, and the miss risk may occur.
(3) Horizontal section composite drilling proportion prediction method
The maximum length Delta L of the composite drilling section in a half regulation period can be derived from the formula (5.c)rMaximum length of sliding drilling section DeltaLsBuild-up rate K with sliding drillingsComposite drilling well deviation rate KiAnd rate of change of azimuth KaThere is the following relationship therebetween.
ΔLs·Ks＞ΔLr·Ki(6.a)
ΔLs·Ks＞ΔLr·Ka(6.b)
Proportion of composite drilling well section (by R)rExpression) and slip drilling build rate KsComposite drilling well deviation rate KiAnd rate of change of azimuth KaThere is the following relationship therebetween.
According to the formula (7), the proportion of the composite drilling well section is mainly determined by the slip drilling build-up rate KsComposite drilling well deviation rate KiAnd rate of change of azimuth KaIndependent of the target region parameters. Given slip drilling build rate KsThen, the composite drilling proportion is mainly determined by the composite drilling well deviation change rate KiAnd rate of change of azimuth Ka。
In order to improve the length and proportion of the composite drilling section of the steady-slope section and the horizontal section, the sliding drilling build-up rate must be properly improved, the drilling tool combination design and the optimized drilling parameters are optimized, the composite drilling well inclination change rate and the azimuth change rate are reduced, and the composite drilling stability and stability are improved. Among them, reducing the rate of change of the composite drilling well deviation is particularly important.
(4) Horizontal section borehole tortuosity regulation and control process
The horizontal section borehole tortuosity control flow is shown in figure 2. The key steps are as follows:
①, determining the slip drilling build-up rate, the composite drilling inclination and the azimuth change rate according to actual drilling data;
calculating the allowed maximum deviation of the well inclination angle and the maximum deviation of the azimuth angle according to the formulas (4.a) - (4. c);
③, calculating the length of the composite drilling section and the length of the sliding drilling section according to the formulas (5.a) - (5. c);
and fourthly, regulating and controlling the horizontal section well track according to the calculation result of the key well tortuosity parameters.
(5) Simulation calculation analysis result
And respectively calculating the maximum deviation of the inclination angle of the target section, the length of the composite drilling section, the length of the sliding drilling section and other key parameters allowed by the target section in an adjusting period under the conditions of limiting the build-up rate of the sliding drilling, the composite drilling inclination and the azimuth change rate.
the simulation calculation analysis shows that the length of the composite drilling section and the composite drilling proportion are both reduced along with the increase of the inclination change rate of the composite drilling well when the build-up rate of the sliding drilling is limited, the deviation of the inclination angle and the length of the sliding drilling section are increased along with the increase of the inclination change rate of the composite drilling well, the length and the proportion of the composite drilling section are smaller when the inclination change rate and the direction change rate of the composite drilling well are larger, the length of the composite drilling section, the deviation of the inclination angle and the composite drilling proportion are all increased along with the increase of the build-up rate of the sliding drilling when the change rate and the direction change rate of the composite drilling well are limited, and the length of the sliding drilling section is reduced along with the increase of the build-.
The invention is further illustrated by the following specific application examples.
The key parameter calculation and regulation process of the horizontal section borehole tortuosity is shown in figure 2. The key steps are as follows: firstly, determining the slip drilling build-up rate, the composite drilling well deviation and the azimuth change rate according to actual drilling data; calculating the allowed maximum deviation of the inclination angle and the maximum deviation of the azimuth angle according to the formulas (4.a) - (4.c), and calculating the length of the composite drilling section and the length of the sliding drilling section according to the formulas (5.a) - (5. c); and finally, regulating and controlling the horizontal section borehole trajectory according to the borehole tortuosity key parameter calculation result.
Taking the horizontal well drilling of a certain oil field in China as an example, the slope rate of sliding drilling is limited to 4.5-9.0 degrees/30 m, the inclination change rate of a composite drilling well is 0.9 degrees/30 m, the azimuth change rate is 0.3 degrees/30 m, the target area is 1.0m multiplied by 6.0m, the fluctuation range of a well bore is limited within the range of 0.3 times of the height and width of a target frame, and the calculation results of key parameters for regulating and controlling the tortuosity of the well bore in the horizontal section are shown in a table 2.
TABLE 2
Claims (3)
1.A wellbore tortuosity control method capable of improving horizontal section composite drilling effect is characterized by comprising the following steps:
(1) determining horizontal wellbore tortuosity description parameters
the design well inclination angle corresponding to the horizontal section is set as alphaTAzimuthal angle of phiTAdopting a rectangular columnar target, the target half width is a, the target half height is b, and the borehole tortuosity description parameter includes composite drilling section length delta LrWell deviation rate of change KiAzimuth change rate Ka(ii) a Sliding drilling section length Δ LsSlip drilling build-up rate Ksmaximum deviation of inclination angle delta alphaTMaximum deviation of azimuth angle delta phiT；
(2) establishing a maximum deviation Delta alpha of the well inclination angleTMaximum deviation of azimuth angle delta phiTFormula for calculation
In a half of the adjusting period, the longitudinal and transverse fluctuation amplitudes of the actual drilling track satisfy the following relations:
cosγ＝cosΔαTcosΔφT(1.c)
the maximum deviation Delta α of the well inclination angle can be obtained by the formulaTMaximum deviation from azimuth angle delta phiT；
deviation of maximum angle of inclination of well delta alphaTMaximum deviation from azimuth angle delta phiTConversion into composite drilling section length DeltaL within half of the adjustment periodrAnd sliding drilling section length Δ LsThe form is as follows:
cos(ΔLs·Ks)＝cos(ΔLr·Ki)cos(ΔLr·Ka) (2.c)
the slip drilling build-up rate K can be obtained by the formulasComposite drilling well deviation rate KiAnd rate of change of azimuth KaLength of composite drilling section DeltaL in corresponding half regulation periodrAnd sliding drilling section length Δ Ls；
(3) Carry out the adjustment and control of the tortuosity of the horizontal section of the well
firstly, determining a sliding drilling build-up rate, a well inclination change rate and an azimuth change rate of a composite drilling section according to actual drilling data;
secondly, calculating the allowed maximum deviation of the well inclination angle and the maximum deviation of the azimuth angle according to the formulas (1.a), (1.b) and (1. c);
③, calculating the length of the composite drilling section and the length of the sliding drilling section according to the formulas (2.a), (2.b) and (2. c);
and fourthly, regulating and controlling the horizontal section well track according to the calculation results of the maximum deviation of the inclination angle, the maximum deviation of the azimuth angle, the composite drilling section length and the sliding drilling section length.
2. The method for regulating and controlling the tortuosity of the borehole, which can improve the composite drilling effect of the horizontal section, according to claim 1, is characterized by further comprising the following steps: using R as the proportion of the composite drilling well sectionrDenotes, set up RrBuild-up rate K with sliding drillingsComposite drilling well deviation rate KiAnd rate of change of azimuth KaThe relation between
3. The method for regulating and controlling the tortuosity of the borehole capable of improving the composite drilling effect of the horizontal section according to claim 1, wherein: the means capable of improving the horizontal section composite drilling effect comprises optimizing the design of a drilling tool combination and optimizing drilling parameters, improving the slip drilling build-up rate and reducing the inclination change rate and the azimuth change rate of the composite drilling well.
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| CN104481400A (en) * | 2014-12-10 | 2015-04-01 | 中国石油化工股份有限公司 | Three-dimensional (3D) horizontal well borehole track controlling method |
| CN104615803A (en) * | 2014-12-10 | 2015-05-13 | 中国石油化工股份有限公司 | Three-dimensional horizontal well borehole trajectory design method and system |
| CN106437513A (en) * | 2016-09-26 | 2017-02-22 | 中国石油大学(华东) | Complex structural well friction resistance reduction and power drill tool face adjusting method |
| CN106567675A (en) * | 2015-10-08 | 2017-04-19 | 中国石油化工股份有限公司 | Borehole track control method of rotary navigation drilling |
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| CN104481400A (en) * | 2014-12-10 | 2015-04-01 | 中国石油化工股份有限公司 | Three-dimensional (3D) horizontal well borehole track controlling method |
| CN104615803A (en) * | 2014-12-10 | 2015-05-13 | 中国石油化工股份有限公司 | Three-dimensional horizontal well borehole trajectory design method and system |
| CN106567675A (en) * | 2015-10-08 | 2017-04-19 | 中国石油化工股份有限公司 | Borehole track control method of rotary navigation drilling |
| CN106437513A (en) * | 2016-09-26 | 2017-02-22 | 中国石油大学(华东) | Complex structural well friction resistance reduction and power drill tool face adjusting method |
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Effective date of registration: 20210205 Address after: 257061 No. two, 271 North Road, Shandong, Dongying Patentee after: China University of Petroleum (East China) Patentee after: CHINA NATIONAL PETROLEUM Corp. Patentee after: CNPC Chuanqing Drilling Engineering Co.,Ltd. Address before: 266580 No. 66 Changjiang West Road, Qingdao economic and Technological Development Zone, Shandong Patentee before: China University of Petroleum (East China) |