CN113719236B

CN113719236B - Borehole trajectory correction method, device, equipment and storage medium for horizontal well

Info

Publication number: CN113719236B
Application number: CN202110390087.8A
Authority: CN
Inventors: 高健; 王国勇; 魏斌; 梁治国; 熊小林; 白森; 段志勇; 刘吉; 沈柏坪; 曾番惠; 田士伟; 郑丽君; 敖苍穹
Original assignee: China National Petroleum Corp; CNPC Great Wall Drilling Co
Current assignee: China National Petroleum Corp; CNPC Great Wall Drilling Co
Priority date: 2021-04-12
Filing date: 2021-04-12
Publication date: 2024-03-26
Anticipated expiration: 2041-04-12
Also published as: CN113719236A

Abstract

The application provides a method, a device, equipment and a storage medium for correcting a borehole trajectory of a horizontal well, and belongs to the technical field of petroleum exploration and development. The method comprises the following steps: based on the chemical element parameters and the lithology parameters, respectively determining a lithology graph and a lithology graph of the reservoir to be researched; determining a first contrast map based on the lithogram and the pen-stone map; determining a second contrast map based on the penmanship map and the first log; determining a target reservoir of the reservoir to be studied based on the chemical element parameters of each stratum of the reservoir to be studied; determining a target lithology type and a target penstone type of a target reservoir based on the first contrast map; determining the lithology type and the pen-stone type of the drilling stratum based on the second logging curve, the second contrast diagram, the while-drilling curve and the while-drilling interpretation curve; based on the differences between the lithofacies type and the lithocarpal stone type of the drilling stratum and the target lithofacies type and the target lithocarpal stone type, the well track of the target well is adjusted, so that the well track is aligned to the target reservoir, and the development efficiency of the reservoir to be researched is improved.

Description

Borehole trajectory correction method, device, equipment and storage medium for horizontal well

Technical Field

The present disclosure relates to the field of petroleum exploration and development technologies, and in particular, to a method, an apparatus, a device, and a storage medium for correcting a borehole trajectory of a horizontal well.

Background

Shale gas is unconventional natural gas stored in shale reservoirs; when the shale gas is developed, the horizontal well drilling work of the shale reservoir is guided mainly through a geological comprehensive evaluation technology, so that the shale gas can be drilled to a target reservoir rich in the shale gas in the shale reservoir according to a preset well track during drilling. Because the borehole trajectory of the horizontal well is subject to errors from the target reservoir, it is necessary to correct the borehole trajectory of the horizontal well.

In the related art, after drilling is completed, a borehole track of the horizontal well is measured by means of geological analysis assay, geophysical logging and the like, and then the borehole track of the horizontal well is adjusted based on the error between the borehole track of the horizontal well and the existence of a target reservoir.

Because means such as geological analysis test and geophysical well logging of evaluating shale reservoir are basically carried out after well drilling is completed, while-drilling evaluation in the horizontal well drilling process cannot be realized, namely the well track of the horizontal well cannot be adjusted in the well drilling process, so that the drilling meeting rate of the well track and a target reservoir during well drilling cannot be ensured, the well track in the well drilling process needs to be adjusted greatly in the later period, further construction of well drilling operation is affected, and development efficiency of shale gas is low.

Disclosure of Invention

The embodiment of the application provides a method and a device for correcting a borehole trajectory of a horizontal well, which can improve the development efficiency of shale gas. The technical scheme is as follows:

in one aspect, a method for correcting a borehole trajectory of a horizontal well is provided, the method comprising:

acquiring chemical element parameters, a penstock parameter and a first logging curve of a reservoir to be researched;

determining a lithogram of the reservoir to be studied based on the chemical element parameters, the lithogram comprising a lithogram type and formation parameters for each location depth of the reservoir to be studied;

determining a lithograph of the reservoir to be studied based on the litho parameters, wherein the litho graph comprises a litho type and a litho layering parameter of each position depth of the reservoir to be studied;

determining a first contrast map based on the lithology map and the lithology map, wherein the first contrast map comprises a lithology type, a stratum parameter, a lithology type and a lithology layering parameter of each position depth;

determining a second comparison graph based on the pencil stone graph and the first well logging curve, wherein the second comparison graph comprises the pencil stone type, the pencil stone layering parameters and the first well logging curve of each position depth;

Determining a target reservoir of the reservoir under study based on chemical element parameters of each formation of the reservoir under study;

determining a target lithology type and a target pen stone type of the target reservoir based on the first contrast map;

acquiring an explanation while drilling curve of the reservoir to be researched, wherein the explanation while drilling curve comprises a lithofacies type, a stratum parameter, a first element logging curve and a first natural gamma curve of each position depth;

acquiring a second logging curve and a while-drilling curve of a drilling stratum where a well track of the target well of the reservoir to be researched is located when the target well is drilled, wherein the while-drilling curve comprises a second element logging curve and a second natural gamma curve;

determining a lithology type and a lithology type of the drilling formation based on the second log, the second contrast map, the while-drilling curve, and the while-drilling interpretation curve;

and adjusting a borehole trajectory of the target well based on a difference between the lithofacies type and the pen stone type of the drilling formation and the target lithofacies type and the target pen stone type, such that the borehole trajectory is aligned with the target reservoir.

In one possible implementation, the determining the lithology type and the pen stone type of the drilling formation based on the second log, the second contrast map, the while-drilling curve, and the while-drilling interpretation curve includes:

For a drilling stratum in the second log, acquiring a pen-stone type of the drilling stratum from the second contrast graph;

and for the drilling stratum in the while-drilling curve, acquiring the lithology type of the drilling stratum from the while-drilling interpretation curve.

In one possible implementation, the adjusting the wellbore trajectory of the target well based on a lithofacies type and a lithocarpal stone type of the drilling formation and a difference of the target lithofacies type and the target lithocarpal stone type, the aligning the wellbore trajectory with the target reservoir comprises:

comparing the type of the written stone of the drilling stratum with the type of the target written stone, and adjusting the well track to enable the well track and the target reservoir to be in the same written stone layering;

and comparing the lithofacies type of the drilling stratum with the target lithofacies type, and adjusting the well track which is in the same lithostratification with the target reservoir so that the well track and the target reservoir are in the same lithostratification and the same stratum.

In one possible implementation, the method further includes:

determining a plurality of lithofacies segment parameters of the target well in a horizontal segment based on the chemical element parameters of the target reservoir, wherein the horizontal segment is a target reservoir segment to be fractured in the target reservoir aligned with the borehole track after the borehole track is adjusted;

Dividing a plurality of fracturing segments with different lithofacies segment parameters based on the lithofacies segment parameters of the horizontal segment, wherein the fracturing segments are positioned in the horizontal segment;

for each fracturing segment, determining pressure parameters of the fracturing segment based on lithofacies segment parameters of the fracturing segment, wherein the pressure parameters are used for guiding the fracturing segment to fracture.

In one possible implementation, the lithofacies segment parameters include lithofacies type and brittleness index, and the chemical element parameters include chemical element parameters of a plurality of lithofacies segments;

the determining a plurality of lithofacies segment parameters of the target well in a horizontal segment based on the chemical element parameters of the target reservoir comprises:

for each lithofacies segment, determining a mineral content and a brittleness index that match chemical element parameters of the lithofacies segment based on the chemical element parameters;

based on the mineral content, a lithofacies type is determined that matches the mineral content.

In one possible implementation, the determining the target reservoir of the reservoir under study based on the chemical element parameters of each formation of the reservoir under study includes:

for each formation, determining a brittleness index and an organic matter abundance index that match chemical element parameters of the formation based on the chemical element parameters;

Determining a reservoir type of the formation based on the brittleness index and the organic abundance index;

a target reservoir for the reservoir under study is determined from a plurality of formations based on reservoir types of the plurality of formations.

In one possible implementation, the chemical element parameters include chemical element parameters of each formation of the reservoir under study, and the determining a lithogram of the reservoir under study based on the chemical element parameters includes:

for each formation, determining a mineral content matching a chemical element parameter of the formation based on the chemical element parameter;

determining a lithofacies type matching the mineral content based on the mineral content;

and determining a lithogram of the reservoir to be researched based on the lithology type of each stratum.

In another aspect, a wellbore trajectory correction device for a horizontal well is provided, the device comprising:

the first acquisition module is used for acquiring chemical element parameters, a penstock parameter and a first logging curve of the reservoir to be researched;

a first determining module for determining a lithogram of the reservoir to be studied based on the chemical element parameters, the lithogram including a lithogram type and a formation parameter for each location depth of the reservoir to be studied;

A second determining module, configured to determine a pen-stone map of the reservoir to be studied based on the pen-stone parameters, where the pen-stone map includes a pen-stone type and a pen-stone layering parameter for each location depth of the reservoir to be studied;

a third determining module, configured to determine a first contrast map based on the lithology map and the penstone map, where the first contrast map includes a lithology type, a formation parameter, a penstone type, and a penstone layering parameter for each location depth;

a fourth determining module, configured to determine a second comparison graph based on the penstock graph and the first log, where the second comparison graph includes a penstock type, a penstock layering parameter, and the first log for each location depth;

a fifth determination module for determining a target reservoir of the reservoir under study based on chemical element parameters of each formation of the reservoir under study;

a sixth determining module, configured to determine a target lithology type and a target pen stone type of the target reservoir based on the first contrast map;

the second acquisition module is used for acquiring an interpretation curve while drilling of the reservoir to be researched, wherein the interpretation curve while drilling comprises a lithofacies type, stratum parameters, a first element logging curve and a first natural gamma curve of each position depth;

The third acquisition module is used for acquiring a second logging curve and a while-drilling curve of a drilling stratum where a well track of the target well of the reservoir to be researched is located when the target well is drilled, wherein the while-drilling curve comprises a second element logging curve and a second natural gamma curve;

a seventh determination module for determining a lithology type and a pen stone type of the drilling formation based on the second log, the second contrast map, the while-drilling curve, and the while-drilling interpretation curve;

and the adjustment module is used for adjusting the well track of the target well based on the differences between the lithofacies type and the lithocarpus type of the drilling stratum and the target lithofacies type and the target lithocarpus type so as to align the well track with the target reservoir.

In one possible implementation manner, the seventh determining module includes:

the first acquisition unit is used for acquiring the pen stone type of the drilling stratum from the second contrast diagram for the drilling stratum in the second logging curve;

and the second acquisition unit is used for acquiring the lithology type of the drilling stratum from the interpretation while drilling curve for the drilling stratum in the while drilling curve.

In one possible implementation, the adjusting module includes:

The first adjusting unit is used for comparing the type of the penrock of the drilling stratum with the type of the target penrock, and adjusting the well track to enable the well track and the target reservoir to be in the same penrock layering;

and the second adjusting unit is used for comparing the lithofacies type of the drilling stratum with the target lithofacies type, and adjusting the well track which is in the same lithostratification with the target reservoir so that the well track and the target reservoir are in the same lithostratification and the same stratum.

In one possible implementation, the apparatus further includes:

an eighth determining module, configured to determine, based on chemical element parameters of the target reservoir, a plurality of lithofacies segment parameters of the target well in a horizontal segment, where the horizontal segment is a target reservoir segment to be fractured in a target reservoir aligned with the wellbore trajectory after the wellbore trajectory is adjusted;

the dividing module is used for dividing a plurality of fracturing segments with different lithofacies segment parameters based on the lithofacies segment parameters of the horizontal segment, and the fracturing segments are all positioned in the horizontal segment;

and a ninth determining module, configured to determine, for each fracturing segment, a pressure parameter of the fracturing segment based on a lithofacies segment parameter of the fracturing segment, where the pressure parameter is used to guide the fracturing segment to perform fracturing.

In one possible implementation, the lithofacies segment parameters include lithofacies type and brittleness index, and the chemical element parameters include chemical element parameters of a plurality of lithofacies segments; the eighth determination module includes:

a first determining unit for determining, for each lithofacies segment, a mineral content and a brittleness index matching with a chemical element parameter of the lithofacies segment based on the chemical element parameter;

and a second determination unit for determining a lithology type matching the mineral content based on the mineral content.

In one possible implementation manner, the fifth determining module includes:

a third determining unit, configured to determine, for each formation, a brittleness index and an organic matter abundance index that match chemical element parameters of the formation, based on the chemical element parameters;

a fourth determining unit configured to determine a reservoir type of the formation based on the brittleness index and the organic matter abundance index;

a fifth determination unit for determining a target reservoir of the reservoir under investigation from a plurality of formations based on reservoir types of the plurality of formations.

In one possible implementation, the chemical element parameters include chemical element parameters of each formation of the reservoir under study, and the first determining module includes:

A sixth determining unit for determining, for each formation, a mineral content matching a chemical element parameter of the formation based on the chemical element parameter;

a seventh determining unit for determining a lithology type matching the mineral content based on the mineral content;

and an eighth determining unit, configured to determine a lithogram of the reservoir to be studied based on the lithology type of each stratum.

In another aspect, a computer device is provided that includes one or more processors and one or more memories having stored therein at least one instruction loaded and executed by the one or more processors to perform operations performed by a method of wellbore trajectory correction for a horizontal well as described in any of the above implementations.

In another aspect, a computer readable storage medium having stored therein at least one instruction loaded and executed by a processor to perform the operations performed by the method for wellbore trajectory correction for a horizontal well of any of the above implementations is provided.

In another aspect, a computer program product or a computer program is provided, the computer program product or the computer program comprising computer program code, the computer program code being stored in a computer readable storage medium. The processor of the computer device reads the computer program code from the computer readable storage medium, and the processor executes the computer program code such that the computer device performs the operations performed by the above-described method of determining a water intrusion layer.

The beneficial effects of the technical scheme provided by the embodiment of the application at least comprise:

the embodiment of the application provides a method for correcting a borehole track of a horizontal well, and because a second comparison graph determined by the method comprises a pencil stone type, a pencil stone layering parameter and a first logging curve of each position depth, the pencil stone type of a drilling stratum can be determined based on the second logging curve and the second comparison graph of the drilling stratum where the borehole track is located when a target well is drilled. Because the while-drilling interpretation curve comprises the lithofacies type, the stratum parameters, the first element logging curve and the first natural gamma curve of each position depth, the lithofacies type of the drilling stratum can be determined based on the second element logging curve and the second natural gamma curve of the drilling stratum, and further, the well track during the drilling of the target well can be timely adjusted based on the differences between the lithofacies type and the pen-stone type of the drilling stratum and the target lithofacies type and the target pen-stone type of the target reservoir, so that the well track is aligned to the target reservoir, the drilling rate of the well track and the target reservoir in the drilling process can be ensured, and the development efficiency of the reservoir to be researched is improved.

Drawings

In order to more clearly illustrate the technical solutions of the embodiments of the present application, the drawings that are needed in the description of the embodiments will be briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present application, and that other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art.

FIG. 1 is a flow chart of a method for correcting a borehole trajectory of a horizontal well according to an embodiment of the present application;

FIG. 2 is a lithofacies partition standard chart provided in an embodiment of the present application;

FIG. 3 is another petrographic division standard chart provided by an embodiment of the present application;

FIG. 4 is a first comparison chart provided by an embodiment of the present application;

FIG. 5 is a second comparative diagram provided by an embodiment of the present application;

FIG. 6 is an illustrative graph while drilling provided in an embodiment of the present application;

FIG. 7 is a mineral and element complex diagram provided in an embodiment of the present application;

FIG. 8 is a diagram of mineral composition provided in an embodiment of the present application;

FIG. 9 is a diagram of an elemental distribution provided by an embodiment of the present application;

FIG. 10 is a schematic illustration of a wellbore trajectory provided by an embodiment of the present application;

FIG. 11 is a schematic illustration of another wellbore trajectory provided by an embodiment of the present application;

FIG. 12 is a schematic illustration of staged fracturing provided in an embodiment of the present application;

FIG. 13 is a graph of pressure parameters provided by an embodiment of the present application;

FIG. 14 is a staged fracturing schematic provided in an embodiment of the present application;

FIG. 15 is a schematic view of a borehole trajectory correction device for a horizontal well according to an embodiment of the present application;

fig. 16 is a block diagram of a computer device provided in an embodiment of the present application.

Detailed Description

For the purpose of making the objects, technical solutions and advantages of the present application more apparent, the embodiments of the present application will be described in further detail below with reference to the accompanying drawings.

The terms "first," "second," "third," and "fourth" and the like in the description and in the claims of this application and in the drawings, are used for distinguishing between different objects and not for describing a particular sequential order. Furthermore, the terms "comprising," "including," and "having," and any variations thereof, are intended to cover a non-exclusive inclusion. For example, a process, method, system, article, or apparatus that comprises a list of steps or elements is not limited to only those listed steps or elements but may include other steps or elements not listed or inherent to such process, method, article, or apparatus.

The embodiment of the application provides a method for correcting a borehole track of a horizontal well, referring to fig. 1, the method comprises the following steps:

step 101: the computer device obtains chemical element parameters, a penholder parameter and a first log of the reservoir to be studied.

The reservoir to be researched is a shale gas reservoir; for example, the reservoir to be studied is a longmaxi group shale gas reservoir in the whispering area.

The rock parameters are fossil parameters of a rock animal obtained through core experiments of key wells of the reservoir to be researched, core samples in the core experiments are obtained through core taking operation of the key wells, the key wells are gas wells for completing drilling operation on the reservoir to be researched, and the rock parameters, logging parameters and other well data are complete. The pen parameters include pen parameters of each position depth, taking the shale gas reservoir of the Lobster group in Wifar area as an example, and the pen parameters of different position depths include Kudzuvine spiral pen, saiki spinosa, spiral horn pen, triangular half-harrow pen, curved back crown pen, shaft capsule pen, shaoxing and the like.

The chemical element parameters are parameters of chemical elements obtained through an element logging technology during the drilling of a key well. The chemical element parameters comprise the depth of each position and the chemical element parameters of each stratum, and the chemical element parameters comprise the contents of various elements such as S, al, mg, ca and the like. The element logging technology is to analyze rock by XRF (X-ray fluorescence spectroscopy) technology after discharging the rock generated by drilling at each position depth in the drilling process to the ground, so as to obtain chemical element parameters of each position depth and each stratum.

The first well logging curve is obtained through a well logging technology when a key well is drilled, the first well logging curve comprises a plurality of well logging curves of each position depth, and the plurality of well logging curves comprise at least one of a natural gamma GR curve, a uranium-free gamma KHT curve, a resistivity RT curve, a neutron CNL curve, a density DEN curve and an element well logging curve.

Step 102: the computer device determines a lithogram of the reservoir to be studied based on the chemical element parameters.

Wherein the lithogram comprises lithofacies types and formation parameters for each location depth of the reservoir to be investigated. The stratum parameters comprise stratum parameters of depth of each position, namely a Loongmaxi group shale gas reservoir in the Wifar region is used as a reservoir to be researched, and the stratum parameters comprise a Loongyi 1-4 upper layer, a Loongyi 1-4 lower layer, a Loongyi 1-3 layer, a Loongyi 1-2 layer, a Loongyi 1-1 upper layer, a five-peak group gray stratum and a five-peak group page stratum from top to bottom in sequence.

This step can be achieved by the following steps (1) - (3):

(1) For each formation, the computer device determines a mineral content matching the chemical element parameter based on the chemical element parameter of the formation.

Wherein the computer device determines a compound parameter of the formation based on the chemical element parameter of the formation, determines a mineral content matching the compound parameter based on the compound parameter of the formation from the target relationship data; wherein the target relationship data is used to represent the relationship between the compound parameter and the mineral content.

The minerals mainly comprise at least one of dolomite, calcite, quartz, clay and other minerals; different minerals may be determined by different chemical element parameters. The computer device determines a compound parameter of the formation based on the chemical element parameter of the formation, and the step of determining a mineral content matching the compound parameter based on the compound parameter of the formation from the target relationship data comprises:

for each mineral, determining a target chemical element parameter from the chemical element parameters of the formation, determining a target compound parameter matching the target chemical element parameter based on the target chemical element parameter, and determining a mineral content matching the target compound parameter based on the target compound parameter by target relationship data. The target chemical element parameter may be the content of one chemical element or the content of a plurality of chemical elements, and the target compound parameter may be the content of one compound or the content of a plurality of compounds.

In the examples of the present application, minerals including dolomite, calcite, quartz, clay and other minerals are exemplified. The target relationship data comprises first relationship data for representing the target compound parameter and dolomite, second relationship data for representing the target compound parameter and calcite, third relationship data for representing the target compound parameter and quartz, fourth relationship data for representing the target compound parameter and clay, and fifth relationship data for representing the target compound parameter and other minerals.

Wherein, in the case that the mineral includes dolomite, the target chemical element parameter is magnesium Mg, and the content of the target compound magnesium oxide MgO is obtained based on the sum of the content of magnesium Mg and the content of oxygen matched with the content of magnesium in the target chemical element parameter.

The first relationship data may be the following equation one:

equation one: w (W) _{Dolomite (Dolomite)} ＝184W _MgO /40

Wherein W is _{Dolomite (Dolomite)} Is the content of dolomite, W _MgO Is the content of MgO, 184 is CaMg (CO ₃ ) ₂ 40 is the relative molecular mass of magnesium oxide.

Wherein, in the case that the minerals include calcite, the target chemical element parameters are magnesium Mg and calcium Ca, the computer device obtains the content of the target compound magnesium oxide MgO based on the sum of the content of the target chemical element parameters magnesium Mg and the content of oxygen matching the content of magnesium, and the computer device obtains the content of the target compound calcium oxide CaO based on the sum of the content of the target chemical element parameters calcium Ca and the content of oxygen matching the content of calcium.

The second relationship data may be the following equation two:

formula II: w (W) _Calcite ＝100(W _CaO -56W _MgO /40)/56

Wherein W is _Calcite To calcite content, W _CaO 100 is CaCO of calcium carbonate ₃ 56 is the relative molecular mass of calcium oxide CaO and 40 is the relative molecular mass of magnesium oxide MgO.

Wherein, in the case of minerals including quartz, the target chemical element parameters are aluminum Al and silicon Si, and the computer equipment is based on the target chemical element silicon SiThe sum of the content and the oxygen content matched with the content of silicon gives the target compound silicon dioxide SiO ₂ The computer equipment obtains the target compound aluminum oxide Al based on the sum of the content of the target chemical element aluminum Al and the content of oxygen matched with the content of aluminum ₂ O ₃ Is contained in the composition.

The third relationship data may be the following equation three:

and (3) a formula III:

wherein W is _Quartz Is the content of quartz, including terrestrial quartz and biological silicon;is carbon dioxide SiO ₂ Is added to the mixture according to the content of (3),is aluminum oxide Al ₂ O ₃ Content of k ₁ SiO in clay mineral of ancient world underground Sichuan basin in Weifar area ₂ The proportioning coefficient of (2) is obtained by calculating the content of X-ray diffraction clay, and the value of the proportioning coefficient is 1.60-1.70 by adopting an illite content correction means.

Where the minerals include quartz, calcite, dolomite and clay, the fourth relationship data may be the following equation four:

equation four: w (W) _Clay ＝[100％-(W _Quartz +W _Calcite +W _{Dolomite (Dolomite)} )]×k ₂

Wherein W is _Clay For clay content, W _Quartz For quartz content, W _Calcite To calcite content, W _{Dolomite (Dolomite)} Is the content of dolomite. k (k) ₂ The method is characterized in that the clay mineral content of a shale gas reservoir of the Loma stream group in the Weifar area is calculated according to actual measurement XRD (X-ray diffraction) data of core samples of key wells or the same layer of the area, and the average value is 0.8. The content of quartz, calcite and dolomite was determinedThe procedure is the same as the procedure for determining the contents of quartz, calcite and dolomite in the above steps, and will not be described again here.

The reservoir to be researched contains main minerals such as quartz, clay, calcite, dolomite and the like, and also contains a small amount of other minerals such as pyrite, feldspar minerals and the like.

Where the minerals include quartz, calcite, dolomite, clay and other minerals, the fifth relationship data may be of the following formula five:

formula five: w (W) _Others ＝100％-(W _Quartz +W _Calcite +W _{Dolomite (Dolomite)} +W _Clay )

Wherein W is _Others Is the content of other minerals such as pyrite, feldspar minerals, and the like, W _Clay For clay content, W _Quartz For quartz content, W _Calcite To calcite content, W _{Dolomite (Dolomite)} Is the content of dolomite. The process of determining the content of quartz, calcite, dolomite and clay is the same as the process of determining the content of quartz, calcite, dolomite and clay in the above steps, and will not be described again here.

(2) The computer device determines a lithofacies type that matches the mineral content based on the mineral content.

Wherein the computer device determines the lithology type matching the mineral content based on the mineral content through a lithology division standard chart.

Referring to fig. 2, fig. 2 is a graph of a facies partition criteria, in which computer equipment corresponds the content of quartz, dolomite, and clay in the formation, and is able to determine the type of facies that matches the mineral content in the formation. Wherein, the main component of the dolomite is carbonate, and the content of the carbonate in the lithofacies division standard chart represents the content of the dolomite.

Referring to fig. 3, fig. 3 is a lithofacies partition standard diagram of a shale gas reservoir of the longmaxi group in the wilregion.

The stratum is divided into five lithofacies based on different mineral contents, namely calcareous shale, siliceous shale, high-calcium mixed shale and low-calcium mixed shale.

The content of quartz in siliceous shale is more than 50%, the content of clay in argillaceous shale is more than 50%, the content of carbonate in calcareous shale is more than 50%, the content of carbonate in high-calcium mixed shale is more than 33%, and the content of carbonate in low-calcium mixed shale is less than 33%.

Continuing with the example of a shale gas reservoir of the Loma stream group in the Weifar area, the computer equipment determines the lithology type matched with the mineral content based on the mineral content of each stratum in the shale gas reservoir through the lithology division standard diagram of FIG. 3.

The lithofacies type of the upper layer 1-4 of Longya in the Weifar area is low-calcium mixed shale; the lithofacies type of the lower layer of Loongyi 1-4 is high-calcium mixed shale; the lithofacies type of the Dragon 1-3 layer is low-calcium mixed shale; the lithofacies type of the Dragon 1-2 layer is siliceous shale; lithofacies type high-calcium mixed shale on the upper layer of Longya 1-1; the lithofacies type of the lower layer of Longya 1-1 is siliceous shale; the five-peak group gray rock stratum is calcareous shale; the five-peak shale layer is siliceous shale.

In one possible implementation, the computer device obtains, for each formation, the lithology of each formation from core data of key wells of the reservoir to be investigated.

Taking the shale gas reservoir of the Lobster group in the Wifar area as an example, the Lobster group belongs to the lower system of the reserved system in the stratum system, the lithology of the Lobster group at the upper part and the middle part is huge thick dark gray shale and gray black shale, and the lower part is thick gray shale, gray black siliceous shale and shale. The five-peak group belongs to an upper system of an Otto system in a stratum system, the lithology is mainly black shale, the lower part is filled with argillaceous siltstone, the argillite is rich in pen-stone fossils, the top development thin layer black gray scale limestone is a five-peak group stratum contrast mark layer, and the upper part of the mark layer can be determined to be a Drama-xi group stratum by the mark layer; the lower part of the five peak groups is gray black siliceous shale. By taking the lithology of each formation, a finer interpretation of the reservoir to be investigated can be made.

(3) The computer device determines a lithogram of the reservoir to be studied based on the lithofacies type of each formation.

Wherein the lithogram comprises lithofacies types and formation parameters for each location depth of the reservoir to be investigated.

And the computer equipment marks the lithofacies types of each stratum on the same graph in sequence, wherein the graph comprises the depth of each position and the lithofacies types of each stratum, and the lithofacies graph of the reservoir to be researched is obtained.

Step 103: the computer device determines a penmanship map of the reservoir to be studied based on the penmanship parameters.

Wherein the stone map comprises a stone type and stone stratification parameters for each location depth of the reservoir to be investigated.

Wherein the stone parameters include stone parameters for each depth and each stone stratification. Taking a shale gas reservoir of a Longmaxi group in a Wifar area as an example, the pen stone parameters comprise at least one of a Kudzuvine spiral pen stone, a Sai tool thorn pen stone, a spiral horn pen stone, a triangular half-harrow pen stone, a curved back crown pen stone, a shaft capsule pen stone, a Sharplike pen stone and the like.

The computer equipment divides depth sections with the same stone parameters into the same stone layering, and continuously takes a Longmaxi group shale gas reservoir in the Weifar area as an example, wherein the stone layering parameters are sequentially divided into: LM9 bottom, LM8 bottom, LM7 bottom, LM6 bottom, LM5 bottom, LM4 bottom, LM1-3 bottom, and guan yin bridge bottom.

Wherein, the pen and stone layer of the Gray spiral pen and stone is LM9 bottom boundary, record its position depth; the pencil stone with the Sai's pencil stone is layered into an LM8 bottom boundary, and the position depth is recorded; the pen and stone layer of the spiral horn pen and stone is LM7 bottom boundary, record its position depth; the pencil stone layering of the triangular half pencil stone is LM6 bottom boundary, and the position depth is recorded; the pen stone layer with the curved back crown pen stone is an LM5 bottom boundary, and the position depth is recorded; the pen and stone layer of the pen and stone with the axle bag is LM4 bottom boundary, and the position depth is recorded; the pen stones with the pointed Chinese zodiac pointed pen stones are layered into LM1-3 bottom boundaries, and the position depth is recorded; the pen and stone with the shell are layered as the bottom boundary of the guan-yin bridge, and the position depth is recorded.

The computer equipment marks the pencil stone type of each pencil stone layering on the same graph based on the position depth, wherein the graph comprises pencil stone layering parameters and pencil stone types of each position depth, and the pencil stone graph of the reservoir to be researched is obtained.

Step 104: the computer device determines a first contrast map based on the lithology map and the penmanship map.

Wherein the first contrast map includes a lithofacies type, a formation parameter, a pen-stone type, and a pen-stone stratification parameter for each location depth.

And marking the lithofacies type, stratum parameters, the pencil stone type and the pencil stone layering parameters of each position depth on the same graph respectively to obtain a first comparison graph.

Continuing with the example of the Wilman's shale gas reservoir in Wilman, FIG. 4 is a first comparison of the Wilman's shale gas reservoir in Wilman, including the lithofacies type, formation parameters, pen and stone type and pen and stone stratification parameters for each location depth.

Step 105: the computer device determines a second contrast map based on the penmanship map and the first log.

Wherein the second contrast map comprises a pen-stone type, a pen-stone stratification parameter and a log for each location depth.

The computer equipment marks the pen and stone type, the pen and stone layering parameters and the first logging curve of each position depth on the same graph respectively, and a second comparison graph is obtained.

Continuing with the example of the Wilman's shale gas reservoir, FIG. 5 is a second comparative graph of the Wilman's shale gas reservoir.

The first logging curve comprises a natural gamma GR curve, a uranium-free gamma KHT curve, a resistivity RT curve, a neutron CNL curve, a density DEN curve and an element logging curve, wherein the element logging curve comprises content curves of elements Ca, si and Al.

Wherein the first log on the second comparison plot has different log response characteristics at different penstone stratification locations. For example, at the depth of the location of the LM9 bottom boundary, the gamma value of the natural gamma curve has no significant change, the gamma value of the uranium-free gamma curve has a maximum value, the resistivity value of the resistivity curve has a minimum value, the neutron value of the neutron curve has a minimum value, the density value of the density curve has a minimum value, and the elemental log curve has no significant change.

Step 106: the computer device determines a target reservoir for the reservoir under study based on the chemical element parameters of each formation of the reservoir under study.

Wherein the target reservoir is a shale gas-rich reservoir.

This step can be achieved by the following steps (1) - (3):

(1) The computer device determines, for each formation, a brittleness index and an organic abundance index that match the chemical element parameters based on the chemical element parameters of the formation.

The computer device determines, for each formation, a mineral content matching the chemical element based on a chemical element parameter of the formation, and determines a brittleness index matching the mineral content based on the mineral content. The specific process of determining the mineral content is the same as that of step (1) of determining the mineral content in step 102, and will not be described herein.

Wherein the computer device determines a brittleness index matching the mineral content based on the mineral content by a brittleness index formula.

Taking a Wilmatian shale gas reservoir in the Wilmatian area as an example, siliceous minerals, calcite, dolomite and the like are classified as brittle minerals according to the rock chemistry and mineral composition characteristics of the Wilmatian shale gas reservoir in the Wilmatian area, and the brittleness index represents the fracturing property of the reservoir.

The brittleness index formula is:

BI＝(W _Quartz +W _calcite +W _{Dolomite (Dolomite)} )/(W _Quartz +W _Calcite +W _{Dolomite (Dolomite)} +W _Clay )

Wherein BI is a brittleness index, W _Quartz For quartz content, W _Calcite To calcite content, W _{Dolomite (Dolomite)} Is the content of dolomite, W _Clay Is the clay content.

The computer device determines, for each formation, an organic content that matches the chemical element parameter based on the chemical element parameter of the formation. The computer equipment determines an organic matter abundance index matched with the organic matter content through an organic matter abundance index formula based on the organic matter content.

Taking a Wilman's group shale gas reservoir in the Wilman area as an example, according to the research on the rock chemical characteristics of the Wilman's group shale gas reservoir in the Wilman area, the shale is rich in sulfur trioxide SO ₃ Often related to biological or plant development, higher levels reflect higher levels of organic matter and sulfur trioxide SO ₃ (except for evaporite) has good correlation with organic carbon content, SO sulfur trioxide SO can be applied ₃ And (3) calculating the organic matter index and evaluating shale reservoir. And the shale is rich in alumina Al ₂ O ₃ Representing the clay content, the organic matter abundance index becomes lower as the clay content becomes higher. Thus, it is possible to pass sulfur trioxide SO ₃ And alumina Al ₂ O ₃ The content of (2) establishes an organic matter abundance index.

The formula of the abundance index of the organic matters is as follows:

wherein OI is the abundance index of organic matters,for the content of sulfur trioxide->Is the content of alumina.

Wherein sulfur trioxide SO is obtained based on the sum of the content of S in the chemical element and the content of oxygen matching the content of S ₃ Is contained in the composition. Obtaining aluminum oxide Al based on the sum of the aluminum Al content and the oxygen content matched with the aluminum content in the chemical element ₂ O ₃ Is contained in the composition.

(2) The computer device determines a reservoir type of the formation based on the brittleness index and the organic abundance index.

Wherein the computer device is provided with a plurality of reservoir types in advance, and an index range comprising a brittleness index and an organic matter abundance index of each reservoir type; thus this step may be: the computer equipment determines a first index range in which the brittleness index is located based on the brittleness index, and determines a second index range in which the organic matter abundance index is located based on the organic matter abundance index. And determining the reservoir type corresponding to the first index range and the second index range from the corresponding relation between the index range and the reservoir type according to the first index range and the second index range.

Taking a shale gas reservoir of a Longmaxi group in a Weifar area as an example, referring to Table 1, table 1 is a shale reservoir evaluation standard established based on chemical element parameters in the area, wherein the shale reservoir evaluation standard comprises a plurality of reservoir types, and an index range of brittleness index and organic matter abundance index of each reservoir type, and the shale reservoir evaluation standard is established by comprehensively analyzing by referring to research result data of a Sichuan basin in the Weifar area, logging interpretation conclusion and gas testing result of a plurality of wells such as the Sichuan basin in the Weifar area. According to the brittleness index and the abundance index of the organic matters, the reservoir categories are divided into three categories, wherein the category I is a good reservoir, the category II is a medium reservoir, and the category III is a poor reservoir.

TABLE 1

Reservoir type	Brittleness Index (BI)	Organic matter abundance index (OI)
			Ⅰ	＞0.60	＞0.40
Ⅱ	0.60～0.50	0.40～0.25
			Ⅲ	＜0.50	＜0.25

Continuing to take the Wilmatian shale gas reservoir as an example, referring to Table 2, table 2 is a table of brittleness index and organic matter abundance index of each stratum of the Wilmatian shale gas reservoir.

TABLE 2

(3) The computer device determines a target reservoir for the reservoir under study from the plurality of formations based on the reservoir types of the plurality of formations.

The computer equipment determines a stratum with the good reservoir type from the multiple strata based on the reservoir types of the multiple strata, and determines the stratum with the best reservoir type from the stratum with the good reservoir type based on the brittleness index and the organic matter index as a target reservoir.

Taking a shale gas reservoir of a Longmaxi group in a Wifar area as an example, continuing to refer to a table 2, wherein the reservoir types of a Longyi 1-4 upper layer, a Longyi 1-4 lower layer, a Longyi 1-3 layer, a Longyi 1-2 layer and a Wufeng group shale layer are all of class II, the reservoir type of the Wufeng group shale layer is of class III, and the reservoir types of the Longyi 1-1 upper layer and the Longyi 1-1 lower layer are of class I; the type I reservoir is a good reservoir, and the stratum with the best reservoir type is determined from the upper layer of Dragon 1-1 and the lower layer of Dragon 1-1 to be used as a target reservoir. As the brittleness index and the organic matter index of the lower layer of Loongyi 1-1 are respectively larger than those of the upper layer of Loongyi 1-1, the low layer of Loongyi 1-1 has good fracturing property and high organic matter content, and therefore, the lower layer of Loongyi 1-1 is determined to be a target reservoir.

With continued reference to fig. 4, the first comparative plot also includes an intersection of an ESC (elemental capture) log and an elemental log, the measured elements including Si and Ca, and with reference to fig. 4, the Si and Ca content of the ESC log and the elemental log are substantially the same; for example, the Si content of the silicon is high at the 1-1 lower layer of the target reservoir, and the Ca content of the calcium is low at the 1-1 lower layer of the target reservoir, which means that the accuracy of chemical element parameters measured according to the element logging curve is high.

With continued reference to fig. 4, the first comparative graph further includes a neutron CNL curve, a density DEN curve, and an acoustic AC curve, where the stratum density value at the depth of the position corresponding to the 1-1 lower layer of the target reservoir is low, and the pore value is large, which indicates that the gas-containing property is good, and the characteristics of the target reservoir are met.

With continued reference to FIG. 4, the first comparison plot also includes an intersection of natural gamma and uranium-free gamma; the intersection width of the shale position depth is large, the intersection width of the limestone position depth is small, the lithofacies type above the limestone is siliceous shale and accords with a target reservoir, the lower layer of Loongyi 1-1 is further determined to be the target reservoir through the intersection curve, and the accuracy of determining the lithofacies type based on the chemical element parameters is high.

Step 107: the computer device determines a target lithology type and a target pen stone type for the target reservoir based on the first contrast map.

The computer equipment determines the position depth of the target reservoir, determines the lithofacies type and the pen stone type corresponding to the position depth from the first comparison chart, and determines the lithofacies type and the pen stone type corresponding to the position depth as the target lithofacies type and the target pen stone type of the target reservoir.

Continuing to take the Wifar area Longmaxi group shale gas reservoir as an example, the target reservoir is a Longyan 1-1 lower layer, continuing to refer to fig. 4, the computer equipment determines the position depth of the Longyan 1-1 lower layer from the first contrast diagram of fig. 4, and then determines the target lithofacies type corresponding to the position depth as siliceous shale from the first contrast diagram, and the target pen type as sharpening pen.

In the embodiment of the application, the lithology type, the stratum parameter, the pen-stone type and the pen-stone layering parameter of each position depth of the reservoir to be researched are collected into the first contrast map through determining the first contrast map, so that the lithology type and the pen-stone type of the target reservoir can be quickly and directly obtained from the first contrast map after the target reservoir is determined, time and labor are saved, and the efficiency of determining the target lithology type and the target pen-stone type is improved.

Step 108: the computer device obtains an interpretation while drilling curve of the reservoir to be studied.

Wherein the while-drilling interpretation profile includes a lithofacies type, a formation parameter, a first element log, and a first natural gamma curve for each location depth. The first element logging curve is obtained through an element logging technology in the key well drilling process of the reservoir to be researched, and the first natural gamma curve is obtained through a logging technology in the key well drilling process of the reservoir to be researched.

Continuing with the example of a shale gas reservoir of the Loma stream group in the Wifar area, referring to FIG. 6, the first elemental log comprises an intersection of elemental sulfur S-iron Fe, an intersection of aluminum Al-silicon Si, an intersection of magnesium Mg-calcium Ca and an intersection of phosphorus P-manganese Mn. The first element log and the first natural gamma curve of different formations have different log response characteristics.

The lithofacies type of the upper layer of Loongyi 1-4 is low-calcium mixed shale, lithology is gray black shale, and logging response characteristics of the corresponding first element logging curve and the first natural gamma curve are not changed obviously. The lithofacies type of the lower layer of Loone 1-4 is high-calcium mixed shale, lithology is gray shale, response characteristics of the corresponding first element logging curves are respectively Al as a median value, si as a median value, mg as a low value, ca as a high value and while-drilling gamma value as a low value. The lithofacies of the Loongyi 1-3 layers are low-calcium mixed shale, lithology is black shale, response characteristics of corresponding first element logging curves are respectively that Al is a high value, si is a median value, mg is a median value, ca is a low value, and while-drilling gamma value is a median value. The lithofacies of the Loongyi 1-2 layers are siliceous shale, lithology is black shale, response characteristics of corresponding first element logging curves are respectively that Al is a high value, si is a median value, mg and Ca are low values, and while-drilling gamma values are low values. The lithofacies type of the upper layer of Loone 1-1 is high-calcium mixed shale, lithology is black cloud shale, response characteristics of the corresponding first element logging curves are respectively that Al and Si are low values, mg and Ca are greatly increased, and while-drilling gamma values are extremely high values. The lithofacies of the lower layer of Loone 1-1 are siliceous shale, lithology is gray black siliceous shale, response characteristics of the corresponding first element logging curves are respectively Al as a median, si as a median, mg as a low value, ca as a high value and while-drilling gamma value as a low value. The lithofacies type of the five-peak group gray rock layer is calcareous shale, lithology is gray limestone, response characteristics of the corresponding first element logging curves are respectively low values of Al, si and Mg, high values of Ca and extremely low values of gamma while drilling.

Referring to table 3, table 3 is a table of five peak group-longmaxi group formation characteristics for the Sichuan region corresponding to fig. 6, including lithology, gamma while drilling (API) values, contents of elemental aluminum Al, silicon Si, magnesium Mg and calcium Ca, brittleness index, and reservoir type for each formation.

TABLE 3 Table 3

The gamma value while drilling, the content of each element, the brittleness index and the reservoir type of each stratum can be directly obtained from the table 3, and the method is more visual.

Referring to fig. 7, fig. 7 is a mineral and element comprehensive graph of a shale gas reservoir of the longmaxi group in the wilregion, wherein the graph comprises stratum parameters, mineral content curves and element logging curves of each position depth; the mineral content is obtained through core experiments after drilling, the element logging curve is obtained through logging technology in the drilling process, and the element logging curve is basically matched with the mineral content curve as can be known from the figure; for example, the quartz mainly comprises silicon, and the silicon content in the element logging curve is the largest at the position depth of the maximum quartz content in the mineral content curve, so that the accuracy of chemical element parameters in the element logging curve measured by the logging technology is high and accords with the actual situation.

Referring to fig. 8, fig. 8 is a diagram of mineral composition of each stratum of the shale gas reservoir of the longmaxi group in the wilregion matched with fig. 7, and it can be seen from the diagram that the quartz content of the lower layer of the longyi 1-1 is highest and exceeds 50%, and accords with the rule that the quartz content in siliceous shale is greater than 50%, which indicates that the accuracy of the determined target reservoir is high.

Referring to fig. 9, fig. 9 is an element distribution diagram of each stratum of the longmaxi group shale gas reservoir in the wilregion matched with fig. 7, and it can be seen from the figure that the content of Si element in the lower layer of the longyi 1-1 is highest, and the Si element is matched with the content of quartz obtained by the analysis experiment of the rock core of the lower layer of the longyi 1-1, so that the accuracy of chemical element parameters in an element logging curve measured by a logging experiment is high, and the accuracy is consistent with the actual situation.

Step 109: the computer device obtains a second log and a while-drilling profile of the formation in which the borehole trajectory is located while the target well of the reservoir to be investigated is drilled.

The while-drilling curve comprises a second element logging curve and a second natural gamma curve, and the second logging curve and the while-drilling curve are curves obtained in the drilling process.

The target well is a horizontal well, and the well track is drilled to a reservoir to be researched according to a preset well track and is positioned near the target reservoir.

Step 110: the computer device determines a lithology type and a lithology type of the drilling formation based on the second log, the second contrast map, the while-drilling curve, and the while-drilling interpretation curve.

The computer device obtains a pen-stone type of the drilling formation from the second contrast map for the drilling formation in the second log.

The second contrast graph comprises a pen and stone type, a pen and stone layering parameter and a logging curve of each position depth. The computer device determines a first target location depth from a first log interpretation curve in the second comparison graph, the first target location depth being the location depth of the drilling formation, the first target location depth being the location depth having the same log response characteristics as the log response characteristics of the second log curve. The computer device determines a type of pen stone for the first target location depth from the second comparison map based on the first target location depth as the type of pen stone for the drilling formation.

In the embodiment of the application, through determining the second contrast diagram, the pen and stone type, the pen and stone layering parameters and the logging curve of each position depth in the reservoir to be researched are collected into the second contrast diagram, so that after the second logging curve of the drilling stratum is obtained, the pen and stone type of the drilling stratum can be obtained through the second contrast diagram, the situation that the pen and stone type of the drilling stratum is determined by carrying out core experiments again in a coring operation is avoided, time and labor are saved, and the efficiency of determining the pen and stone type of the drilling stratum is improved.

The computer device obtains a lithology type of the drilling formation from the interpretation while drilling curve for the drilling formation in the while drilling curve.

Wherein the while-drilling interpretation profile includes a lithofacies type, a formation parameter, a first element log, and a first natural gamma curve for each location depth. The computer equipment determines a second target position depth from the interpretation curve while drilling, and takes the second target position depth as the position depth of the drilling stratum, wherein the second target position depth is the position depth of which the logging response characteristics of the first element logging curve and the first natural gamma curve in the interpretation curve while drilling are respectively identical to the logging response characteristics of the second element logging curve and the second natural gamma curve in the interpretation curve while drilling. The computer device determines a lithofacies type of the second target location depth from the while-drilling interpretation curve based on the second target location depth as a lithofacies type of the drilling formation.

In the embodiment of the application, the lithofacies type of the drilling stratum can be determined through the explanation curve while drilling after the second element logging curve and the second natural gamma curve of the drilling stratum are obtained by collecting the lithofacies type, stratum parameters, the first element logging curve and the first natural gamma curve of each position depth into the drilling explanation curve, so that time and labor are saved, and the efficiency of determining the lithofacies type of the drilling stratum is improved.

Step 111: the computer device adjusts a borehole trajectory of the target well based on a lithofacies type and a lithocarpal stone type of the drilling formation and a difference of the target lithofacies type and the target lithocarpal stone type to align the borehole trajectory with the target reservoir.

Wherein, this step can be achieved by the following steps (1) - (2).

(1) The computer device compares the type of the penstock of the drilling stratum with the type of the target penstock, adjusts the well track, and enables the well track and the target reservoir to be in the same penstock layering.

And if the pencil stone layer of the drilling stratum is positioned above the stratum of the target pencil stone type, the well track is adjusted downwards, so that the well track and the target reservoir are positioned in the same pencil stone layer.

If the pencil stone layer of the drilling stratum is positioned below the stratum of the target pencil stone type, the well track is adjusted upwards, so that the well track and the target reservoir are positioned in the same pencil stone layer.

Continuing with the example of a shale gas reservoir of the Lobster group in the Wifar area, referring to FIG. 10, after the wellbore trajectory reaches the reservoir to be studied, the wellbore trajectory begins to be deviated in the reservoir to be studied, enters a deviation section, and is adjusted based on the difference between the type of the penstock of the drilling stratum and the type of the target penstock. If the type of the pen stone of the drilling stratum where the well track is located is the same as that of the pen stone of the Dragon 1-4 upper layer, which means that the well track is located on the Dragon 1-4 upper layer above the target reservoir, for example, at the point A, the well track needs to be adjusted downwards. If the type of the pen stone of the drilling stratum where the well track is located after the well track is adjusted downwards is the same as the type of the pen stone of the first 1-4 lower layers, which means that the well track is located in the first 1-4 lower layers above the target reservoir, for example, in the point B, the well track is adjusted downwards continuously. If the type of the pen stones of the drilling stratum where the well track is located after the well track is down-regulated is the same as the type of the pen stones of the Dragon 1-3 layers, which means that the well track is located on the Dragon 1-3 layers above the target reservoir, for example, the well track is located at the point C, the well track is continuously down-regulated. If the type of the pen stone of the drilling stratum where the well track is located after the well track is adjusted downwards is the same as the type of the pen stone of the Dragon 1-2 layers, which means that the well track is located on the Dragon 1-2 layers above the target reservoir, for example, the well track is adjusted downwards continuously at the point D. If the type of the pen stone of the drilling stratum where the well track is located after the well track is adjusted downwards is the same as that of the pen stone of the Dragon 1-1 layer, the pen stone type of the Dragon 1-1 layer is the target pen stone type, which indicates that the well track and the target reservoir are in the same pen stone layering, and the pen stone type of the Dragon 1-1 upper layer and the Dragon 1-1 lower layer are the same and are in the same pen stone layering, so that the well track cannot be adjusted based on the pen stone type any more. In this way, in the construction process of the deflecting section, according to the drilling curve of the target well, the stratum where the well track of the target well is located can be clamped in real time, the position depth of the target reservoir is predicted, the well track is adjusted layer by layer in real time, and the drilling rate of the well track and the target reservoir can be improved.

(2) The computer device compares the lithofacies type of the drilling stratum with the target lithofacies type, and adjusts the well track in the same lithostratifying as the target reservoir so that the well track and the target reservoir are in the same lithostratifying and the same stratum.

And if the stratum where the lithofacies type of the drilling stratum is located above the stratum where the target lithofacies type is located, the well track which is in the same lithostratification with the target reservoir is adjusted downwards, so that the well track and the target reservoir are in the same lithostratification and the same stratum.

If the stratum where the lithofacies type of the drilling stratum is located below the stratum where the target lithofacies type is located, the well track which is in the same lithostratification with the target reservoir is adjusted upwards, so that the well track and the target reservoir are in the same lithostratification and the same stratum.

Referring to fig. 11, continuing with the example of a torma stream group shale gas reservoir in the wefar region, the wellbore trajectory begins to progress in the horizontal segment after the drilling formation and the target reservoir are in the same litho-zone. The computer device compares the lithofacies type of the drilling formation with the target lithofacies type, and if the lithofacies type of the drilling formation in which the wellbore trajectory is located is the same as the lithofacies type of the five-peak set of gray rock layers, it is indicated that the wellbore trajectory is located in the five-peak set of gray rock layers below the target reservoir, for example, at point E or point F, the wellbore trajectory is up-regulated. And if the lithofacies type of the drilling stratum where the up-regulated well track is located is the same as that of the upper layer of Dragon 1-1, the well track is down-regulated until the lithofacies type of the drilling stratum is the same as that of the lower layer of Dragon 1-1 of the target reservoir. Thus, according to the lithology type of the drilling stratum, the relative position of the well track in the reservoir can be timely and accurately judged, a reference basis is provided for adjusting the well track, multiple micro-amplitude adjustment of the well track is truly realized, the later construction difficulty and the sleeve deformation probability caused by large-amplitude adjustment after the layer penetration are reduced, meanwhile, the drilling meeting rate of the target reservoir is effectively improved, the success rate of drilling to the target reservoir is improved, and the smoothness of the track is also met; the drilling meeting rate of the target reservoir is improved, and the well track is prevented from being greatly adjusted in the horizontal interval, so that the well completion operation construction is influenced, and the geological engineering integration is truly realized.

In the embodiment of the present application, through the steps 101-111 described above, the wellbore trajectory can be aligned to the target reservoir; embodiments of the present application may also determine pressure parameters of the fracturing stage by the following steps 112-114.

Step 112: the computer device determines a plurality of lithofacies segment parameters of the target well at the horizontal segment based on the chemical element parameters of the target reservoir.

The horizontal section is a target reservoir section to be fractured in a target reservoir aligned with the well track after the well track is adjusted. The facies segment parameters include facies type and brittleness index of each facies segment, and the chemical element parameters include chemical element parameters of a plurality of facies segments.

This step can be achieved by the following steps (1) - (2):

(1) The computer device determines, for each lithology segment, a mineral content and a brittleness index that match the chemical element parameter based on the chemical element parameter of the lithology segment. This step is the same as the determination of mineral content and brittleness index in step 106 and will not be described in detail here.

Referring to table 4, table 4 is a table of classification of facies segments for a target reservoir segment to be fractured, including the brittleness index of each facies segment.

TABLE 4 Table 4

The process of determining the lithology type in step 102 is the same, and will not be described here.

With continued reference to Table 4, the facies type for each facies segment is also included in Table 4.

Step 113: the computer equipment divides a plurality of fracturing segments with different lithofacies segment parameters based on a plurality of lithofacies segment parameters of the horizontal segment, and the fracturing segments are all positioned on the horizontal segment.

The computer equipment classifies the lithofacies sections with the same lithofacies type and brittleness index into the same fracturing section, see fig. 12, and fig. 12 is a staged fracturing schematic diagram of a horizontal section, wherein the staged fracturing schematic comprises a plurality of fracturing sections.

Step 114: for each fracturing segment, the computer device determines pressure parameters of the fracturing segment based on lithofacies segment parameters of the fracturing segment.

The pressure parameter is used for guiding the fracturing section to fracture and is a pressure value for fracturing the pressure section.

Wherein the computer device determines, for each of the fracture segments, a pressure parameter of the fracture segment based on the brittleness index of the fracture segment. Since the brittleness index represents the frawability of the target reservoir, the value of the pressure parameter of the fracturing segment with low brittleness index is large and the value of the pressure parameter of the fracturing segment with high brittleness index is small.

Referring to fig. 13, fig. 13 is a graph of pressure parameters of a certain target reservoir corresponding to table 4, the 1 st and 2 nd litho-phase sections having litho-phase types E and F, respectively, a brittleness index lower than 29%, the 6 th and 7 th litho-phase sections having litho-phase types J and K, respectively, and a brittleness index of 51-69%. Since the brittleness index of the 1 st and 2 nd facies segments is lower than the brittleness index of the 6 th and 7 th facies segments, and the brittleness index represents the frawability of the target reservoir, the pressure parameters of the 1 st and 2 nd facies segments are higher than the pressure parameters of the 6 th and 7 th facies segments.

Continuing taking the shale gas reservoir of the Longmaxi group in the Weifar area as an example, referring to FIG. 15, FIG. 15 is a comprehensive staged fracturing chart of horizontal segments to be fractured in the lower layer of Longya 1-1 of the target reservoir, wherein the comprehensive staged fracturing chart comprises a natural gamma curve, a uranium-free gamma curve, a mineralogical composition curve, a pore structure data curve, a density curve, a brittleness index curve, a weaknesses index curve, mineralogy index, a porosity index, a compressibility index, a comprehensive index and other logging curves and logging indexes of each fracturing segment. The comparison of fig. 14 shows that the logging curves and logging indexes of different fracturing sections are different, which indicates that the geological structures of different pressure sections are different, and the rock elastic mechanical parameters of the lithofacies sections with different lithofacies section parameters are greatly different, so that the stratum fracture pressure during fracturing is also greatly different, and the fracturing engineering parameter configuration is also different. In the same fracturing section, if different rock types exist, the rock mechanical heterogeneity is strong, an extension seam is easy to form, the effective rate of fracturing is reduced, and the fracturing effect of the whole well is directly affected. In the horizontal well construction process, the lithology section parameters of the horizontal section necessarily have diversity due to abrupt structural changes, thinning of high-quality reservoir thickness and engineering reasons. It is necessary to optimize the fracturing segmentation of the horizontal segment based on the rock segment parameters.

In the embodiment of the application, the horizontal segments to be fractured are divided through the chemical element parameters, so that a plurality of fracturing segments with different pressure parameters are obtained, and when the horizontal segments to be fractured are guided to be fractured in a staged manner based on the pressure parameters, the targeted fracturing of each fracturing segment is realized, the efficiency of fracturing construction can be improved, the formation of a three-dimensional fracture network structure after fracturing is facilitated, and the single well gas yield is improved.

In the embodiment of the application, the chemical element parameters are used for determining the target reservoir, adjusting the borehole track and determining the pressure parameters during fracturing, so that geological knowledge of the chemical element parameters is tightly combined with engineering practice, effective fusion of shale gas development technologies such as geology, drilling and fracturing is realized, a technical system integrating optimization of the target reservoir, adjustment of the borehole track and optimization design of fracturing is formed, and the development effect of shale gas is comprehensively improved.

By the method provided by the embodiment of the application, the well position deployment and adjustment 8-platform 42 ports of the shale gas reservoir of the Lobster group in the Wifar area are finished at present; completing 27 geological guiding ports of a horizontal well, wherein the drilling rate of siliceous shale reaches 96%; by optimizing the reservoir reconstruction design, the sand adding strength and the crack complexity are improved, the sand adding strength is improved by 12.03%, the sleeve transformation rate is reduced by 11.8%, the shale gas is produced in 2019 for 9 hundred million square, and the plan is exceeded by 1.08 hundred million square. Compared with the fracturing ageing in 2018, the fracturing ageing in 2019 saves 19.46 days, and increases the gas yield by 5113 kilowatts. The platform for producing 100 square meters of natural gas in 3 days is produced, wherein the test yield of the Wei 202H40 platform is up to 233 square meters per day, the highest daily yield of the H40-3 well is 60 square meters, the platform in the Weifar area and the highest test yield of a single well are created, and technical support is provided for efficient development of shale gas.

In one aspect, there is provided a wellbore trajectory correction device for a horizontal well, referring to fig. 15, the device comprising:

a first acquisition module 1501 for acquiring chemical element parameters, pen-stone parameters and a first log of a reservoir to be investigated;

a first determining module 1502 for determining a lithogram of the reservoir to be studied based on the chemical element parameters, the lithogram comprising a lithogram type and formation parameters for each location depth of the reservoir to be studied;

a second determining module 1503, configured to determine a lithograph of the reservoir to be studied based on the litho parameters, where the litho graph includes a litho type and a litho layering parameter for each location depth of the reservoir to be studied;

a third determining module 1504 configured to determine a first contrast map based on the lithology map and the lithology map, the first contrast map including a lithology type, a formation parameter, a lithology type, and a lithology layering parameter for each location depth;

a fourth determination module 1505 for determining a second comparison graph based on the penstock graph and the first log, the second comparison graph including a penstock type, a penstock layering parameter, and the first log for each location depth;

a fifth determination module 1506 for determining a target reservoir for the reservoir under study based on the chemical element parameters of each formation of the reservoir under study;

A sixth determining module 1507 for determining a target lithology type and a target pen stone type of the target reservoir based on the first contrast map;

a second obtaining module 1508, configured to obtain an interpretation-while-drilling curve of the reservoir to be studied, where the interpretation-while-drilling curve includes a lithofacies type, a formation parameter, a first element logging curve, and a first natural gamma curve for each depth of location;

a third obtaining module 1509, configured to obtain a second logging curve and a while-drilling curve of a drilling stratum where a wellbore trajectory is located when a target well of the reservoir to be studied is drilled, where the while-drilling curve includes a second element logging curve and a second natural gamma curve;

a seventh determination module 1510 for determining a lithology type and a lithology type of the drilling formation based on the second log, the second contrast map, the while-drilling curve, and the while-drilling interpretation curve;

an adjustment module 1511 for adjusting a borehole trajectory of the target well based on a lithofacies type and a lithocarpal type of the drilling formation and a difference of the target lithofacies type and the target lithocarpal type to align the borehole trajectory with the target reservoir.

In one possible implementation, the seventh determining module 1510 includes:

the first acquisition unit is used for acquiring the pen-stone type of the drilling stratum from the second contrast graph for the drilling stratum in the second logging curve;

In one possible implementation, the adjustment module 1511 includes:

the first adjusting unit is used for comparing the type of the penstock of the drilling stratum with the type of the target penstock, adjusting the well track and enabling the well track and the target reservoir to be in the same penstock layering;

In one possible implementation, the apparatus further includes:

an eighth determining module 1512, configured to determine a plurality of lithofacies segment parameters of the target well in a horizontal segment based on the chemical element parameters of the target reservoir, where the horizontal segment is a target reservoir segment to be fractured in the target reservoir aligned with the wellbore trajectory after adjusting the wellbore trajectory;

the dividing module 1513 is configured to divide a plurality of fracturing segments with different lithofacies segment parameters based on a plurality of lithofacies segment parameters of the horizontal segment, where the plurality of fracturing segments are all located in the horizontal segment;

a ninth determining module 1514 is configured to determine, for each of the fracturing segments, a pressure parameter of the fracturing segment based on a lithofacies segment parameter of the fracturing segment, the pressure parameter being used to guide the fracturing segment to fracture.

In one possible implementation, the lithofacies segment parameters include lithofacies type and brittleness index, and the chemical element parameters include chemical element parameters of a plurality of lithofacies segments; an eighth determination module 1512 includes:

a first determining unit for determining, for each lithofacies segment, a mineral content and a brittleness index matching the chemical element parameter based on the chemical element parameter of the lithofacies segment;

In one possible implementation, the fifth determining module 1506 includes:

a third determining unit for determining, for each formation, a brittleness index and an organic matter abundance index that match the chemical element parameters based on the chemical element parameters of the formation;

a fourth determining unit for determining a reservoir type of the formation based on the brittleness index and the organic matter abundance index;

and a fifth determining unit for determining a target reservoir of the reservoir to be studied from the plurality of formations based on reservoir types of the plurality of formations.

In one possible implementation, the chemical element parameters include chemical element parameters for each formation of the reservoir under study, and the first determining module 1502 includes:

A sixth determining unit for determining, for each formation, a mineral content matching the chemical element parameters based on the chemical element parameters of the formation;

a seventh determining unit for determining a rock phase type matching the mineral content based on the mineral content;

and an eighth determining unit for determining a lithogram of the reservoir to be studied based on the lithology type of each stratum.

Fig. 16 shows a block diagram of a computer device 1600 provided in an exemplary embodiment of the present application. The computer device 1600 may be a portable mobile computer device such as: a smart phone, a tablet computer, an MP3 player (Moving Picture Experts Group Audio Layer III, motion picture expert compression standard audio plane 3), an MP4 (Moving Picture Experts Group Audio Layer IV, motion picture expert compression standard audio plane 4) player, a notebook computer, or a desktop computer. Computer device 1600 may also be referred to by other names of user devices, portable computer devices, laptop computer devices, desktop computer devices, and the like.

In general, the computer device 1600 includes: a processor 1601, and a memory 1602.

Processor 1601 may include one or more processing cores, such as a 4-core processor, an 8-core processor, and the like. The processor 1601 may be implemented in at least one hardware form of a DSP (Digital Signal Processing ), FPGA (Field-Programmable Gate Array, field programmable gate array), PLA (Programmable Logic Array ). The processor 1601 may also include a host processor, which is a processor for processing data in an awake state, also referred to as a CPU (Central Processing Unit ); a coprocessor is a low-power processor for processing data in a standby state. In some embodiments, the processor 1601 may be integrated with a GPU (Graphics Processing Unit, image processor) for taking care of rendering and rendering of content to be displayed by the display screen. In some embodiments, the processor 1601 may also include an AI (Artificial Intelligence ) processor for processing computing operations related to machine learning.

Memory 1602 may include one or more computer-readable storage media, which may be non-transitory. Memory 1602 may also include high-speed random access memory, as well as non-volatile memory, such as one or more magnetic disk storage devices, flash memory storage devices. In some embodiments, a non-transitory computer readable storage medium in memory 1602 is used to store at least one instruction for execution by processor 1601 to implement the wellbore trajectory correction method for a horizontal well provided by the method embodiments in the present application.

In some embodiments, computer device 1600 may also optionally include: a peripheral interface 1603, and at least one peripheral. The processor 1601, memory 1602, and peripheral interface 1603 may be connected by bus or signal lines. The individual peripheral devices may be connected to the peripheral device interface 1603 by buses, signal lines, or circuit boards. Specifically, the peripheral device includes: at least one of radio frequency circuitry 1604, a display screen 1605, a camera assembly 1606, audio circuitry 1607, a positioning assembly 1608, and a power supply 1609.

Peripheral interface 1603 may be used to connect I/O (Input/Output) related at least one peripheral to processor 1601 and memory 1602. In some embodiments, the processor 1601, memory 1602, and peripheral interface 1603 are integrated on the same chip or circuit board; in some other embodiments, either or both of the processor 1601, memory 1602, and peripheral interface 1603 may be implemented on separate chips or circuit boards, which is not limited in this embodiment.

The Radio Frequency circuit 1604 is used for receiving and transmitting RF (Radio Frequency) signals, also known as electromagnetic signals. The radio frequency circuit 1604 communicates with a communication network and other communication devices via electromagnetic signals. The radio frequency circuit 1604 converts an electrical signal into an electromagnetic signal for transmission, or converts a received electromagnetic signal into an electrical signal. Optionally, the radio frequency circuit 1604 includes: antenna systems, RF transceivers, one or more amplifiers, tuners, oscillators, digital signal processors, codec chipsets, subscriber identity module cards, and so forth. The radio frequency circuit 1604 may communicate with other computer devices via at least one wireless communication protocol. The wireless communication protocol includes, but is not limited to: the world wide web, metropolitan area networks, intranets, generation mobile communication networks (2G, 3G, 4G, and 5G), wireless local area networks, and/or WiFi (Wireless Fidelity ) networks. In some embodiments, the radio frequency circuit 1604 may also include NFC (Near Field Communication ) related circuits, which are not limited in this application.

The display screen 1605 is used to display a UI (User Interface). The UI may include graphics, text, icons, video, and any combination thereof. When the display 1605 is a touch display, the display 1605 also has the ability to collect touch signals at or above the surface of the display 1605. The touch signal may be input to the processor 1601 as a control signal for processing. At this point, the display 1605 may also be used to provide virtual buttons and/or virtual keyboards, also referred to as soft buttons and/or soft keyboards. In some embodiments, the display screen 1605 may be one, disposed on the front panel of the computer device 1600; in other embodiments, the display screen 1605 may be at least two, respectively disposed on different surfaces of the computer device 1600 or in a folded design; in other embodiments, display 1605 may be a flexible display disposed on a curved surface or a folded surface of computer device 1600. Even more, the display screen 1605 may be arranged in an irregular pattern other than rectangular, i.e., a shaped screen. The display 1605 may be made of LCD (Liquid Crystal Display ), OLED (Organic Light-Emitting Diode) or other materials.

The camera assembly 1606 is used to capture images or video. Optionally, camera assembly 1606 includes a front camera and a rear camera. Typically, the front camera is disposed on a front panel of the computer device and the rear camera is disposed on a rear surface of the computer device. In some embodiments, the at least two rear cameras are any one of a main camera, a depth camera, a wide-angle camera and a tele camera, so as to realize that the main camera and the depth camera are fused to realize a background blurring function, and the main camera and the wide-angle camera are fused to realize a panoramic shooting and Virtual Reality (VR) shooting function or other fusion shooting functions. In some embodiments, camera assembly 1606 may also include a flash. The flash lamp can be a single-color temperature flash lamp or a double-color temperature flash lamp. The dual-color temperature flash lamp refers to a combination of a warm light flash lamp and a cold light flash lamp, and can be used for light compensation under different color temperatures.

Audio circuitry 1607 may include a microphone and a speaker. The microphone is used for collecting sound waves of users and environments, converting the sound waves into electric signals, and inputting the electric signals to the processor 1601 for processing, or inputting the electric signals to the radio frequency circuit 1604 for voice communication. For purposes of stereo acquisition or noise reduction, the microphone may be multiple, each disposed at a different location of the computer device 1600. The microphone may also be an array microphone or an omni-directional pickup microphone. The speaker is used to convert electrical signals from the processor 1601 or the radio frequency circuit 1604 into sound waves. The speaker may be a conventional thin film speaker or a piezoelectric ceramic speaker. When the speaker is a piezoelectric ceramic speaker, not only the electric signal can be converted into a sound wave audible to humans, but also the electric signal can be converted into a sound wave inaudible to humans for ranging and other purposes. In some embodiments, audio circuitry 1607 may also include a headphone jack.

The location component 1608 is used to locate the current geographic location of the computer device 1600 to enable navigation or LBS (Location Based Service, location based services). The positioning component 1608 may be a positioning component based on the United states GPS (Global Positioning System ), the Beidou system of China, or the Galileo system of Russia.

A power supply 1609 is used to power the various components in the computer device 1600. The power supply 1609 may be an alternating current, a direct current, a disposable battery, or a rechargeable battery. When the power supply 1609 includes a rechargeable battery, the rechargeable battery may be a wired rechargeable battery or a wireless rechargeable battery. The wired rechargeable battery is a battery charged through a wired line, and the wireless rechargeable battery is a battery charged through a wireless coil. The rechargeable battery may also be used to support fast charge technology.

In some embodiments, computer device 1600 also includes one or more sensors 1610. The one or more sensors 1610 include, but are not limited to: acceleration sensor 1611, gyroscope sensor 1612, pressure sensor 1613, fingerprint sensor 1614, optical sensor 1615, and proximity sensor 1616.

The acceleration sensor 1611 may detect the magnitudes of accelerations on three coordinate axes of a coordinate system established with the computer device 1600. For example, the acceleration sensor 1611 may be used to detect components of gravitational acceleration in three coordinate axes. The processor 1601 may control the display screen 1605 to display a user interface in a landscape view or a portrait view based on the gravitational acceleration signal acquired by the acceleration sensor 1611. The acceleration sensor 1611 may also be used for acquisition of motion data of a game or a user.

The gyro sensor 1612 may detect a body direction and a rotation angle of the computer device 1600, and the gyro sensor 1612 may collect 3D motion of the user to the computer device 1600 in cooperation with the acceleration sensor 1611. The processor 1601 may implement the following functions based on the data collected by the gyro sensor 1612: motion sensing (e.g., changing UI according to a tilting operation by a user), image stabilization at shooting, game control, and inertial navigation.

Pressure sensor 1613 may be disposed on a side frame of computer device 1600 and/or on an underlying layer of display 1605. When the pressure sensor 1613 is disposed on a side frame of the computer device 1600, a grip signal of the computer device 1600 by a user may be detected, and the processor 1601 performs a left-right hand recognition or a shortcut operation according to the grip signal collected by the pressure sensor 1613. When the pressure sensor 1613 is disposed at the lower layer of the display screen 1605, the processor 1601 performs control on an operability control on the UI interface according to a pressure operation of the display screen 1605 by a user. The operability controls include at least one of a button control, a scroll bar control, an icon control, and a menu control.

The fingerprint sensor 1614 is used to collect a fingerprint of a user, and the processor 1601 identifies the identity of the user based on the fingerprint collected by the fingerprint sensor 1614, or the fingerprint sensor 1614 identifies the identity of the user based on the collected fingerprint. Upon recognizing that the user's identity is a trusted identity, the processor 1601 authorizes the user to perform related sensitive operations including unlocking the screen, viewing encrypted information, downloading software, paying for and changing settings, etc. The fingerprint sensor 1614 may be disposed on the front, back, or side of the computer device 1600. When a physical key or vendor Logo is provided on the computer device 1600, the fingerprint sensor 1614 may be integrated with the physical key or vendor Logo.

The optical sensor 1615 is used to collect ambient light intensity. In one embodiment, the processor 1601 may control the display brightness of the display screen 1605 based on the ambient light intensity collected by the optical sensor 1615. Specifically, when the intensity of the ambient light is high, the display brightness of the display screen 1605 is turned up; when the ambient light intensity is low, the display brightness of the display screen 1605 is turned down. In another embodiment, the processor 1601 may also dynamically adjust the capture parameters of the camera module 1606 based on the ambient light intensity collected by the optical sensor 1615.

A proximity sensor 1616, also referred to as a distance sensor, is typically provided at the front panel of the computer device 1600. The proximity sensor 1616 is used to collect distance between the user and the front of the computer device 1600. In one embodiment, when the proximity sensor 1616 detects a gradual decrease in the distance between the user and the front of the computer device 1600, the processor 1601 controls the display 1605 to switch from the on-screen state to the off-screen state; when the proximity sensor 1616 detects that the distance between the user and the front of the computer device 1600 gradually increases, the processor 1601 controls the display 1605 to switch from the off-screen state to the on-screen state.

Those skilled in the art will appreciate that the architecture shown in fig. 16 is not limiting as to the computer device 1600, and may include more or fewer components than shown, or may combine certain components, or employ a different arrangement of components.

In another aspect, a computer readable storage medium is provided, in which at least one instruction is stored, the at least one instruction being loaded and executed by a processor to implement operations performed by a method for wellbore trajectory correction for a horizontal well according to any one of the above implementations.

In some embodiments, the computer program related to the embodiments of the present application may be deployed to be executed on one computer device or on multiple computer devices located at one site, or on multiple computer devices distributed across multiple sites and interconnected by a communication network, where the multiple computer devices distributed across multiple sites and interconnected by a communication network may constitute a blockchain system.

The foregoing description of the preferred embodiments is merely exemplary in nature and is in no way intended to limit the invention, since it is intended that all modifications, equivalents, improvements, etc. that fall within the spirit and scope of the invention.

Claims

1. A method of wellbore trajectory correction for a horizontal well, the method comprising:

2. The method of borehole trajectory correction for a horizontal well according to claim 1, wherein said determining a lithology type and a lithology type of the drilling formation based on the second log, the second contrast map, the while-drilling curve, and the while-drilling interpretation curve comprises:

3. The method of correcting a borehole trajectory of a horizontal well according to claim 1, wherein the adjusting the borehole trajectory of the target well to align the borehole trajectory with the target reservoir based on a difference between a lithofacies type and a pen stone type of the drilling formation and the target lithofacies type and the target pen stone type comprises:

4. The method of wellbore trajectory correction for a horizontal well of claim 1, wherein the method further comprises:

5. The method of wellbore trajectory correction for a horizontal well of claim 4, wherein the facies segment parameters comprise facies type and brittleness index, and the chemical element parameters comprise chemical element parameters of a plurality of facies segments;

6. The method of wellbore trajectory correction for a horizontal well according to claim 1, wherein the determining a target reservoir for the reservoir under investigation based on chemical element parameters of each formation of the reservoir under investigation comprises:

7. The method of wellbore trajectory correction for a horizontal well according to claim 1, wherein the chemical element parameters comprise chemical element parameters for each formation of the reservoir under investigation, the determining a lithogram of the reservoir under investigation based on the chemical element parameters comprising:

8. A wellbore trajectory correction device for a horizontal well, the device comprising:

9. A computer device comprising one or more processors and one or more memories having stored therein at least one instruction loaded and executed by the one or more processors to perform the operations performed by the method of wellbore trajectory correction for a horizontal well of any of claims 1 to 7.

10. A computer readable storage medium having stored therein at least one instruction loaded and executed by a processor to perform the operations performed by the method of borehole trajectory correction for a horizontal well as claimed in any one of claims 1 to 7.