JP6604093B2 - Oil well pipe - Google Patents

Description

  The present disclosure relates to an oil well pipe, and more particularly to an oil well pipe connected to another oil well pipe directly or via a coupling.

Conventionally, martensitic stainless steel has been widely used in oil well environments. Conventional oil well environments contain carbon dioxide (CO ₂ ) and / or chlorine ions (Cl ⁻ ). Martensitic stainless steel (hereinafter referred to as 13% Cr steel) containing about 13% by mass of Cr has excellent corrosion resistance in such a conventional oil well environment.

In recent years, deep oil wells have been developed due to soaring crude oil prices. Deep oil wells are deep. And deep oil wells are highly corrosive and hot. More specifically, the deep well contains a hot corrosive gas. Corrosive gases, CO ₂ and / or Cl ^- containing, further, sometimes containing hydrogen sulfide gas. Corrosion reactions at high temperatures are more severe than those at normal temperatures. Therefore, oil well steel used for deep oil wells is required to have higher strength and corrosion resistance than 13% Cr steel.

  Here, duplex stainless steel has a higher Cr content than 13% Cr steel. Therefore, duplex stainless steel has higher corrosion resistance than 13% Cr steel. Examples of the duplex stainless steel include 22% Cr steel containing 22% Cr and 25% Cr steel containing 25% Cr. However, duplex stainless steel is expensive because it contains many alloying elements. Accordingly, there is a need for stainless steel that has higher corrosion resistance than 13% Cr steel and is less expensive than duplex stainless steel.

  In response to this requirement, stainless steel containing 15.5-18% Cr and having high corrosion resistance in a high temperature oil well environment has been proposed. Japanese Patent Laying-Open No. 2005-336595 (Patent Document 1) proposes a stainless steel pipe having high strength and having carbon dioxide corrosion resistance in a high temperature environment of 230 ° C. The chemical composition of this steel pipe contains 15.5-18% Cr, 1.5-5% Ni and 1-3.5% Mo, Cr + 0.65Ni + 0.6Mo + 0.55Cu-20C ≧ 19.5 is satisfied, and Cr + Mo + 0.3Si-43.5C-0.4Mn-Ni-0.3Cu-9N ≧ 11.5 is satisfied. The metal structure of this steel pipe contains 10 to 60% of a ferrite phase and 30% or less of an austenite phase, and the balance consists of a martensite phase.

  International Publication No. 2010/050519 (Patent Document 2) has corrosion resistance in a high-temperature carbon dioxide gas environment at 200 ° C., and further, the recovery of crude oil or gas temporarily stops the environment temperature of the oil well or gas well. We propose a stainless steel pipe with high resistance to sulfide stress corrosion cracking even when the resistance decreases. The chemical composition of this steel pipe contains more than 16% to 18% Cr, more than 2% to 3% Mo, 1 to 3.5% Cu, and less than 3 to 5% Ni. Mn] × ([N] −0.0045) ≦ 0.001 is satisfied. The metal structure of the steel pipe contains a ferrite phase of 10 to 40% by volume and a residual austenite phase of 10% or less, and the balance is a martensite phase.

  International Publication No. 2010/134498 (Patent Document 3) proposes a high-strength stainless steel having excellent corrosion resistance in a high temperature environment and excellent SSC resistance at room temperature. The chemical composition of this steel is over 16% to 18% Cr, 1.6 to 4.0% Mo, 1.5 to 3.0 Cu, and over 4.0 to 5.6%. Ni is contained, Cr + Cu + Ni + Mo ≧ 25.5 is satisfied, and −8 ≦ 30 (C + N) + 0.5Mn + Ni + Cu / 2 + 8.2-1.1 (Cr + Mo) ≦ −4 is satisfied. The metal structure of this steel contains a martensite phase, 10 to 40% ferrite phase, and a retained austenite phase, and the ferrite phase distribution ratio is higher than 85%.

  By the way, in the high Cr stainless steel containing 15.5 to 18% Cr disclosed in these documents, the low temperature toughness may be insufficient. Japanese Patent Application Laid-Open No. 2010-209402 (Patent Document 4) proposes a high-strength stainless steel pipe for oil wells having excellent low-temperature toughness. This steel pipe contains 15.5 to 17.5% of Cr, and the largest one among the crystal grains in the microstructure has a distance between any two points in the crystal grain of 200 μm or less (in other words, In this case, the crystal grain size is 200 μm or less). In addition, in International Publication No. 2013/179667 (Patent Document 5), a GSI value defined as the number of ferrite-martensite grain boundaries existing per unit length of a line segment drawn in the thickness direction is a thickness. It is described that it has excellent corrosion resistance and low temperature toughness by having a structure of 120 or more in the center.

  Steel pipes called oil well pipes are used for exploration, trial drilling, or production of oil wells, natural gas wells, and the like (hereinafter collectively referred to as oil wells). Generally, oil well pipes are connected to each other by screw joints and installed in oil wells.

  In the development of the oil well, first, the work of making a pilot hole is carried out. That is, a well is drilled using a drill pipe and a drill bit. When the well reaches a certain depth, the drill pipe is once pulled out, and a large-diameter oil well pipe called a casing pipe is buried to reinforce the well wall. Then use the drill pipe again to dig deeper inside the well. After repeating these operations several times and finally reaching the product reservoir, an oil well pipe for pumping called a tubing pipe is installed inside the well. This completes the development of the oil well.

  In order to develop deep oil wells by the above procedure, casing pipes are installed in multiple layers. Of these casing pipes, the outermost pipe is usually the largest diameter and the shallowest. The casing pipe arranged on the inner side has a smaller diameter and a deeper depth. The structure of the underground casing pipe (string design) varies from oil well to well, but in general, the outermost multi-layered casing pipe is the conductor, the surface casing, the intermediate casing, and the production casing as it goes inward. Called. An oil well pipe called a liner may be inserted between these casings.

  In recent years, a well development technique called “Drilling with Casing (abbreviated as DwC)” is becoming widespread in order to improve the efficiency of well development and excavation in soft ground. In DwC, drilling is not performed using a drill pipe, but drilling is performed using a pipe having a drill bit attached to the tip. After excavation is completed, the pipe is buried without being pulled up. As a result, the operation of pulling out the drill pipe once and inserting the casing pipe can be omitted, and the pipe used for excavation can be directly installed as the casing pipe. For this reason, even if it is soft ground, there is no possibility that a well wall will collapse.

JP 2005-336595 A International Publication No. 2010/050519 International Publication No. 2010/134498 JP 2010-209402 A International Publication No. 2013/179667

  Conventionally, DwC has been applied around a surface casing having a relatively shallow depth. However, in recent years, since deeper excavation has become possible due to the development of excavation technology, the movement of applying DwC to intermediate casings or production casings is becoming widespread.

  Until now, the oil well pipe used in DwC has been mainly made of carbon steel of API (American Petroleum Institute) standard. However, as the depth of the oil well increases, corrosive gases such as carbon dioxide and hydrogen sulfide increase. As for oil well pipes used in DwC, high corrosion resistance is required as the depth of excavation increases.

  Furthermore, when performing DwC, dynamic rotary bending is loaded for a long time on the oil well pipe and the threaded joint connecting them at the bent portion of the underground well. For this reason, particularly in threaded joints, fatigue resistance, which has been hardly required in the past, has been demanded.

  An object of the present disclosure is to provide an oil well pipe having high corrosion resistance and fatigue resistance.

The oil well pipe according to the present disclosure is made of stainless steel. The oil well pipe is connected to another oil well pipe directly or through a coupling. Stainless steel has a chemical composition of mass%, C: 0.001 to 0.06%, Si: 0.05 to 0.5%, Mn: 0.01 to 2.0%, P: 0.03. % Or less, S: less than 0.005%, Cr: 15.5 to 18.0%, Ni: 2.5 to 6.0%, V: 0.005 to 0.25%, Al: 0.05% Hereinafter, N: 0.06% or less, O: 0.01% or less, Cu: 0 to 3.5%, Co: 0 to 1.5%, Nb: 0 to 0.25%, Ti: 0 to 0 .25%, Zr: 0 to 0.25%, Ta: 0 to 0.25%, B: 0 to 0.005%, Ca: 0 to 0.01%, Mg: 0 to 0.01%, and REM: 0 to 0.05% is contained. The stainless steel further contains one or two selected from the group consisting of Mo: 0 to 3.5% and W: 0 to 3.5% in a range satisfying the formula (1). The balance of stainless steel consists of Fe and impurities. The matrix structure has a volume ratio of 40 to 70% tempered martensite phase, 10 to 50% ferrite phase, and 1 to 15% austenite phase. A 1 mm × 1 mm microstructure image obtained by photographing a matrix structure at a magnification of 100 times is arranged in an xy coordinate system in which the thickness direction is the x axis and the length direction is the y axis, and is 1024 × 1024. When each pixel is expressed in gray scale, β defined by Equation (2) is 1.55 or more.
1.0 ≦ Mo + 0.5W ≦ 3.5 (1)

Here, Mo and W are Mo and W content (mass%).

However, in Formula (2), Su is defined by Formula (3), and Sv is defined by Formula (4).

In the equations (3) and (4), F (u, v) is defined by the equation (5).

  In equation (5), f (x, y) represents the gradation of the pixel at coordinates (x, y).

  The oil well pipe according to the present disclosure includes a pipe main body and a pin. The pin is continuously formed on at least one end of the tube body. The pin includes a male screw portion formed on the outer periphery thereof. The pin is inserted into another oil well tube box or coupling box. The male thread portion includes a plurality of thread valley bottom surfaces and a plurality of load flank surfaces as viewed in a cross section in a plane including the tube axis. The plurality of load flank surfaces are provided corresponding to the plurality of screw valley bottom surfaces. Each of the plurality of load flank surfaces is connected to a corresponding one thread valley bottom surface through an arc surface. Each arc surface has a radius of curvature of 0.3 mm or more.

  According to the oil well pipe according to the present disclosure, high corrosion resistance and fatigue resistance can be ensured.

FIG. 1 is a microstructure image showing an example of a microstructure of stainless steel for oil country tubular goods according to an embodiment. FIG. 2 is a logarithmic frequency spectrum diagram obtained by two-dimensional discrete Fourier transform of the microstructure image of FIG. FIG. 3 is a photograph showing an example of the microstructure of a stainless steel as a comparative example. FIG. 4 is a logarithmic frequency spectrum diagram obtained by two-dimensional discrete Fourier transform of the microstructure image of FIG. FIG. 5 is a microstructure image showing an example of the microstructure of stainless steel for oil country tubular goods according to the embodiment. FIG. 6 is a logarithmic frequency spectrum diagram obtained by two-dimensional discrete Fourier transform of the microstructure image of FIG. FIG. 7 is a photograph showing an example of a microstructure of stainless steel as a comparative example. FIG. 8 is a logarithmic frequency spectrum diagram obtained by two-dimensional discrete Fourier transform of the microstructure image of FIG. FIG. 9 is a graph showing the relationship between β and the ductile brittle transition temperature. FIG. 10 is a view showing a longitudinal section of one end portion in the pipe axis direction of the oil well pipe used for the examination of the structure. FIG. 11 is a graph showing the relationship between the stress concentration factor and the radius of curvature with respect to the circular arc surface connecting the thread valley bottom surface of the male screw portion and the load surface. FIG. 12 is a partial cross-sectional view of an oil well pipe according to an embodiment. FIG. 13 is a view showing a longitudinal section of one end portion of the oil well pipe shown in FIG. 12 in the tube axis direction. FIG. 14 is an enlarged view of the XIV portion of the complete thread portion shown in FIG. FIG. 15 is an enlarged view of the XV portion of the incomplete thread portion shown in FIG. FIG. 16 is a partial cross-sectional view of an oil well pipe having a structure different from that shown in FIG. FIG. 17 is a graph showing the relationship between β and the fatigue limit. FIG. 18 is a graph showing the relationship between the radius of curvature of the arc surface connecting the thread valley bottom surface and the load surface and the fatigue limit. FIG. 19 is a diagram showing the relationship between the distance from the tip of the pin and the stress concentration at each thread valley bottom of the male thread in the oil country tubular goods according to each example and comparative example.

<1. About Oil Well Pipe Materials>
The oil well pipe according to the embodiment is made of stainless steel. Hereinafter, stainless steel used as the material of the oil well pipe according to the embodiment will be described.

  The matrix structure of stainless steel includes a ferrite phase, a tempered martensite phase, and an austenite phase (hereinafter referred to as a substantial martensite phase). In the matrix structure, when the ferrite phase and the substantial martensite phase extend along the rolling direction (length direction) and are arranged in layers, the stainless steel is excellent in low temperature toughness. On the other hand, when the ferrite phase is irregularly distributed like a network in the matrix structure, the low temperature toughness of stainless steel is low. When stainless steel is a steel plate, the central axis of the steel plate extended by rolling is defined as the rolling direction. When stainless steel is a steel pipe, the central axis of the steel pipe is the rolling direction.

  Here, the present inventors perform a two-dimensional discrete Fourier transform of a microstructure image, a microstructure microstructure, characterized in that the ferrite phase and the substantial martensite phase of stainless steel extend long in the length direction. Thus, it was found that both the thickness direction and the length direction can be evaluated and quantified. Hereinafter, this point will be described in detail.

  From a cross section perpendicular to the plate width direction of stainless steel, a microstructure image having an observation magnification of 100 times and a size of 1 mm × 1 mm is obtained by using an optical microscope in gray scale (256 gradations). An example of the microstructure image is shown in FIG. In FIG. 1, the microstructure image is arranged in the xy coordinate system. The y-axis in FIG. 1 is the length direction, and the x-axis is the thickness direction perpendicular to the length direction. In FIG. 1, the gray portion is the substantial martensite phase, and the white portion located between the grains of the substantial martensite phase is the ferrite phase. The microstructure image has M = 1024 pixels in the x-axis direction and N = 1024 pixels in the y-axis direction. That is, the microstructure image has the number of pixels of M × N = 1024 × 1024.

Two-dimensional data f (x, y) of each pixel (x, y) (x = 0 to M−1, y = 0 to N−1) is obtained from the microstructure image. f (x, y) represents the gray scale of the pixel at the coordinate (x, y). A two-dimensional discrete Fourier transform (2D DFT) defined by equation (5) is performed on the obtained two-dimensional data. M-1 = 1023 and N-1 = 1023.

  Here, F (u, v) is a two-dimensional frequency spectrum after two-dimensional discrete Fourier transform of the two-dimensional data f (x, y). The frequency spectrum F (u, v) is generally a complex number and includes information on the periodicity and regularity of the two-dimensional data f (x, y). In other words, the frequency spectrum F (u, v) includes information on the periodicity and regularity of the structure of the ferrite phase and the substantial martensite phase in the microstructure image as shown in FIG.

  FIG. 2 is a logarithmic frequency spectrum diagram of the microstructure image shown in FIG. The horizontal axis in FIG. 2 is the v-axis, and the vertical axis is the u-axis. The frequency spectrum diagram of FIG. 2 is a black and white gradation image (grayscale image), where the maximum value of the frequency spectrum is white and the minimum value is black. For example, in the case of FIG. 2, the portion having a high frequency spectrum (white portion in FIG. 2) has a shape extending on the u axis, and the boundary is not clear.

Here, in the frequency spectrum F (u, v) of the frequency spectrum diagram, the sum Su of the absolute values of the spectrum on the u-axis is defined by Expression (3). In the frequency spectrum F (u, v), the sum Sv of the absolute values of the spectrum on the v-axis is defined by Expression (4). Furthermore, the ratio of Su to Sv is β defined by equation (2). Note that Su and Sv do not include the spectral intensity at coordinates (0, 0) in the (u, v) space.

  Moreover, the microstructure image of the stainless steel shown in FIGS. Further, a logarithmic frequency spectrum diagram is obtained from each of the microstructure images shown in FIGS. 4 is a logarithmic frequency spectrum diagram of the microstructure image shown in FIG. 3, FIG. 6 is a logarithmic frequency spectrum diagram of the microstructure image shown in FIG. 5, and FIG. 8 is a diagram of the microstructure image shown in FIG. It is a logarithmic frequency spectrum diagram. Hereinafter, the microstructure shown in FIG. 1 is referred to as organization 1, the microstructure shown in FIG. 3 is referred to as organization 2, the microstructure shown in FIG. 5 is referred to as organization 3, and the microstructure shown in FIG. Four.

  Comparing the image of the structure 1 (FIG. 1) and the image of the structure 2 (FIG. 3), the structure 1 has a shape in which the ferrite phase and the substantial martensite phase extend in the rolling direction (length direction) more than the structure 2. . Further, the structure 1 is regular and has a shorter lamination period (period aligned in the thickness direction) of the ferrite phase and the substantial martensite phase than the structure 2. Comparing the image of the tissue 1 and the image of the tissue 3 (FIG. 5), each of the tissue 1 and the tissue 3 has a shape in which each phase extends in the length direction. Furthermore, the structure 3 has a short lamination period and is regular like the structure 1. Comparing the image of the tissue 3 and the image of the tissue 4 (FIG. 7), the tissue 3 has a shape in which each phase extends in the length direction as compared with the tissue 4. Furthermore, the structure 3 has a shorter lamination cycle than the structure 4 and is regular.

  Moreover, as for the logarithmic frequency spectrum figure of each structure | tissue 1-structure | tissue 4, the white part extends along u axis | shaft. However, the tissue 1 and the tissue 4 have a narrower white portion in the v-axis direction than the tissue 2 and the tissue 4. As for β, the structure 1 is 2.024, the structure 2 is 1.458, the structure 3 is 2.183, and the structure 4 is 1.395. In short, the lower β is, the shorter the white portion is in the u-axis direction and the v-axis direction is expanded.

Further, the transition temperature of ductile brittleness is that the structure 1 is −82 ° C., the structure 2 is −12 ° C., the structure 3 is −109 ° C., and the structure 4 is −19 ° C. The transition temperature is the result under the same conditions as in the examples described later. FIG. 9 is a diagram showing the relationship between β and the transition temperature (° C.). FIG. 9 was obtained by the following method. The chemical composition is within the range of this embodiment described later, and a plurality of stainless steels having different βs were produced. Each stainless steel was subjected to a low-temperature toughness evaluation test described later to obtain a transition temperature, and FIG. 9 was created. The straight line in FIG. 9 is a line obtained by the least square method from all the plots in FIG. 9, and R ² is a correlation function.

  Thus, it turned out that there exists a tendency which is excellent in low-temperature toughness, when (beta) becomes large. From the above, it can be considered that β indicates the degree of layering.

  Based on the above findings, the present inventors have completed stainless steel used in the oil well pipe according to the embodiment. Hereinafter, the stainless steel will be described.

The stainless steel for oil country tubular goods according to the embodiment has a chemical composition of mass%, C: 0.001 to 0.06%, Si: 0.05 to 0.5%, Mn: 0.01 to 2.0. %, P: 0.03% or less, S: less than 0.005%, Cr: 15.5 to 18.0%, Ni: 2.5 to 6.0%, V: 0.005 to 0.25% Al: 0.05% or less, N: 0.06% or less, O: 0.01% or less, Cu: 0 to 3.5%, Co: 0 to 1.5%, Nb: 0 to 0.25 %, Ti: 0 to 0.25%, Zr: 0 to 0.25%, Ta: 0 to 0.25%, B: 0 to 0.005%, Ca: 0 to 0.01%, Mg: 0 -0.01%, and REM: 0-0.05% is contained. Furthermore, 1 type or 2 types selected from the group which consists of Mo: 0-3.5% and W: 0-3.5% are contained in the range with which Formula (1) is satisfy | filled. The balance consists of Fe and impurities. The matrix structure has a volume ratio of 40 to 70% tempered martensite phase, 10 to 50% ferrite phase, and 1 to 15% austenite phase. A 1 mm × 1 mm microstructure image obtained by photographing a matrix structure at a magnification of 100 times is arranged in an xy coordinate system in which the thickness direction is the x axis and the length direction is the y axis, and is 1024 × 1024. When each pixel is expressed in gray scale, β defined by Equation (2) is 1.55 or more.
1.0 ≦ Mo + 0.5W ≦ 3.5 (1)

Here, Mo and W are Mo and W content (mass%).

However, in Formula (2), Su is defined by Formula (3), and Sv is defined by Formula (4).

In the equations (3) and (4), F (u, v) is defined by the equation (5).

  In equation (5), f (x, y) represents the gradation of the pixel at coordinates (x, y).

  This stainless steel has a ductile brittle transition temperature of −30 ° C. or lower because β is 1.55 or more. As a result, this stainless steel is excellent in low temperature toughness. Furthermore, this stainless steel has high strength and is excellent in SCC resistance at high temperature and SSC resistance at room temperature.

  The chemical composition of the stainless steel is 1% or 2% selected from the group consisting of Cu: 0.2-3.5% and Co: 0.05-1.5% in mass%. Also good.

  The chemical composition of the stainless steel is mass%, Nb: 0.01 to 0.25%, Ti: 0.01 to 0.25%, Zr: 0.01 to 0.25%, and Ta: 0.00. You may contain 1 type, or 2 or more types selected from the group which consists of 01-0.25%.

  The chemical composition of the stainless steel is, by mass, B: 0.0003 to 0.005%, Ca: 0.0005 to 0.01%, Mg: 0.0005 to 0.01%, and REM: 0.00. You may contain 1 type, or 2 or more types selected from the group which consists of 0005-0.05%.

[Chemical composition]
The stainless steel for oil country tubular goods according to the embodiment has the following chemical composition. Hereinafter, “%” related to an element means mass%.

C: 0.001 to 0.06%
Carbon (C) increases the strength of the steel. However, if there is too much C content, the hardness after tempering will become high too much and SSC resistance will fall. Furthermore, in the chemical composition of the present embodiment, the Ms point decreases as the C content increases. Therefore, as the C content increases, austenite tends to increase and yield strength tends to decrease. Therefore, the C content is 0.06% or less. The C content is preferably 0.05% or less, and more preferably 0.03% or less. Moreover, if the cost concerning the decarburization process in a steelmaking process is considered, C content is 0.001% or more. The C content is preferably 0.003% or more, and more preferably 0.005% or more.

Si: 0.05-0.5%
Silicon (Si) deoxidizes steel. However, if there is too much Si content, the toughness and hot workability of steel will fall. If the Si content is too large, the amount of ferrite produced further increases and the yield strength tends to decrease. Therefore, the Si content is 0.05 to 0.5%. The Si content is preferably less than 0.5%, more preferably 0.4% or less. The Si content is preferably 0.06% or more, and more preferably 0.07% or more.

Mn: 0.01 to 2.0%
Manganese (Mn) deoxidizes and desulfurizes steel and improves hot workability. If the Mn content is too small, the above effect cannot be obtained effectively. On the other hand, if the Mn content is too high, austenite tends to remain excessively during quenching, and it becomes difficult to ensure the strength of the steel. Therefore, the Mn content is 0.01 to 2.0%. The Mn content is preferably 1.0% or less, and more preferably 0.6% or less. The Mn content is preferably 0.02% or more, and more preferably 0.04% or more.

P: 0.03% or less Phosphorus (P) is an impurity. P decreases the SSC resistance of the steel. Therefore, it is preferable that the P content is as small as possible. The P content is 0.03% or less. The P content is preferably 0.028% or less, more preferably 0.025% or less. Moreover, although it is preferable to reduce P content as much as possible, extreme reduction leads to the increase in steelmaking cost. Therefore, the P content is preferably 0.0005% or more, and more preferably 0.0008% or more.

S: Less than 0.005% Sulfur (S) is an impurity. S decreases the hot workability of steel. Therefore, it is preferable that the S content is as small as possible. The S content is less than 0.005%. The S content is preferably 0.003% or less, and more preferably 0.0015% or less. Moreover, although it is preferable to reduce S content as much as possible, extreme reduction invites the increase in steelmaking cost. Therefore, the S content is preferably 0.0001% or more, and more preferably 0.0003% or more.

Cr: 15.5 to 18.0%
Chromium (Cr) increases the corrosion resistance of steel. Specifically, Cr lowers the corrosion rate and increases the SCC resistance of the steel. If the C content is too small, the above effect cannot be obtained effectively. On the other hand, if there is too much Cr content, the volume fraction of the ferrite phase in steel will increase and the strength of steel will fall. Therefore, the Cr content is 15.5 to 18.0%. The Cr content is preferably 17.8% or less, and more preferably 17.5% or less. The Cr content is preferably 16.0% or more, and more preferably 16.3% or more.

Ni: 2.5-6.0%
Nickel (Ni) increases the toughness of the steel. Ni further increases the strength of the steel. If the Ni content is too small, the above effect cannot be obtained effectively. On the other hand, if the Ni content is too large, a large amount of austenite is generated, and as a result, the strength of the steel decreases. Therefore, the Ni content is 2.5 to 6.0%. The Ni content is preferably less than 6.0%, and more preferably 5.9% or less. The Ni content is preferably 3.0% or more, and more preferably 3.5% or more.

V: 0.005-0.25%
Vanadium (V) increases the strength of the steel. However, if there is too much V content, toughness will fall. Therefore, the V content is 0.005 to 0.25%. V content becomes like this. Preferably it is 0.20% or less, More preferably, it is 0.15% or less. V content becomes like this. Preferably it is 0.008% or more, More preferably, it is 0.01% or more.

Al: 0.05% or less Aluminum (Al) deoxidizes steel. However, when there is too much Al content, the inclusion in steel will increase and the toughness of steel will fall. Therefore, the upper limit is made 0.05%. The Al content is preferably 0.048% or less, and more preferably 0.045% or less. The Al content is preferably 0.0005% or more, and more preferably 0.001% or more.

N: 0.06% or less Nitrogen (N) increases the strength of steel. However, if there is too much N content, austenite will produce | generate excessively and the inclusion in steel will also increase. As a result, the toughness of the steel is reduced. Therefore, the N content is 0.06% or less. N content is 0.05% or less, More preferably, it is 0.03% or less. The N content is preferably reduced as much as possible, but extreme reduction leads to an increase in steelmaking costs. Therefore, the N content is preferably 0.001% or more, and more preferably 0.002% or more.

O: 0.01% or less Oxygen (O) is an impurity. O reduces the toughness and corrosion resistance of steel. Therefore, the O content is 0.01% or less. The O content is preferably less than 0.01%, more preferably 0.009% or less, and still more preferably 0.006% or less. The O content is preferably reduced as much as possible, but extreme reduction leads to an increase in steelmaking costs. Therefore, the O content is preferably 0.0001% or more, and more preferably 0.0003% or more.

Mo: 0 to 3.5%, W: 0 to 3.5%
Molybdenum (Mo) and tungsten (W) are elements that can be substituted for each other, and may contain both or only one. It is essential that Mo and W contain at least one. These elements increase the SCC resistance of the steel. On the other hand, if there is too much content of these elements, the effect will be saturated. Therefore, Mo content is 0-3.5%, W content is 0-3.5%, and 1 type or 2 types selected from the group which consists of Mo and W satisfy | fills Formula (1). It is necessary to contain in the range. Mo content becomes like this. Preferably it is 3.3% or less, More preferably, it is 3.0% or less. Mo content becomes like this. Preferably it is 0.01% or more, More preferably, it is 0.03% or more. W content becomes like this. Preferably it is 3.3% or less, More preferably, it is 3.0% or less. The W content is preferably 0.01% or more, and more preferably 0.03% or more.
1.0 ≦ Mo + 0.5W ≦ 3.5 (1)

  The chemical composition of the stainless steel according to this embodiment may contain the following selective elements. That is, none of the following elements may be contained in the stainless steel according to the present embodiment. Moreover, only a part may be contained.

Cu: 0 to 3.5%, Co: 0 to 1.5%
Copper (Cu) and cobalt (Co) are mutually replaceable elements. These elements are selective elements. These elements increase the volume fraction of the tempered martensite phase and increase the strength of the steel. Furthermore, Cu precipitates as Cu particles during tempering and further increases its strength. If the content of these elements is too small, the above effects cannot be obtained effectively. On the other hand, if there is too much content of these elements, the hot workability of steel will fall. Therefore, the Cu content is 0 to 3.5%, and the Co content is 0 to 1.5%. Further, in order to sufficiently obtain the above effect, it may contain one or two selected from the group consisting of Cu: 0.2 to 3.5% and Co: 0.05 to 1.5%. preferable. Cu content becomes like this. Preferably it is 3.3% or less, More preferably, it is 3.0% or less. The Cu content is preferably 0.3% or more, and more preferably 0.5% or more. The Co content is preferably 1.0% or less, and more preferably 0.8% or less. The Co content is preferably 0.08% or more, and more preferably 0.1% or more.

Nb: 0 to 0.25%, Ti: 0 to 0.25%, Zr: 0 to 0.25% and Ta: 0 to 0.25%
Niobium (Nb), titanium (Ti), zirconium (Zr), and tantalum (Ta) are mutually replaceable elements. These elements are selective elements. These elements increase the strength of the steel. These elements improve the pitting corrosion resistance and SCC resistance of steel. If these elements are contained even a little, the above effect can be obtained. However, if there is too much content of these elements, the toughness of steel will fall. Therefore, the Nb content is 0 to 0.25%, the Ti content is 0 to 0.25%, the Zr content is 0 to 0.25%, and the Ta content is 0 to 0.25. %. Furthermore, in order to sufficiently obtain the above effects, Nb: 0.01 to 0.25%, Ti: 0.01 to 0.25%, Zr: 0.01 to 0.25%, and Ta: 0.00. It is preferable to contain 1 type or 2 types selected from the group which consists of 01-0.25%. The Nb content is preferably 0.23% or less, more preferably 0.20% or less. The Nb content is preferably 0.02% or more, more preferably 0.05% or more. The Ti content is preferably 0.23% or less, and more preferably 0.20% or less. The Ti content is preferably 0.02% or more, and more preferably 0.05% or more. The Zr content is preferably 0.23% or less, and more preferably 0.20% or less. The Zr content is preferably 0.02% or more, more preferably 0.05% or more. The Ta content is preferably 0.24% or less, and more preferably 0.23% or less. The Ta content is preferably 0.02% or more, and more preferably 0.05% or more.

Ca: 0 to 0.01%, Mg: 0 to 0.01%, REM: 0 to 0.05%, and B: 0 to 0.005%
Calcium (Ca), magnesium (Mg), rare earth element (REM), and boron (B) are mutually replaceable elements. These elements are selective elements. These elements improve hot workability during production. If these elements are contained even a little, the above effect can be obtained to some extent. However, if there is too much content of Ca, Mg and REM, it will combine with oxygen to significantly reduce the cleanliness of the alloy and degrade the SSC resistance. Moreover, if there is too much B content, the toughness of steel will be reduced. Therefore, the Ca content is 0 to 0.01%, the Mg content is 0 to 0.01%, the REM content is 0 to 0.05%, and the B content is 0 to 0.005. %. In order to sufficiently obtain the above effects, Ca: 0.0005 to 0.01%, Mg: 0.0005 to 0.01%, REM: 0.0005 to 0.05%, and B: 0.0003 It is preferable to contain 1 type or 2 types selected from the group which consists of -0.005%. The Ca content is preferably 0.008% or less, and more preferably 0.005% or less. The Ca content is preferably 0.0008% or more, and more preferably 0.001% or more. The Mg content is preferably 0.008% or less, and more preferably 0.005% or less. The Mg content is preferably 0.0008% or more, and more preferably 0.001% or more. The REM content is preferably 0.045% or less, and more preferably 0.04% or less. The REM content is preferably 0.0008% or more, and more preferably 0.001% or more. The B content is preferably 0.0045% or less, and more preferably 0.004% or less. The B content is preferably 0.0005% or more, and more preferably 0.0008% or more.

  REM is a general term for a total of 17 elements of scandium (Sc), yttrium (Y), and lanthanoid. In the present embodiment, the REM content means the total content of one or more of the 17 elements described above.

  Note that the balance of the chemical composition of the stainless steel according to the present embodiment is Fe and impurities. An impurity here means the element mixed from the ore and scrap utilized as a raw material, or the element mixed from the environment of a manufacturing process, etc. when manufacturing stainless steel industrially.

[Microstructure]
The matrix structure of the stainless steel according to the present embodiment has a volume ratio of 40 to 70% tempered martensite phase, 10 to 50% ferrite phase, and 1 to 15% austenite phase. Henceforth,% regarding these volume fractions (fraction) of a matrix structure means volume%.

  The volume fraction of the ferrite phase in the matrix structure (ferrite fraction:%), the volume fraction of the austenite phase (austenite fraction:%), and the volume fraction of the tempered martensite phase (martensite fraction:%) are as follows. taking measurement.

[Measurement method of ferrite fraction]
Samples are taken from any location on the stainless steel. The surface of the sample corresponding to the stainless steel cross section (hereinafter referred to as the observation surface) is polished. The polished observation surface is etched using a mixed solution of aqua regia and glycerin. The portion corroded in white by etching is a ferrite phase, and the area ratio of the ferrite phase is measured by a point calculation method based on JIS G0555 (2003). Since the measured area ratio is considered to be equal to the volume fraction of the ferrite phase, this is defined as the ferrite fraction (%).

[Method for measuring austenite fraction]
The austenite fraction is determined using an X-ray diffraction method. A 15 mm × 15 mm × 2 mm sample is taken from any location on the stainless steel. Using samples, the X-ray intensities of the (200) plane and (211) plane of the ferrite phase (α phase), the (200) plane, the (220) plane, and the (311) plane of the austenite phase (γ phase) are measured. Measure and calculate the integrated intensity of each surface. After the calculation, the volume ratio Vγ is obtained by using the following equation (6) for each combination (6 sets in total) of each surface of the α phase and each surface of the γ phase. The average value of the volume fraction Vγ of each surface is defined as the austenite fraction (%).
Vγ = 100 / {1+ (Iα × Rγ) / (Iγ × Rα)} (6)

  Here, Iα is the integrated intensity of the α phase, Rγ is the crystallographic theoretical calculation value of the γ phase, Iγ is the integrated intensity of the γ phase, and Rα is the crystallographic theoretical calculation value of the α phase. .

[Measurement method of martensite fraction]
The remainder of the matrix structure other than the ferrite phase and the austenite phase is defined as the volume ratio (martensite fraction) of the tempered martensite phase. That is, the martensite fraction (%) is a value obtained by subtracting the ferrite fraction (%) and the austenite fraction (%) from 100%.

[Β]
In the stainless steel of the present embodiment, β defined by the formula (2) is 1.55 or more. β is obtained by the following method. A matrix structure is photographed at a magnification of 100 times from a cross section perpendicular to an arbitrary plate width direction of stainless steel (in the case of a steel pipe, a thick cross section parallel to the tube axis). The obtained 1 mm × 1 mm microstructure image is arranged in an xy coordinate system in which the thickness direction is the x-axis and the length direction is the y-axis, and each 1024 × 1024 pixel is represented in gray scale. Therefore, a microstructure image expressed in gray scale (256 gradations) is obtained from a cross section of a surface including a thickness direction and a length direction in stainless steel. Furthermore, β defined by the equation (2) is obtained from the microstructure image expressed in gray scale using two-dimensional discrete Fourier transform.

However, in Formula (2), Su is defined by Formula (3), and Sv is defined by Formula (4).

In the equations (3) and (4), F (u, v) is defined by the equation (5).

  In equation (5), f (x, y) represents the gradation of the pixel at coordinates (x, y).

  As described above, β and low temperature toughness have the relationship shown in FIG. The stainless steel according to one embodiment of the present invention has a ductile brittle transition temperature of −30 ° C. or less as shown in FIG. 9 when β obtained from the matrix structure is 1.55 or more. Therefore, the stainless steel according to one embodiment of the present invention exhibits excellent low temperature toughness at the normally required -10 ° C. β is preferably 1.6 or more, and more preferably 1.65 or more.

  From the above, the stainless steel according to the present embodiment has high strength, excellent SCC resistance at high temperature and SSC resistance at room temperature, and excellent low temperature toughness.

[Production method]
An example of the manufacturing method of the stainless steel of this embodiment is demonstrated. By hot rolling a steel material (slab, bloom, billet or other slab or steel slab) having the above-described chemical composition at a rolling rate as high as possible in an appropriate temperature range, a matrix structure having a β of 1.55 or more is obtained. can get. In this example, a stainless steel plate manufacturing method will be described as an example of a stainless steel manufacturing method.

  A steel material having the above chemical composition is prepared. The raw material may be a slab produced by continuous casting, or a plate material produced by hot working a slab or an ingot.

The prepared material is charged into a heating furnace or a soaking furnace and heated. The heated material is hot-rolled to produce an intermediate material (steel material after hot rolling). At this time, the rolling rate in the hot rolling process is set to 40% or more. Here, the rolling ratio (r:%) is defined by the following formula (7).
r = {1- (the thickness of the steel material after hot rolling / the thickness of the steel material before hot rolling)} × 100 (7)

  The steel material temperature (rolling start temperature) during hot rolling is set to 1200 to 1300 ° C. The steel material temperature here means the surface temperature of the material. The surface temperature of the material is measured at the start of hot rolling, for example. The surface temperature of the material is an average of the surface temperatures measured along the axial direction of the material. When the material is soaked in a heating furnace at a heating temperature of 1250 ° C., for example, the steel material temperature is substantially equal to the heating temperature and becomes 1250 ° C. Furthermore, the steel material temperature at the end of hot rolling (rolling end temperature) is preferably 1100 ° C. or higher.

  When a plurality of hot rolling steps are present during the manufacturing process, the rolling rate means the cumulative rolling rate of the hot rolling step continuously performed on the material having a steel material temperature of 1100 to 1300 ° C.

  When the steel material temperature falls below 1100 ° C. during hot rolling, a large amount of wrinkles may be generated on the surface of the steel material due to a decrease in hot workability. Therefore, the one where the heating temperature of steel materials is higher is preferable. On the other hand, in order to increase the degree of layering, it is preferable to roll at a high rolling rate.

  Quenching and tempering are performed on the base plate (intermediate material) after hot rolling. By performing quenching and tempering on the intermediate material, the yield strength of the stainless steel plate can be increased to 758 MPa or more. Furthermore, the matrix structure has a tempered martensite phase.

  Preferably, in the quenching step, the intermediate material is once cooled to a temperature near normal temperature. Then, the cooled intermediate material is heated to a temperature range of 850 to 1050 ° C. The heated intermediate material is cooled with water or the like and quenched to produce a stainless steel plate. Preferably, in the tempering step, the quenched intermediate material is heated to a temperature of 650 ° C. or lower. That is, the tempering temperature is preferably 650 ° C. or lower. This is because if the tempering temperature exceeds 650 ° C., austenite increases in the steel and the strength tends to decrease. Preferably, in the tempering step, the quenched intermediate material is heated to a temperature exceeding 500 ° C. That is, the tempering temperature is preferably a temperature exceeding 500 ° C.

  By the above manufacturing process, a stainless steel plate having β of 1.55 or more is manufactured. Stainless steel is not limited to a steel plate, and may have a shape other than a steel plate. Preferably, the material is soaked for a predetermined time at a temperature of 1200 to 1250 ° C., and then hot rolling is performed at a rolling rate of 50% or more and a rolling end temperature of 1100 ° C. or more. In this case, a stainless steel material having a high degree of layering can be obtained while suppressing generation of surface flaws.

<2. About the relation between the material and structure of the oil well pipe>
As described above, in recent years, an oil well pipe used for DwC is also required to have corrosion resistance. Moreover, since the oil well pipe used for DwC is subjected to rotational bending at the bent portion of the well, fatigue resistance is required. The present inventors have secured high corrosion resistance by adopting stainless steel having the above-described chemical composition and matrix structure as the material of the oil well pipe. Furthermore, the present inventors have found that in an oil well pipe made of stainless steel, if the structure is devised, the fatigue resistance is remarkably improved.

  The oil well pipe has a male threaded portion formed on the outer periphery of at least one end. The male threaded portion is screwed into a female threaded portion formed on the inner periphery of another oil well pipe or coupling. Generally, the end portion of the oil well pipe in which the male screw portion is formed is referred to as a pin because it includes an element inserted into the female screw portion. The end of the oil well pipe or coupling in which the female threaded portion is formed is referred to as a box because it includes an element that receives the male threaded portion.

  By rounding the boundary portion between the thread valley bottom surface and the load surface in the male screw portion, stress concentration in the boundary portion is alleviated. That is, by connecting the bottom surface of the thread valley and the load surface with a circular arc surface in the male thread portion, the stress concentration factor can be reduced and the fatigue resistance of the oil well pipe can be improved. The present inventors examined an appropriate curvature radius of the arc surface in order to ensure fatigue resistance suitable for DwC at a deep depth.

According to the High Pressure Gas Safety Association (KHK) Technical Standards KHKS1222 “Strength Design Guidelines for Screw Structures”, in the case of a sawtooth screw, it is applied to the bottom of the thread root of the male screw based on the load acting on the thread of the male screw by contact with the female screw. The resulting peak stress σ _s can be expressed by the following equations derived from the Heywood equation.

Here, a in formula (8) is a thread pitch. Wherein (9), alpha screw load surface angle, beta screw insertion face angle, [rho fillet radius of the screw root, h _e is the actual height of the screw thread. In Expression (8), w is an axial component of the thread load (N / mm) per unit length of the thread helical winding, and is represented by the following Expression (10).

In Expression (10), H is a distribution coefficient of the thread load, w _m is an average value of w in the effective meshing length of the screw, and W is a total axial force transmitted through the screw, that is, acts on the threaded joint. Total axial force (N), D is the average effective diameter of the screw. n is the number of effective meshing threads, which is the effective meshing screw length divided by the thread pitch a.

Next, the peak stress σ _a generated at the bottom of the thread root of the male screw based on the axial load directly acting on the male screw member will be considered. Regarding the stress concentration at the bottom of multiple notches due to axial stress, Neuber's formula is adopted in the KHKS technical standard and can be expressed by the following formulas.

Wherein (11), W is the total axial force, A is the effective cross-sectional area of the male screw member, K _t2 is the stress concentration factor of the bottom-out multi notch with respect to the average stress, h _e is the real height of the thread, [rho is thread root Is the fillet radius. γ is called a stress relaxation coefficient due notches multiplexing, given as a function of the ratio a / h _e between the actual height h _e thread pitch a and the thread. Result of consideration by KHK, JIS metric threads, JIS trapezoidal screw, or BS buttress screws, _{K t2} be thread form is changed is almost unchanged about 2.1 to 2.5. For this reason, the KHKS technical standard stipulates that K _t2 = 2.5 regardless of the type and shape of the screw.

The maximum stress sigma _max of thread root of the male thread _is a superposition of the sigma _s and sigma _a described above. However, since the generation positions of σ _s and σ _a differ by an angle difference Δθ, the following Heywood composite stress equation is used for the superposition.

C in the equation (13) is a superposition coefficient, and it is known experimentally that C = (Δθ / 44) ² .

  Each of the above formulas is considered to be applicable to a screw often used in a threaded joint for an oil well pipe, such as a tapered trapezoidal screw. In view of this, the present inventors theoretically obtain the stress concentration coefficient on the above-described arc surface with respect to a position where a fatigue main crack occurs in the threaded joint, taking a known threaded joint (VAMTOP (registered trademark)) as an example. I thought about the formula. FIG. 10 shows a schematic configuration of the pin portion of the threaded joint taken as an example in this study.

As shown in FIG. 10, in the male screw portion, the screw substantially meshes at a position separated by Li / 3 (Li: length of the incomplete screw portion) from the cut-up end of the incomplete screw portion in the tube axis direction. Assuming that it is the endmost part, fatigue fracture occurs at the endmost part. The stress concentration factor K in the circular arc surface of the bottom of the thread root of the male thread is obtained by dividing the maximum stress σ _max of the bottom of the thread by the average stress σ _mean , and is expressed by the following formula (14).

Here, when the following equation (15) is substituted into equation (14), equation (16) is obtained.

In each of the above formulas, W is the total axial force acting on the male screw portion, A is the cross-sectional area of the bottom of the thread valley at the end of the effective meshing portion, Le (= na) is the length of the effective meshing portion, D Is the average diameter of the male screw part (the diameter at the center of the effective meshing part), C = (Δθ / 44) ² . A, Le, and D are shown in FIG. In the threaded joint taken as an example in this study, since the load surface angle α = −3 (deg) and the insertion surface angle β = 10 (deg), Δθ = 6.5 (deg).

Under 100% tension obtained by elastic analysis separately performed on a known oil well pipe (VAMTOP (registered trademark) 9-5 / 8 "53.5 # (outer diameter: 244.5 mm, wall thickness: 13.8 mm)) According to the results of the distribution of the thread load, it is known that the thread load share is the largest in the thread at the end of the effective meshing portion, and about 9% of the total axial force acts. When used, the distribution coefficient H can be expressed by the following equation (17).

K _t1 is calculated using the above equation (9). At that time, the fillet radius ρ of the thread valley bottom is defined as the radius of curvature R of the arc surface connecting the thread valley bottom surface and the load surface, and the actual thread height h he is _defined as h / 2 (h: the thread of the complete thread portion). Height). In the case of the threaded joint taken as an example in this study, the thread pitch a is 5.08, and the thread height h of the complete thread portion is 1.575. The screw taper TT is 6.25%.

  With the above procedure, the relationship between the stress concentration factor K at the arc surface connecting the thread valley bottom surface and the load surface and the curvature radius R of the arc surface in the male thread portion was derived. FIG. 11 and Table 1 show the relationship between the stress concentration factor K and the curvature radius R obtained by the present inventors.

  From FIG. 11 and Table 1, it can be seen that the stress concentration factor K decreases as the radius of curvature R of the arc surface connecting the thread valley bottom surface and the load surface increases. The present inventors considered that when the radius of curvature R of the arc surface is 0.3 mm, the stress concentration factor K is reduced to about 4.6, and high fatigue resistance can be obtained.

  Based on the above findings, the present inventors have completed the oil well pipe according to the embodiment.

  The oil well pipe according to the embodiment is made of stainless steel having the above-described chemical composition and matrix structure. The oil well pipe includes a pipe body and a pin. The pin is continuously formed on at least one end of the tube body. The pin includes a male screw portion formed on the outer periphery thereof. The pin is inserted into another oil well tube box or coupling box. The male thread portion includes a plurality of thread valley bottom surfaces and a plurality of load flank surfaces as viewed in a cross section in a plane including the tube axis. The plurality of load flank surfaces are provided corresponding to the plurality of screw valley bottom surfaces. Each of the plurality of load flank surfaces is connected to a corresponding one thread valley bottom surface through an arc surface. Each arc surface has a radius of curvature of 0.3 mm or more.

  Since the oil well pipe according to the embodiment is made of stainless steel having the above-described chemical composition and matrix structure, the oil well pipe has high corrosion resistance. Moreover, in the said oil well pipe, in the external thread part provided in the pin, each thread valley bottom face is connected with the load flank face via the circular arc surface. The radius of curvature of the arc surface is set to 0.3 mm or more, which has a high effect of relaxing stress concentration at the bottom of the thread valley. For this reason, the said oil well pipe has high fatigue resistance.

  In the oil well pipe, the male screw portion has a complete screw portion and an incomplete screw portion. The incomplete thread portion is disposed closer to the tube body than the complete thread portion. The incomplete thread portion includes at least one thread crest surface that is connected to the corresponding one load flank surface and the inclined surface when viewed in a cross section in a plane including the tube axis. The length of the inclined surface in the direction perpendicular to the tube axis is 6 to 13% of the height of the thread of the complete thread portion.

  According to the above configuration, in the incomplete thread portion of the external thread portion, at least one thread top surface is connected to the load flank surface via the inclined surface. Thereby, stress redistribution can be caused in an incomplete thread portion where a fatigue crack is likely to occur.

  In particular, when the length of the inclined surface in the tube axis direction is set to 6 to 13% of the height of the thread of the complete thread portion, appropriate stress redistribution can be caused. Therefore, in the incomplete thread part, the stress concentration at each thread valley bottom part can be further relaxed, and the fatigue resistance of the oil well pipe can be further improved.

  In the oil country tubular good, the incomplete thread portion may include a stress concentration region. The stress concentration region is a region from the first position to the second position. The first position is at a distance of 0.1 × Li from the end of the incomplete screw portion on the tube main body side, where Li is the length in the tube axis direction of the incomplete screw portion. The second position is at a distance of 0.5 × Li from the end of the incomplete thread portion on the tube body side. At least one thread top surface is disposed in the stress concentration region.

  The stress concentration region is a region where the stress at the bottom of the thread valley is likely to be high even in the incomplete thread portion. By providing a thread crest surface that is continuous with the above-described inclined surface in the stress concentration region, stress can be redistributed in the vicinity of the stress concentration region, so that the effect of relaxing the stress concentration can be further enhanced. . Therefore, the fatigue resistance of the oil well pipe can be further improved.

[Structure of oil well pipe]
Hereinafter, the structure of the oil well pipe will be described in more detail with reference to FIGS. In the drawings, the same or corresponding components are denoted by the same reference numerals, and the same description is not repeated. For convenience of explanation, in each drawing, the configuration may be simplified or schematically illustrated, or a part of the configuration may be omitted.

  FIG. 12 is a partial cross-sectional view showing a schematic configuration of an oil well pipe according to an embodiment. FIG. 12 shows a state where one oil well pipe 10 is connected to another oil well pipe 10. The oil well pipes 10 and 10 are connected to each other via a tubular coupling 20. The oil well pipes 10 and 10 and the coupling 20 are made of stainless steel having the above-described chemical composition and matrix structure.

  The oil well pipe 10 includes a pin 11 and a pipe body 12. The pin 11 is formed continuously at one end of the tube body 12 in the tube axis direction. Although not shown, the pin 11 is continuously formed at the other end of the tube body 12 in the tube axis direction. That is, both end portions of the oil well pipe 10 are configured by the pins 11 respectively.

  The pin 11 is inserted into the box 21 of the coupling 20 and fastened to the box 21. The pin 11 includes a male screw portion 111 provided on the outer periphery thereof. In the present embodiment, the pin 11 further includes a nose portion 112, a pin seal surface 113, and a pin shoulder surface 114.

  The male screw portion 111 is disposed on the tube body 12 side with respect to the nose portion 112 in the pin 11. The male screw part 111 is configured by, for example, a taper screw. On the outer periphery of the pin 11, a pin seal surface 113 is disposed between the male screw portion 111 and the nose portion 112. The pin shoulder surface 114 is an annular surface formed on the tip surface of the pin 11.

  As will be described in detail later, the male threaded portion 111 has a plurality of thread crest surfaces, thread trough bottom surfaces, load flank surfaces (hereinafter also referred to as load surfaces), and insertion flank, as viewed in a cross section in a plane including the tube axis CL. It has a surface (hereinafter also referred to as an insertion surface). Each insertion surface is a surface that is preceded by screwing the pin 11 into the box 21. Each load surface is arranged on the opposite side of each insertion surface.

  The coupling 20 has boxes 21 at both ends in the tube axis direction. In each box 21, the pin 11 of the oil well pipe 10 is inserted and fastened to the pin 11. By fastening one box 21 to the pin 11 of one oil well pipe 10 and fastening the other box 21 to the pin 11 of another oil well pipe 10, the oil well pipes 10 and 10 are connected.

  Each box 21 includes a female screw portion 211. Each box 21 according to the present embodiment further includes a box seal surface 213 and a box shoulder surface 214.

  The female screw portion 211 is formed on the inner periphery of the box 21 corresponding to the male screw portion 111 of the pin 11. The female screw portion 211 is configured by a screw that meshes with a screw constituting the male screw portion 111.

  Although not shown, the female thread portion 211 has a plurality of thread valley bottom surfaces, a screw thread top surface, a load surface, and an insertion surface, as viewed in a cross section in a plane including the tube axis CL. In the fastening state of the pin 11 and the box 21, the plurality of thread valley bottom surfaces, the screw thread top surface, the load surface, and the insertion surface of the female thread portion 211 are respectively the plurality of screw thread top surfaces, the thread valley bottom surface, and the load of the male screw portion 111. It faces the surface and the insertion surface. In the fastened state, at least the load surfaces of the male screw portion 111 and the female screw portion 211 are in contact with each other.

  The box seal surface 213 is formed on the inner periphery of the box 21 corresponding to the pin seal surface 113. The box seal surface 213 contacts the pin seal surface 113 when the pin 11 and the box 21 are fastened.

  In the fastened state, the box seal surface 213 forms a seal portion by metal-metal contact together with the pin seal surface 113. That is, the diameter of the pin seal surface 113 is slightly larger than the diameter of the box seal surface 213. The difference in diameter between the pin seal surface 113 and the box seal surface 213 is referred to as an interference amount. Due to this amount of interference, when the pin seal surface 113 and the box seal surface 213 are fitted together by fastening, an elastic recovery force is generated in which each of the pin seal surface 113 and the box seal surface 213 returns to the original diameter. In addition, contact pressure is generated on the box seal surface 213. As a result, the pin seal surface 113 and the box seal surface 213 are in close contact with each other.

  The nose portion 112 amplifies the elastic recovery force of the pin seal surface 113 by not interfering with the box 21 in the fastened state. Thereby, the contact pressure of a seal part becomes high and the sealing performance of the pin 11 and the box 21 improves.

  The box shoulder surface 214 corresponds to the pin shoulder surface 114 and is formed on the end surface of the box 21 in the tube axis direction. The box shoulder surface 214 contacts the pin shoulder surface 114 in the fastened state.

  The pin shoulder surface 114 and the box shoulder surface 214 are pressed against each other by screwing the pin 11 into the box 21. The pin shoulder surface 114 and the box shoulder surface 214 form a shoulder portion by such a pressing contact with each other.

  FIG. 13 is a view showing a longitudinal section of one end of the oil well pipe 10 in the pipe axis direction. As shown in FIG. 13, the male thread portion 111 of the pin 11 has a complete thread portion 111p and an incomplete thread portion 111i. The incomplete threaded portion 111i is disposed closer to the tube body 12 than the complete threaded portion 111p.

  FIG. 14 is an enlarged view of the XIV portion of the complete screw portion 111p shown in FIG. As shown in FIG. 14, when the complete thread portion 111p is seen in a cross section in a plane including the tube axis CL, the thread valley bottom surface 111b is connected to the adjacent load surface 111r via the arc surface 111a. That is, the boundary portion between the thread valley bottom surface 111b and the load surface 111r is rounded. The radius of curvature R of the arc surface 111a is 0.3 mm or more.

  The thread of the complete thread portion 111p has a height h. The height h is a distance in a direction perpendicular to the tube axis CL from the straight line SL connecting the thread valley bottom faces 111b to the thread top face 111t in the complete thread portion 111p.

  FIG. 15 is an enlarged view of the XV portion of the incomplete screw portion 111i shown in FIG. Also in the incomplete thread part 111i, the adjacent thread valley bottom face 111b and the load surface 111r are connected via the circular arc surface 111a similarly to the complete thread part 111p.

  Although not shown in FIGS. 14 and 15, the complete thread portion 111 p and the incomplete thread portion 111 i are respectively a plurality of thread valley bottom surfaces 111 b and a plurality of screws when viewed in a cross section in a plane including the tube axis CL. A plurality of load surfaces 111r corresponding to the valley bottom surface 111b. Each thread valley bottom face 111b is connected via a corresponding one load face 111r and a circular arc face 111a. In short, in the male threaded portion 111, the boundary portion between the thread valley bottom surface 111b and the load surface 111r is rounded with a curvature radius of 0.3 mm or more.

  As shown in FIG. 15, when the incomplete thread portion 111i is viewed in a cross section in a plane including the tube axis CL, the thread top surface 111t is connected to the load surface 111r through the inclined surface 111s. That is, chamfering is applied to the boundary portion between the thread crest surface 111t and the load surface 111r adjacent to each other.

  The inclined surface 111s is tilted so that the outer peripheral end is positioned closer to the distal end side of the pin 11 than the inner peripheral end when viewed in a cross section in a plane including the tube axis CL. The angle formed between the inclined surface 111s and the surface perpendicular to the tube axis CL is not particularly limited, but can be, for example, about 10 °.

The length of the inclined surface 111s in the direction perpendicular to the tube axis CL, that is, the chamfering height is 6 to 13% of the thread height h (FIG. 14) of the complete threaded portion 111p. That is, when the chamfer height is represented by λh, λ satisfies the following equation (18).
0.06 ≦ λ ≦ 0.13 (18)

  In the incomplete thread portion 111i, at least one screw thread top surface 111t is connected to the load surface 111r via the inclined surface 111s. More preferably, the plurality of thread crest surfaces 111t are connected to the corresponding load surfaces 111r and inclined surfaces 111s.

Screw crest surface 111t continuous with the inclined surface 111s is preferably arranged in the stress concentration area _{A i} shown in FIG. 13. The stress concentration region A _i is disposed in the incomplete screw portion 111 _i . The stress concentration area A _i is an area where the end E _i1 on the tube body 12 side of the incomplete threaded portion 111i is 0% and the end E _i2 on the complete threaded portion 111p side is 100%, preferably 10 to 50%. More preferably, it is 15 to 40% of range.

In other words, the stress concentration area A _i is an area from the position P1 to the position P2. The position P1 is separated from the end E _i1 of the incomplete threaded portion 111i on the tube body 12 side by a distance of 0.1 × Li in the tube axis direction. Li is the length of the incomplete threaded portion 111i in the tube axis direction. The position P2 is separated from the end E _{i1 by} a distance of 0.5 × Li in the tube axis direction. More preferably, the distance in the tube axis direction between the end E _i1 and the position P1 is 0.15 × Li, and the distance in the tube axis direction between the end E _i1 and the position P2 is 0.4 × (Li + Lp).

  14 and 15 has a substantially trapezoidal shape in a cross section in a plane including the tube axis CL. However, the screw shape of the male screw portion 111 is not particularly limited. The screw shape of the male screw portion 111 may be, for example, a dovetail shape. The female screw portion 211 has a screw shape corresponding to the male screw portion 111.

[Main effects of structure]
As described above, the oil well pipe 10 according to the present embodiment is made of stainless steel having the above-described chemical composition and matrix structure, and thus has high corrosion resistance. Further, the oil well pipe 10 is connected to the threaded thread bottom surface 111b of the male threaded portion 111 of the pin 11 via the corresponding load surface 111r and the arc surface 111a. The radius of curvature R of each arc surface 111a is set to 0.3 mm or more, which has a high effect of reducing stress concentration at the bottom of the thread valley. For this reason, high fatigue resistance can be ensured.

  In the present embodiment, at the incomplete threaded portion 111i, at least one thread top surface 111t is connected to the load surface 111r via the inclined surface 111s. Thereby, in the incomplete thread part 111i in which a fatigue crack is likely to occur, stress is redistributed, and the stress concentration at each thread valley bottom part can be relaxed.

  In particular, in the present embodiment, the length (chamfering height) in the tube axis direction of the inclined surface 111s is configured to be 6 to 13% of the thread height h of the complete threaded portion 111p. Thereby, in the incomplete thread part 111i, more appropriate redistribution of stress can be produced, and the stress concentration in each thread valley bottom part can be relieved effectively. As a result, the fatigue resistance of the oil well pipe 10 can be further improved.

In the incomplete thread portion 111i, the stress concentration area A _i is an area of 10 to 50% when the end E _i1 on the tube body 12 side is 0% and the end E _i2 on the complete thread portion 111p side is 100%. is there. In general, an oil well pipe, the stress concentration area A _i vicinity likely higher stress thread root portion, the fatigue crack tends to occur. According to this embodiment, the stress concentration area _{A i,} the inclined surface 111s is formed between at least one screw crest surface 111t and the load surface 111 r. Therefore, in the oil well pipe 10, stress can be redistributed in a region where fatigue cracks are likely to occur, and fatigue resistance can be improved.

  The structure of the oil well pipe according to the present disclosure is not limited to the above. For example, in the oil well pipe 10 described above, at the incomplete threaded portion 111i of the male threaded portion 111, a chamfer is applied to a boundary portion between at least one screw thread top surface 111t and the load surface 111r. However, the chamfering is not essential. That is, all the thread crest surfaces 111t in the incomplete threaded portion 111i may be connected to the corresponding load surface 111r without passing through the inclined surface 111s.

  The pin 11 of the oil well pipe 10 described above includes a nose portion 112, a pin seal surface 113, and a pin shoulder surface 114. However, the nose portion 112, the pin seal surface 113, and the pin shoulder surface 114 are not essential components in the pin 11.

  In FIG. 12, one oil well pipe 10 is connected to another oil well pipe 10 via a coupling 20. However, it can also be configured such that oil well pipes are directly connected to each other.

  FIG. 16 is a partial cross-sectional view showing oil well pipes 10A and 10A that are directly connected. Each oil well pipe 10A has a pin 11 at one end in the pipe axis direction. Each oil well pipe 10A has a box 21 at the other end in the pipe axis direction. The pin 11 of one oil well pipe 10 </ b> A is inserted into the box 21 of another oil well pipe 10 </ b> A and is fastened to the box 21. Thereby, oil well pipe 10A, 10A is directly connected, without passing through the coupling 20 (FIG. 12).

  The pin 11 may further have a pin seal surface 115 on the outer periphery at the end on the tube body 12 side. In this case, a box seal surface 215 corresponding to the pin seal surface 115 is provided on the inner periphery of the box 21. In the fastening state between the pin 11 and the box 21, the pin seal surface 115 and the box seal surface 215 form a seal portion by metal-metal contact.

  The pin 11 may further have a pin shoulder surface 116 on the end surface on the tube body 12 side. In this case, the box 21 is provided with a box shoulder surface 216 corresponding to the pin shoulder surface 116. In the fastened state, the pin shoulder surface 116 and the box shoulder surface 216 are pressed against each other to form a shoulder portion.

  Although the embodiments have been described above, the present disclosure is not limited to the above-described embodiments, and various modifications can be made without departing from the gist thereof.

  Hereinafter, the present disclosure will be described in more detail by way of examples. However, the present disclosure is not limited to the following examples.

<1. About Oil Well Pipe Materials>
Steels A to V having chemical compositions shown in Table 2 were melted to produce ingots. The chemical compositions of steel types A to V are within the scope of the present embodiment. Each ingot was hot forged to produce a plate material having a width of 100 mm and a height of 30 mm. The manufactured board material was prepared as a steel raw material of numbers 1-36. In the chemical composition shown in Table 2, the content of each element is mass%, and the balance is Fe and impurities.

  A plurality of prepared materials were heated in a heating furnace. The heated raw material was extracted from the heating furnace, and after the extraction, hot rolling was performed immediately to produce intermediate materials having numbers 1 to 36. Table 3 shows the steel temperature of each material during hot rolling. In this example, since the material was heated in a heating furnace for a sufficient time, the steel material temperature was equal to the heating temperature. Table 3 shows the rolling ratio of each number in hot rolling.

  Quenching and tempering were performed on each of the intermediate materials of Nos. 1-36. The quenching temperature was 950 ° C. The holding time (heat treatment time) at the quenching temperature was 15 minutes. The intermediate material was quenched by water cooling. The tempering temperatures were 550 ° C. for the intermediate materials Nos. 23 to 30, 32, and 33, and 600 ° C. for the intermediate materials Nos. 2 to 22, 31, and 34 to 36. The holding time at the tempering temperature was 30 minutes. The steel plate of each number was manufactured according to the above manufacturing process.

[Microstructure observation test]
The steel plates Nos. 1 to 36 were cut in the length direction at the width center. A sample for microstructural observation was taken from the central portion of the steel sheet in the cut surface (the length direction is the y-axis and the thickness direction is the x-axis). From the collected samples, the area ratio was measured by the method described above and defined as the volume ratio of the ferrite phase. Furthermore, the volume fraction of the austenite phase was determined by the X-ray diffraction method described above. Furthermore, the volume ratio of the tempered martensite phase was determined by the above-described method using the volume ratio of the ferrite phase and the volume ratio of the austenite phase.

  Further, a microstructure image (for example, an image as shown in FIG. 1) having an observation magnification of 100 times and a size of 1 mm × 1 mm was obtained from an arbitrary position in the observation surface. Using the obtained microstructure image, β of each numbered steel sheet was calculated by the method described above.

[Yield strength evaluation test]
A round bar for a tensile test was collected from the central portion in the thickness direction of each of the steel plates Nos. 1 to 36. The longitudinal direction of the round bar was a direction (L direction) parallel to the rolling direction of the steel plate. The diameter of the parallel part of the round bar was 6 mm, and the distance between the gauge points was 40 mm. The collected round bar was subjected to a tensile test at room temperature in accordance with JIS Z2241 (2011) to determine the yield strength (0.2% yield strength).

[Low temperature toughness evaluation test]
A Charpy impact test was conducted as a low temperature toughness evaluation test. Full-size test pieces based on ASTM E23 were collected from the central part in the thickness direction of each of the steel plates of Nos. 1 to 36. The longitudinal direction of the test piece was parallel to the plate width direction. Using the collected specimen, a Charpy impact test was performed in a temperature range of 20 ° C. to −120 ° C., the absorbed energy (J) was measured, and the fracture surface transition temperature of ductile brittleness was obtained.

[High temperature SCC resistance evaluation test]
Four-point bending test pieces were collected from each of the steel plates Nos. 1-36. The length of the test piece was 75 mm, the width was 10 mm, and the thickness was 2 mm. The test piece was given deflection by 4-point bending. At this time, in accordance with ASTM G39, the amount of deflection of the test piece was determined so that the stress applied to the test piece was equal to the 0.2% offset proof stress of the test piece. A 200 ° C. autoclave in which 30 bar (3.0 MPa) CO ₂ and 0.01 bar (1 kPa) H ₂ S were sealed under pressure was prepared for each of Nos. 1 to 36. The bent specimen was stored in an autoclave. The test piece was immersed in a 25 mass% NaCl solution in an autoclave for 720 hours. The solution was adjusted to pH 4.5 with a CH ₃ COONa + CH ₃ COOH buffer system containing 0.41 g / l CH ₃ COONa. The presence or absence of occurrence of stress corrosion cracking (SCC) was observed on the test specimen after immersion. Specifically, the cross section of the portion where the tensile stress was applied to the test piece was observed with an optical microscope at a magnification of 100 times to determine the presence or absence of cracks. In Table 4, “No crack” is “Good”, “With crack” is “Good”, and “Good” is better in SCC resistance than “No”. Furthermore, corrosion weight loss was calculated | required based on the variation | change_quantity of the weight before a test, and the weight after immersion with respect to a test piece. The annual corrosion amount (mm / Year) was calculated from the obtained corrosion weight loss.

[SSC resistance evaluation test at room temperature]
A round bar test piece for NACE TM0177 METHOD A was collected from each of the steel plates Nos. 1-36. The diameter of the test piece was 6.35 mm, and the length of the parallel part was 25.4 mm. A tensile stress was applied in the axial direction of the test piece. At this time, based on NACA TM0177-2005, the stress applied to the test piece was adjusted to be 90% of the actual measured yield stress of the test material. The test piece was immersed in a 25 mass% NaCl solution saturated with 0.01 bar (1 kPa) of H ₂ S and 0.99 bar (0.099 MPa) of CO ₂ for 720 hours. The solution was adjusted to pH 4.0 with a CH ₃ COONa + CH ₃ COOH buffer system containing 0.41 g / l CH ₃ COONa. Furthermore, the temperature of the solution was adjusted to 25 ° C. The test piece after immersion was observed for the presence or absence of sulfide stress cracking (SSC). Specifically, among the test pieces numbered 1 to 36, for each of the test piece that was broken during the test and the test piece that was not broken, the parallel part was observed with the naked eye, and cracks or pitting corrosion was observed. The presence or absence of occurrence was determined. In Table 4, the case where there is no occurrence of cracks or pitting corrosion is o, the case where cracks or pitting corrosion occurs is x, and the case of o is better in SSC resistance than the case of x.

[Test results]
Table 4 shows the test results. All of the steel plates numbered 1 to 36 have the ferrite phase volume fraction (α fraction), the austenite phase volume fraction (γ fraction) and the tempered martensite phase volume fraction (M fraction) of this embodiment. It was within the range. All of the steel materials of Nos. 1 to 36 had a yield strength of 758 MPa or more, an annual corrosion amount of 0.01 mm / year or less, and excellent SCC resistance and SSC resistance.

  Each of the steel materials of Nos. 1, 4, 7, 10, 12-16, and 19-36 had β of 1.55 or more. These steel materials have a transition temperature of −30 ° C. or less and are excellent in low temperature toughness.

  Moreover, all the steel materials of numbers 2, 3, 5, 6, 8, 9, 11, 17, and 18 had β of less than 1.5, and the transition temperature exceeded −30 ° C. These steel materials are inferior in low temperature toughness.

<2. About the relation between the material and structure of the oil well pipe>
A plurality of oil well pipe samples made of stainless steel having the same chemical composition and matrix structure as the steel materials of Nos. 1 to 36 described above were manufactured. Each oil well pipe has dimensions of 9-5 / 8 "53.5 # (outer diameter: 244.5 mm, wall thickness: 13.8 mm), and has the basic structure shown in FIG.

  In the male threaded portion (111) of all oil well pipes, an arc surface (111a) that connects each thread valley bottom surface (111b) and each load surface (111r) was provided. However, the curvature radius R of the circular arc surface (111a) is changed to 0.1 mm, 0.3 mm, and 0.4 mm.

  In some oil well pipes, an inclined surface (111s) that connects the thread crest surface (111t) and the corresponding load surface (111r) is provided in the incomplete thread portion (111i) of the male thread portion (111). The inclined surface (111s) was formed by chamfering 10% of the outer diameter side end slope of the load surface (111r) of the incomplete thread portion (111i).

A fatigue test in a fastened state was performed on each oil well pipe sample. The fatigue test method was a resonance type physical fatigue test. The eccentric weight at the sample end was rotated by a motor to generate a primary resonance mode, and a repeated bending moment was applied to the threaded joint. The test frequency was 20-25 Hz. An air pressure of about 1.0 MPa was sealed in the sample, and the point in time when the internal pressure began to decrease due to penetration of a crack or leakage from the seal portion was defined as the fatigue life. The stress amplitude σa at 2 × 10 ⁶ cycles was defined as the fatigue limit. The obtained test results are shown in Tables 5A to 5F.

  Numbers 1 to 36 in Tables 5A to 5F correspond to the steel materials of the above numbers 1 to 36, respectively. That is, numbers 1 to 36 in Tables 5A to 5F mean oil well pipes made of stainless steel having the same chemical composition and matrix structure as the steel materials of numbers 1 to 36 described above, respectively.

  The oil well pipes indicated by branch numbers 1 and 2 for numbers 1 to 36 each have a radius of curvature R of the arcuate surface (111a) of 0.3 mm. The curvature radius R of the arc surface (111a) in the oil well pipe indicated by branch numbers 3 and 4 is 0.4 mm, and the curvature radius R of the arc surface (111a) in the oil well pipe indicated by branch numbers 5 and 6 is 0.1 mm.

  For each of Nos. 1 to 36, the oil well pipes of branch numbers 2, 4, and 6 are provided with a thread crest surface (111t) and a load surface (111r) at the incomplete thread portion (111i) of the male thread portion (111). An inclined surface (111s) to be connected was provided. The inclined surface (111s) was formed by chamfering 10% of the outer diameter side end slope of the load surface (111r) of the incomplete thread portion (111i).

  The oil well pipes indicated by the numbers 1, 4, 7, 10, 12 to 16, and 19 to 36 are all made of stainless steel having β of 1.55 or more. From Tables 5A to 5F and FIG. 17, these oil well pipes have the same structure, and β of numbers 2, 3, 5, 6, 8, 9, 11, 17, 18 having a β of less than 1.55. It can be seen that the fatigue limit is significantly higher than that of the oil well pipe. This is presumably because the martensite structure and ferrite structure are layered in a direction perpendicular to the direction of fatigue crack propagation. As the structure of the stainless steel constituting the oil well pipe becomes layered, the crack growth rate in the oil well pipe decreases.

  From Tables 5A to 5F, the oil well pipes of branch numbers 1 to 4 whose radius of curvature R of the arc surface (111a) is 0.3 mm or more are oil well pipes of branch numbers 5 and 6 whose radius of curvature R is less than 0.3 mm. It can be seen that the fatigue limit is higher than that. The fatigue limit increased as the radius of curvature R increased. In particular, in oil well pipes of numbers 1, 4, 7, 10, 12-16, 19-36 where β is 1.55 or more, numbers 2, 3, 5, 6, 8, where β is less than 1.55, Compared to 9, 11, 17, 18 oil well pipes, the fatigue limit increase rate is large.

  FIG. 18 shows the relationship between the radius of curvature R of the arc surface (111a) and the fatigue limit. In an oil well pipe having β of 1.55 or more, the fatigue limit is significantly increased when the radius of curvature R is 0.3 and 0.4. In an oil well pipe having a β of less than 1.55, the fatigue limit gradually increases as the radius of curvature R increases, but the increase rate of the fatigue limit is small.

  The reason why the fatigue limit is increased is that by providing the arc surface (111a), the stress concentration coefficient at the bottom of the thread root of the male threaded portion (111) is lowered, and the stress acting on the bottom of the thread root is alleviated. Although the relationship between the stress concentration and the fatigue limit is generally known, in the case of an oil well pipe made of stainless steel according to the present disclosure in which β is 1.55 or more, if the curvature radius R is 0.3 mm or more, Compared with oil well pipes made of known steel, the fatigue limit is significantly increased. This is considered to be a phenomenon peculiar to the stainless steel according to the present disclosure in which the martensite structure and the ferrite structure are layered.

  The oil well pipes of the branch numbers 2, 4, and 6 are chamfered at the incomplete threaded portion (111i) of the male threaded portion (111) to provide the inclined surface (111s), so that there is no inclined surface (111s). The fatigue limit is increased compared to the oil well pipes of Nos. 1, 3, and 5. This is due to the redistribution of the stress acting on the bottom of the thread root of the male thread portion (111). The stress redistribution will be described in detail later.

In addition, for the oil well pipe sample that has not been chamfered, a fatigue test for obtaining a fatigue limit at the time of 2 × 10 ⁶ cycles with a stress higher than the fatigue limit was performed. In the incomplete thread portion (111i), The oil well pipe broke at a position of approximately 15 to 40%, assuming that the end on the pipe body (12) side was 0% and the end on the complete threaded part (111p) side was 100%. Even in the calculation using the finite element method, it is known that the fatigue limit increases when chamfering is performed at the incomplete thread portion (111i). Therefore, in the incomplete thread portion (111i), by chamfering the thread in the range of at least 10 to 50%, more preferably in the range of 15 to 40%, the oil well pipe can be more reliably prevented from breaking. It is thought that you can.

<3. About the length of the inclined surface in the tube axis direction>
In order to confirm an appropriate range of the length (chamfering height) of the inclined surface in the tube axis direction, numerical simulation analysis was performed by an elastoplastic finite element method. The analysis conditions are as follows.
-Analysis object: VAMTOP (registered trademark) 9-5 / 8 "53.5 # (outer diameter: 244.5 mm, wall thickness: 13.8 mm) LL-PNBN
Material: Elasticity (Young's modulus E = 210 GPa, Poisson's ratio ν = 0.3)
・ Analysis parameters: Position of the inclined surface and chamfer height in the incomplete thread part ・ Loading condition: After fastening with RASC 1/100 turn, a tensile load of 10% of the yield strength (equivalent to 110 ksi) was applied.

  The analysis results are shown in FIG.

  In each of Examples 1 to 3 shown in FIG. 19 and Table 6, chamfering is performed only on the load surface N1 continuous with the bottom surface of the thread root having the highest stress in the male screw portion. That is, the load surface N1 is connected to the screw thread top surface through the inclined surface. An angle (chamfer angle) formed by the inclined surface and a surface perpendicular to the tube axis is 10 °. However, Examples 1 to 3 have different chamfering heights of the load surface N1. In the comparative example, any load surface is not chamfered.

  FIG. 19 shows the stress distribution at the bottom of the thread root of the male thread for each of the comparative example and Examples 1-3. The nominal stress was the average stress of the tube body part. From FIG. 19, it can be seen that the stress at the bottom of the thread valley is high at the incomplete threaded portion on the tube body side. The stress at the bottom of the thread valley is also high in the incomplete thread portion on the tip end side of the pin, but the crack does not progress on the tip end side of the pin, and the oil well pipe does not break. Therefore, here, attention is focused on the result of the incomplete thread portion on the tube body side.

  From FIG. 19, it can be seen that in Examples 1 to 3, redistribution of the stress at the bottom of the thread root occurs in the incomplete thread portion on the tube body side including the load surface N1. Further, FIG. 19 and Table 6 show that the chamfering height of the load surface N1 has an influence on the redistribution of the stress.

  More specifically, in Example 1, the chamfer height is the smallest, and the ratio λ of the chamfer height to the height of the thread of the complete thread portion is slightly over 5%. In Example 1, the stress at the bottom of the thread valley continuous with the load surface N1 is slightly lower than in the comparative example. However, the stress at the bottom surfaces of the thread valleys continuous with the load surfaces N0 and N2 adjacent to the load surface N1 is almost the same as that of the comparative example, and the effect of stress concentration relaxation is small.

  In Example 3, the chamfer height is the largest, and λ is less than 16%. In Example 3, the stress at the bottom of the thread valley that continues to the load surface N1 is remarkably low, but the stress at the bottom of each screw valley that continues to the load surfaces N0 and N2 is higher than that of the comparative example. That is, stress concentration occurs around the load surface N1 that has been chamfered.

  In Example 2, λ is about 10%, and the stress at the bottom of the thread valley continuous with the load surface N1 is considerably lower than that in the comparative example. Further, the stress at the bottom of each thread valley continuous with the load surfaces N0 and N2 is only slightly higher than that of the comparative example. That is, in Example 2, there is no place where the stress protrudes and becomes high, and it can be said that redistribution of the stress occurs appropriately.

  From the above, it has been found that if at least one load surface is chamfered in the incomplete threaded portion on the tube main body side of the male threaded portion, the stress is redistributed at the bottom of the thread valley and the stress concentration can be relaxed. In particular, if the chamfering height is 6 to 13% of the height of the thread of the complete thread portion, appropriate stress redistribution can be caused, and stress concentration can be more reliably mitigated.

DESCRIPTION OF SYMBOLS 10,10A: Oil well pipe 11: Pin 111: Male thread part 111p: Complete thread part 111i: Incomplete thread part 111t: Screw thread top surface 111b: Screw valley bottom surface 111r: Load flank surface 111a: Arc surface 111s: Inclined surface 20: Cup Ring 21: Box

Claims (6)

An oil well pipe made of stainless steel and connected to another oil well pipe directly or via a coupling,
The stainless steel is
Chemical composition is mass%,
C: 0.001 to 0.06%,
Si: 0.05 to 0.5%,
Mn: 0.01 to 2.0%,
P: 0.03% or less,
S: less than 0.005%,
Cr: 15.5 to 18.0%,
Ni: 2.5-6.0%,
V: 0.005-0.25%,
Al: 0.05% or less,
N: 0.06% or less,
O: 0.01% or less,
Cu: 0 to 3.5%
Co: 0 to 1.5%,
Nb: 0 to 0.25%,
Ti: 0 to 0.25%,
Zr: 0 to 0.25%,
Ta: 0 to 0.25%,
B: 0 to 0.005%,
Ca: 0 to 0.01%,
Mg: 0 to 0.01%, and REM: 0 to 0.05%,
Mo: 1.4 to 3.5%, and W: the 0 to 3.5% contained in a range satisfying the equation (1),
The balance consists of Fe and impurities,
The matrix structure has a volume ratio of 40 to 70% tempered martensite phase, 10 to 50% ferrite phase, and 1 to 15% austenite phase,
A 1 mm × 1 mm microstructure image obtained by photographing the matrix structure at a magnification of 100 times is arranged in an xy coordinate system in which the thickness direction is the x axis and the length direction is the y axis, and is 1024 × 1024. When each pixel is expressed in grayscale, β defined by Equation (2) is 1.55 or more,
1.0 ≦ Mo + 0.5W ≦ 3.5 (1)
Here, Mo and W are Mo and W content (mass%).
However, in Formula (2), Su is defined by Formula (3), and Sv is defined by Formula (4).
In the equations (3) and (4), F (u, v) is defined by the equation (5).
In Expression (5), f (x, y) represents the gradation of the pixel at the coordinates (x, y).
The oil well pipe is
A tube body;
A pin inserted into the box of the other oil well pipe or the box of the coupling, including a male screw portion formed continuously on at least one end of the pipe body and formed on the outer periphery;
With
The male screw portion is seen in a cross section in a plane including the tube axis,
A plurality of screw valley bottoms;
A plurality of load flank surfaces provided corresponding to the plurality of thread valley bottom surfaces, each connected via a corresponding one thread valley bottom surface and an arc surface having a radius of curvature of 0.3 mm or more;
Including oil well pipe. An oil well pipe according to claim 1,
The male screw part is
A complete thread,
An incomplete thread portion disposed closer to the tube body than the complete thread portion;
Have
The incomplete thread portion includes at least one thread crest surface that is connected via a corresponding one load flank surface and an inclined surface when viewed in a cross-section in a plane including the tube axis,
The inclined surface is an oil well pipe whose length in the direction perpendicular to the pipe axis is 6 to 13% of the height of the thread of the complete thread portion. An oil well pipe according to claim 2, wherein
The incomplete thread portion has a length in the tube axis direction Li, and is 0.5 × Li from the tube body side end from the first position at a distance of 0.1 × Li from the tube body side end. A stress concentration region up to a second position at a distance of
The oil well pipe, wherein the at least one screw thread top surface is disposed in the stress concentration region. The oil well pipe according to any one of claims 1 to 3,
The stainless steel is
The chemical composition is mass%,
An oil well pipe containing one or two selected from the group consisting of Cu: 0.2 to 3.5% and Co: 0.05 to 1.5%. An oil well pipe according to any one of claims 1 to 4,
The stainless steel is
The chemical composition is mass%,
Nb: 0.01 to 0.25%,
Ti: 0.01 to 0.25%,
An oil well pipe containing one or more selected from the group consisting of Zr: 0.01 to 0.25% and Ta: 0.01 to 0.25%. An oil well pipe according to any one of claims 1 to 5,
The stainless steel is
The chemical composition is mass%,
B: 0.0003 to 0.005%,
Ca: 0.0005 to 0.01%,
An oil well pipe containing one or more selected from the group consisting of Mg: 0.0005 to 0.01% and REM: 0.0005 to 0.05%.