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Petroleum & Petrochemical Engineering Journal Research Article 16 min read

Analyzing the Effects of Drillstring Speed on Bottom Hole Assembly Vibration in S-Shape Directional Wells: A Comprehensive Sensitivity Analysis

AlGburi H, Halafawi M*, Lazăr D, Gal S and Avram L
* Corresponding author
ISSN: 2578-4846  10.23880/ppej-16000337  Received: February 10, 2023  Published: March 02, 2023
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Keywords
Vibration RPM BHAs parameters Performance Stress Forces Torque and displacement
Abstract

The main objective of this article is to do a comprehensive sensitivity analysis so as to study the influence of rotational speeds on the drillstring and BHA vibrations in well ZB-290 of s-shape well profile. This study is an extention of our reseach work of drillstring vibrations that were previously implemented to identify, analyze and control the resulting vibration in Zubair field wells. This well (ZB-290) has been drilled in Zubair field. Furthermore, recorded time-based vibration data and the vibration logs of this well to perform this analysis. BHAs forces, stresses, displacements, torque, and moments have been successfully identified and analysed taking into account the change of drilling speed. Drilling performance and future well designs will be enhanced based on the previous and this work.

Introduction

Due to the random nature of multiple components, including bit/formation contact, drillstring/borehole interaction, and hydraulics, drillstring vibrations are incredibly complicated. They contain a wide variety of phenomena, which makes the analysis rather difficult. Drilling may cause vibration in three different ways: axial, torsional, and lateral. These modes are accompanied by the phenomena bit bounce, stick/slip, and spinning, respectively. External excitations like bit/formation contact can cause drillstring vibrations [1, 2]. In these circumstances, changing the excitation source to the drillstring assembly’s or its component’s native frequency might result in harmful movements. Additionally, self-excited vibrations are present underground [1, 3]. The flow in the drillstring annulus may also cause vibrations [1, 4]. Dynamic systems can be either transient (unsteady state) or steady state (static).

The various assembly components may experience premature wear and damage as a result of drillstring vibrations, and the rate of penetration (ROP) decreases as a result because some of the drilling energy required to cut the rock is lost in vibrations. Additionally, vibrations may interfere with instruments used for measurement while drilling (MWD). Finally, vibrations frequently cause wellbore instabilities that can aggravate the well’s state and impair directional control as well as the wellbore’s general quality [1].

Therefore, sensitivity analysis is done in order to show the impact of drillstring speed on its bottom hole Assembly

(BHA) vibration analysis. Previously, to determine the sorts of vibrations that occurred in each well and each run, their sources, their severity, and the best mitigation strategies for each well, a diagnostic-analysis study was conducted and published in RJPGT. Additionally, these vibrations are graded and categorized to establish the level of severity of each run in drilled wells. In order to forecast the optimal drilling parameters for next operations, drilling parameters are also displayed and their trend lines are generated. Here, our work is to continue this research work and study the impact of various drillstring speeds on the vibrations’ analysis. To do this work, we will firstly review previous studies and simulation models. After that a field description will be also presented.

Background Studies

Drillstring vibrations have been extensively studied since several long years. A lot of authors and textbooks have presented several studies, simulations, developed models so as to measure or detect, model, simulate, and control the vibrations resulting from running the drillstring into the wellbore. Here, Table 1 shows a literature reviews of most of previous studies, published articles and techiques.

YearAuthor (s)Study, Method, Technique, Approach, or Model
1960Finnie & Bailey [3]Describing the apparatus that has been created to experimentally detect axial force, torque,
and axial and rotational movements at the top of a drill string.
1968Huang & Dareing [5]Addressing the drill pipe’s lateral vibrations and buckling.
1981Millheim & Apostal
[6]		Reporting on how BHA dynamics affect a bit’s trajectory is a part of an ongoing project to
create a computer model that replicates the bit’s 3D travel.
1984Dareing [7]Giving advice for reducing severe drill string vibrations and explaining their sources.
1985Wolf, et al. [8]Presenting field data of downhole drillstring vibrations and quickly going through
the relationship between downhole longitudinal and lateral vibrations and formation
properties.
1987Mitchell & Allen [9]Providing 8 case studies of real BHA failures where the model predicted lateral vibrations
with critical rotation speeds that nearly match the operational parameters at the moment of
failure in all the analyzed BHAs.
1987Skaugen [10]Employing a drillstring dynamic model that operates in the time domain to examine how
quasi-random drill bit vibrations affect drillstring dynamic behavior.
1990Vandlver, et al. [11]Describing the drill-collar spinning and the linear connection between WOB variations and
the bending vibration of an originally curved BHA as the two main causes of the two case
studies of BHA bending vibration.
1990Rector III [12]Demonstrating the use of downhole seismic sources created by drill-bit vibrations.
1990Wang [13]Investigating the impact of the lowing drilling fluid on drill stem stability and lateral
vibration.
1991Rector III & Marion
[14]		Describing a novel wellbore seismic approach that makes advantage of the vibrations a drill
bit produces during drilling as a source of downhole seismic energy.
1998Dunayevsky &
Abbassian [15]		Considering three basic mechanical systems that describe string torsional vibration, bit
lateral dynamics, and coupled torsional-lateral vibration allows us to better understand the
dynamic stability of PDC bits under induced torsional and lateral vibrations.
1998Macpherson, et al.
[16]		Analyzing drilling vibration data that was collected during a field test using both down-bole
and surface vibration measuring equipment.
2000Baumgart [17]Employing nonlinear differential equations of motion for the longitudinal, lateral, and
rotational motion of the pipe as well as for the rate of flow and pressure of the mud, one may
develop and numerically solve a mathematical model as an initial value issue for the drilling
procedure.
2001Yigit & Christoforou
[18]		Presenting an active control method for stick-slip vibrations together with a fully linked
model for axial, bending, and torsional vibrations.
2001Liu & Huang [19]Establishing the vertical, lateral, and torsion coupled vibration of full-hole drilling strings
and its solution for the lateral vibration dynamic model of roller cone rock bit.
2002Chen, et al. [20]Showing a field examination of the impact of lateral, spin, and stick-slip vibrations on roller-
cone bit performance
2003Al-Hiddabi, et al. [21]Utilizing a non-linear dynamic inversion control design strategy to reduce a non-linear
drillstring’s lateral and torsional vibrations.
2005Pan, et al. [22]Highlighting and summarizing the use of computational fluid dynamics methods in the
investigation of vortex-induced vibration of maritime structures, as well as its hotspots and
advancement.
2005Cobern & Wassell
[23]		Putting an active drilling vibration monitoring and control system through laboratory
testing.
2006Yigit & Christoforou
[24]		Showing stick-slip and bit-bounce interactions in oil well drillstrings, by developing a
straightforward model that accurately captures the dynamics and simulates the impacts of
changing operating circumstances on stick-slip and bit-bounce interactions.
2009Shi, et al. [25]Designing and controlling the theory of the sidetrack horizontal well and branch wellbore
trajectory.
2010Reckmann, et al. [26]Establishing a connection between MWD or LWD tool failure and downhole drilling
dynamics in order to lower failure rates and expenses.
2010Bailey & Remmert
[27]		Controlling drilling vibrations through BHA design optimization to considerably improve
performance and find ideal rotary-speed “sweet spots”.
2010Wassell [28]Describing a technique for evaluating vibration damage accumulation in drilling tools and
setting vibration limits.
2011Pavković, et al. [29]Suggesting a torque estimator-based control technique with an auto-tuning algorithm for
active dampening of torsional vibrations in oil well drill strings.
2012Zhu, et al. [30]Developing a down-hole measuring device that, when used for deepwater top-hole drilling,
can measure annulus pressure, drill pipe pressure, and bottom hole temperatures in real-
time.
2012Kreuzer & Steidl [31]Demonstrating the use of traveling wave decomposition to control the torsional vibrations of
drill strings.
2013Yang, et al. [32]Demonstrating the development of MWD equipment and its study.
2013Patil & Teodoriu [33]Comparing various methods of simulating, regulating, and conducting laboratory-based
experiments using torsional vibrations.
2014Zhu, et al. [34]Covering the phenomena and modeling techniques of stick-slip vibrations, as well as
providing an up-to-date overview of stick-slip vibration behavior in drillstrings.
2015Ghasemloonia, et al.
[35]		Presenting an extensive literature review on drillstring vibration simulation. The current
status of models for axial, torsional, and bending vibration prediction (uncoupled and
coupled), boundary condition assumptions, equation formulation techniques, and
applications to vibration mitigation are examined. Additionally, the difficulties of simulating
drillstring vibration in the presence of contemporary drilling methods including deviated
drilling and the usage of vibrating downhole instruments are covered.

Table 1: Literature review study.

Drillstring Vibrations: Theory and Types

It has long been known that drill collars and nearby drillpipes are the parts that are subjected to the most hazardous vibrations. As a result, the BHA not only affects the assembly’s overall dynamic response, but it also serves as the site of the majority of failures. Therefore, comprehension of the BHA’s dynamic behavior is necessary for vibration mitigation. However, it should be noted that downhole vibrations can be a useful source of data that sheds light on bit wear, formation characteristics, and drillstring/wellbore interactions. They may potentially be employed as a possible seismic source, according to some research. Additionally, drillstring vibrations have been thought of as a way to improve drilling efficiency by boosting the power available to the bit [1, 2].

Due to the random nature of multiple components, including bit/formation contact, drillstring/borehole interaction, and hydraulics, drillstring vibrations are incredibly complicated. They contain a wide variety of phenomena, which makes the analysis rather difficult. Drilling can cause vibration in three different ways: axial, torsional, and lateral. These modes are accompanied by the phenomena bit bounce, stick/slip, and whirling, respectively [1, 2, 4, 15].

**Axial Vibration Model**

The undamped classical wave equation is expressed as follows:

$$\frac{\partial^2 \xi(x,t)}{\partial x^2} = \frac{1}{c^2} \frac{\partial^2 \xi(x,t)}{\partial t^2}$$

(1)

The general solution of the above equation including the superposition of terms is expressed in the following form:

$$\xi_n(x,t) = \left( A_n \sin \frac{\omega_n}{c} x + B_n \cos \frac{\omega_n}{c} x \right) \left( C_n \sin \omega_n t + D_n \cos \omega_n t \right), n=1,2,\ldots$$

(2)

Where $x$ refers to distance/or the beam axis, and $t$ refers to time. Also, the axial wave velocity is expressed as follows:

$$c^2 = \frac{E}{\rho}$$

(3)

Where $E$ is the Young modulus and $\rho$ is the material density.

The motion equation of the axial drillstring vibrations taking damping and external forces into account is expressed as follows:

$$\rho \frac{\partial^2 \xi}{\partial t^2} + c_a \frac{\partial \xi}{\partial t} - E \frac{\partial^2 \xi}{\partial x^2} + \rho g_z = g_a \left( x,t, \xi, \frac{\partial \xi}{\partial x}, \frac{\partial \xi}{\partial t} \right)$$

(4)

Where $C_a$ is a damping factor, $g_z$ is the acceleration gravity, and $g_a$ is the external axial force/unit mass affecting on the drillstring.

Bit bounce: The radial variation considering the coupling of axial and torsional vibrations of the drillstring BHA and with establishing the surface continuity in its center, is expressed as follows:

$$S(r,\phi) = S_n \sin \left( \frac{r}{\Delta r_b} \frac{\pi}{2} \right) \sin (3\phi), 0 \leq r \leq \Delta r_b \text{ and } 0 \leq \phi \leq 2\pi$$

$$S_o \sin \left( \frac{r}{\Delta r_b} \frac{\pi}{2} \right) \sin (3\phi), \Delta r_b \leq r \leq r_b$$

(5)

Where $r_b$ is the wellbore radius, $\Delta r_b$ is a smaller radius than $r_b$, and $r$ & $\phi$ are the radial and angular coordinates.

**Torsional Vibrations**

The torsional behavior of the assembly is expressed as follows:

$$\rho J \frac{\partial^2 \phi}{\partial t^2} - JG \frac{\partial^2 \phi}{\partial x^2} = g_T \left( x, \phi, t \right)$$

(6)

Where $J$ is the polar moment of inertia, $\phi$ is the angular displacement of the BHA, $G$ is the shear modulus of material, $g_T(x,0,t)$ is the torsional applied load, and $JG$ the product represents the torsional stiffness.

Stick/Slip Model: The equation of motion for this model when the rotary table moves at surface with constant speed, is expressed as follows:

$$I \dot{\phi} + c_r \dot{\phi} + F(\dot{\phi}) + k \phi = k \dot{U} t$$

(7)

Where $c_r$ is the coefficient of viscous damping, $k$ is the torsional stiffness of the drillstring, $I$ is the mass moment of inertia with respect to the rotation axial, and $F(\phi)$ is the friction induced forces.

Lateral Vibrations: The Euler-Bernoulli equation taking the axial forces effect into consideration with differential equations is expressed as follows:

$$\rho \frac{\partial^2 \phi}{\partial t^2} - \frac{\partial^2 \phi}{\partial x^2} \left( EI_z \frac{\partial^2 u}{\partial x^2} \right) = g(x,t)$$

(8)

$$\rho \frac{\partial^2 u}{\partial t^2} + \frac{\partial^2 \phi}{\partial x^2} \left( EI_z \frac{\partial^2 u}{\partial x^2} \right) - P \frac{\partial^2 u}{\partial t^2} = g(x,t)$$

(9)

Where $u(x,t)$ is the lateral displacement, $\rho$ is the mass density, $E$ is the modulus of elasticity, $Iz$ is the moment of inertia, and $g(x,t)$ refers to the external load.

**Whirling Model**

Equations of motion considering the RPM as a constant for a point equidistant located between two stabilizers are presented as follows:

$$ m \ddot {y} + c _ {w} \dot {y} + k _ {w} y = m e _ {0} \mathrm {U} ^ {2} \cos (\mathrm {U} t) \tag {10} $$ ( ) $$ m \ddot {z} + c _ {w} \dot {z} + k _ {w} y = m e _ {0} \mathrm {U} ^ {2} \sin (\mathrm {U} t) \tag {11} $$ ( ) Where e0 is the eccentricity of the center of mass cw is the damping coefficient kw is the lateral stiffness of collar m is the mass of DC y & z are the lateral coordinates Ω is the drillstring rotational speed

Field Data Description

One of the onshore oil reservoir fields is called Zubair field, and it is situated in southern Iraq. Figure 1 depicts a map of the producing zones, including the third and fourth pay zones and their drilled wells, as well as a structural contour map. The reference wells for the production expectation for well ZB-398 Dir (proposed) in the third pay zone reservoir are ZB-283, ZB-325, ZB-078, ZB-116 as oil producers and injectors, and ZB-278 and ZB-210 as water injectors. The reference well for ZB-385 Dir (new) production expectation in the fourth pay zone reservoir, however, is ZB-200. The company’s long-term goals include expanding into new markets and boosting output. The current plans, however, represent a development strategy. It is consequently intended to drill three development wells to improve oil output from the Zubair field reservoir’s third pay zone. The third pay zone is being produced by 14 wells. The three to be drilled wells are designated ZB-390, ZB-391, and ZB-398. The vibration logs are accessible for six wells: ZB-288, ZB-290, ZB-295, ZB-311, ZB-349, and ZB-367, and time- based vibration data are collected. For each well, three runs of vibration logs are recorded ZB 288 runs: 500, 600, and 700; ZB 290 runs: 500, 600, and 700; and ZB 295 runs: 400, 500, and 600.

Wells ZB 311 and 349 run at 400, 500, and 600, respectively, whereas well ZB 367 runs at 300, 400, and 500. Tables 3 & 4 display the depth interval for each run for each well. The combined gamma ray, total flow, ROP, surface pressure, surface rotary speed, average WOB, average torque, lateral vibrations (Avg X and Avg Y), axial vibrations, DDSr RPM Variation, and other recorded data are all included in the vibration logs displayed in Figure 2. There have been more explanations and information published about this field [36, 37, 38]. Figure 1-b shows the s-shape profile with details of well ZB-290 and the necessary BHA for drilled 8 1/2” hole section appeared in Table 2.

Figure 1
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Figure 1

Figure 1a: Zubair field with its wells [36].

DescriptionOD (in)ID (in)MaK OD (in)Bottom Conn.Top Conn.Length (m)Cumulative Length (m)
18 1/2” PDC bit8.5-8.54 1/2” REG B0.280.28
17” SperryDrill Lobe 7/8 - 7.5 stg, STB sleeve 8.125, BH 1.22°74.958.254 1/2” REG B4 1/2” 1F B9.319.59
1Float Sub6.82.756.84 1/2” IF P4 1/2” 1F B0.8210.41
17 5/8” Stabilizer6.82.817.6254 1/2” IF P4 1/2” 1F B1.5711.98
16 3/4” OM COLLAR6.753.136.754 1/2” IF P4 1/2” 1F B2.814.78
16 3/4” DGR COLLAR6.751.926.754 1/2” If P4 1/2” If B1.9616.74
16 3/4” EWR-P4 COLLAR6.7526.754 1/2” IF P4 1/2” 1F B3.6620.4
16 3/4” HCIM COLLAR6.751.926.754 1/2” IF P4 1/2” 1F B1.4521.85
16 3/4” BAT COLLAR6.751.916.754 1/2” IF P4 1/2” 1F B6.7428.59
16 3/4” TM COLLAR6.753.136.754 1/2” IF P4 1/2” 1F B3.0431.63
125” HWDP5354 1/2” IF P4 1/2” 1F B112.32143.95
16 1/2” DJ6.52.56.54 1/2” IF P4 1/2” I F B6.47150.42
95” HWDP5354 1/2” IF P4 1/2” I F B84.29234.71

Table 2: Directional BHA for 8 ½” hole section (3190m-3559m).

Figure 2: There have been more explanations and information published about this field [36- 38]. Figure 1-b shows the s-shape profile with details of well ZB-290 and the necessary BHA for drilled 8 1/2” hole section appeared in Table 2.
Click to enlarge
Figure 2: There have been more explanations and information published about this field [36- 38]. Figure 1-b shows the s-shape profile with details of well ZB-290 and the necessary BHA for drilled 8 1/2” hole section appeared in Table 2.

Figure 1b: Well ZB-290 profile S-shape with all drilled section.

Figure 3: Variation of displacements for various RPMs.
Click to enlarge
Figure 3: Variation of displacements for various RPMs.

Study Results and Analysis

It is obvious that the various kinds of drilling vibrations have a significant influence on drilling performance and lengthen non-productive time. As a result, the non- productive cost will go up. There are six Zubair fields drill wells here (Figure 1) with vibration data shown Figure 2. ZB-288, ZB-290, ZB-295, ZB-311, ZB-349, and ZB-367 are the wells in question. Previously, vibration logs and drilling parameters were used to identify and evaluate the vibrations caused by the drillstring of Zubair field wells. Following the identification of the various vibration mode types and their associated sources, proposed mitigation measures are given. Additionally, these vibrations are graded and categorized to establish the level of severity of each run in drilled wells. Here, we present only the results of well ZB-290 which will be used in our work in this paper. Tables 3 & 4 show the diagnostic analysis of recoded vibrations, their modes and the required control methods.

Value (RPM) %Stick-Slip (RPM)% (RUN)LevelStateDepth (M)Limit Time
160-200>100 (500)SevereStick-slip2707-2723Immediately reduce vibration
ZB 29020-400~40 (600)Low-3245-3270NO
80-12080~100(700)HighStick-slip3549-3556Must reduce vibration 30 minutes

Table 3: Diagnostic and vibrations analysis of data recorded in 6 Zubair wells [38].

ValueAvg X(g)Avg Y(g)Avg Z(g)Peak X(g)Peak Y(g)Peak Z(g)Formal & TypesActionSigns of Success
290 Run 500RANG0-200-200-(10/-10)0-2000-2000-(100/-100)Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration
290 Run 500MIN0.130.402.71.360Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration
290 Run 500MAX0.9391.07012.169.520Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration
290 Run 500>2>2>20>20>10Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration
290 Run 600RANG0-200-200-(10/-10)0-2000-2000-(100/-100)Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration
290 Run 600MIN0.540.5401.346.710Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration
290 Run 600MAX1.211.210.2731212.082.73Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration
290 Run 600>2>2>20>20>10Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration
290 Run 600RANG0-200-200-(10/-10)0-2000-2000-(100/-100)Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration
290 Run 600MIN0.540.5401.346.710Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration
290 Run 600MAX1.211.210.2731212.082.73Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration
290 Run 600>2>2>20>20>10Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration
290 Run 700RANG0-200-200-(10/-10)0-2000-2000-(100/-100)Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration
290 Run 700MIN0.130.4502.481.830Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration
290 Run 700MAX1.21.10.510.588.192.71Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration
290 Run 700>2>2>20>20>10Stick Slip (torsional vibration)Reduce SWOB & increase RPMLower vibration

Table 4: Identifying the drilling vibration modes and their mitigation ways for Zubair wells [38].

In this work, a sensitivity analysis study is done in well ZB-290 during drilling 8 1/2” hole section with directional BHA using Landmark software (Figures 1-b and Table 2) as shown in Figures 3 through 16. The study shows the impact of drillsting speed (RPM) on the BHA dynamics and vibration analysis. Firstly, the drillstring displacement shows higher values for lower speeds and 160-180 RPMs range (Figure 3) and show also higher values at shorter distances and higher rotational speeds (Figure 4). Figures 5 & 6 shows the torsional displacement from the bit with various RPMs. It’s clear that the more RPM, the higher torsional displacement appears after passing the speed of 100 RPM and in regard with the distance from the bit; the lower speed, the higher torsional displacement from the bit results. Then, the variation of torque for various RPMs shows an increasingly relationship i.e. the higher torque values achieve at higher rotational speed and at shorter distance from the bit (Figures 7 & 8). Furthermore, changing the RPM does not have any impact on the axial displacement until 180 RPM speed and this displacement appears with higher values at longer distance from the bit and decreases slowly with increasing the distance from the bit (Figure 9 & 10). This is due to the axial forces results at the same distances and behave like displacement change with the bit. Also, these forces rise with increasing the RPMs and vice versa (Figures 11 & 12). However, the variation of drillstring moments have a different behavior due to alteration of RPMs. Initially, their values increase with higher rotational speeds but values of 100-120 RPMs and 160-180 RPMs show an inclined higher values than normal trend. Additionally, shorter distance from the bit results in higher moments (Figures 13 &14). Finally, the stress components of BHA; which are bending, shear, torsional and shear; are gently rising with rotating the drillstring with higher RPMs. At short distance from the bit and at low RPMs, they appear lower stresses but the more RPMs, the higher stresses are results (Figures 15 & 16).

Figure 4: Variation of displacements with distance from bit for various RPMs.
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Figure 4: Variation of displacements with distance from bit for various RPMs.
Figure 5: Variation of torsional displacement for various RPMs.
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Figure 5: Variation of torsional displacement for various RPMs.
Figure 6: Variation of torsional displacement with distance from bit for various RPMs.
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Figure 6: Variation of torsional displacement with distance from bit for various RPMs.
Figure 7: Variation of torque with distance from the bit for various RPMs.
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Figure 7: Variation of torque with distance from the bit for various RPMs.
Figure 8: Variation of torque for various RPMs.
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Figure 8: Variation of torque for various RPMs.
Figure 9: Variation of axial displacement with distance from the bit for various RPMs.
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Figure 9: Variation of axial displacement with distance from the bit for various RPMs.
Figure 10: Variation of axial displacement for various RPMs.
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Figure 10: Variation of axial displacement for various RPMs.
Figure 11: Variation of axial force with distance from the bit for various RPMs.
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Figure 11: Variation of axial force with distance from the bit for various RPMs.
Figure 12: Variation of axial force for various RPMs.
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Figure 12: Variation of axial force for various RPMs.
Figure 13: Variation of moments for various RPMs.
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Figure 13: Variation of moments for various RPMs.
Figure 14: Variation of moments with distance from the bit for various RPMs.
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Figure 14: Variation of moments with distance from the bit for various RPMs.
Figure 15: Variation of stresses with distance from bit for various RPMs.
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Figure 15: Variation of stresses with distance from bit for various RPMs.
Figure 16: Variation of stresses for various RPMs.
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Figure 16: Variation of stresses for various RPMs.
Figure 17
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Figure 17

Conclusions

Based on the results and analysis, the following conclusions and recommendations are extracted:

  1. Sensitivity analysis is an important study showing the impact of any parameter on drilling performance and diagnosing the vibration modes and mitigation methods.
  2. RPM is a key-element in vibration analysis of the drillstring and BHAs.
  3. BHA dynamics and vibration analysis have been enhanced for Zubair wells.
  4. BHAs forces, stresses, displacements, torque, and moments have been successfully identified and analysed.
  5. This study adds a value in developing Zubair field and future wells.
  6. Drilling performance and future well designs will be enhanced based on the previous and this work.

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@article{algburi2023,
  title   = {Analyzing the Effects of Drillstring Speed on Bottom Hole Assembly Vibration in S-Shape Directional Wells: A Comprehensive Sensitivity Analysis},
  author  = {AlGburi H, Halafawi M, Lazăr D, Gal S and Avram L},
  journal = {Petroleum & Petrochemical Engineering Journal},
  year    = {2023},
  volume  = {7},
  number  = {1},
  doi     = {10.23880/ppej-16000337}
}
AlGburi H, Halafawi M, Lazăr D, Gal S and Avram L (2023). Analyzing the Effects of Drillstring Speed on Bottom Hole Assembly Vibration in S-Shape Directional Wells: A Comprehensive Sensitivity Analysis. Petroleum & Petrochemical Engineering Journal, 7(1). https://doi.org/10.23880/ppej-16000337
TY  - JOUR
TI  - Analyzing the Effects of Drillstring Speed on Bottom Hole Assembly Vibration in S-Shape Directional Wells: A Comprehensive Sensitivity Analysis
AU  - AlGburi H, Halafawi M, Lazăr D, Gal S and Avram L
JO  - Petroleum & Petrochemical Engineering Journal
PY  - 2023
VL  - 7
IS  - 1
DO  - 10.23880/ppej-16000337
ER  -