scholarly journals Optimasi Hidrolika Sumur “SH” Lapangan “U” Kalimantan Timur dengan Metode Bit Hydroulic Horse Power

2018 ◽  
Vol 2 (2) ◽  
pp. 1
Author(s):  
Sri Haryono
Keyword(s):  
Hydraulic System ◽  
Actual Data ◽  
Drilling Process ◽  
Fluid Flow Rate ◽  
Drilling Mud ◽  
East Kalimantan ◽  
Nozzle Size ◽  
Drilling Data ◽  
Drilling System ◽  
Horse Power

<p>Lapangan “U” ditempatkan di Cekungan Tarakan, yang merupakan salah satu daerah cekungan hidrokarbon Kalimantan Timur. Formasi yang ditembus oleh mata bor terdiri dari batupasir, batulanau, batulempung dan batubara. Oleh karena itu, kita perlu mengatur ulang sistem lumpur pengeboran terutama pada sistem hidrolik lumpur pengeboran. Penelitian ini bertujuan untuk mengoptimalkan sistem hidrolik dalam proses pengeboran untuk sumur “SH” Lapangan “U” menggunakan metode <em>Bit Hydraulic Horse Power (BHHP). </em>Hasil<em> </em>dari metode ini adalah untuk menentukan laju alir fluida <em>BHHP</em> yang optimal, daya tembus, ukuran nozzle, dan membandingkan parameter ini dengan data pengeboran aktual sebelum optimasi (data aktual) sehingga penetrasi proses pembentukan juga optimal. Berdasarkan data aktual dari semua pengeboran sumur ke 13 titik kedalaman harus dioptimalkan terutama dalam sistem pengeboran hidrolik dengan mengubah ukuran area aperture pada <em>nozzle</em> bor dan daya sesuai dengan perhitungan.</p><p><em><span class="tlid-translation translation" lang="en">The "U" field is located in the Tarakan Basin, which is one of the East Kalimantan hydrocarbon basin areas. The formation penetrated by the drill bit consists of sandstone, siltstone, claystone and coal. Therefore, we need to rearrange the drilling mud system, especially in the hydraulic drilling mud system. This study aims to optimize the hydraulic system in the drilling process for "SH" well "U" wells using the Bit Hydraulic Horse Power (BHHP) method. The result of this method is to determine the optimal BHHP fluid flow rate, permeability, nozzle size, and compare these parameters with actual drilling data before optimization (actual data) so that the penetration of the formation process is also optimal. Based on actual data from all wells drilling to 13 points the depth must be optimized especially in the hydraulic drilling system by changing the size of the aperture area on the drill nozzle and the power according to the calculation.</span></em></p>

scholarly journals Drilling in Karstified Carbonates: Early Risk Detection Technique

2020 ◽  
Author(s):  
Danil Maksimov ◽  
Alexey Pavlov ◽  
Sigbjørn Sangesland
Keyword(s):  
Real Time ◽  
Barents Sea ◽  
Rock Properties ◽  
Drilling Process ◽  
Drilling Mud ◽  
Online Tool ◽  
Low Contrast ◽  
Lost Circulation ◽  
Drilling Data ◽  
Mud Loss

Abstract Heterogeneous nature and complex rock properties of carbonate reservoirs makes the drilling process challenging. One of these challenges is uncontrolled mud loss. Caves or a system of cavities could be a high-risk zone for drilling as the mud losses cannot always be controlled by conventional methods, such as mud weight (MW) / equivalent mud weight (ECD) optimization, or by increasing concentration of lost circulation material (LCM) in the drilling mud. Seismic-based detection of such karstification objects is inefficient due to relatively small size, various shapes and low contrast environment. In this paper we, based on drilling data from the Barents sea, analyzed possible patterns in real-time drilling data corresponding to drilling through karstification objects. These patterns can serve as real-time indicators of zones with higher risk of karsts and can be used as an online tool for decision support while drilling in karstified carbonates.

scholarly journals Autonomous Decision-Making While Drilling

Energies ◽  
2021 ◽  
Vol 14 (4) ◽  
pp. 969
Author(s):  
Eric Cayeux ◽  
Benoît Daireaux ◽  
Adrian Ambrus ◽  
Rodica Mihai ◽  
Liv Carlsen
Keyword(s):  
Decision Making ◽  
Internal State ◽  
Drilling Process ◽  
Autonomous Decision ◽  
Internal States ◽  
Markov Decision ◽  
Drilling Operations ◽  
Drilling System ◽  
Drilling Conditions ◽  
Erratic Behavior

The drilling process is complex because unexpected situations may occur at any time. Furthermore, the drilling system is extremely long and slender, therefore prone to vibrations and often being dominated by long transient periods. Adding the fact that measurements are not well distributed along the drilling system, with the majority of real-time measurements only available at the top side and having only access to very sparse data from downhole, the drilling process is poorly observed therefore making it difficult to use standard control methods. Therefore, to achieve completely autonomous drilling operations, it is necessary to utilize a method that is capable of estimating the internal state of the drilling system from parsimonious information while being able to make decisions that will keep the operation safe but effective. A solution enabling autonomous decision-making while drilling has been developed. It relies on an optimization of the time to reach the section total depth (TD). The estimated time to reach the section TD is decomposed into the effective time spent in conducting the drilling operation and the likely time lost to solve unexpected drilling events. This optimization problem is solved by using a Markov decision process method. Several example scenarios have been run in a virtual rig environment to test the validity of the concept. It is found that the system is capable to adapt itself to various drilling conditions, as for example being aggressive when the operation runs smoothly and the estimated uncertainty of the internal states is low, but also more cautious when the downhole drilling conditions deteriorate or when observations tend to indicate more erratic behavior, which is often observed prior to a drilling event.

Enhancement lubricity properties of water-based mud with nanoparticles

2020 ◽  
pp. 70-74
Author(s):  
V.V. Guliyev ◽  
◽  
◽  
Keyword(s):  
Yield Point ◽  
Coefficient Of Friction ◽  
Drilling Fluid ◽  
Research Work ◽  
Shear Thinning ◽  
Rheological Parameters ◽  
Drilling Process ◽  
Drilling Mud ◽  
Pseudoplastic Fluid ◽  
Water Based

Currently, a great number of drilling fluids with different additives are used all over the world. Such additives are applied to control the properties of the drilling mud. The main purpose for controlling is to achieve more effective and safe drilling process. This research work aims to develop Water-Based Mud (WBM) with a Coefficient of Friction (CoF) as low as Oil-Based Mud (OBM) and better rheological properties. As it is known, produced CoF by WBM is higher than OBM, which means high friction between wellbore or casing and drill string. It was the reason for studying the effect of nanosilica on drilling fluid properties such as lubricity, rheological parameters and filtrate loss volume of drilling mud. The procedures were carried out following API RP 13B and API 13I standards. Five concentrations of nanosilica were selected to be tested. According to the results obtained, it was defined that adding nanosilica into the mud decreases CoF of basic WBM by 26 % and justifies nanosilica as a good lubricating agent for drilling fluid. The decreasing trend in coefficient of friction and plastic viscosity for nanosilica was obtained until the concentration of 0.1 %. This reduction is due to the shear thinning or pseudoplastic fluid behavior. After 0.1 %, an increase at PV value trend indicates that it does not follow shear thinning behavior and after reaching a certain amount of dissolved solids in the mud, it acts like normal drilling fluid. The yield point of the mud containing nanoparticles was higher than the basic one. Moreover, a growth in the concentration leads to an increase in yield point value. The improvement of this fluid system cleaning capacity via hydraulics modification and wellhole stability by filter cake endurance increase by adding nanosilica is shown as well. The average well construction data of “Neft Dashlary” field was used for the simulation studies conducted for the investigation of hydraulics parameters of reviewed fluids for all series of experiments. The test results were accepted reliable in case of at least 3 times repeatability.

Real-Time Software to Estimate Friction Coefficient and Downhole Weight on Bit During Drilling of Horizontal Wells

2014 ◽  
Author(s):  
Mazeda Tahmeen ◽  
Geir Hareland ◽  
Bernt S. Aadnoy
Keyword(s):  
Friction Coefficient ◽  
Real Time ◽  
Information Transfer ◽  
Horizontal Wells ◽  
Drill String ◽  
Surface Measurement ◽  
Drilling Process ◽  
Drilling Data ◽  
Weight On Bit ◽  
Drag Analysis

The increasing complexity and higher drilling cost of horizontal wells demand extensive research on software development for the analysis of drilling data in real-time. In extended reach drilling, the downhole weight on bit (WOB) differs from the surface seen WOB (obtained from on an off bottom hookload difference reading) due to the friction caused by drill string movement and rotation in the wellbore. The torque and drag analysis module of a user-friendly real-time software, Intelligent Drilling Advisory system (IDAs) can estimate friction coefficient and the effective downhole WOB while drilling. IDAs uses a 3-dimensional wellbore friction model for the analysis. Based on this model the forces applied on a drill string element are buoyed weight, axial tension, friction force and normal force perpendicular to the contact surface of the wellbore. The industry standard protocol, WITSML (Wellsite Information Transfer Standard Markup Language) is used to conduct transfer of drilling data between IDAs and the onsite or remote WITSML drilling data server. IDAs retrieves real-time drilling data such as surface hookload, pump pressure, rotary RPM and surface WOB from the data servers. The survey data measurement for azimuth and inclination versus depth along with the retrieved drilling data, are used to do the analysis in different drilling modes, such as lowering or tripping in and drilling. For extensive analysis the software can investigate the sensitivity of friction coefficient and downhole WOB on user-defined drill string element lengths. The torque and drag analysis module, as well as the real-time software, IDAs has been successfully tested and verified with field data from horizontal wells drilled in Western Canada. In the lowering mode of drilling process, the software estimates the overall friction coefficient when the drill bit is off bottom. The downhole WOB estimated by the software is less than the surface measurement that the drillers used during drilling. The study revealed verification of the software by comparing the estimated downhole WOB with the downhole WOB recorded using a downhole measuring tool.

A New Numerical Solution To Predict the Temperature Profile of Gas-Hydrate-Well Drilling

SPE Journal ◽  
2017 ◽  
Vol 22 (04) ◽  
pp. 1201-1212 ◽  
Author(s):  
Ben Li ◽  
Hui Li ◽  
Boyun Guo ◽  
Xiao Cai ◽  
Mas lwan Konggidinata
Keyword(s):  
Numerical Model ◽  
Temperature Profile ◽  
Gas Hydrates ◽  
Gas Hydrate ◽  
Drilling Fluid ◽  
Drilling Process ◽  
Thomson Effect ◽  
Drilling Mud ◽  
Pumping Rate ◽  
Well Drilling

Summary Gas-hydrate cuttings are conveyed upward by the drilling fluid through the outer drillpipe/wellbore annulus during the gas-hydrate-well-drilling process. The temperature profile along the wellbore during the drilling process has not been thoroughly investigated because the gas-hydrate cuttings could affect the temperature of the drilling fluid along the wellbore. As the mixture of drilling fluid and gas hydrates flows from the bottom to the surface, the methane and other hydrocarbons present in the gas hydrates would change from liquid to gas phase and further cause well-control issues. Furthermore, the bottomhole pressure would decrease and could not provide sufficient balance to the formation pressure, which could significantly increase the risk of well blowout. A numerical solution is presented in this paper to predict the temperature profile of the gas-hydrate well during the drilling process. The main considerations were the following: Hydrate cuttings entrained in the bottom of the hole would affect the temperature of the fluid in the annulus space. The entrained hydrate cuttings could affect the fluid thermal properties in the drillstring and in the annulus. Because of the Joule-Thomson cooling effect at the outlet of the nozzles, the fluid temperature at the bottom of the hole was lower than that above the drill-bit nozzles. Hence, the gas-hydrate-dissociation characteristics were considered and integrated in the proposed numerical model. The numerical model was validated by comparing the obtained data with the Shan et al. (2016) analytical model. In addition, the obtained data were also compared with the measured temperature data of a conventional well drilled in China and a gas-hydrate-well drilling record in India. Sensitivity analysis was used to evaluate the effects of the pumping rate, Joule-Thomson effect, and injection drilling-mud temperature on the annulus temperature-profile distribution. It was found that the injection drilling-mud temperature and pumping rate could affect the temperature profile in the annulus, whereas the Joule-Thomson effect could decrease the annulus temperature of the drilling mud near the bottom.

scholarly journals A temperature-pressure coupling model for predicting gas temperature profile in gas drilling

2020 ◽  
pp. 193-193
Author(s):  
Jinjiang Liu ◽  
Wenlin Wu ◽  
Peng Qian ◽  
Shuo Wang
Keyword(s):  
Temperature Profile ◽  
Drilling Fluid ◽  
Physical Parameters ◽  
Drilling Process ◽  
Gas Temperature ◽  
Gas Drilling ◽  
Bottom Hole ◽  
Pump Rate ◽  
Nozzle Size ◽  
Wellbore Temperature

In the gas drilling design, accurate prediction of wellbore temperature profile is very crucial. Different from liquid drilling fluid, physical and thermo-physical parameters of gases are sensitive to the change of pressure and temperature, at the same time, the change of these parameters will react against the wellbore temperature and pressure. Based on the energy conservation principle, a temperature-pressure coupling calculation model was established to predict the gas temperature profile during gas drilling process. The model is solved by cycle coupling iteration method. The calculation shows that annular temperature rises sharply near the wellhead, drops sharply at bottom hole and is a little higher than the formation temperature in other places. Without considering the influence of friction heat, calculated temperature is lower than the actual temperature. Temperature trends are the same under different pump rates and larger pump rate leads to larger temperature range at the wellhead and at bottom hole. Compared with the pump rate, bit nozzle size has more influence on the temperature drop range. Temperature reduction increases from 31.3?C to 57.2?C while bit nozzle size decreases from 539 mm2 to 339 mm2.

scholarly journals Exploitation of Field Drilling Data with an Innovative Drilling Simulator: Highly Effective Simulation of Rotating and Sliding Mode

2021 ◽  
Author(s):  
Alexis Koulidis ◽  
Vassilios Kelessidis ◽  
Shehab Ahmed
Keyword(s):  
Field Data ◽  
Sliding Mode ◽  
P Wave ◽  
Drilling Process ◽  
Continuous Change ◽  
Rate Of Penetration ◽  
Drilling Performance ◽  
Drilling Parameters ◽  
Rock Drillability ◽  
Drilling Data

Abstract Drilling challenging wells requires a combination of drilling analytics and comprehensive simulation to prevent poor drilling performance and avoid drilling issues for the upcoming drilling campaign. This work focuses on the capabilities of a drilling simulator that can simulate the directional drilling process with the use of actual field data for the training of students and professionals. This paper presents the results of simulating both rotating and sliding modes and successfully matching the rate of penetration and the trajectory of an S-type well. Monitored drilling data from the well were used to simulate the drilling process. These included weight on bit, revolutions per minute, flow rate, bit type, inclination and drilling fluid properties. The well was an S-type well with maximum inclination of 16 degrees. There were continuous variations from rotating to sliding mode, and the challenge was approached by classifying drilling data into intervals of 20 feet to obtain an appropriate resolution and efficient simulation. The simulator requires formation strength, pore and fracture pressures, and details of well lithology, thus simulating the actual drilling environment. The uniaxial compressive strength of the rock layer is calculated from p–wave velocity data from an offset field. Rock drillability is finally estimated as a function of the rock properties of the drilled layer, bit type and the values of the drilling parameters. It is then converted to rate of penetration and matched to actual data. Changes in the drilling parameters were followed as per the field data. The simulator reproduces the drilling process in real-time and allows the driller to make instantaneous changes to all drilling parameters. The simulator provides the rate of penetration, torque, standpipe pressure, and trajectory as output. This enables the user to have on-the-fly interference with the drilling process and allows him/her to modify any of the important drilling parameters. Thus, the user can determine the effect of such changes on the effectiveness of drilling, which can lead to effective drilling optimization. Certain intervals were investigated independently to give a more detailed analysis of the simulation outcome. Additional drilling data such as hook load and standpipe pressure were analyzed to determine and evaluate the drilling performance of a particular interval and to consider them in the optimization process. The resulting rate of penetration and well trajectory simulation results show an excellent match with field data. The simulation illustrates the continuous change between rotating and sliding mode as well as the accurate synchronous matching of the rate of penetration and trajectory. The results prove that the simulator is an excellent tool for students and professionals to simulate the drilling process prior to actual drilling of the next inclined well.

scholarly journals STUDI LABORATORIUM PENGARUH PENAMBAHAN POLIMER SINTESIS DAN TEPUNG SAGU TERHADAP SIFAT RHEOLOGY LUMPUR AIR ASIN SISTEM DISPERSI PADA BERBAGAI TEMPERATUR

PETRO ◽  
2019 ◽  
Vol 7 (4) ◽  
pp. 165
Author(s):  
Randy Mahaputra Ginting
Keyword(s):  
Physical Properties ◽  
Polymer Materials ◽  
Colloid Solution ◽  
Drilling Process ◽  
Drilling Mud ◽  
Standard Specification ◽  
Dispersion System ◽  
Large Dispersion ◽  
Potential Problems ◽  
Dispersing Medium

<p><em>Drilling is one of the important things in the drilling process, from the start of drilling to the point of reaching the intended depth, can assist the smooth process of drilling. The potential problems that can arise one of them is the drilling mud reply (loss of circulation). One way to prevent and cope with the discovery of drilling mud is dissolved. At this time Polymers Synthesis and Sago Flour as material for dissolved system. Both materials enter into the colloidal effect. The colloid solution itself is a relatively large, relatively large dispersion system within the dispersing medium.</em></p><p><em>The purpose and objective in collecting these tasks is to determine the effectiveness of Synthetic and Sago Flour Polymer materials in tackling the drilling mud stock problem. Based on the results of the research found, that A sludge system can provide most of the standard specification where the value of physical properties and rheology. While the B sludge system is inversely proportional, most of it does not meet the standard specification. It can be underlined that B system with Sago Flour as LCM is effective in handling dispersion drilling mud.</em></p>

Continuous High-Frequency Measurements of the Drilling Process Provide New Insights into Drilling System Response and Transitions between Vibration Modes

2014 ◽  
Author(s):  
Adam Ian Bowler ◽  
Lojini Logesparan ◽  
Junichi Sugiura ◽  
Benjamin P Jeffryes ◽  
Richard John Harmer ◽  
...  
Keyword(s):  
High Frequency ◽  
System Response ◽  
Drilling Process ◽  
Vibration Modes ◽  
Frequency Measurements ◽  
Drilling System
Sign in / Sign up

Export Citation Format

Share Document