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<![CDATA[Comparison of Rock Type Determination Based on Permeability Estimation and FZI Value in Upper Cibulakan Shaly Sand Formation, ASR Field ]]>
<![CDATA[Anditya Sapta Rahesthi]]>;
<![CDATA[Ratnayu Sitaresmi]]>;
<![CDATA[Sigit Rahmawan]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 2 No. 3 (2019): JEESET VOL. 2 NO. 3 2019 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v2i3.6388
<![CDATA[Rock permeability is an important rock characteristic because it can help determine the rate of fluid production. Permeability can only be determined by direct measurement of core samples in the laboratory. Even though coring gives good results, the disadvantage is that it takes a lot of time and costs so it is not possible to do coring at all intervals. So that the well log is required to predict the level of permeability indirectly. However, the calculation of permeability prediction using well log data has a high uncertainty value, so rock typing is required so that the calculation of permeability prediction becomes more detailed. This research was conducted in an effort to determine the Hydraulic Flow Unit (HFU) of the reservoir in the well that has core data using the Flow Zone Indicator (FZI) parameter and FZI value propagation on wells that do not have core data so that the type of rock and permeability value are obtained from every well interval. From the results of the study, the reservoirs on the ASR field can be grouped into six rock types. The six rock types each have permeability as a function of validated porosity by applying it at all intervals. After FZI is calculated from log data and validated with core data, it can be seen that the results of the method produce a fairly good correlation (R2 = 0.92). Furthermore, from the permeability equation values for each different rock type, the predicted permeability results are also quite good (R2 = 0.81).]]>
<![CDATA[Modification of DS-01 Drilling Fluid to Reduce Formation Damage ]]>
<![CDATA[Winarto S.]]>;
<![CDATA[Sugiatmo Kasmungin]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 2 No. 3 (2019): JEESET VOL. 2 NO. 3 2019 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v2i3.6389
<![CDATA[In the process of drilling for oil and gas wells the use of appropriate drilling mud can reduce the negative impacts during ongoing drilling and post-drilling operations (production). In general, one of the drilling muds that are often used is conventional mud type with weighting agent barite, but the use of this type of mud often results in skin that is difficult to clean. Therefore in this laboratory research an experiment was carried out using a CaCO3 weigting agent called Mud DS-01. CaCO3 is widely used as a material for Lost Circulation Material so that it is expected that using CaCO3 mud will have little effect on formation damage or at least easily cleaned by acidizing. The aim of this research is to obtain a formula of mud with CaCO3 which at least gives formation damage. Laboratory experiments on this drilling mud using several mud samples adjusted to the property specifications of the mud program. Mud sample consists of 4, namely using super fine, fine, medium, and conventional CaCO3. First measuring mud properties in each sample then testing the filter cake breaker, testing the initial flow rate using 200 ml of distilled water and a 20 micron filter disk inserted in a 500 ml HPHT cell then assembled in a PPA jacket and injecting a pressure of 100 psi. The acidification test was then performed using 15% HCL and then pressured 100 psi for 3 hours to let the acid work to remove the cake attached to the filter disk (acidizing). Laboratory studies are expected which of these samples will minimize the formation damage caused by drilling fluids.]]>
<![CDATA[Optimization and Prediction of Sucker Rod Pump Performance on Well X-1 in Field X in the Future ]]>
<![CDATA[Mohammad Firdaus Sabaruddin]]>;
<![CDATA[Ilman Muhammad Azmi]]>;
<![CDATA[Callula Engrasia Fathoni Firdaus]]>;
<![CDATA[Muhamad Reza Shahrazade]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 2 No. 3 (2019): JEESET VOL. 2 NO. 3 2019 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v2i3.6390
<![CDATA[The performance of the sucker rod pump is influenced by the characteristics of the well and reservoir such as pressure, well productivity, physical properties of the fluid, depth and diameter of the well. Therefore, pumping pumps need to be designed and optimized taking into account these conditions. As time goes on production changes in physical properties occur in the reservoir such as a decrease in reservoir pressure and a decrease in well productivity. Changes in the physical properties of the reservoir will affect the performance of the sucker rod pump. The purpose of this study is to design a sucker rod pump at X-1 well and forecast production in the future. The flow rate determination is obtained from the point of intersection between the pump intake pressure curve and IPR curves both in the present and in the future. In this study the pump speed is set at 10 SPM. Based on this method it was found that the well can produce with a flow rate of 1132 bpd with an oil flow rate of 27 bpd. The stroke length for this condition is 304 inch. Over time the production is estimated to cause the pressure to decrease to 1010 psi in 2040. The decrease in reservoir pressure causes the reduction in the flow rate of sucker rod pump to 1046 bpd with an oil flow rate of 14.6 bopd. So that the magnitude of the reduction in the flow rate of liquid between 2019 and 2040 was 7.6%, while the decrease in the oil flow rate was 45.9%. If the speed is set at 10 SPM, the stroke length needs to be reduced with time. The stroke length was designed to be 304 inches in 3019 and reduced to 281 inches in 2040.]]>
<![CDATA[Implication of the Multiphase Influx in Well Control and Circulating System ]]>
<![CDATA[Sonny Irawan]]>;
<![CDATA[Imros B. Kinif]]>;
<![CDATA[Muhammad Taufiq Fathaddin]]>;
<![CDATA[Zulfadli B. Zakaria]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 3 No. 1 (2020): JEESET VOL. 3 NO. 1 2020 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v3i1.6391
<![CDATA[A multiphase flow system is commonly faced by oil and gas industries where it constituted of complex design and analysis [1]. Previous studies on the multiphase system have established a number of models including Hagerdon & Brown, Duns & Ros, Orkiszewki and Beggs & Brill [1]. Numerous studies have been carried out on the multiphase system related to production engineering [3]. However, the study on the multiphase system is found limited to be related to well control and drilling management. The multiphase system is interestingly important in well control especially during unwanted circumstances such as kick. Flow behavior and pattern might be different from one phase system where normally only gas kick is considered during design stage of the drilling campaign. Since the multiphase kick might represent different outcome compared to one phase system, an accurate calculation of multiphase kick is desired. Therefore, the purpose of this study is to observe the impact on the multiphase kick with on the pressure drop reading and its connection with a circulating system. The study will cover on Pressure drop calculation using Beggs & Brill correlation by consolidating all the data given from various sources; Identification of flow regime of the multiphase system for the base case with several reference pressure; Sensitivity analysis including the effect of different liquid content and liquid flow rate towards the pressure drop. The expected outcomes from this study are beneficial for well control management where necessary actions to prevent blowout.]]>
<![CDATA[The Effect of Invisible Lost Time on Drilling Performance of Geothermal Wells ]]>
<![CDATA[Fernandez Sabar Hasudungan Pangaribuan]]>;
<![CDATA[Sugiatmo Kasmungin]]>;
<![CDATA[Suryo Prakoso]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 3 No. 1 (2020): JEESET VOL. 3 NO. 1 2020 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v3i1.6662
<![CDATA[Drilling activity has been focused in time on each activity to reach target depth (TD) immediately and efficient in cost. The priority also aimed to Geothermal drilling by doing specific measurement on Invisible Lost Time (ILT) as new focus to perform. Time becomes main aspect which it would affect the cost, therefore it is important to complete the well in time manner. The research was done to analyze the offset well of well A, B, C and D in order to identify Productive Time and Non Productive Time. Key Performance Indicator (KPI) has been identified from each activity also targeted from two wells of well B dan Well D due to time efficiency used during operation. The method used by comparing offset wells then continue to identify each KPI by measuring each activity based on ASCII time and Daily Drilling Report (DDR). The result from offset wells showed inefficiency in time with Flat time 49%, Drilling 42% and non-flat time (NPT) 9% from 28 days without completion. KPI based on the crew performance has confirmed that day shift crew performed better than night shift crew. KPI on rate of penetration (ROP) on day shift crew at 6 m/hr and night crew at 3 m/hr. KPI on Weight to Weight on day shift crew at 28.43 minute/stand faster than night shif crew at 34.65 minute/stand. KPI on Tripping in cased hole on day shift crew at 4.5 minute/stand faster than night crew shift at 4.6 minute/stand. KPI on Tripping in open hole on day shift crew at 2.7 minute/stand faster than night shift crew at 3.7 minute/stand. KPI on Tripping out open hole on day shift crew at 3.0 minute/stand slower than night shift crew at 2.8 minute/stand. KPI on Tripping out cased hole on day shift crew at 3.36 minute/stand faster than night crew shift at 3.74 minute/stand. ILT from both wells to 20 % or 5 days inefficiency on each well. It detects of potential savings to 10 billion rupiah from both wells.]]>
<![CDATA[The Application of Permanent Magnet Motor on Electric Submersible Pump in X Well ]]>
<![CDATA[Andreas Setiabudi]]>;
<![CDATA[Muhammad Taufiq Fathaddin]]>;
<![CDATA[Suryo Prakoso]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 3 No. 1 (2020): JEESET VOL. 3 NO. 1 2020 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v3i1.6675
<![CDATA[In thisresearch the application of permanent magnet motor and asynchronous motor in X Well was evaluated. The permanent magnet motor and asynchronous motor used in this research are PM51 – NFO 150 FLT @50hz and AM51 – NFO 150 FLT @50hz, respectively. Several parameters are compared such energy losses, energy consumption, motor heating, and production rate. Based on the data analysis, there are some advantages by using permanent magnet motor which can help to improve efficiency and consume less energy, therefore can give more profit within the same period of production. These advantages consist of durability for motor, consume less electricity energy to maintain the operation of ESP string, give bigger production rate, and longer expected life time than an asynchronous motor. The implementation of permanent magnet motor is recommended in oil well that has high fluctuation in production flow rate, since the setting flow rate of the motor is adjustable. This advantage can be useful to give longer lifetime and hence to reduce the pump replacement program]]>
<![CDATA[Compartement Analysis of Reservoir X Uses Dynamic Data and Geology Data in ND Structure, South Sumatera ]]>
<![CDATA[Nida Muthia Lamis]]>;
<![CDATA[Suryo Prakoso]]>;
<![CDATA[Rini Setiati]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 3 No. 1 (2020): JEESET VOL. 3 NO. 1 2020 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v3i1.6676
<![CDATA[The ND Structure is located in the South Sumatra Basin, which is located in the ND Block. The ND Structure is located in the South Sumatra Basin, South Sumatra Province. This Structure is the southern part of the South Sumatra Basin onshore.The reservoir x compartmentalization analysis is carried out using the fault seal analysis method, mapping the reservoir x property combined with the analysis of pressure data between compartments. Combining the method between fault seal analysis, history of pressure trend analysis and mapping of subsurface properties can be used as a method to explain and describe reservoir compartment. Reservoir connectivity of Reservoir X separated by faults and property barriers in ND Structure, so from the analysis that reservoir X is divided into 4 (four) compartments.]]>
<![CDATA[Study of Polymer Flooding Behavior in Heterogeneous Two-Layered Porous Media ]]>
<![CDATA[Muhammad Taufiq Fathaddin]]>;
<![CDATA[Kartika Fajarwati Hartono]]>;
<![CDATA[Trijana Kartoatmodjo]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 3 No. 1 (2020): JEESET VOL. 3 NO. 1 2020 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v3i1.6679
<![CDATA[In this paper, a numerical study was conducted to investigate the effect of spatial heterogeneity of multiple porosity fields on oil recovery, residual oil saturation, polymer retained, and polymer adsorption. The generated porosity fields were applied to UTCHEM for simulating polymer and water flooding in heterogeneous two-layered porous media. From the analysis, the increase of reservoir heterogeneity resulted in higher polymer retention and lower polymer adsorption. In general, polymer flooding results in more balance residual oil saturation in the upper and lower layer than water flooding. This indicated that the vertical sweep efficiency of polymer flooding was better than water flooding. Residual oil saturation ratio between layers after water or polymer flooding was about equal along with the increase of reservoir heterogeneity. Spatial heterogeneity of multiple porosity fields had only a small effect on recovery factor. The variation of the recovery factor of polymer and water flooding due to the reservoir heterogeneity was under 1%.]]>
<![CDATA[Simulation Study of Hot Waterflood and WASP Injection Post Mature Steamflood ]]>
<![CDATA[Ludovika Jannoke]]>;
<![CDATA[Iwan Setya Budi]]>;
<![CDATA[Astra Agus Pramana]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 3 No. 2 (2020): JEESET VOL. 3 NO. 2 2020 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v3i2.7600
<![CDATA[Steamflood is the most successful thermal EOR applied throughout the world and have produced the biggest portion of oil from EOR methods. As high intensity energy and associated cost are put to produce oil, optimization in any level can have tremendous impacts. Optimization in steamflood operation can be achieved by optimizing steam injection (rate, time), especially in mature pattern/ field or nearing the end of field life/ abandonment. This objective can be done thru utilization of retained heat in the reservoir and overburden/ underburden as they are not instantaneously produced with fluids. By using reservoir simulation, it can be shown that injection is not necessary to be continue until abandonment but can be stopped at a much earlier time hence a much profitable steamflood operation can be achieved.]]>
<![CDATA[Pipe Network Evaluation for "X" Field Production Optimization ]]>
<![CDATA[Slamet Widodo Kurniansyah]]>;
<![CDATA[Esaim Mustafa Abrahim Omar]]>;
<![CDATA[Dwi Atty Mardiana]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 3 No. 2 (2020): JEESET VOL. 3 NO. 2 2020 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v3i2.7601
<![CDATA[Fields "X" is an old field in the South East Sumatra Block. The area was developed using ten platforms. One main problems on this field is the disruption of some wells productivity due to flow constraints in the piping network. The objective of this paper is to evaluate the pipeline network for area "X1" using simulation model. The simulation results show that there are bottlenecking and backpressure problems in the network. By fixing the problems, total oil production in this area can be increased up to 19 percent or 1,006.2 BOPD higer than initial condition.]]>
