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Ristiyan Ragil Putradianto
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Journal of Petroleum and Geothermal Technology
Published by Universitas Pembangunan Nasional Veteran Yogyakarta
ISSN : 27230988     EISSN : 27231496     DOI : https://doi.org/10.31315/jpgt.v1i1
Core Subject : Science, Engineering,
Earth & Planetary Sciences Energy Engineering
Journal of Petroleum and Geothermal Technology (JPGT) is a journal managed by Petroleum Engineering Department, Universitas Pembangunan Nasional "Veteran" Yogyakarta. This Journal focuses on the petroleum and geothermal engineering including; reservoir engineering, drilling engineering and production engineering.
Arjuna Subject : Teknik (semua kategori) - Teknik (Lain-Lain)
Articles 39 Documents
 1   2   3   4 
An Experimental Investigation the Optimum of Salinity and Ph of Sea-Water to Improve Oil Recovery from Sandstone Reservoir as A Secondary Recovery Process Madi Abdullah Naser; Mohammed A Samba; Yiqiang Li
Journal of Petroleum and Geothermal Technology Vol 1, No 2 (2020): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v1i2.3810

Abstract

Laboratory tests and field applications shows that the salinity of water flooding could lead to significant reduction of residual oil saturation. There has been a growing interest with an increasing number of low-salinity water flooding studies. However, there are few quantitative studies on seawater composition change and it impact on increasing or improving oil recovery.  This study was conducted to investigate only two parameters of the seawater (Salinity and pH) to check their impact on oil recovery, and what is the optimum amount of salinity and ph that we can use to get the maximum oil recovery.  Several core flooding experiments were conducted using sandstone by inject seawater (high, low salinity and different pH). The results of this study has been shown that the oil recovery increases as the injected water salinity down to 6500 ppm and when the pH is around 7. This increase has been found to be supported by an increase in the permeability. We also noticed that the impact of ph on oil recovery is low when the pH is less than 7.
Squeeze Cementing Using Braden Head Squeeze Method On ‘Dsr-29’ Well Tarakan Field PT. Medco E&P Indonesia Ristiyan Ragil Putradianto; Dafa Surya Ramadhan
Journal of Petroleum and Geothermal Technology Vol 1, No 1 (2020): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v1i1.3322

Abstract

Squeeze cementing is an operation in which a cement slurry is pressed to a certain pressure on an oil or gas well. The purpose of doing squeeze cementing is to block water or gas flow and oil zones, close certain zones to produce other productive zones, repair damaged casing, and as a continuation of primary cementing work. Squeeze Cementing is done when workover a well. Workover and well service operations in a well, is a type of activity in the oil industry aimed to maintain wells so that they can continue to produce optimally and increase productivity back wells due to production problems. Squeeze Cementing Project on Tarakan field, DSR-29 well serves to block perforation that is no longer needed or open hole section at a depth of 630 - 635 m (670 MZ) so that a reservoir can be isolated and the casing can be firm or strong against pressure. Squeeze cementing method used in the well is the Braden Head Squeeze method. In the middle of workover process, there are problems such as existence of remaining perforating gun, and gas traps. Certain procedure is applied so that the cementing process has been carried out successfully.
Analysis Study Of The Effect In Selecting Combination Of Fracturing Fluid Types And Proppant Sizes On Folds Of Increase (FOI) To Improve Well Productivity Dimas Ramadhan; Hidayat Tulloh; Cahyadi Julianto
Journal of Petroleum and Geothermal Technology Vol 1, No 2 (2020): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v1i2.3886

Abstract

As fracturing materials, fracturing fluid and proppant are two very important parameters in doing hydraulic fracturing design. The combination of fractuirng fluid and proppant selection is the main focus and determinant of success in the hydraulic fracturing process. The high viscosity of the fracturing fluid will make it easier for the proppant to enter to fill the fractured parts, so that the conductivity of the fractured well will be better and can increase the folds of increase (FOI) compared to fracturing fluid with lower viscosity (Economides, 2000). This research was conducted by using the sensitivity test method on the selection of fracturing fluid combinations carried out at the TX-01 well with various sizes of proppants (namely; 12/18, 16/20, and 20/40 mesh) with the proppant selected being ceramic proppant type carbolite performed using the FracCADE simulator. Fracturing fluid was selected based on its viscosity, namely YF240OD and PrimeFRAC20 fluids with viscosity value of 4.123 cp and 171.1 cp, with a fixed pump rate of 14 bpm. The results showed that the combination of high-viscosity fluids (PrimeFRAC20) and 16/20 mesh proppant size resulted in a greater incremental fold (FOI) between the choice of another combination fracturing fluids and proppant sizes, namely 6.25.
The Application of Diagnostic Plots to Evaluate Water Flooding Ratna Widyaningsih; Muhamad Zamzam Istimaqom; Hizballah Nidaulhaq; Atma Budi Arta
Journal of Petroleum and Geothermal Technology Vol 1, No 1 (2020): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v1i1.3323

Abstract

To analyze production optimization using waterflood, several types of diagnostic plots are needed to determine the response to using waterflood. If you have analyzed 1 plot, it is necessary to conduct a comprehensive analysis to evaluate its success rate by combining it using another plot analysis. The X-Min Field is a field that produces light oil and is managed by the Asset Optimization SLO North PT. Chevron Pacific Indonesia. This field was discovered in 1959 and started to be produced in 1966. Currently, 100 wells have been drilled with 37 active wells from 43 production wells, active injector wells are 18 out of 19, inactive wells 30, 4 wells have been plugged in, and there are 4 active wells that produce gas. The number of OOIPs in this field is 593 MMBO with cumulative production reaching 283.7 MMBO and Recovery Factor reaching 47.7%. In 2017 it was noted that the current production in December 2017 amounted to 5,374 BOPD / 121,264 BFPD or in other words the water cut reached 96.6%. Meanwhile, the amount of injection used to optimize this field is 144,103 BWIPD. Reservoirs in this field have 4 reservoirs namely Res-1, Res-2, Res-3, and Res-4 wherein each reservoir there are several grains of sand optimized using waterflood. There was 8 sand analyzed, including Sand Asyique, Sand Bajubaru, Sand Cemangad, Sand Emakpintar, Sand Fantamantap, Sand Gulungulung, Sand Harikita, and Special Sand. Closes the producer indicated premature water breakthrough. General recommendations given to various sands include adding or subtracting, both injectors and producers based on the response of each sand to water flooding.
Optimization Study of Integrated Scenarios on Cyclic Steam Stimulation (CSS) Using CMG STARS Simulator Boni Swadesi; Suranto Suranto; Indah Widiyaningsih; Matrida Jani
Journal of Petroleum and Geothermal Technology Vol 1, No 1 (2020): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v1i1.3315

Abstract

Reservoirs in the world contain various types of oil, the difference of these oil types can be seen in the viscosity value and also the value of the API degree. Reservoirs in the U-field contain heavy oil that cannot be produced conventionally so we need the EOR (Enhanced Oil Recovery) method. CSS is a method that uses high-temperature hot steam aimed at reducing the viscosity of the oil so that oil can be produced. In this final project, a simulation is conducted to study the effect of various parameters such as steam quality, injection rate, and cyclic period on CSS and also determine the best scenario for U-field. The simulation begins by determining the best steam quality value, then doing sensitivity to the expected injection rate, followed by sensitivity to the cyclic period. The best scenario results are the integration of optimum parameters, namely steam quality 0.8, the injection rate of 550 BPD, and cyclic period of 20 days injection, 4 days soaking, and 60 days of production produce RF of 35.02%.
Application of Fracture Barrier Analysis in Well Stimulation Planning for Upper Baturaja Limestone Formation Based on Well Log & Drill Cutting Data from OBF-01 and OBF-04 Wells, Offshore Southeast Sumatra Aris Buntoro; Muhammad Nurcholis; Basuki Rahmad; Allen Haryanto Lukmana; Ristiyan Ragil Putradianto
Journal of Petroleum and Geothermal Technology Vol 1, No 2 (2020): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v1i2.3686

Abstract

In general, the South Sumatra Regional Stratigraphy of the Baturaja Limestone Formation facies is deposited on the Buildup Carbonate (Reef) and the Limestone Clastic Carbonate of the Baturaja Formation which grows as a buildup reef on the platform in the Basement High (Horst) underneath is the Lemat Formation volcanic deposits. Referring to the facies model in general, the Baturaja Limestone Formation, the depositional environment starts from Shelf Lagoon Open Circulation - Winnowed Edge Sand - Organic Buildup - Fore Slope - Deep Shelf Margin - Open Sea Shelf - Basin, meaning that carbonate is formed starting from pure organic Cabonate Buildup Reef without / a little sludge / mud to the Carbonate Basin where more muddy / mud is present, this condition causes clay minerals to also more and more mix with Terigenous Clastics (Quartz, feldpar). The complexity of the Baturaja Limestone Formation requires fracture barrier analysis associated with well stimulation planning in order to increase oil productivity with the appropriate method.   Fracture barrier fracture analysis is an approach method to determine the depth interval that becomes a barrier in hydraulic fracturing by correlating the results of geomechanical analysis from well log data and mineralogical analysis from drill cuttings data, so that a commonly used well stimulation method can be selected, namely hydraulic fracturing, acidizing, and acid-fracturing.From the ternary diagram plot the XRD (bulk) analysis results show that the distribution of the main minerals (Quartz, Clay, Calcite) is more dominant in the ductile zone, hard to frac category. This shows that all the depth intervals in the OBF-01 and OBF-04 wells are more ductile, and are not recommended for hydraulic fracturing. From the XRD (bulk) analysis, Calcite mineral is more dominant, so for well stimulation work it is recommended to use acidizing or acid-fracturing.
Direct Utilization of Geothermal Energy in Menengai, Kenya: Pilot Project for Drying Food Commodities in Lesiolo, Nakuru Allen Haryanto Lukmana Lukmana
Journal of Petroleum and Geothermal Technology Vol 1, No 1 (2020): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v1i1.3319

Abstract

Kenya is a developing country highly dependent on economic rotation in agricultural sector with main commodities corn, tea and fruits. In order to maintain quality of commodity within a certain period, a drying process is needed. Purpose of drying is to reduce moisture content of a commodity to a certain level. Alternative energy that can be used for drying activities in Kenya is geothermal energy. In assessing direct utilization of geothermal energy, a pilot project was made in Lesiolo, Nakuru by utilizing heat energy from the Menengai geothermal waste fluid area, Nakuru. Drying process can utilize brine from separator or condensate from power plant by using a heat exchanger to get required drying temperature. One drying room can hold about 20 tons in ambient air conditions. This dryer is shaped like a tunnel where hot air will flow from each side of drying chamber. Food commodities used in this project are wheat, corn and barley. Heat energy needed to dry each of these food commodities comes from geothermal waste fluid that enters heat exchanger with a minimum input temperature of 130oC and an output of 93oC. Mass flow rate needed to dry every 30 m3 of commodity is 2 kg/s
Securing Annulus Abnormal Pressure Build-up (APB) with Polymer Plug; a Case Study Ganesha R Darmawan
Journal of Petroleum and Geothermal Technology Vol 1, No 2 (2020): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v1i2.3825

Abstract

The life cycle of a production well was facing challenges related to well integrity issue where A-Annulus pressure tracking the tubing pressure and increased repeatedly above the Maximum Allowable Wellhead Operating Pressure (MAWOP). Several well control operations were executed to reduce A-Annulus abnormal pressure build-up (APB) with no success.Literature and well historical studies were performed in order to secure this well, normal bleed and lube was ruled out owing to several attempts already performed for more than a year, but the APB keep on appearing after 2-4 months. Bullheading is not a viable option to kill the well. Well securing planned and prepared with some options such as, mechanical barriers/plugs, cement plug or polymer plugs as temporary plug to avoid APB re-occurrence. There were some constrains in operation planning that need to be addressed carefully, with additional challenge of tight injectivity as if it was a closed system.The polymer plug successfully stops the gas migration to surface, and secured the well from any reoccurrences of APB. The details of well control histories, operation design and planning and operation execution with the complete results and evaluation will be presented in this paper.
Analysis of the Difference between Hydraulic Fracturing and Flow Channel Fracturing Mia Ferian Helmi; Muhammad Zakiy Y.; Dinar Kaesti; Maulida Aulia Fadhina; Anisa Novia Risky
Journal of Petroleum and Geothermal Technology Vol 1, No 1 (2020): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v1i1.3320

Abstract

As time goes by, there will be a decline in formation productivity, as reflected in the decline in the rate of oil production from production wells. The decline in the rate of production was caused by many things such as a decrease in reservoir pressure, also formation damage. Where damage to the formation will result in a decrease in rock permeability. The decrease in rock permeability is caused by the blockage of rock pores due to the invasion of solids and drill mud filtrate, cementing, fluid fluids or previous stimulation. Besides the small rate of oil production can also be caused by the low natural permeability of rocks. With the decreasing productivity of the formation, it is necessary to make efforts to increase the productivity of the formation again, where one of them is by the method of hydraulic fracture stimulation. In this analysis, we will discuss the difference between conventional stimulation methods and flow channel fracturing. Flow channel fracturing is a fracturing process by making a network around proppant granules to form proppant pillar, so that a path is formed for the fluid to flow more easily. What distinguishes between conventional hydraulic fracturing with flow channel fracturing is the resulting fracture form, fracturing fluid injection pattern, and the amount of proppant used.
Simulation Study of Fluid Flow and Estimation of a Heterogeneous Porous Media Properties Using Lattice Gas Automata Method Dedy Kristanto; Windyanesha Paradhita
Journal of Petroleum and Geothermal Technology Vol 1, No 2 (2020): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v1i2.3856

Abstract

Most models used in reservoir simulation studies are on the scale of meters to hundreds of meters. However, increasing resolution in geological measurements results in finer geological models. Simulations study of particle movements provide an alternative to conventional reservoir simulation by allowing the study of microscopic and/or macroscopic fluid flow, which is close to the scale of geological models. In this paper, the FHP-II (Frisch, Hasslacher and Pomeau - FHP) model of lattice gas automata were developed to study fluid flow in order to estimate the properties of heterogeneous porous media. Heterogeneity simulated by placing solid obstacles randomly in a two-dimensional test volume. Properties of the heterogeneous porous media were estimated by the shape, size, number of the obstacles and by the distribution of the obstacles within the volume. Results of the effects of grain sizes and shapes, and its distribution in the porous media on the tortuosity, effective porosity, permeability and displacement efficiency were obtained. An investigation of fluid flow and comparison with laboratory experiment were also presented. Reasonably good agreement between the lattice gas automata simulation and laboratory experiment results were achieved.

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