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All Journal ASEAN Journal of Systems Engineering Seminar Nasional Teknik Kimia Kejuangan Journal of Petroleum and Geothermal Technology Journal of Earth Energy Science, Engineering, and Technology Scientific Contributions Oil and Gas
Dewi Asmorowati
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Biochemistry, Genetics & Molecular Biology Chemical Engineering, Chemistry & Bioengineering Earth & Planetary Sciences Energy Engineering Environmental Science

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Peramalan Kinerja Reservoir Lapangan Panas Bumi Gunung Iyang-Argopuro, Jawa Timur, Indonesia Menggunakan Simulasi Numerik TOUGH2 Dewi Asmorowati; Allen Haryanto Lukmana; Intan Paramita Haty; Intan Sulistiyani
Prosiding Seminar Nasional Teknik Kimia "Kejuangan" 2020: PROSIDING SNTKK 2020
Publisher : Seminar Nasional Teknik Kimia "Kejuangan"

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Abstract

PREDICTION OF WELL BEHAVIOR USING WELL DELIVERABILITY ANALYSIS Dewi Asmorowati; M. Waziz Wildan; Khasani -
ASEAN Journal of Systems Engineering Vol 2, No 1 (2014): ASEAN Journal of Systems Engineering
Publisher : Master in Systems Engineering

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Abstract

In operating geothermal field, the thing to note is the sustainable production as well as problems that affect it. The problem that often occurs in the geothermal field is scale, corrosion and mechanical problems. One technique that can be used to predict the problems that occur around the bottom hole to the surface is using the well deliverability analysis method. Analysis is done by data and curve interpretation of deliverability curve based on Grant experiment. This study take data from several wells in two Geothermal Field in Indonesia. From the analysis, well A, D and F show production decline The deliverability curve of well A shows the production decline for about 60 – 85%, it is caused by moving of the flashing point, it shows from the increasing of dryness value from 7-14% in 1997 become 13-15% in 2010. The deliverability curve of well D shows the production decline for about 50%, it is caused by declining of reservoir pressure that can be seen from the decreasing  of feed zone pressure in 1997 is 27 bar and in 2010 is 20 bar. The deliverability curve of well F shows the production decline for about 29%, it is caused by moving  of the flashing point.
Synthesis of Synthetic Brine to Estimate Carbonate Scale Index in Oil Industry Nugraha, Fanata Yudha; Asmorowati, Dewi; Saputra, Ega Dimas; Astuti, Dian Indri; Tony, Brian; Waisnawa, I Putu Gema Bujangga
Journal of Petroleum and Geothermal Technology Vol. 5 No. 2 (2024): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v5i2.13636

Abstract

The decreased oil production due to scaling in production equipment results in costs. In oil wells, ions such as calcium, barium, carbonate, sulfate, magnesium, sodium, and chloride are commonly present in formation water. Excessive solubility of ions can trigger precipitation or what is often called scale. This study focuses on creating synthetic brine with a composition resembling field formation water as an alternative solution for rapid laboratory-scale measurement of the scale index. In this study focus on carbonate and bicarbonate scale. The stages of the research involves synthetic brine preparation, physical and chemical testing of the brine, comparison with formation water, and calculation of the Stability Index (SI) using Stiff & Davis method. The results indicate that synthetic brine can be prepared based on laboratory analysis of field samples by estimating the materials and masses present in formation water, thus allowing replication using natural or chemical materials in the laboratory while considering parameters such as pressure, temperature, and pH during the manufacturing process. The pH significantly impacts the risk of scale formation, where a slightly basic pH, around pH 8, supports higher concentrations of carbonate ions (CO32-) and bicarbonate ions (HCO3-), thereby increasing the risk of scale formation.
Hydraulic Fracturing Stimulation Planning of “X” Well in Talang Akar Formation Helmy, Mia Ferian; Nugraha, Fanata Yudha; Boni Swadesi; Dewi Asmorowati; Susanti Rina
Journal of Earth Energy Science, Engineering, and Technology Vol. 8 No. 1 (2025): JEESET VOL. 8 NO. 1 2025
Publisher : Penerbitan Universitas Trisakti

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25105/arygvm79

Abstract

“X” well is a well with a productive sandstone formation with a productivity index of 0.1 bfpd/psi. Hydraulic fracturing will be performed based on screening results, with design simulated using commercial software. The design process includes analyzing well data, reservoir characteristics, and rock geomechanics using the Perkins, Kern, and Nordgren (PKN) fracture model. The chosen fracturing fluid is YF135.1HTD with Carbolite Proppant (12/18 mesh). The geometric model applied uses the PKN method with results of a fracture length of 463.9 ft, fracture height of 9.84 ft, fracture width of 0.37 inch, and fracture conductivity of 77063 md.ft using a total volume of fracturing fluid of 13500 gallons and a total mass of proppant. amounting to 40590 lbs. The required surface injection pressure is 4176.13 psi with an injection rate of 18 bpm and a total pumping time of 20.2 minutes. The performance improvement of the “X” well was in the form of average formation permeability from 29.2 mD to 369.4 mD, an increase in productivity index of 6.5 times and an increase in production rate from 50.46 bfpd to 296.48 bfpd. So, the planning of the hydraulic fracturing design for the “X” Well can be considered for implementation.
Rheological Interactions Between Divalent Barium and Sulfate Ions in Hydroxypropyl Guar Polymer Fracturing Fluids Asmorowati, Dewi; Hidayat, Miftah; Kristanto, Dedi; Hakim Lumban Gaol , Ardhi; Ariadji , Tutuka; Marhaendrajana , Taufan
Scientific Contributions Oil and Gas Vol 48 No 4 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i4.1904

Abstract

The use of produced water as a primary component in formulating polymer-based fracturing fluids is becoming a viable option due to the limited availability of fresh water in the field. Nevertheless, the practical use of production water faces several challenges due to its complex composition, which includes monovalent and divalent ions that considerably affect the fluid’s viscosity. Recent studies have shown that calcium ions substantially influence the viscosity of linear fracturing fluids, whereas magnesium ions, do not have a notable effect. However, the effects of other divalent ions commonly found in production water, such as barium and sulfate, remain underreported. In this study, the influence of barium and sulfate ions on linear fracturing fluids will be examined. The viscosity of linear gel fracturing fluids, prepared using hydroxypropyl guar (HPG) polymer with varying concentrations of barium and sulfate ions, will be investigated under different shear rates and temperatures. The results indicate that produced water contains barium and sulfate ions, which affect the rheology of the linear fracturing fluid. A concentration of 150 ppm of BaCl2 can increase the viscosity by 30%, whereas 150 ppm of Na2SO4  increases the HPG viscosity by 7% at ambient temperature (25 °C). At 70 °C, the effect of barium and sulfate ions on the increase in viscosity of the HPG linear fracturing fluid are observed to be less significant.
Co-Authors Allen Haryanto Lukmana Ariadji , Tutuka Astuti, Dian Indri Boni Swadesi Hakim Lumban Gaol , Ardhi Helmy, Mia Ferian Hidayat, Miftah Intan Paramita Haty Intan Sulistiyani Khasani - Kristanto, Dedi M. Waziz Wildan Marhaendrajana , Taufan Nugraha, Fanata Yudha Saputra, Ega Dimas Susanti Rina Tony, Brian Waisnawa, I Putu Gema Bujangga