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All Journal Journal of Engineering and Technological Sciences Journal of Petroleum and Geothermal Technology Scientific Contributions Oil and Gas
Nur Suhascaryo
Petroleum Engineering Department Bandung Institute of Technology
Chemical Engineering, Chemistry & Bioengineering Earth & Planetary Sciences Energy Engineering

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The Effect of CaO and MgO as Expanding Additives to Improve Cement Isolation Strength under HPHT Exposure Rubiandini, Rubi; Siregar, Septoratno; Suhascaryo, Nur; Efrial, Deny
Journal of Engineering and Technological Sciences Vol 37, No 1 (2005)
Publisher : ITB Journal Publisher, LPPM ITB

Show Abstract | Download Original | Original Source | Check in Google Scholar | Full PDF (894.368 KB) | DOI: 10.5614/itbj.eng.sci.2005.37.1.3

Abstract

Cementing is one of the most important parts in oil-well drilling. Recent development in oil-well drilling technology has led to a more problematic case in cementing. High temperature cementing is one of the problems. High temperature cementing may cover steam recovery wells, geothermal wells and ultra deep wells.The use of expanding cements as an effort to improve the sealing efficacy of annulus cementing has been considered for a long time as a promising solution to the existing problems. CaO and MgO have been proposed as two of the most effective additives to create excellent expanding cement.The purpose of this study is to find the effect of adding up burnt pure CaO and MgO to the value of compressive strength and shear bond strength of API class G cement in high pressure and high temperature condition. The method that we used within this research is an evaluation of the data taken from a simulator that simulated within temperature range of 100 – 250 oC and pressure of 2000 psi.The conclusion is taken according to the results which saying that the addition of burnt pure CaO and MgO would increase the shear bond strength and the compressive strength on specific condition up to 200 oC temperature. The addition won’t be effective for the condition of 250 oC temperature. The behavior of cement strength was also influenced by the length of curing time.Further more, research on expanding cement needs to be developed and extended whether to vary its compositions, temperatures, or curing time conditions. The compatibility when mixed with other additives together with silica flour has not yet been figured out.
ACIDIZING EVALUATION OF CARBONATE ROCK IN BDA-F WELL, JATIBARANG FIELD Widyanata, Andri; AM, Suranto; Suhascaryo, Nur
Journal of Petroleum and Geothermal Technology Vol. 4 No. 1 (2023): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v4i1.7335

Abstract

Acidizing is a dissolving activity, whether it is dissolving rock formations or other materials (natural or foreign) in reservoir of the rock. To maintain production in the Jatibarang field, especially in Bangodua (BDA) structure, there are 1 well that have experienced a short decline in production since drilling. The reservoir properties of that well is not good and there is impurity material (damage). Thus, requiring stimulation in the form of matrix acidizing. Evaluation of the matrix acid work in this well, is required for the same activities in other wells.To restore productivity this well, data were collected starting from production data, reservoir data, and well composition data. Then, candidate analysis and matrix acidizing job design are carried out. The design stage will be brought to the execution of matrix acidizing in the field. Then an evaluation was carried out after the presence of matrix acidizing in this wellThis well carried out matrix acidizing activities, produced oil production gains. BDA-F well produced with artificial lift of Electrical submersible pump – ESP in C1 layer (1128 – 1130.5 mMD), experienced an increase in test production from 749 BLPD to 1865 BLPD with a decrease in skin factor from +32 to -1.
Hitting the Jackpot: Reaching up to 10000 BBL through Simson Idle Well Reactivation Strategy Purnomo, Simson; Kristanto, Dedi; Suhascaryo, Nur
Journal of Petroleum and Geothermal Technology Vol. 6 No. 2 (2025): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v6i2.14188

Abstract

This study seeks the effective reactivation strategy of the Simson idle well in the Purnomo oilfield PT Pertamina EP Cepu to produce free-emulsion oil with low costs and technical risks. DCA and Pipesim were used to calculate the production forecast, the precise choke, and the flow coefficient. Due to its remote location, a rig-less and naturally flowing well minimized the cost. A modified choke manifold compliant with the API 6A was installed to control the flow rate from the annulus to the Tank on Site (TOS). The cumulative production in 2023 reached 10.961 bbl with the average BSW at 2%. To avoid water coning, the well should be operated under the critical rate of 60 BFPD.  To maintain stable production, the optimum flow coefficient was Cd 0.838 by installing the first 5-mm choke and the second 8.7-mm choke. The average daily production rate by intermittent flow i.e. of 5-hour production and 19-hour shut-in well was 34 blpd, 33 bopd with water cut at 1.64%. By the end of the PSC contract in 2035, the production forecast value using the choke manifold can reach 81 MSTB – 50 MSTB higher than the SRP method. Keywords: idle well reactivation, flow coefficient, choke manifold
Waterflood and Polymer Injection Design for New Target Reservoir based on Injection Pattern Optimization, Injection Rate Sensitivity, and Injection Pressure Sensitivity Fransiscus Asisi Lugas Ariobimo; Swadesi, Boni; Suhascaryo, Nur
Journal of Petroleum and Geothermal Technology Vol. 6 No. 2 (2025): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v6i2.16337

Abstract

Field “X” is in Tabalong Regency, South Kalimantan, and is operated by Pertamina Hulu Indonesia Zona 9. The peak primary production occurred in March 1963, reaching 47,963 BOPD. Full-scale waterflood implementation with a staggered line-drive injection pattern began in January 1995, and the peak secondary production occurred in January 1999 at 10,095 BOPD. This study was conducted using a dynamic model that had undergone initialization validation and history matching. The assessment of polymer injection pattern candidates was carried out through a screening stage based on screening criteria and reservoir property analysis to determine patterns that could be prioritized as pilot areas for an optimal polymer injection scenario in Zone B. Pattern analysis criteria were based on movable remaining oil saturation, movable remaining oil in place, pattern area, and average transmissibility, evaluated for the Zone B reservoir under post-waterflood conditions. Sensitivity analyses on water injection rate and injection pressure were then performed to obtain the optimum waterflood injection scenario. After optimizing the injection pattern and determining the optimum waterflood injection scenario, polymer input parameters were applied to the model, followed by sensitivity analyses on polymer injection rate and pressure to obtain the optimum polymer injection scenario for Zone “B” of Field “X By the end of the production forecast in January 2066, the optimum waterflood injection scenario at the end of the production forecast provides an incremental oil gain of 1.5 MMSTB with an incremental recovery factor of 2.19% relative to OOIP, while the combination of optimum waterflood and polymer injection at the end of the production forecast provides an incremental oil gain of 2.14 MMSTB with an incremental recovery factor of 3.13% relative to OOIP; demonstrating improved sweep efficiency, oil bank formation, and effective mobilization of residual oil across Zone B.
Comparative Analysis of The Use of Nanosilica and Potassium Chloride as Shale Inhibitor in Water Based Mud Suhascaryo, Nur; Ramadhanti, Syifa Khasyikirana; Ketut Rama Wijaya; Miftahul Jannah
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.v48i4.1768

Abstract

Swelling shale is one of the most common problems encountered in oil and gas drilling operations. Potassium chloride (KCl) is widely applied as a shale inhibitor due to its ionic inhibition mechanism; however, excessive KCl concentrations can have detrimental effects on drilling mud performance. This study examines the potential of nanosilica derived from geothermal industrial waste as a substitute for KCl. Five mud samples were tested: base fluid, 1% nanosilica, 3% nanosilica, 1% KCl, and 3% KCl. The samples were evaluated through a series of physical property tests, including density, rheology, filtration loss, pH, methylene blue test (MBT), K⁺ concentration, and Cl⁻ concentration. Swelling-related parameters were also assessed using Linear Swelling Meter (LSM), accretion tests, and erosion tests under both before hot rolling (BHR) and after hot rolling (AHR) conditions at 200°F for 16 hours. The results indicate that nanosilica improved rheological properties and reduced shale swelling compared to the base fluid. Meanwhile, the 1% KCl formulation demonstrated strong performance in LSM and erosion tests. Overall, nanosilica shows potential as a partial substitute for KCl as a shale inhibitor; however, surface modification and field-scale validation are recommended for further confirmation.
Co-Authors AM, Suranto Boni Swadesi Deny Efrial Fransiscus Asisi Lugas Ariobimo Ketut Rama Wijaya Kristanto, Dedi MIFTAHUL JANNAH Purnomo, Simson Ramadhanti, Syifa Khasyikirana Rubi Rubiandini Septoratno Siregar Widyanata, Andri