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Teknologi Otomasi dalam Industri Makanan-Studi Kasus: Optimalisasi Mesin Pencetak Bakso dengan Sistem Potong Berbentuk Sendok Sindu Arifin, Kurniawan; Kristanto, Dedi; Prihartanto, Ari; Satria Praja, Alfreda
KONSTELASI: Konvergensi Teknologi dan Sistem Informasi Vol. 5 No. 1 (2025): Juni 2025
Publisher : Program Studi Sistem Informasi Universitas Atma Jaya Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.24002/konstelasi.v5i1.11398

The meatball industry in the Micro, Small, and Medium Enterprises (MSMEs) sector faces challenges in increasing production capacity and maintaining consistency in meatball size. This study aims to optimize a meatball forming machine with a spoon-shaped cutting system to improve production efficiency, size accuracy, and reduce reliance on manual labor. Testing was conducted by comparing manual and automatic meatball molding methods based on production speed, energy consumption, and mechanical durability. The results show that the machine can produce an average of 150 meatballs per minute, compared to the manual method, which only reaches 50-60 meatballs per minute. Furthermore, the machine's energy consumption of 500 watts per hour results in lower operational costs than the manual method, which requires additional labor. In terms of durability, the main components of the machine have a lifespan of more than 10 years with minimal maintenance. The study concludes that the implementation of an automatic meatball forming machine has a significant impact on MSMEs, improving productivity, reducing operational costs, and ensuring a more consistent product quality. Keywords: Meatball forming machine; production efficiency; spoon-shaped cutting system; MSMEs; automation

Teknologi Otomasi dalam Industri Makanan-Studi Kasus: Optimalisasi Mesin Pencetak Bakso dengan Sistem Potong Berbentuk Sendok Sindu Arifin, Kurniawan; Kristanto, Dedi; Prihartanto, Ari; Satria Praja, Alfreda
KONSTELASI: Konvergensi Teknologi dan Sistem Informasi Vol. 5 No. 1 (2025): Juni 2025
Publisher : Program Studi Sistem Informasi Universitas Atma Jaya Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.24002/konstelasi.v5i1.11398

The meatball industry in the Micro, Small, and Medium Enterprises (MSMEs) sector faces challenges in increasing production capacity and maintaining consistency in meatball size. This study aims to optimize a meatball forming machine with a spoon-shaped cutting system to improve production efficiency, size accuracy, and reduce reliance on manual labor. Testing was conducted by comparing manual and automatic meatball molding methods based on production speed, energy consumption, and mechanical durability. The results show that the machine can produce an average of 150 meatballs per minute, compared to the manual method, which only reaches 50-60 meatballs per minute. Furthermore, the machine's energy consumption of 500 watts per hour results in lower operational costs than the manual method, which requires additional labor. In terms of durability, the main components of the machine have a lifespan of more than 10 years with minimal maintenance. The study concludes that the implementation of an automatic meatball forming machine has a significant impact on MSMEs, improving productivity, reducing operational costs, and ensuring a more consistent product quality. Keywords: Meatball forming machine; production efficiency; spoon-shaped cutting system; MSMEs; automation

Analysis Of Co2 Storage in A Saline Aquifer Using A Fully Implicit Integrated Network Modeling Approach in the 'AZ' Field Swadesi, Boni; Zayd, Ahmad; Buntoro, Aris; Kristanto, Dedi; Widiyaningsih, Indah; Lukmana, Allen Haryanto
Journal of Geoscience, Engineering, Environment, and Technology Vol. 10 No. 4 (2025): JGEET Vol 10 No 04 : December (2025)
Publisher : UIR PRESS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.25299/jgeet.2025.10.4.25106

The increasing carbon dioxide (CO2) emissions from industrial and energy activities have driven the development of Carbon Capture and Storage (CCS) technology as a key solution for climate change mitigation. Among various geological storage options, saline aquifers offer significant advantages due to their large storage capacity, wide distribution, independence from hydrocarbon value, and stable geological and geochemical conditions. The “AZ” Field, located near a power plant emitting 2.2 million tons of CO2 annually, was selected as the study site for CO2 storage. This study aims to analyze the trapping mechanisms and optimize the CO2 storage capacity (storativity) using a fully implicit integrated modeling approach. The methodology involves building a static and dynamic model of the Johansen Formation saline aquifer, and integrating well and surface facility models using the well designer and network designer features in tNavigator. A 140-year simulation was conducted, comprising 40 years of injection and 100 years of post-injection period. Simulation results show that the “AZ” Field can store up to 83.9 Mt of CO2, predominantly through solubility/residual trapping mechanisms, in addition to structural trapping. No leakage was observed to the surface, indicating that caprock integrity remained intact throughout the simulation period. The fully implicit integrated modeling approach effectively captured the dynamic interactions between the reservoir, wells, and surface facilities, supporting the feasibility of the “AZ” Field as a safe and sustainable CO2 storage site.

Sucker Rod Pump Design using Petroleum Engineering Application– PEARL 4.0 as a Breakthrough Solution in Digitalization (Study Case PWP-13) at Limau Field, Pertamina Hulu Rokan, South Sumatra, Indonesia Putra, Panca Wibawa; Suranto, Suranto; Kristanto, Dedi
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.v6i2.13935

PT. Pertamina Limau Field in South Sumatra, producing 4,113 BOPD and 10.69 MMSCFD from 11 structures, have a significant low production issue with well PWP-13. Although the well produces 40 BOPD, frequent failures in the sucker rod pump (SRP) system cause excessive downtime and low production, reaching 4,505 barrels oil (BO) in 2023. This research aimed to optimize PWP-13 production by redesigning the SRP system, applying API RP 11 L standards to improve the pump’s reliability. Build new calculation, The Petroleum Engineering Application (PEARL 4.0) integrated variables such as taper rod arrangement and sucker rod type. This PEARL 4.0 was then applied to well PWP-13 with Rig Service. Monitoring results indicated a production increase to 90 BOPD, with average incremental production reaching 60 BOPD, supported by extended operational lifetime. Financial analysis showed a high net present value (NPV) of 693 MUSD, internal rate of return (IRR) of 498%, and a payback period (POT) of 0.189 years, confirming a rapid return on investment (ROI) 8.6. The SRP redesign offers a sustainable solution for sucker rod failures, enhancing production efficiency and profitability for company. Keywords: artificial lift, sucker rod pump design, petroleum engineering application

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

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

Chemical Enhanced Oil Recovery (CEOR) Injection Planning to Obtain the Optimum Development Scenario: A Case Study in TBG Field Aliefan, Tubagus Adam; Kristanto, Dedi; Swadesi, Boni
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.v6i2.14218

Chemical Enhanced Oil Recovery (CEOR), particularly through the use of surfactant and polymer injection, has emerged as one of the most effective tertiary recovery techniques for increasing oil recovery from mature reservoirs. CEOR enhances volumetric and microscopic sweeping efficiency, improving the overall recovery factor (RF). This study focuses on Zone C of the TBG Field, a mature oil field with a current recovery factor below 25%, highlighting its potential for further optimization through CEOR. The field, which began production in 1961 and introduced peripheral water injection in 1995, remains a key candidate for unlocking remaining oil in place. This research integrates primary data, including core analysis, PVT data, and polymer field trial results, with secondary data such as petrophysical properties and production performance. Using dynamic modeling with CMG software, the study evaluates three CEOR injection scenarios to determine the most effective method for improving oil recovery. The scenarios simulated included Baseline Waterflood + Polymer (0.4 PV) and Baseline Waterflood + (Surfactant + Polymer) + (Polymer) (0.2 PV SP + 0.7 PV P). The optimal scenario, involving Baseline Waterflood + (Surfactant + Polymer) + (Polymer), demonstrated an incremental oil recovery of 1.24 MMSTB and a recovery factor improvement of 0.974%. The novelty of this research lies in its integration of polymer field trial data with innovative surfactant-polymer combinations tailored specifically to Zone C's reservoir characteristics. This approach provides a scientifically robust and practical strategy for enhancing oil recovery in challenging reservoir conditions. The study concludes that CEOR is a viable method for mature fields like TBG, offering significant potential for improved oil recovery. Future recommendations include exploring the economic feasibility of the selected injection scenario and ensuring the readiness of surface facilities to support full-scale implementation.

A Comparative Cost Estimation of Plug and Abandonment Well Using SNI 13-6910-2002 and NORSOK Standard D-010 Regulations: A Case Study in the H-11 Well of Colibri Field Yusgiantoro, Luky A.; Kristanto, Dedi; Hariyadi, Hariyadi; Stephanie, Vania Raina; Irawan , Gondo
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.v6i2.14731

This research discusses the comparative determination of appropriate method for plug and abandonment (P&A) activities in directional wells, and finding an economical cost between SNI 13-6910-2002 and NORSOK Standard D-010 regulations. Colibri field consists of several wells, including H-11 well which is a directional well, where the well was used as a reference for determination in implementation of plug and abandonment activities after the well condition has reached the economic limit. Plug and abandonment (P&A) activities in the Colibri field was implemented with designing a work plan to determine the section for the zone to be plugged by calculating the volume of cement, additives, and completion fluid, using the rig method. The result of the research is to determine the estimation costs that need to be prepared to implement well abandoned activities according to the closing year using SNI 13-6910-2002 and NORSOK Standard D-010 regulations. The cost estimation result of H-11 well using SNI 13-6910-2002 is 417,630.25 USD, while for NORSOK Standard D-010 is 813,315.77 USD. Therefore, based on the cost estimation results, the proposed method chosen for cost estimation of plug and abandoned of H-11 well in Colibri Field is SNI 13-6910-2002 regulation.

An Integrated Analysis of Shut-In Well Reactivation for Oil Production Optimization in The DLN-11 Well Kristanto, Dedi; Yusgiantoro, Luky Agung; Hariyadi; Paradhita, Windyanesha
Scientific Contributions Oil and Gas Vol 49 No 1 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i1.2012

DLN-11 well was temporarily shut-in due to excessive water production, which became the main issue causing a decline in daily oil production. Therefore, this study conducted an integrated analysis to determine the cause of excessive water production, so that appropriate mitigation measures could be implemented, as well as to formulate a well reactivation strategy aimed at optimizing oil production. The methodology in this study was carried out in an integrated manner through technical and economic evaluations. The technical analysis began with the application of the Chan diagnostic plot as an initial mitigation step, followed by the evaluation of data logging, core analysis data, and production data as advanced mitigation steps to obtain appropriate solutions for addressing production-related issues. In addition, an economic analysis was conducted as a basis for decision-making within a risk management framework. Based on the results of the integrated analysis between the Chan diagnostic plot method and cement evaluation data from Cement Bond Log (CBL), Variable Density Log (VDL) dan Ultra Sonic Imaging Tool (USIT), the high water cut in DLN-11 well, as a reactivation candidate, was caused by water channeling due to the presence of free pipe conditions, where the cement did not properly isolate the annulus between the casing and the formation. To overcome this issue, remedial cementing was carried out to improve the quality of cement bonding. Furthermore, based on the evaluation results of the C/O Log, DLN-11 well still owns five potential oil-bearing zones that can be produced. The reactivation strategy was implemented by opening the interval of 7927-7942 ftMD, resulting in a production rate of 549 BOPD with a water cut of 82%. The economic analysis results indicate that DLN-11 well yields an NPV of 1,256,000 US$, an IRR of 247.5%, and a Pay Out Time (POT) of 3 months and 16 days. Therefore, from both technical and economic perspectives, the implemented reactivation strategy for DLN-11 well has proven to increase oil production and generate positive economic indicators.

Caprock Integrity Assessment from Core-Based Formation Analysis and Laboratory Workflow: A Case Study of The Asri Basin Caprock Buntoro, Aris; Putra, Teddy Eka; Kristanto, Dedi; Swadesi, Boni; Amir, Zulhemi; Lukmana, Allen Haryanto; Wicaksono, Dimas Suryo; Nurcholis, Muhammad
Scientific Contributions Oil and Gas Vol 49 No 1 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i1.2021

Caprock integrity is a critical factor in ensuring the long-term safety of CO₂ geological storage, enhanced oil recovery (EOR), and wellbore stability. This study investigates the sealing performance of shale- and carbonate-rich caprock intervals from the Asri Basin, with specific focus on the Baturaja and Gita Formations. This study introduces a CT-guided integrated laboratory workflow for caprock integrity assessment, which simultaneously links petrophysical sealing capacity, mineralogical controls, and geomechanical strength within a unified experimental framework, a workflow rarely applied in Southeast Asian basins. Whole-core sections from Well ASR-1 were screened using computed tomography (CT) imaging to identify fractures and heterogeneity prior to plug extraction. Laboratory methods included porosity and permeability determination under variable confining stresses, mercury injection capillary pressure (MICP) analysis to evaluate sealing capacity, mineralogical characterization by X-ray diffraction (XRD), scanning electron microscopy (SEM–EDS), petrography, and mechanical testing (UCS, triaxial, and Brazilian tensile tests). The results demonstrate significant depth-dependent variability: The Baturaja Formation exhibited heterogeneous sealing capacity, with entry pressures ranging from 217 to 1,197 psi, while the Gita Formation consistently displayed strong sealing, with maximum Pc_entry of 2,844 psi and pore systems dominated by <0.1 µm throats. Mechanical tests confirmed adequate strength and the preservation of low permeability under confining stress, with clay content and carbonate cementation identified as primary controls on integrity. The integrated workflow enables a process-based interpretation of lithology-controlled sealing mechanisms, improving the robustness of site selection and risk assessment for CO₂ storage in the Asri Basin and similar carbonate and mudstone systems.

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