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Steven Chandra
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Chemical Engineering, Chemistry & Bioengineering Energy

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NANO-SURFACTANT HUFF AND PUFF OPTIMATIZATION IN MARGINAL X FIELD USING COMMERCIAL SIMULATOR Ariel Paramastya; Steven Chandra; Wijoyo Niti Daton; Sudjati Rachmat
Scientific Contributions Oil and Gas Vol 42 No 2 (2019)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.42.2.375

Abstract

Economic optimization of an oil and gas project is an obligation that has to be done to increase overall profi t, whether the fi eld is still economically feas ible or the fi eld has surpassed its economic limit. In this case, a marginal fi eld waschosen for the study. In this marginal fi eld EOR methods have been used to boost the production rate. However, a full scale EOR method might not be profi table due to the amount of resources that is required to do it. Alternatively, Huff and Puff method is an EOR technique that is reasonable in the scope of single well. The Huff and Puff method is an EOR method where a single well serves as both a producer and an injector. The technique of Huff and Puff: (1) The well isinjected with designed injection fl uid, (2) the well is shut to let the fl uid to “soak” in the reservoir for some time, and (3) the well is opened and reservoir fl uids are allowed to be produced. The injection fl uid (in this case, nano surfactant) is hypothesized to reduce interfacial tension between the oil and rock, thus improving the oil recovery. In this study, the application of Huff and Puff method using Nanoparticles (NPs) as the injected fl uid, as a method of improving oil recovery is presented in a case study of a fi eld in South Sumatra. The study resulted that said method yields an optimum Incremental Oil Production (IOP) in which the economic aspect gain more profi t, and therefore it is considered feasible to be applied in the fi eld.
PROGRESSING CAVITY PUMP AS A SOLUTION TO INCREASE PRODUCTIVITY OF HIGHLY VISCOUS OIL WELLS WITH SAND PRODUCTION: A CASE STUDY OF FIELD X Amanda Efa D; Ronaldo H.T.; Wijoyo N.D.; Steven Chandra; Prasandi AA
Scientific Contributions Oil and Gas Vol 42 No 3 (2019)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.42.3.376

Abstract

Major oil fi elds in Indonesia have been experiencing massive decline in production, accompanied by excessive sand production that is not benefi cial to the integrity of the production system. Sand production has been known to increase the potential of corrosion, reducing lifetime of well equipment, and also known to shut in wells completely due to sand buildup in wellbore. Progressive Cavity Pump has been proposed as a solution to withstand these complications, due to its nature that can handle many types of fl uids and even produced solid. The idea is then tested to a mature Alabaster fi eld where the majority of the wells have been shut in due to excessive sand problem and low productivity. It is worth nothing that after installing the PCP, production modeling indicates possibility of sustaining production through the application of PCP, where the production increases around 120 STB/ day. Although PCP has proven its effectiveness, it is important to note that auxiliary sand mitigation techniques is required to maintain facilities integrity after several years of production.
Well Integrity Study for CO2 WAG Application in Mature Field X, South Sumatra Area for the Fulfillment as CO2 Sequestration Sink Steven Chandra; Prasandi A Aziz; Muhammad Raykhan Naufal; Wijoyo Niti Daton
Scientific Contributions Oil and Gas Vol 44 No 2 (2021)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.44.2.587

Abstract

The most of today's global oil production comes from mature fields. Oil companies and governments are both concerned about increasing oil recovery from aging resources. To maintain oil production, the mature field must apply the Enhanced Oil Recovery method.  water-alternating-gas (WAG) injection is an enhanced oil recovery method designed to improve sweep efficiency during  injection with the injected water to control the mobility of . This study will discuss possible corrosion during  and water injection and the casing load calculation along with the production tubing during the injection phase. The following study also performed a suitable material selection for the best performance injection. This research was conducted by evaluating casing integrity for simulate  water-alternating-gas (WAG) to be applied in the X-well in the Y-field, South Sumatra, Indonesia. Corrosion prediction were performed using Electronic Corrosion Engineer (ECE®) corrosion model and for the strength of tubing which included burst, collapse, and tension of production casing was assessed using Microsoft Excel. This study concluded that for the casing load calculation results in 600 psi of burst pressure, collapse pressure of 2,555.64 psi, and tension of 190,528 lbf. All of these results are still following the K-55 production casing rating. While injecting , the maximum corrosion rate occurs. It has a maximum corrosion rate of 2.02 mm/year and a minimum corrosion rate of 0.36 mm/year. With this value, it is above NORSOK Standard M-001 which is 2 mm/year and needs to be evaluated to prevent the rate to remain stable and not decrease in the following years. To prevent the effect of maximum corrosion rate, the casing material must use a SM13CR (Martensitic Stainless Steel) which is not sour service material.
Tubing Strength Evaluation and Failure Assessment for Reactivation of Well PDD-2 as Steam Injector Well Steven Chandra; Wijoyo Niti Daton; Mohammad Hafidz Setiawan
Scientific Contributions Oil and Gas Vol 44 No 3 (2021)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.44.3.712

Abstract

Many old oil wells still exist in Indonesia, some of those wells has been shut in due to several reasons, two of those reasons are: the oil production that declines significantly and weak well integrity so that the well cannot withstand obstructions that occur during production. To maintain and boost Indonesia's oil production, Enhanced Oil Recovery (EOR) methods can be applied in mature fields. One of EOR methods that has the most extensive application is steam flooding, in which the fluid is injected continuously to drive the oil from injector to producer. This EOR method is a successful method to increase heavy-oil production.The application of steam flooding, most notably in older wells presents itself with possible well integrity problem. Steam flooding well has a very high risk of casing and tubing failure that caused by the loads from burst, collapse, tension, and thermal effect due to the high temperature steam that can decrease the rating of casing or tubing. Hence, this study focuses on evaluating tubing's strength on the existing well whether the tubing is applicable for steam flooding or must be replaced. In this study, a tubing strength evaluation of well PDD-2 for steam flooding method will be discussed. Tubing strength evaluation consists of two stage. The first stage is evaluation due to burst, collapse, and tension loads and the other stage is evaluation due to thermal effects of injected steam. Well PDD-2 has K-55 tubing with 3.5 inch OD, burst rating of 7,947.5 psi, collapse rating of 7,052.9 psi, and tension rating of 160,262 Ibf. Based on the evaluation result, this existing K-55 tubing still be able to withstand the loads from burst, collapse, tension, and thermal effects. Hence, the reactivation of Well PDD-2 as steam injector well can be done without replacing or upgrading the tubing.
Co-Authors Amanda Efa D Ariel Paramastya Daton, Wijoyo Niti Mohammad Hafidz Setiawan Muhammad Raykhan Naufal Prasandi A Aziz Prasandi AA Ronaldo H.T. Sudjati Rachmat Wijoyo N.D.