Abstract Surfactant injection is one of the EOR methods used to increase oil recovery. Using of surfactants is intended to reduce the interface tension between oil and water. The types of surfactants commonly used are oil-based surfactants, such as petroleum sulfonate. This condition causes the price of surfactants very dependent on oil prices. As efficient alternative, research on plant-based surfactants sourced from nature is being developed. Like the type of surfactant that will be used in this study is Sodium Lignosulfonate (NaLS) sourced from bagasse waste. The purpose of this study is to add reference of the characteristics of the NaLS surfactant to be used optimally. The screenings in this experiment were Aqueous Stability test, phase behaviour test, and IFT test on 1.5% NaLS concentration and high salinity 75,000 ppm Nacl. The results of aqueous stability test are transparent, the results of phase behaviour test are middle phase emulsion with an emulsion percent of 8.75%, and the results of IFT test obtained value of 1.98 mN/m. Based on these results, surfactants meet the screening parameters so can proceed to the injection stage for determine the value of recovery factor. Recovery factor result for NaLS bagasse waste based surfactant injection is 4.74%.
Abstract This field X well production has indeed occurred in the sand and this well has been carried out with water flooding with injection water that is currently available. In this study of sand problems, it is intended to find out the cause of the problem of sandiness in terms of laboratory analysis of formation rock samples and injection fluid. Laboratory analysis consists of fluid characterization, rock characterization that is specifically assigned to rock minerals (SEM and XRD), and fluid injection compatibility tests with rocks, then a sand retention test is performed. After the addition of clay stabilizer in injection water, Zone A, Zone B and Zone C have increased apparent permeability to reach an interval of 500% -1000% mD. The use of Zetpass cannot be used in zone A because there is a lot of clay and the grain is very fine, but it can be used in zones B and C. Fluid interactions with rock minerals and chemical interactions will reduce the cementation of rocks so that they can trigger the occurrence of sand. Clay stabilizer is important to note in wells that have done water flooding. ZetPass solution is able to become sand control but has limitations. The ZetPas solution is able to become sand control but has limitations, where if it is applied to a reservoir that has a significant composition of clay minerals (smectite, illlite and chloride), the performance will decrease.
Abstract It is widely accepted that the chemical enhanced oil recovery (EOR) technique, especially polymer flooding, has been successfully implemented and improves oil production in oilfields worldwide. Polymers are injected into the well to increase the viscosity of the displacing fluid. Most of the polymer flooding projects employ synthetic polymer, and the rest uses biopolymer. Considering the environmental concern, it is encouraging to select biopolymer as an EOR agent. This study focuses on the current status of the development of the cellulose-based biopolymer for EOR since cellulose is abundant organic material in nature. Hydroxyethylcellulose (HEC) and Carboxymethylcellulose (CMC) have been utilized in the oil industry, while cellulose nanocrystal (CNC) and cellulose nanofibril (CNF) are recently being introduced as potential EOR agents. The evidence from the previously published data shows that cellulose-based biopolymers can improve oil recovery and have distinct characteristics. This study is a preliminary attempt for further application of cellulose-based biopolymer in EOR.
Aims: This study aims to determine the synthesis of bagasse to form surfactants and evaluation of the performance of the sample to increase oil yield. Indonesia generates very large amounts of solid waste, without recycling or adequate management efforts to preserve the environment. Bagasse emerged as one of the most abundant biomass due to the operations of large plantations and factories. Furthermore, previous studies showed extensive uses in the fields of compost, animal feed, bioethanol energy, paper, and reinforced building materials. Methodology and Results: Lignin was extracted from bagasse to process sodium lignosulfonate surfactant (SLS surfactant). The synthesis was characterized several times, and certain examples showed significant HLB values, as a function of emulsion builder. This condition in the oil reservoir is required to reduce interface stress (IFT) and friction in the movement of particles. Another analyses involves the assessment of core flooding of specific synthetic core and crude samples. Conclusion, significance and impact of study: The results confirm the ability of surfactant bagasse to increase oil recovery, namely the HLB value of 11.6. The results also show the surfactant classification with the ability to form a middle-phase emulsion in order to increase petroleum products. Therefore, bagasse as solid waste has a performance effect on the process of increasing petroleum production.
Abstract Sand problem is one problem that can disrupt oil well production. With the sand problem, the productivity of the well decreases so that there will be a decrease in oil production. Sand problems that occur result in increased production loss and cost lost. The purpose of this research is to find the right solution in overcoming sand problem, by studying the characteristics of the rock. Laboratory experiments were carried out using a mechanical method approach which was then used to determine the appropriate gravelpack design. The steps taken include testing the strength of the core of the three zones, the decrease of strength can conclude that the core of the three zones has begun to weaken. The results of the analysis of the grain size of the D50 then used to determine the appropriate gravelpack design in each zone. Zone A, using gravelpack 60/80, zone B using gravelpack 16/20, and zone C using gravelpack 30/50. From the gravelpack design obtained then a sand retention test is performed to determine the gravelpack’s performance. With the results of the sand retention test showing good gravelpack performance for each zone, where the permeability value is good and the solid produced is not too much.
<p class="IEEEAbtract"><em>Polymer injection is one of the methods of increasing oil recovery or Enhanced Oil Recovery (EOR) after the water injection method is performed, to reduce residual oil saturation. The polymer reduces the water mobility ratio so that the sweeping efficiency will increase to encourage bypassed and unswept residual oil saturation. For polymer injection applications, partially hydrolyzed polyacrylamide (PHPA) or commercially known as HPAM is the most widely used type. At the current low oil prices, design optimization of polymer injections in certain reservoirs is important. The purpose of this research is to analyze the effect of permeability and polymer concentration on residual oil saturation by core flooding method in the effort of optimization of polymer injection. The optimal concentration in this study is 1,500 ppm which has the lowest residual oil saturation value. The increase in concentration from 500 ppm to 1.500 ppm, residual oil saturation decreased in four variations of Berea sandstone permeabilities. However, when the polymer concentration is added to 2.500 ppm, the residual oil saturation value increases. This can be caused by pore clogging. Whereas with permeability, residual oil saturation is directly proportional. The greater the permeability the greater the value of residual oil saturation. Core Y7 Berea has the highest permeability and saturation of residual oil. The results of this study are expected to be useful in the development of polymer injections on EOR activity.</em><em></em></p><p><strong><em>Keywords.</em></strong><em> </em><em>polymer injection, concentration, permeability, PHPA, residual oil saturation</em><em></em></p>
This paper describes a method to rank potential infill well locations using Artificial Neural Networks (ANN) from existing well data. Sensitivity test was conducted for training and testing data used with comparison 2:8, 4:6, 5:5, 6:4 and 8:2 for each data. Root Mean Square Error difference between training and test data show that the best results obtained from the ratio of training data and testing data 8: 2. Two ANN models were built. The first model predicted top sand depth, resistivity, gamma-ray and density-neutron from infill well location (chosen from structural position and good oil rates from offset wells). The second model predicted initial oil rate from outputs from the first model. Predicted initial oil rates from the ANN model were compared with those from the 3D reservoir simulation model. They shows similar prediction of oil rates which gave high confidence in the predicted oil rate. Very different oil rate prediction between the two models can be used as consideration to improve the simulation model.
Abstract The needs of petroleum as energy, have increasing while the oil production has depleting. Due to that needs, the method of Enhanced Oil Recovery (EOR) or in other hands as tertiary recovery (after primary recovery and secondary recovery) is being developed. EOR has many methods; one of the methods is chemical injection that consists of surfactant, alkaline and polymer. In this experiment, the author is using surfactant injection. The using of surfactant is to decrease the interfacial tension between oil and water, with the result is surfactant can displace oil through rock pores. This study will be discussing about the effect of salinity, surfactant types and surfactant concentrations on surfactant injection for carbonate rock. The surfactant types are Alpha Olefin Sulfonate (AOS) and Tween 20. The surfactant concentration varieties are 0,1%; 0,25%; 0,5%; 0,75% and 1%. Salinity varieties are 10.000 ppm; 15.000 ppm; 20.000 ppm and 25.000 ppm. From this study, it had determined that surfactant can displace the oil from rock pores based on the influence of salinity, surfactant concentrations and surfactant types to recovery factor. The determination of recovery factor will be using these methods; Amott apparatus (imbibition process) and injection using core holder and syringe pump. From experiments that have been done, the effect of surfactant injection on carbonate rocks is more optimal in core flooding process compared with imbibition process, with the recovery factor percentage is 57%. Core flooding process uses the external thrust, therefore the oil displacement with surfactant is more evenly and optimally.
This article discusses the prospect of geothermal energy development in Indonesia and its obstacles. The research method used in this research is library research from various sources. This study found that the main obstacles to geothermal energy development are inconsistent with government policies and regulations. So it could be concluded that a smarter government is needed in formulating, implementing, and controlling the government policies and regulations, impacting on the development and utilization of this energy could run properly.
Abstract Oil wells in the x field in the offshore Natuna Indonesia generally use gas lifts as artificial lifts. As time goes, the field enters of oil production decline phase. To maintain oil production and evaluate the other artificial lift, the Electric Submersible Pump or ESP method was conducted on five wells A-01, A-02, A-03, A-04, and A-05, with various reservoir properties. The research objective is to evaluate the technical application of the ESP and obtain the highest potential well to increase oil recovery. The methodology was carried out by collecting field primary data such as reservoir data, Depth, slope, etc. Then the ESP application design is carried out by manually calculating the wells. Result and discussion: based on the calculations, the ESP method can be applied to wells A-01, A-02, A-03, and A-04. A-05 cannot be used well because it has a high turpin meter value (16.35) due to a high GOR (Gas Oil Ratio) value of 2385 SCF/STB. The well with the highest potential to increase oil recovery is well A-01 with the additional oil production +1116 BOPD. It can be concluded that the most potential to be developed into ESP well is A-01.
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