Articles
90 Documents
<![CDATA[Aerated Drilling Optimization in Geothermal Well Drilling in Field “X” Cluster “Y” ]]>
<![CDATA[Raka Aditya Pratama]]>;
<![CDATA[Astra Agus Pramana]]>;
<![CDATA[Bambang Kustono]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 1 No. 2 (2018): JEESET-VOL.1-NO.2-2018 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v1i2.3945
<![CDATA[Aiming for productive fault in Suban Agung Rim, Field X Cluster Y Bengkulu Province, Indonesia, PT Pertamina Geothermal Energy (PGE) drilled some wells to discover the potential awaited. However there are challenge awaits each meter ahead especially in reservoir sections where loss circulation is expected. Knowing the risk, PGE decided to drill the well utilizing aerated drilling. The method has known for decades to be the most effective approach in dealing loss circulation. The method applies certain value of compressed air to be injected in fluid stream, so bubbling process can be achieved in order to reduce the mud weight. The method has benefit to maintain ROP and minimize the risk for pipe get stuck due to poor hole cleaning in fractured formation. There are three wells drilled in Field X Cluster Y which has the same problem in 9-7/8” section; all experienced stuck pipe while drilling. During the process aerated drilling was utilized, however it was not sufficient. This paper will discuss and explain on how the occurrence happened and what to do next in similar condition to avoid the problems.]]>
<![CDATA[Flare Gas Recovery System Using Integrated Reciprocating Compressor in Gathering Station C ]]>
<![CDATA[Tamado Sitorus]]>;
<![CDATA[Ratnayu Sitaresmi]]>;
<![CDATA[Hari Hari Oetomo]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 1 No. 2 (2018): JEESET-VOL.1-NO.2-2018 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v1i2.3946
<![CDATA[Flare gas recovery is needed to handling gas flares in oil and gas fields. Field C production wells experience a decline as a result the gas flow pressure in the wellhead becomes low. Low pressure gas enters the LP separator then is burned as a gas flare containing CO2 of 33.38 mol and GHV of 1048.9 BTU / ft3. The flare gas recovery system is applied to reduce gas flares with the integrated reciprocating compressor unit for compression at suction pressure ± 10 psig, discharge pressure ± 100 psig and total flowrate ± 1 MMSCFD. Then the CO2 removal plant produces gas with a CO2 content of 7.09% mol and GHV of 1314.9 BTU / ft3. During operation, requires gas fuel ranging 11 MSCFD and the actual power ranges from 36.46 HP and 39.64 BHP. Economic aspects analysis, gas flare monetization for the period of 2015 until 2022, gross reserves 2,062,917 MMBTU and gross income of US$ 6,026,744. The operating cost of the the lease purchase scheme, the government US $ 2,079,696 and the contractor US $ 1,386,464 with POT 1.7 years and IRR 151.5%.]]>
<![CDATA[The Use of Critical Porosity on Grouping of Rocks Quality of Sandstone Formations ]]>
<![CDATA[Sigit Rahmawan]]>;
<![CDATA[Ratnayu Sitaresmi]]>;
<![CDATA[Suryo Prakoso]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 2 No. 1 (2019): JEESET VOL. 2 NO. 1 2019 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v2i1.4646
<![CDATA[Research in the classification of rock quality formations has been carried out by many previous researchers with various methods using core sample data. However, from this research there are still many uncertainties that are found due to the difficulty of the data observed. The study uses the critical porosity for grouping the rock quality. The study obtained evidence on the surface conditions of critical porosity values obtained by the Nur method, et al. Using data P and S wave velocity data on measuring core samples surface pressure conditions that produce different rock quality based on different criticcal porosity ranges. Rock type formed based on the critical porosity has a relation to the pore geometry and pore structure that forms the linkages of each rock type. The similarity of the formation of rock types resulting from the value of critical porosity on rock types using the Wibowo and Permadi methods. In this study ten rock types were obtained. With the formation of rock quality groups that are different from the critical porosity values, further research is needed to find out whether the acoustic log in the data log that has P wave propagation speed can be used to determine the critical porosity value and determine the rock quality classification.]]>
<![CDATA[Application of Hydrodynamic Potential Analysis to Investigate Possibility Reservoir Connectivity between Neighboring Gas Fields ]]>
<![CDATA[Tri Firmanto]]>;
<![CDATA[Muhammad Taufiq Fathaddin]]>;
<![CDATA[R. S. Trijana Kartoatmodjo]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 2 No. 1 (2019): JEESET VOL. 2 NO. 1 2019 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v2i1.4647
<![CDATA[T field is a producting gas field in North Bali PSC, which currently producing 210 mmscfd from paciran sand stone formation. Paciran formation extends more than 20 km across the PSC area, which consists of 3 developed gas fields and one potential development field. The flowing material balance analysis conducted on T field suggests possibility of reservoir connectivty between this field and its neighboring fields. Even though each field is already have a well defined Gas Water Contact, a thorough investigation was done using hyrdodynamic potential analysis to see if theres any hydrodynamic potential that allowed connectivity between these fields, and enable tilted contact occurred between these field. Using pressure data taken from each fields exploration wells the analysis can be conducted that conclude that there is an existing hydrodynamic potential between gas fields in paciran formation. A review on the tilted contact analysis concludes that the existing hydrodynamic potential is not enough to tilt the contact as per actually observed contact.]]>
<![CDATA[Effect of Baggase NaLS Surfactant Concentration to Increase Recovery Factor ]]>
<![CDATA[Arinda Ristawati]]>;
<![CDATA[Sugiatmo Kasmungin]]>;
<![CDATA[Rini Setiati]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 2 No. 1 (2019): JEESET VOL. 2 NO. 1 2019 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v2i1.4648
<![CDATA[Surfactant flooding may increase oil recovery by lowering interfacial tension between oil and water. Bagasse is one of the organic materials which contain fairly high lignin, where lignin is the basic substance of making Natrium Lignosulfonate (NaLS) Surfactant. In this research, bagasse based surfactant was applied for surfactant flooding. The research was divided into two sections, namely: phase behavior test and NaLS Surfactant flooding where the water contained 70,000 ppm NaCl. Two surfactant concentrations which were used were 0.75% and 1.5% NaLS surfactant. Phase behavior tests were carried out to find the middle phase emulsion formation. Based on phase behavior test results, the percentage of emulsion volume for 0.75% and 1.5% NaLS is 13.75% and 8.75%, respectively. NaLS surfactant flooding was performed for to obtain the best recovery factor. FTIR equipment used determine recovery factor. The optimum condition was obtained at 0.75% NaLS surfactant concentration where the recovery factor was 4.4%.]]>
<![CDATA[Effect of High Temperature on Rheology and Electrical Stability of Saraline and Smooth Fluid 05 Mud ]]>
<![CDATA[Apriandi Rizkina Rangga Wastu]]>;
<![CDATA[Muhammad Taufiq Fathaddin]]>;
<![CDATA[Abdul Hamid]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 2 No. 1 (2019): JEESET VOL. 2 NO. 1 2019 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v2i1.4650
<![CDATA[In drilling operations, drilling mud plays a very important role because it is irreplaceable functions. Drilling activities relate to problems caused by complex conditions in formation due to changes in temperature, pressure, and contamination from formation fluids. Using Oil Base Mud (OBM) mud systems in the form of Saraline and Smooth Fluid 05 is tested for drilling fluid performance and the results can be a reference for drilling operation. This research consist of two parts, the first: determining the drilling mud rheology value in the form of (Plastic Viscosity, Yield Point and Gel Strength) in each drilling mud of Saraline and Smooth fluid 05 mud using various high temperature parameters of 350oF, 300oF, and 270oF. The results of the mud rheology tests show at the higher the temperature, the values of rheology decreases. The second experiment is to determine the level of electrical stability in the mud which functions of oil-wet content in oil sludge (Saraline and Smooth fluid 05). The electrical stability value has a minimum limit value in OBM, which is 500 volts. In this experiment showed that the higher the temperature value, the electrical stability value in the mud will decrease, but in this study the value of electrical stability in Saraline mud and Smooth fluid 05 has a value above 500 volts, the composition OBM of Saraline and Smooth Fluid 05 sludge has very good oilwet content.]]>
<![CDATA[Geometry Modified Square Edge Orifice Valve Study for Efficiency Gas Lift with Computational Fluid Dynamic (CFD) Method ]]>
<![CDATA[Adam Fatchur Rohman]]>;
<![CDATA[Sugiatmo Kasmungin]]>;
<![CDATA[Dwi Atty Mardiana]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 2 No. 1 (2019): JEESET VOL. 2 NO. 1 2019 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v2i1.4651
<![CDATA[The gas lift lifting system is widely used as an artificial lift on the X Field, with an average depth of gas lift production wells of 3,000-3,500 ft. Design of 3 to 5 Gas lift Valves (GLV) designwith size of 1 inch is ussualy applied. While at the point of gas injection, the GLV square edge orifice is applied. The problem in the optimization of gas lift wells is the flow instability due to gas flow rate fluctuations, the limited volumetric gas injection and limited gas compressor pressure. With the limited compressor pressure, the lift flow and gas design speed is very dependent on the amount of pressure on the compressor, the production wells with limited injection pressure will result in a limited amount of gas injection, the square edge orifice requires a pressure difference of 40% to achieve the maximum gas flow rate. This study aims to find the modification of the GLV orifice geometry to improve the efficiency of the gas lift system so that it can get optimal production. This GLV design modification includes changing the GLV orifice geometry. Design studies using Computational Fluid Dynamic (CFD) simulations aim to analyze any changes in GLV geometry design to the performance of the gas flow rate in the orifice valve described in the valve performance curve. The design modification approach is in accordance with the GLV venturi orifice geometry and the availability of equipment for GLV modification. The CFD simulation results of the first modification geometry by increasing the orifice diameter from 0.25 to 0.5 inch with the condition of upstream 650 psig and downstream 625 psig pressure increasing the injection gas flow rate capacity by 355% and modifying the second geometry with the venturi orifice form by 280%. In modifying the shape of the orifice venture to reach critical flow requires a pressure difference of 10%. Based on simulation results, the modified orifice application is able to increae production up to 44%.]]>
<![CDATA[Hydrocarbon Accounting Verification for Reasonable Assurance on EJGP Open Access Pipe System ]]>
<![CDATA[Mildo Hasoloan Nainggolan]]>;
<![CDATA[I Putu Suarsana]]>;
<![CDATA[Suryo Prakoso]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 2 No. 2 (2019): JEESET VOL. 2 NO. 2 2019 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v2i2.4670
<![CDATA[The East Java Gas Pipeline (EJGP) pipeline network system is an open access for transporting almost ± 310 MMSCFD of Natural Gas from fields in East Java offshore to the onshore Power Plant consumers. The deviation between the calculated and mass balance of gas stock is called the Discrepancy in which BPHMIGAS set up a maximum value of ± 0.85%. The objective of the study is to develop a verification methodology to support hydrocarbon accounting in the EJGP Pipeline Network System. The methodology will be assisted by Flow Quantity Assurance software. After obtaining sufficient data, a new baseline can be taken empirically which can be used as a reference for the maximum allowable discrepancy in the EJGP Pipeline Network System. The data used in this simulation are taken from September - October 2013 such as pipes dimension of the entire network piping system, flowrate, pressure, temperature, and the composition of natural gas. The results of verification are compared with the calculations carried out by Pertamina Gas as operators. The calculation of Discrepancy from the Operators with different tools is around 0.12%, meaning that operator calculations are acceptable. The maximum allowable discrepancy ± 0.85%, can be reviewed to be reduced according to the history of the average system discrepancy in 2017-2018 (around 0.54%). The New Shipper from Sirasun Batur Field is still more economics by using the existing pipeline network even though it bears Discrepancy / Losses up to 1% compared to building new pipes to consumers. It is found that the discrepancy is getting smaller (reducing the error) if there is a gas balance, meaning that the end consumers will take the gas according to the agreed nomination.]]>
<![CDATA[The Effect of Resin Injection on the Productivity of Shallow Sandstone Layer in Mawar Field ]]>
<![CDATA[Catur Sunawan Balya]]>;
<![CDATA[Muhammad Taufiq Fathaddin]]>;
<![CDATA[Rachmat Sudibjo]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 2 No. 2 (2019): JEESET VOL. 2 NO. 2 2019 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v2i2.4671
<![CDATA[Mawar Field is located in North Kalimantan Province. The field has an unconsolidated sandstone layer which is located in Tarakan formation. Porosity of the layer is more than 20%, while permeability of that is between 100 mD and 1000 mD. The zone which is poorly cemented is a source of sand problem. This sand production has an effect on the stability of oil and gas production. Sand production results in the formation of channeling around cement bonding. Sand production problem can be reduced. To overcome the acidity of the shallow formation, it can be done in two ways, that is Gravel pack using propan and stimulation using resin where the sand will be retained behind the formation. In research that has been done using core data and produced sand samples where the results obtained information about the characteristics of sand in shallow zones so that the appropriate treatment method can be recommended that is stimulation with resin. In the use of this resin there will be a permeability reduction of 15% -27% and a maximum fow rate reduction of 20%.]]>
<![CDATA[Simulation Model Application to Predict the Effect of Salinity on Surfactant Adsorption and Retention in Alkali Surfactant Flooding ]]>
<![CDATA[Muhammad Taufiq Fathaddin]]>;
<![CDATA[Rachmat Sudibjo]]>;
<![CDATA[Kartika Fajarwati H.]]>;
<![CDATA[Shabrina Sri Riswati]]>
<![CDATA[ Journal of Earth Energy Science, Engineering, and Technology Vol. 2 No. 2 (2019): JEESET VOL. 2 NO. 2 2019 ]]>
Publisher : <![CDATA[Penerbitan Universitas Trisakti ]]>
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DOI: 10.25105/jeeset.v2i2.4672
<![CDATA[Modeling works of alkali surfactant injection are presented in this paper, in order to analysis the effect of salinity on surfactant adsorption and retention. Simulation model was built using UTCHEM simulator. The simulation model was validated using laboratory experiment. From the laboratory experiment and modeling, it was found that surfactant retention, as well as surfactant adsorption, increased with the salinity. However they were not linearly related. The application of microemulsion Type III (salinity of 1.4% wt.) gave the optimum flooding. Although more surfactant was adsorbed and retained compared to microemulsion Type I (salinity of 1.4% wt.), but it yielded the highest recovery factor. The formation of microemulsion Type II (salinity of 2.0% wt.) should be avoided since it effectively caused surfactant loss due to surfactant adsorption and retention.]]>
