Penerapan Model Isotermal untuk Adsorpsi Statik Xanthan pada Batuan Pasir untuk Berbagai Salinitas

Salah satu fenomena yang biasa terjadi selama injeksi polimer adalah adsorpsi. Fenomena ini memainkan peran penting, karena mereka mempengaruhi sifat batuan dan fluida. Adanya lapisan polimer teradsorpsi akan diameter pori. Hal ini akan menghambat  aliran fluida. Dalam kajian ini dilakukan pengamatan pengaruh konsentrasi dan salinitas terhadap adsorpsi xanthan pada butiran pasir dalam sistem statik (batch). Konsentrasi xanthan divariasikan dari 200 ppm hingga 2,000 ppm sedangkan salinitas divariasikan dari 10,000 ppm hingga 20,000 ppm. Butiran pasir yang digunakan berukuran pasir 100 mesh (0.149 mm). Percobaan dilakukan pada suhu ruang. Pengukuran absorben dilakukan dengan menggunakan spektrophotometer pada panjang gelombang cahaya tampak sebesar 600 nm. Tiga model adsorpsi isothermal digunakan dalam kajian ini yaitu Langmuir, Freundlich, dan Simha-Frish-Eirich untuk membuat korelasi antara konsentrasi partikel teradsorpsi dan konsentrasi larutan xanthan dalam kesetimbangan. Berdasarkan hal pengamatan disimpulkan bahwa tingkat adsorpsi berkurang dengan bertambahnya salinitas. Dalam kajian ini secara umum penerapan model Freundlich memberikan hasil terbaik dalam menggambarkan proses adsorpsi xanthan

Analisis Pengaruh Wetabilitas pada Kinerja Injeksi Air dan CO2 Menggunakan Metode Material Balance Pada Lapangan SNP

Saat ini, CO2 flooding adalah salah satu teknik pemindahan yang paling menarik di lapangan-lapangan minyak. Injeksi CO2 akan memungkinkan minyak berinteraksi dengan CO2 dan memberikan peningkatan positif, sehingga minyak akan lebih mudah mengalir. Tujuan dari penelitian ini adalah untuk mendapatkan skenario penginjeksian terbaik yang memberikan perolehan minyak tertinggi antara injeksi air, injeksi CO2, serta injeksi air dan CO2 secara kontinyu pada kondisi batuan reservoir dengan kebasahan minyak dan reservoir dengan kebasahan air. Penelitian dilakukan pada Lapangan SNP menggunakan simulasi model material balance dengan lama penginjeksian sekitar 30 tahun.  Lapangan SNP memiliki tiga regional (antiklin). Pengamatan dilakukan pada Region 2 dan Region 3. Untuk setiap region dibuat sepuluh skenario dengan variasi laju injeksi air dari 0 hingga 2000 STB/D dan variasi injeksi CO2 dari 0 hingga 0.5 MMSCF/D. Hasil simulasi menunjukkan perolehan minyak pada Region 2 berkisar antara 40.90% hingga 52.65%. Sedangkan   perolehan minyak pada Region 3 berkisar antara 48.88% hingga 60.08%. Dari hasil perbandingan keduapuluh skenario pada kedua region, diperoleh bahwa injeksiCO2 memberikan kinerja terbaik pada reservoir oil wet. Sedangkan pada reservoir water wet kinerja injeksi air lebih baik daripada injeksi CO2. Skenario terbaik pada reservoir water wet adalah dengan penginjeksian air dan CO2 secara kontinyu

Design Optimization and Application of Hybrid Bit to Reduce a Well Cost in Geothermal Field

Hybrid bit is one of the innovations developed for very hard and abrasive formations such as in geothermal field. This bit eliminates the risk of losing cones, reduces tripping time, and increaseas ROP to reduce the well cost. The stage of data processing by calculating the UCS formation using D-BOS software and design optimization based on 9-7/8" bits simulations in granodiorite formations. The 1st phase was to determine the 4 best out of 7 hybrid bit designs that were selected from the highest ROP obtained, the most stable cutter cutting force, and the lowest vibration by comparing the results of FEA modeling of 1 ft drilling simulation. The 2nd phase is to choose 1 of the best from the 4 selected by doing 50 ft of drilling dynamics simulation which is assessed by directional capability, the durability, and the lowest MSE. In this study to improve drilling optimization in geothermal field, it was found that the Z616 hybrid bit design was the most optimal one. Based on 1st phase simulation, this bit was able to produce ROP of 6.38 mph, a stable cutter cutting force, very low average lateral 2.109 g and axial vibration 0.329 g. Furthermore, for the 2nd phase simulation of 50 ft, seen from the comparison of directional capability, this bit has a 0.91 deg/100 ft DLS in rotating mode, and 6.5 deg/100ft DLS in sliding mode means quite stable when drilling in rotary mode and easy to make some angle in slide mode. By its durability, the average value of lateral acceleration is 10 g, and the lateral force is 6 klbf. By MSE side, this bit also produces the lowest average MSE value of 769 psi. From the economic view, this bit can save USD 198,625 - USD 564,712 of a well cost

The Effect of Resin Injection on the Productivity of Shallow Sandstone Layer in Mawar Field

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%

The Importance of Microemulsion for the Surfactant Injection Process in Enhanced Oil Recovery

Microemulsion is the main parameter that determines the performance of a surfactant injection system. According to Myers, there are four main mechanisms in the enhanced oil recovery (EOR) surfactant injection process, namely interface tension between oil and surfactant, emulsification, decreased interfacial tension and wettability. In the EOR process, the three-phase regions can be classified as type I, upper-phase emulsion, type II, lower-phase emulsion and type III, middle-phase microemulsion. In the middle-phase emulsion, some of the surfactant grains blend with part of the oil phase so that the interfacial tension in the area is reduced. The decrease in interface tension results in the oil being more mobile to produce. Thus, microemulsion is an important parameter in the enhanced oil recovery process

Well Test Analysis Using Pressure Derivative Method at Gas Well X-1

Wells X-1 is a gas condensate well which located in lapangan X, Sulawesi Island. At well X-1 well test was conducted using pressure build up, where the analysis was conducted with objective to determine the reservoir characteristic of X-1 wells such as permeability, skin, flow efficiency and investigation radius. In the pressure build up test, the horner plot and derivation analysis using pseudo pressure and P2 approaches were applied with the gas well X-1 has a reservoir pressure of 2555 psia. The analysis is done using saphir 3.20 and Ms.Excel software where the results of the counsel to see if there is any possibility of formation damage. X-1 is also known as homogeneous with a fault boundary present in the fault located at a certain distance from the well X-1 in which the fault is only one direction from the reservoir. The pressure derivative plot analysis was conducted with two methods such as two-point method and three-point method, where the result of the overlay of the derivative curve corresponds to the deviation of the calculation result method which is less than 10%. The horner plot analysis is also done with the ψ(P) pseudo pressure and P2 approach which is the result of horner plot analysis using pseudo pressure ψ(P) pseudo pressure in saphir 3.20 obtained the slope (m), permeability, and skin values respectively were 3.22432E + 5 psi2/cp, 132 mD, and 21.6, whereas Ms.Excel results obtained the price of slope (m), permeability, and skin respectively were 320890.61 psi2/cp, 134.83 mD, and 21.1. To analyze the horner plot using the P2 approach at saphir 3.20 the value of slope (m), permeability, and skins values respectively were 5495.07 psi2/cp, 125 mD, and 21.3 and for the results of Ms. Excel the price of slope (m), permeability, and skin respectively were 5451.66 psi2/cp, 147,29 mD, and 20,1. Positive skin results in both methods of horner plot and derivative plot indicate the well is damaged and need to be stimulated

Implication of the Multiphase Influx in Well Control and Circulating System

A multiphase flow system is commonly faced by oil and gas industries where it constituted of complex design and analysis [1].  Previous studies on the multiphase system have established a number of models including Hagerdon & Brown, Duns & Ros, Orkiszewki and Beggs & Brill [1]. Numerous studies have been carried out on the multiphase system related to production engineering [3]. However, the study on the multiphase system is found limited to be related to well control and drilling management. The multiphase system is interestingly important in well control especially during unwanted circumstances such as kick.  Flow behavior and pattern might be different from one phase system where normally only gas kick is considered during design stage of the drilling campaign. Since the multiphase kick might represent different outcome compared to one phase system, an accurate calculation of multiphase kick is desired. Therefore, the purpose of this study is to observe the impact on the multiphase kick with on the pressure drop reading and its connection with a circulating system. The study will cover on Pressure drop calculation using Beggs & Brill correlation by consolidating all the data given from various sources; Identification of flow regime of the multiphase system for the base case with several reference pressure; Sensitivity analysis including the effect of different liquid content and liquid flow rate towards the pressure drop. The expected outcomes from this study are beneficial for well control management where necessary actions to prevent blowout

Well Test and Short Term Multiple Rate Flow Tests Analyses to Successfully Hydraulic Fracturing Program of Block X

Well test analysis was conducted to determine the characteristics of reservoir rocks. From the well test analysis it is obtained information such as permeability and skin factor. The skin factor is a quantity indicating the presence of disturbance in the formation as a result of drilling operations, production operations, perforating casing, gravel pack installation, remedial well work, acidizing operation, and hydraulic fracture operation. The objective of this research is to determine the relationship of multi rate test method of Jones, Blount, and Glaze and the comparison result among pressure buildup test and pressure drawdown test analyses, using Kappa software or manually calculation. Therefore, in this paper will study the method of Jones, Blount, and Glaze and the well test analyses to determine further work of the wells on block X. The data used in this paper is secondary data, namely the results of well test from three wells.Applying drawdown test analysis of A, Y, and Z wells yield skin factor values of 3.37; 27.10; and -1.39. Where in buildup pressure Horner method analysis of A, Y, and Z wells yield skin factor values of 16.10; 11.18; and -2.07. In the method of type curve derivatives the drawdown analysis of A, Y, and Z wells yield skin factor values of 7.04; 11.18; and 4.20. The analysis of pressure buildup, of A, Y, and Z wells yield skin factor value of 25.11; 14.47; and 1.93. In the analysis using Kappa software of A, Y, and Z wells yield skin factor values of 5.56; 10.2; and 2.00. The skin results of these wells indicate the formation damages. The Short Term Multiple Rate Flow Tests analysis using Jones, Blount, and Glaze method from the plots of Δp/q versus oil flow rate (q) are b’ high and b’/b low. These indicate that the three wells are encountering formation damages. The Jones, Blount, and Glaze method as well as the pressure buildup and pressure drawdown test analyses in block X indicate that these wells require to be stimulated

Design of Flowline, Separator, and Slug Catcher in X Field

The use of the pipeline is the safest method in sending oil and gas from one area to another in oil and gas transportation system. The only challenge is to keep the pressure drop in the pipeline as small as possible to avoid high pressure differences. This pressure difference can result in reduced production flow rate and affect the flow pattern in the pipeline. The condition can lead to high possibility of a slug on pipelines that drain multiphase flow. Slug becomes one of the main concerns transport processes multiphase flow in pipelines. The emergence of slug in the pipeline could cause an unstable hydrodynamic conditions will continue to affect the liquid level in the inlet separator and cause flooding in the separator. Some of the conclusions mainly on the diameter of the pipeline, the size of the slug catcher and the size of the separator obtained from the calculation based on the study of literature and simulations with software HYSIS and OLGA. Design slug catcher to accommodate the number of processes that occur in the production transportation of X oil and gas field through a pipeline 10 inches along the 12 km with 20.68 m3 volume of slug using 3 (three) finger with diameter 28 inches and length of 10 meters each. For the separation process of oil and gas in the first five (5) years of X oil and gas field  which has a high production of oil and condensate will require separator with 30 inches diameter, seam to seam height of 8.1 ft or 2.5 meters, with retention time for 2 minutes and the 3.2 slenderness ratio of the vertical separator

THE IMPACT OF THE PRODUCTION OF NEIGHBOUR WELLS ON WELL PRODUCTIVITY IN A SHALE GAS RESERVOIR

ABSTRACT: A shale gas reservoir is a self-contained source-reservoir system, characterized by extremely low matrix-permeability and low porosity, which typically requires extensive fracturing to produce gas at commercial rates. This paper presents a simulation experiment, intended to study the impact of well interference on gas recovery in a shale gas reservoir. The simulation model was constructed to study well interference through variation of horizontal well length, fracture half length, number of fracture, and well spacing. The results show that the increment of recovery factor of a well in the presence of neighbour wells is up to 7%. In this study, fracture half length is the most influence parameter on recovery factor, initial rate and reservoir pressure decline. ABSTRAK: Takungan gas syal merupakan sistem sumber-takungan kandung sendiri, khasnya kerana ia mempunyai kebolehtelapan-matriks yang begitu rendah dan keliangan yang rendah.  Sifat sebegini memerlukan ia melalui peretakan yang ekstensif untuk menghasilkan gas pada nilai komersial. Kertas kerja ini membentangkan eksperimen simulasi yang bertujuan untuk mengkaji impak perigi interferens terhadap perolehan gas dalam takungan gas syal.  Model simulasi di konstruksi untuk mengkaji interferens perigi; iaitu menerusi pelbagai variasi  panjang mendatar perigi, retakan separuh panjang dan jarak perigi.  Keputusan menunjukkan peningkatan faktor perolehan perigi sebanyak 7% dengan kehadiran perigi bersebelahan. Dalam kajian ini, retakan separuh panjang merupakan ciri utama dalam faktor perolehan, kadar awalan dan penurunan tekanan takungan