Journal of Earth Energy Engineering
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Modeling Of Oil Flows In Langgak Field Pipeline
No full textAbstract
Congeal in the pipeline is one of the biggest problems faced by PT.SPR Langgak in piping crude oil from production wells to oil processing unit caused by decreasing oil temperature. The purpose of this study is to study the effect of environmental temperature on fluid temperature in the pipeline, study the effect of wind speed on fluid temperature in the pipeline and to determine the location of the occurrence of congeal in PT.SPR Langgak pipeline. Determining the location of the occurrence of congeal using the model T with analytical methods in the Matlab software is by entering parameters of pipe temperature, viscosity, density, fluid velocity, wind speed and environmental temperature. The congeal location was determined by model T obtained in the Zone C pipeline distance 44.9-449m with the average error model T is 1.88%. This model T can be applied provided the paraffin content is 15-60% and the pipe characteristics (pipe thickness, pipe diameter and pipe material) are the same.
 
A New EOR Technology: Gas Alternating Gas Injection
Full text linkA new method of enhanced oil recovery has been developed and applied to a simulation using some of data from the fifth SPE paper " template from CMG ". The simulator was used in this paper is GEM in the Computer Modelling Group (CMG) advanced equation-of-state (EOS) compositional simulator. The new method is called Gas alternating gas injection(GAG). The Gas Alternating Gas process is a cyclic method of injecting alternating cycles of gas followed by gas and repeating. Sensitivity analysis showed this method can give a much better recovery factor for GAG compared with single continues gas injection. GAG benefits that will give low water cut and high oil recovery due to gas segregation between two gases and that will prevent heavier gas to go the top layers. This work indicate that the GAG injection is an economic method compared with continues injection. Especially when we use GAG (Air + CO2).
 
Empirical Model for Heat Transfer of Electric Submersible Pump (ESP) Motor at Oil Producer Well
No full textMotor operating temperature at wells equipped with Electric Submersible Pump (ESP) need to be monitored to maintain ESP performance run life. Not all producer wells equipped with temperature sensor, so it considered necessary to build mathematic model to estimate motor operating temperature. Model of heat transfer to predict motor operating temperature is developed based on empirical equation method. Parameter and variable data obtained from producer wells include water cut, viscosity, specific gravity, operating temperature, ampere and voltage. Procedure to calculate viscosity is ASTM D-88 and procedure to calculate specific gravity is ASTM D-5002.
From 18 wells data obtained from the field, calculated reynolds numbers indicate turbulent flow regime with reynold numbers more than 4,000. Nusselt number were calculated using multiple linear regression with result of Nu = 0.06 * Re0.65 * Pr0.36 with error of 1.3% from downhole sensor measurement. The comparison with similar research also provided that use different Nusselt number empirical equation.
The conclusion from the research showing that empirical approach by using specific constants to predict Nusselt number can be used to predict more accurate heat transfer coefficient with error 1.3%. Higher water cut fluid flow need lower fluid velocity to achieve motor operating temperature below motor limit temperature with fluid velocity above 0.3 m/s
LABORATORY INVESTIGATION OF A NEW LIBYAN CHEMICAL EOR: Impact of GWLI on Relative Permeability, Wettability, Oil Recovery, Breakthrough and Fractional Flow
No full textThe greater demand for crude oil, the increased difficulty of discovering new reservoirs, and the desire to reduce dependence on imports have emphasized the need for enhanced recovery methods capable of economically producing the crude remaining in known reservoirs. Oil recovery from oil reservoirs may be improved by designing the composition and salinity of water injection. The process is sometimes referred to as sea or smart water injection. In this paper, a Gaberoun Water Leak Injection (GWLI) have been discovered and investigated as a new Libyan chemical EOR in laboratories on relative permeability, wettability, oil recovery, breakthrough, and fractional flow for carbonate and sandstone reservoirs. GWLI has several advantages which are relatively cheap, reliable, and available. GWLI potentially would have a wide range of applications in water injection such as wettability alteration. The equipment and the operating procedures were designed to simulate the reservoir condition. The experimental results indicate that, that the GWLI has caused the increasing of oil recovery in sandstone and carbonate core. The impact of GWLI on oil recovery in sandstone core samples was higher than carbonate core samples. The effect of acidity (pH) of GWLI on oil recovery in sandstone and carbonate core samples was higher when the pH is 5 than when the acidity is 10. Hopefully, the research findings can possibly be useful for references and for operating companies as an important source for understanding and visualizing the effects of pH, permeability, porosity, and wettability on oil recovery in reservoir rock using GWLI
A Critical Review on Mathematical Functions Employed for Heptane Plus Characterization in Gas Condensate Reservoirs: Lessons Learned and Future Development
Full text linkCharacterizing heptanes plus fraction in PVT analysis has been a complex problem since its first inception. In this publication, the author is reviewing available mathematical functions employed for this task, whilst pointing out advantages and weaknesses for each of them and proposing a new method that is capable of complex characterization. This publication addresses a new method that is capable of accurately characterize heptane plus fraction especially in discontinued areas where errors could leap up to 40%. The author modifies natural logarithmic function to be used as an accommodation to discontinuities. The modified distribution provides better accuracy in modeling the discontinuities as a straight-line function, making them ideal for real gas condensate composition characterization. The new method is tested against several test data used by previous researchers, and applied to 3 sets of field data. The results have shown that this new method is capable of lowering CPU requirement whilst making better accuracy for all test data
The Optimization and Analysis of Hydrocarbon Recovery under Injection of Biopolymer, Synthetic Polymer and Gels in a Heterogeneous Reservoir
No full textWater injection is a conventional method which increases the recovery by providing pressure support and displacing oil in the heterogeneous porous medium. Mobility ratio is important for a more efficient oil displacement by the injected fluid. Mobility ratio can be reduced using the fluids involving gelling agents. While polymers degrade and break up on experiencing sudden shear stresses and high temperatures, polymer macromolecules are forced to flow into narrow channels and pores where molecular scission processes can take place. It is importance to have a strong understanding of the use of the right type and amount of viscosity as a reduction agent. For polymer injection, a comparison of xanthan polymer and synthetic polymer mechanisms was conducted. A commercial full-physics reservoir simulator was coupled with a robust optimization and uncertainty tool to run the model, where a simplified gel kinetics was assumed to form a microgel with no redox catalyst. Control and uncertainty variables were set to investigate the sensitivity of this process using the coupled optimization and uncertainty tool. Results demonstrate deep penetration of gel and blocking of the high permeability bottom layers. Sensitivity studies indicate the relative merits of biopolymer, xanthan polymer in terms of viscosity effects vs synthetic PAM in terms of resistance factor vs in-situ gelation treatments and their crossflow dependence. Adsorption and retention of polymer and gel are permeability dependent. Considering the potential for application of gel solutions in the U.S. and throughout the world, this study illustrates the relative advantages of different treatments in terms of viscosity reduction in the same model in a comparative way, while outlining the significance of each control and uncertainty variable for better management of reservoirs where displacement efficiency is highly critical
Literature Review of Water Alternation Gas Injection
Full text linkThe Water Alternating Gas (WAG) process is a cyclic method of injecting alternating cycles of gas followed by water and repeating this process over a number of cycles. WAG injection is to improve oil recovery, by both increasing the macroscopic and microscopic sweep efficiency and to help maintain the reservoir pressure. Also, WAG injection is to postpone the gas breakthrough. The WAG process provides mobility control in fast zones which extends gas project life and oil recovery. This paper provided a comprehensive literature study about WAG injection. This paper has collected most of the requirements of the petroleum engineers that has to know about the WAG injection started from basic concepts until the design parameter for WAG injection
Dehydration Simulation of Natural Gas by using Tri Ethylene Glycol
Full text linkWater content in natural gas poses threat to process facilities such as column distillation. Natural gas from reservoirs usually contains water vapor, the presence of water vapor in gas processing causes bad impact to process facilities. Dry Gas composition data was taken from Salamander Energy. Optimization of natural gas dehydration using Tri Ethylene Glycol was carried out using Aspen HYSYS V8.6 with Peng-Robinson fluid package. The natural gas dehydrating plant was designed with operating conditions of 394 bar and 460C and 10 MMSCFD and 6.8 MMSCFD gas flow rate were inputted. Results obtained from HYSYS simulation shows. Three different TEG flowrates were used for this simulation. Results obtained from simulation that . For the purpose of running the plant economically, the minimum flow rate of TEG which will reduce the water content to within the limit of pipeline specification, is very important and the result obtained showed that a minimum of 3 m3/h of TEG is required to reduce the water content of a gas stream of 10MMSCFD to 6.8lb/MMSCFD, which is within the limit of 6-7lb/MMSCFD, this value when compare to gas plant which uses 15m3/h for the gas stream of 10MMSCFD to achieve the same water content specification is far lower. Values below this flow rate (3.5m3/h) may not reduce the water content to the specified limit
Spontaneous Imbibition Test of Low Salinity Injection at Low Saline Waxy Crude Carbonate
Full text linkLow salinity waterflooding (LSW) is categorized as one of emerging EOR technologies. It is done by injecting water with different salt composition and/or concentration. The research has been carried out for both sandstone and carbonate with the results looks promising. However, most of this research still concentrated in the north sea, middle east and North America region. This article discusses the applicability of low salinity waterflooding methodology in Indonesia. Spontaneous imbibition test is carried out to observe the recovery gain from a various combination of concentration and composition of the injected brine. The change of pH of the brine is also examined in order to confirm the pH effect mechanism. Three different concentration of brine (500 ppm, 5.000 ppm, and 10.000 ppm), three different brine composition (NaCl, CaCl2, and MgCl2) and high paraffinic crude oil are used as the fluid sample. It is found that the increased oil recovery is significant at a salinity of 10,000 ppm for MgCl2 and 5,000 ppm for NaCl ions. While the lowest recovery was shown by the test at a salinity of 500 pp
Analysis of Damage Rod String Components in Sucker Rod Pump in The Field SS
Full text linkField SS is a Heavy Oil field which means high viscosity oil making it difficult to flow. Therefore, artificial lift was used in this field to help lifting the high viscosity fluid, i.e. sucker rod pump (SRP). In the last several years, problem of the damage to the rod string was frequently occur. Rod string damage is usually indicated by the occurrence of broken or detached components. In order to overcome the damage of rod string components on the sucker rod pump, several parameters that causes rod string damage in 41 well samples in the field SS were analyzed and then recommendations were made as an alternative to minimize the occurrence of rod string damage. After analyzing the parameters that can cause rod string damage on 41 well samples in SS field, the cause of the breakdown of rod string is fluid pounding for 37 samples well, while the causes for 4 samples of other wells is not detected. After that, recommendation efforts is done, like size down pump speed and stroke length for 9 samples of wells, size down pump size and pump speed for 6 samples of wells and size down pump speed for 22 samples well. As for the undetected cause 4 samples of wells, is recommended to do proactive well service