In order to produce more oil in reservoir, one of the promising methods is Enhanced Oil Recovery (EOR). On the average, conventional production methods will produce only 30% of the Oil Initial In place (OIIP). The remaining 70% will be covered by EOR methods. WAG (Water Alternating Gas) has already exist to recover amount of hydrocarbon. Unfortunately, gas has several disadvantages which are less viscous, less density and causes poor sweep efficiency due to the high gas mobility. Foam is used to overcome the advantages of gas by reducing gas mobility, to increase sweep efficiency by reducing the fingering effect of gas and also foam can travel both high and low permeability region along the core sample. The identification of the foam flood location is an important aspect of monitoring the progression of foam. Resistivity is chosen to monitor foam propagation because it has higher sensitivity, suitable for higher concentration, it has no limitation of gas volume fraction, no need high energy. This experiment will focus to study on resistivity measurement, foam and monitoring foam flood. Objectives of this experiment are to determine the relationship between foam injection time, distance of foam propagation, velocity of foam using resistivity wave. To measure the effect of foam and brine concentration changed against resistivity in the presence of oil. To measure foam propagation can displace brine by the changes in saturation as time progresses in various distance. Resistivity measure at several zones to monitoring foam propagation through a core sample. Core sample will be characterized to identify dimensional of the core plug, porosity and permeability of the core plug. The liquids, such as brine, surfactant, nitrogen gas will be characterized to obtain the value of density, viscosity, salinity of brine for each materials. All those properties will influence the resistivity readings of foam propagation. All liquids will be injected into the core sample as time progresses and it will be measured by multimeter to obtain the resistivity readings. By using Archie’s equation, the brine saturation in each zone of the core sample can be calculated and plotted against injection time. From the experiment, it will be concluded that resistivity increases only in zone 1 approximately at 125 minutes from 280 ohm.m to reach the stable stage at 1100 ohm.m and foam disintegration in zone. Decreasing water saturation in zone 1 approximately at 125 minutes, zone 2 approximately at 141 minutes, zone 3 approximately at 150 minutes. Velocity of the foam propagation approximately 0,01 cm/s and the flow rate of foam propagation was 0,11 cm3/s.
In Field A, recently drilled wells D6, D7 and D8 penetrated at reservoir of good quality sands. However, the production rate declined rapidly within a year after wells kicked off. In an effort to restore new wells productivity, solid propellant technology stimulation and dynamic underbalance stimulation were evaluated for their effectiveness in permeability improvement. The candidates for solid propellant technology and dynamic underbalance stimulation were selected based on a screening workflow. Pressure data was retrieved from pressure downhole gauge to confirm skin buildup post production. The sources of production impairment were then investigated from laboratory analysis of core sample. While waiting for the results of laboratory analysis, solid propellant technology and dynamic underbalance stimulation were applied as quick solutions due relatively cheaper cost than chemical stimulation. Solid propellant technology was chosen for Well D8 whereas dynamic underbalance stimulation was selected for Well D6 and D7. Post solid propellant technology at Well D8, tubing head pressure and production rate slightly increased and sustained. On the other hand, dynamic underbalance stimulation at Well D6 and D7 showed positive results as tubing head pressure and production rates were improved. Unfortunately, production gain from dynamic underbalance at Well D7 only lived for a month before seizing to flow. The implementation of solid propellant technology and dynamic underbalance stimulation were successful to improve production performance for a short period of time. Both stimulation strategies were deemed to be repeated and improved to bypass near wellbore damage for these wells. This paper presents on the challenges and lessons learned that will be applicable to oilfields which are having similar situation to improve well productivity via mechanical stimulation.
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