EAI International Conference on Renewable Energy and Sustainable Manufacturing, 2024
Plan of Development (POD) is an essential component of the long-term strategy aimed at ensuring t... more Plan of Development (POD) is an essential component of the long-term strategy aimed at ensuring the efficient operation of a hydrocarbon field. This is primarily because hydrocarbon production must meet the targets set in POD while management often desires to extract even more from the field. Therefore, the withdrawal strategy needs to be improved in order to enhance cumulative production and recovery factors. This led to the mapping of characteristics as well as the screening of the location of infill wells to determine the most functional areas in this research. The characteristic potential mapping was developed by combining saturation, pressure, and permeability. Meanwhile, appropriate locations were required to be selected to efficiently drain oil from the reservoir and this was achieved by designing the sector model to represent the real circumstances in the full-field of a particular region. Several scenarios were applied based on history to determine the best forecast for incremental production of hydrocarbon. Furthermore, a model was developed for both gas and oil fields and the simulation conducted showed its ability to determine the performance of the fields under several specific scenarios. The results showed that the optimum incremental production of gas was recorded in scenario 4 to be 353.2 MSCF at a recovery factor of 49.23% followed by scenario 5 with 353.2 MSCF and 49.22% respectively. Furthermore, the optimum increment production of oil was found in scenario 2b for infill drilling (production) to be 2.14 MMSTB at a recovery factor of 22.63% while the injection location was scenario 2bii as showed by 3.01 MMSTB and 25.64% respectively. It was also discovered that characteristic potential mapping was able to determine the optimum hydrocarbon cumulative and highest recovery factors in both reservoirs.
Coal is the most abundant fossil fuel on earth, and it is an exceedingly carbonaceous substance. ... more Coal is the most abundant fossil fuel on earth, and it is an exceedingly carbonaceous substance. However, fossil fuels are a non-renewable energy source, and then efforts are needed to reduce the use of coal. Nowadays, researchers conduct studies of coal additives to increase the calorific value of coal and improve combustion efficiency. Coal additives have a function to improve the calorific value of coal and improve combustion efficiency. Some pulverized coal samples were prepared based on ASTM D2013/D2013M-18, then mixed with coal additives until homogeneous. The lab instruments are the bomb calorimeter and the proximate analysis. This study utilizes the phenomenon of parameters such as; the calorific value of coal, Sulfur content, ash content, and fixed carbon. The purpose of this study is to seek the optimum ability of coal additives of escalating the calorific value of coal and improve combustion efficiency.
The Alkali-Surfactant-Polymer (ASP) flooding is one technique of Enhanced Oil Recovery (EOR). The... more The Alkali-Surfactant-Polymer (ASP) flooding is one technique of Enhanced Oil Recovery (EOR). The ASP injection mechanism reduces the interfacial tension (IFT) between fluids as well as fluids and the rock surface. Further, ASP modifies the wettability of the rocks toward water-wet environment. Hence the oil phase can be transferred to the producer. In practice, one of ASP problems in the reservoir rock is the adsorption process of ions on the rock surface. High adsorption decreases the performance of the ASP treatment includes more minor IFT reduction and less wettability alteration. As an Alkali, Sodium Carbonate (Na2CO3) is very effective in reducing surfactant adsorption. However, this type of Alkali consumes a huge of raw material. 105g Sodium Carbonate provides 1 mole of alkalinity. The addition of Ammonium Hydroxide (NH4OH) in ASP sodium carbonate scheme is considered improve the efficiency. Ammonium Hydroxide (NH4OH) provides alkalinity of 1 mole from only 17g of raw material. The synergy of two alkalis can supply bigger alkalinity from the standard ASP technique with the inherent logistical advantages as well. This concept has known as a hybrid-alkali concept. The model has an inverted five spot pattern injection system, two layers of a sandstone formation, and is bordered by shale.
The existing problem in the natural gas plant is a large amount of water vapor in the pipeline. T... more The existing problem in the natural gas plant is a large amount of water vapor in the pipeline. The water content in the natural gas component reaches 0.3192 weight fraction from the well. The chemical separation in the separator still has a 0.0019-mole fraction of water, and water content is up to 19.54 lbs/mmscf. The permissible water vapor content in the gas plant is less than 15 lbs/mmscf, which is under pipe specifications. Therefore, it is necessary to carry out a gas dehydration process to reduce the water vapor content of natural gas by the absorption method using triethylene glycol (TEG) absorbents. The research was conducted to determine the impact of temperature, pressure, and purity of lean TEG in reducing water content in the contactor using a commercial simulator. Based on the data obtained at lean TEG 100 is up to 10.03 lbs/mmscf. The sensitivity simulation shows that the lean TEG 90℉ temperature has the lowest water content of 1.012 lbs/mmscf. Meanwhile, with a pressure of 875 psi, the total water content is 1.170 lbs/mmscf. Finally, 99% TEG, a water content of 0.314 lbs/mmscf, is obtained.
The problem emerging in the natural gas plant is carbon dioxide content in the pipeline. Wellhead... more The problem emerging in the natural gas plant is carbon dioxide content in the pipeline. Wellhead natural gas can contain as much as 30% carbon dioxide. Meanwhile, the minimum specification required includes no more than 2%-3% carbon dioxide. The separation of CO2 from biogas is indispensable to improve so that its quality can be improved. One of the separation methods is adsorption. The adsorption process was varied at the pressure
Waterflood introduces in the oil field a couple of years ago. Several waterflood schemes have bee... more Waterflood introduces in the oil field a couple of years ago. Several waterflood schemes have been implemented in the fields to get the best incremental oil, such as peripheral injection, pattern waterflood, and etcetera. Many waterflood schemes are not working properly to boost the oil recovery due to unpredicted and unexpected water tide array. Then, the tracer practice started to be used for getting a better picture of the transmissibility reservoir as well as the direction of water pathway. This practice honors the parameters, such pressure, water cut, GOR, and rates. The streamline modeling is used to map the tracer, and it concludes that the selection of location of the injector should be based on the highest oil recovery achieved. Subsequently, the cyclic water injection method is one alternative. Apparently, this approach yields a quantify incremental recovery. This research utilizes the pressure different approach to figure out the route of water in the formation. The inter-well tracer technique in this modeling study is a tool to review communication between injectors and producers in the existing pattern. Many scenario should be tried to find the best options for the new pattern opportunities. In parallel, a innovative scheme of waterflood technique should be implemented too for escalating oil recovery. The stream pathway observes a new potential of the waterflood scheme. It is called "cyclic injection" scheme. The novelty of this approach is the ability to solve the poor sweep efficiency due to improper pathway of water influx in the oil bearing".
Excessive water production is one of the biggest problems commonly found in the brown water-flood... more Excessive water production is one of the biggest problems commonly found in the brown water-flood field. There are two treatments of water shut-off (WSO) in hydrocarbon wells. The mechanical WSO is a routine operation that is commonly carried out and is part of standard well work; meanwhile, the chemical WSO is a specific treatment. The study aims to identify the effect of polymer concentration, injection rate, and soaking time on the effectiveness of chemical WSO with cross-linked polymers in a specific field. The study proposes and analyses the optimization of this treatment in the 7E Sandstone field by utilizing a conceptual simulation model. Geographically, this field is located in the Central Sumatera basin. The field is a moderately homogenous sandstone. Last decade, the 7E field was associated with excessive water production issue, some mechanical WSO has been done to solve the problem, but less effective and inefficient. Hence chemical WSO job comes as a promising option to overcome this problem robustly. The cross-link polymer injection treatment is the action of blocking water from entering and reaching production wells by using a mixture of polymer, cross-linker, and water. A base case of the conceptual model has been developed, then over twenty injection scenarios wide-ranging based on polymer concentrations are implemented in the model. Each of these concentration schemes is simulated using different injection flow rates for the total injection volume of 2000 bbl. The injection rate sets at 1000 bbl/day for twice injection and 2000 bbl/day for one injection. Soaking time is settled for one, two, and three days to give time for generating gelatin. A comparison of water production before and after the WSO is used to investigate WSO effectivity. The simulation result mentions that the WSO implementation can decrease excess water from 385,143 bbl to 186,189 bbl.
The study aims to understand the effects of interfacial tension (IFT) and velocity dependent rela... more The study aims to understand the effects of interfacial tension (IFT) and velocity dependent relative permeability (VDRP) to gas production, especially once the wellbore pressure is below the dew point under dynamic conditions beyond the conventional steady-state assumptions. The main impact of this occurrence is liquid loading in the wellbore that may block the gas influx. The interfacial tension (IFT) and velocity dependent relative permeability (VDRP) alteration along with the liquid filling will affect gas production process. A realistic conceptual simulation model is developed by activating the IFT and VDRP options in the base case. The analysis enables us to outline how critical the effects of both parameters to liquid production. Firstly, the liquid drop-out from gas phase, then accumulation, while still immobile until they establish a condensate banking and block a part of the wellbore region so that the gas cannot flow up to the surface, resulting in impairment in well deliverability. This study uses three parameters of IFT, for instance, IFT 1, IFT 5, and IFT 10 as well as activates the VDRP option for another parameter in the scenarios. The scenario IFT 1 shows that liquid production increases up to 0.205%, scenario IFT 5 increases up to 0.371%, and scenario IFT 10 increases up to 0.422%. Meanwhile, the VDRP option exhibits that liquid production increase by up to 57.40%. The analysis indicates that liquid production significantly escalates while the IFT is getting higher, and VDRP options display the liquid loading even more due to the effects of IFT. The novelty of this study is the ability to analyze the dynamic condition of fluid behavior in the wellbore compared to the steady-state condition that has been investigated by several authors in the literature.
The recovery factor in volcaniclastic reservoir depends on matrix permeability, wettability, frac... more The recovery factor in volcaniclastic reservoir depends on matrix permeability, wettability, fracture intensity and fluid properties. In some situations, imbibition of water can be promoted by chemical stimulation to alter the reservoir wettability toward water-wetness such that oil is expelled at an economic rate from rock matrix into pores. Surfactant stimulation technique has recently been seen a new revival to low oil prices environment. Surfactant stimulation has switched the favorable condition that drove the chemical utilization is becoming economical viable in addition to environmental friendly. Understanding of past failures as well as advancements in chemical technologies contribute much for this revitalization of wellbore treatment. The wettability alterations by the surfactants have been characterized using contact angles and oil-water relative permeability. The shifts in relative permeability curves indicate the ability of surfactants to develop mixed-wettability in pores from strongly oil-wet. Adsorption in surfactant treatment process depends on the clays content in the rock formation including montmorillonite, chlorite as well as kaolinite, instead of entrapped in the rock surface. It means the chemical composition of rock is a critical parameter to succeed the stimulation. The volcaniclastic formation consists of andesitic lavas at the base and dacite basaltic lavas interbedded with clays, sandstones, conglomerates and felsic tuffs in the upper parts. Beds of agglomerate and volcanic breccia with intergranular porosity contain fragments of acidic and mafic composition, meanwhile Ferromagnesion minerals mostly subjected to chloritisation and oxidation. In this paper, we propose the huff and puff techniques to stimulate the wellbore by utilizing nonionic surfactant (SC212) with water base condition as fluid carrier to generate a green environment condition which are safety and economic as well as an intentional electrolytes environment. Besides that this paper also promote an essential workflow to conduct a success surfactant treatment, and also boost up several success stories of the surfactant stimulation in the “X-field” with volcaniclastic formation as a case studies. A workflow to assess the balance of viscous, capillary, surface and gravity forces involved in improving oil recovery process is proposed to pre-screen the type of surfactant needed to modify the adhesive force balance between oil and rock.
EAI International Conference on Renewable Energy and Sustainable Manufacturing, 2024
Plan of Development (POD) is an essential component of the long-term strategy aimed at ensuring t... more Plan of Development (POD) is an essential component of the long-term strategy aimed at ensuring the efficient operation of a hydrocarbon field. This is primarily because hydrocarbon production must meet the targets set in POD while management often desires to extract even more from the field. Therefore, the withdrawal strategy needs to be improved in order to enhance cumulative production and recovery factors. This led to the mapping of characteristics as well as the screening of the location of infill wells to determine the most functional areas in this research. The characteristic potential mapping was developed by combining saturation, pressure, and permeability. Meanwhile, appropriate locations were required to be selected to efficiently drain oil from the reservoir and this was achieved by designing the sector model to represent the real circumstances in the full-field of a particular region. Several scenarios were applied based on history to determine the best forecast for incremental production of hydrocarbon. Furthermore, a model was developed for both gas and oil fields and the simulation conducted showed its ability to determine the performance of the fields under several specific scenarios. The results showed that the optimum incremental production of gas was recorded in scenario 4 to be 353.2 MSCF at a recovery factor of 49.23% followed by scenario 5 with 353.2 MSCF and 49.22% respectively. Furthermore, the optimum increment production of oil was found in scenario 2b for infill drilling (production) to be 2.14 MMSTB at a recovery factor of 22.63% while the injection location was scenario 2bii as showed by 3.01 MMSTB and 25.64% respectively. It was also discovered that characteristic potential mapping was able to determine the optimum hydrocarbon cumulative and highest recovery factors in both reservoirs.
Coal is the most abundant fossil fuel on earth, and it is an exceedingly carbonaceous substance. ... more Coal is the most abundant fossil fuel on earth, and it is an exceedingly carbonaceous substance. However, fossil fuels are a non-renewable energy source, and then efforts are needed to reduce the use of coal. Nowadays, researchers conduct studies of coal additives to increase the calorific value of coal and improve combustion efficiency. Coal additives have a function to improve the calorific value of coal and improve combustion efficiency. Some pulverized coal samples were prepared based on ASTM D2013/D2013M-18, then mixed with coal additives until homogeneous. The lab instruments are the bomb calorimeter and the proximate analysis. This study utilizes the phenomenon of parameters such as; the calorific value of coal, Sulfur content, ash content, and fixed carbon. The purpose of this study is to seek the optimum ability of coal additives of escalating the calorific value of coal and improve combustion efficiency.
The Alkali-Surfactant-Polymer (ASP) flooding is one technique of Enhanced Oil Recovery (EOR). The... more The Alkali-Surfactant-Polymer (ASP) flooding is one technique of Enhanced Oil Recovery (EOR). The ASP injection mechanism reduces the interfacial tension (IFT) between fluids as well as fluids and the rock surface. Further, ASP modifies the wettability of the rocks toward water-wet environment. Hence the oil phase can be transferred to the producer. In practice, one of ASP problems in the reservoir rock is the adsorption process of ions on the rock surface. High adsorption decreases the performance of the ASP treatment includes more minor IFT reduction and less wettability alteration. As an Alkali, Sodium Carbonate (Na2CO3) is very effective in reducing surfactant adsorption. However, this type of Alkali consumes a huge of raw material. 105g Sodium Carbonate provides 1 mole of alkalinity. The addition of Ammonium Hydroxide (NH4OH) in ASP sodium carbonate scheme is considered improve the efficiency. Ammonium Hydroxide (NH4OH) provides alkalinity of 1 mole from only 17g of raw material. The synergy of two alkalis can supply bigger alkalinity from the standard ASP technique with the inherent logistical advantages as well. This concept has known as a hybrid-alkali concept. The model has an inverted five spot pattern injection system, two layers of a sandstone formation, and is bordered by shale.
The existing problem in the natural gas plant is a large amount of water vapor in the pipeline. T... more The existing problem in the natural gas plant is a large amount of water vapor in the pipeline. The water content in the natural gas component reaches 0.3192 weight fraction from the well. The chemical separation in the separator still has a 0.0019-mole fraction of water, and water content is up to 19.54 lbs/mmscf. The permissible water vapor content in the gas plant is less than 15 lbs/mmscf, which is under pipe specifications. Therefore, it is necessary to carry out a gas dehydration process to reduce the water vapor content of natural gas by the absorption method using triethylene glycol (TEG) absorbents. The research was conducted to determine the impact of temperature, pressure, and purity of lean TEG in reducing water content in the contactor using a commercial simulator. Based on the data obtained at lean TEG 100 is up to 10.03 lbs/mmscf. The sensitivity simulation shows that the lean TEG 90℉ temperature has the lowest water content of 1.012 lbs/mmscf. Meanwhile, with a pressure of 875 psi, the total water content is 1.170 lbs/mmscf. Finally, 99% TEG, a water content of 0.314 lbs/mmscf, is obtained.
The problem emerging in the natural gas plant is carbon dioxide content in the pipeline. Wellhead... more The problem emerging in the natural gas plant is carbon dioxide content in the pipeline. Wellhead natural gas can contain as much as 30% carbon dioxide. Meanwhile, the minimum specification required includes no more than 2%-3% carbon dioxide. The separation of CO2 from biogas is indispensable to improve so that its quality can be improved. One of the separation methods is adsorption. The adsorption process was varied at the pressure
Waterflood introduces in the oil field a couple of years ago. Several waterflood schemes have bee... more Waterflood introduces in the oil field a couple of years ago. Several waterflood schemes have been implemented in the fields to get the best incremental oil, such as peripheral injection, pattern waterflood, and etcetera. Many waterflood schemes are not working properly to boost the oil recovery due to unpredicted and unexpected water tide array. Then, the tracer practice started to be used for getting a better picture of the transmissibility reservoir as well as the direction of water pathway. This practice honors the parameters, such pressure, water cut, GOR, and rates. The streamline modeling is used to map the tracer, and it concludes that the selection of location of the injector should be based on the highest oil recovery achieved. Subsequently, the cyclic water injection method is one alternative. Apparently, this approach yields a quantify incremental recovery. This research utilizes the pressure different approach to figure out the route of water in the formation. The inter-well tracer technique in this modeling study is a tool to review communication between injectors and producers in the existing pattern. Many scenario should be tried to find the best options for the new pattern opportunities. In parallel, a innovative scheme of waterflood technique should be implemented too for escalating oil recovery. The stream pathway observes a new potential of the waterflood scheme. It is called "cyclic injection" scheme. The novelty of this approach is the ability to solve the poor sweep efficiency due to improper pathway of water influx in the oil bearing".
Excessive water production is one of the biggest problems commonly found in the brown water-flood... more Excessive water production is one of the biggest problems commonly found in the brown water-flood field. There are two treatments of water shut-off (WSO) in hydrocarbon wells. The mechanical WSO is a routine operation that is commonly carried out and is part of standard well work; meanwhile, the chemical WSO is a specific treatment. The study aims to identify the effect of polymer concentration, injection rate, and soaking time on the effectiveness of chemical WSO with cross-linked polymers in a specific field. The study proposes and analyses the optimization of this treatment in the 7E Sandstone field by utilizing a conceptual simulation model. Geographically, this field is located in the Central Sumatera basin. The field is a moderately homogenous sandstone. Last decade, the 7E field was associated with excessive water production issue, some mechanical WSO has been done to solve the problem, but less effective and inefficient. Hence chemical WSO job comes as a promising option to overcome this problem robustly. The cross-link polymer injection treatment is the action of blocking water from entering and reaching production wells by using a mixture of polymer, cross-linker, and water. A base case of the conceptual model has been developed, then over twenty injection scenarios wide-ranging based on polymer concentrations are implemented in the model. Each of these concentration schemes is simulated using different injection flow rates for the total injection volume of 2000 bbl. The injection rate sets at 1000 bbl/day for twice injection and 2000 bbl/day for one injection. Soaking time is settled for one, two, and three days to give time for generating gelatin. A comparison of water production before and after the WSO is used to investigate WSO effectivity. The simulation result mentions that the WSO implementation can decrease excess water from 385,143 bbl to 186,189 bbl.
The study aims to understand the effects of interfacial tension (IFT) and velocity dependent rela... more The study aims to understand the effects of interfacial tension (IFT) and velocity dependent relative permeability (VDRP) to gas production, especially once the wellbore pressure is below the dew point under dynamic conditions beyond the conventional steady-state assumptions. The main impact of this occurrence is liquid loading in the wellbore that may block the gas influx. The interfacial tension (IFT) and velocity dependent relative permeability (VDRP) alteration along with the liquid filling will affect gas production process. A realistic conceptual simulation model is developed by activating the IFT and VDRP options in the base case. The analysis enables us to outline how critical the effects of both parameters to liquid production. Firstly, the liquid drop-out from gas phase, then accumulation, while still immobile until they establish a condensate banking and block a part of the wellbore region so that the gas cannot flow up to the surface, resulting in impairment in well deliverability. This study uses three parameters of IFT, for instance, IFT 1, IFT 5, and IFT 10 as well as activates the VDRP option for another parameter in the scenarios. The scenario IFT 1 shows that liquid production increases up to 0.205%, scenario IFT 5 increases up to 0.371%, and scenario IFT 10 increases up to 0.422%. Meanwhile, the VDRP option exhibits that liquid production increase by up to 57.40%. The analysis indicates that liquid production significantly escalates while the IFT is getting higher, and VDRP options display the liquid loading even more due to the effects of IFT. The novelty of this study is the ability to analyze the dynamic condition of fluid behavior in the wellbore compared to the steady-state condition that has been investigated by several authors in the literature.
The recovery factor in volcaniclastic reservoir depends on matrix permeability, wettability, frac... more The recovery factor in volcaniclastic reservoir depends on matrix permeability, wettability, fracture intensity and fluid properties. In some situations, imbibition of water can be promoted by chemical stimulation to alter the reservoir wettability toward water-wetness such that oil is expelled at an economic rate from rock matrix into pores. Surfactant stimulation technique has recently been seen a new revival to low oil prices environment. Surfactant stimulation has switched the favorable condition that drove the chemical utilization is becoming economical viable in addition to environmental friendly. Understanding of past failures as well as advancements in chemical technologies contribute much for this revitalization of wellbore treatment. The wettability alterations by the surfactants have been characterized using contact angles and oil-water relative permeability. The shifts in relative permeability curves indicate the ability of surfactants to develop mixed-wettability in pores from strongly oil-wet. Adsorption in surfactant treatment process depends on the clays content in the rock formation including montmorillonite, chlorite as well as kaolinite, instead of entrapped in the rock surface. It means the chemical composition of rock is a critical parameter to succeed the stimulation. The volcaniclastic formation consists of andesitic lavas at the base and dacite basaltic lavas interbedded with clays, sandstones, conglomerates and felsic tuffs in the upper parts. Beds of agglomerate and volcanic breccia with intergranular porosity contain fragments of acidic and mafic composition, meanwhile Ferromagnesion minerals mostly subjected to chloritisation and oxidation. In this paper, we propose the huff and puff techniques to stimulate the wellbore by utilizing nonionic surfactant (SC212) with water base condition as fluid carrier to generate a green environment condition which are safety and economic as well as an intentional electrolytes environment. Besides that this paper also promote an essential workflow to conduct a success surfactant treatment, and also boost up several success stories of the surfactant stimulation in the “X-field” with volcaniclastic formation as a case studies. A workflow to assess the balance of viscous, capillary, surface and gravity forces involved in improving oil recovery process is proposed to pre-screen the type of surfactant needed to modify the adhesive force balance between oil and rock.
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Papers by DIKE Putra
Surfactant stimulation technique has recently been seen a new revival to low oil prices environment. Surfactant stimulation has switched the favorable condition that drove the chemical utilization is becoming economical viable in addition to environmental friendly. Understanding of past failures as well as advancements in chemical technologies contribute much for this revitalization of wellbore treatment. The wettability alterations by the surfactants have been characterized using contact angles and oil-water relative permeability. The shifts in relative permeability curves indicate the ability of surfactants to develop mixed-wettability in pores from strongly oil-wet.
Adsorption in surfactant treatment process depends on the clays content in the rock formation including montmorillonite, chlorite as well as kaolinite, instead of entrapped in the rock surface. It means the chemical composition of rock is a critical parameter to succeed the stimulation.
The volcaniclastic formation consists of andesitic lavas at the base and dacite basaltic lavas interbedded with clays, sandstones, conglomerates and felsic tuffs in the upper parts. Beds of agglomerate and volcanic breccia with intergranular porosity contain fragments of acidic and mafic composition, meanwhile Ferromagnesion minerals mostly subjected to chloritisation and oxidation.
In this paper, we propose the huff and puff techniques to stimulate the wellbore by utilizing nonionic surfactant (SC212) with water base condition as fluid carrier to generate a green environment condition which are safety and economic as well as an intentional electrolytes environment. Besides that this paper also promote an essential workflow to conduct a success surfactant treatment, and also boost up several success stories of the surfactant stimulation in the “X-field” with volcaniclastic formation as a case studies.
A workflow to assess the balance of viscous, capillary, surface and gravity forces involved in improving oil recovery process is proposed to pre-screen the type of surfactant needed to modify the adhesive force balance between oil and rock.
Surfactant stimulation technique has recently been seen a new revival to low oil prices environment. Surfactant stimulation has switched the favorable condition that drove the chemical utilization is becoming economical viable in addition to environmental friendly. Understanding of past failures as well as advancements in chemical technologies contribute much for this revitalization of wellbore treatment. The wettability alterations by the surfactants have been characterized using contact angles and oil-water relative permeability. The shifts in relative permeability curves indicate the ability of surfactants to develop mixed-wettability in pores from strongly oil-wet.
Adsorption in surfactant treatment process depends on the clays content in the rock formation including montmorillonite, chlorite as well as kaolinite, instead of entrapped in the rock surface. It means the chemical composition of rock is a critical parameter to succeed the stimulation.
The volcaniclastic formation consists of andesitic lavas at the base and dacite basaltic lavas interbedded with clays, sandstones, conglomerates and felsic tuffs in the upper parts. Beds of agglomerate and volcanic breccia with intergranular porosity contain fragments of acidic and mafic composition, meanwhile Ferromagnesion minerals mostly subjected to chloritisation and oxidation.
In this paper, we propose the huff and puff techniques to stimulate the wellbore by utilizing nonionic surfactant (SC212) with water base condition as fluid carrier to generate a green environment condition which are safety and economic as well as an intentional electrolytes environment. Besides that this paper also promote an essential workflow to conduct a success surfactant treatment, and also boost up several success stories of the surfactant stimulation in the “X-field” with volcaniclastic formation as a case studies.
A workflow to assess the balance of viscous, capillary, surface and gravity forces involved in improving oil recovery process is proposed to pre-screen the type of surfactant needed to modify the adhesive force balance between oil and rock.