The production of oil in offshore wells has used artificial lifting methods in order to maintain or increase production. In this sense, several established methods for onshore production, such as electrical submersible pumping (ESP), have been implemented in offshore scenarios and, as a consequence, new challenges and needing improvements to optimize production in this type of environment had to be faced. Many studies concern the gas-liquid flow inside de pump but avoid include the motor and its thermal management. In this context, this study focused to assess the complex flow around an ESP motor installed in subsea skids on the seabed (Skid-ESP) through the analysis of their operational and geometric conditions using a computational fluid dynamics (CFD) tool. The main question is: is it possible to create a thermal operational map of the motor in function of motor frequency with CFD tools? The Volume-of-Fluid (VOF) model was applied together with a homogeneous heat transfer (shared temperature field among phases) coupled to the heat conduction inside motor. This approach is known as Conjugate Heat Transfer (CHT). The ESP motor is modeled as a homogeneous and isotropic body with constant volumetric heat generation. The flow analysis was performed applying the model on an industrial scale with incompressible oil and gas in in-situ conditions and considering the heat transfer between the fluid mixture and the its boundary conditions (seawater constant temperature of 4°C and variable motor heat flux as function of motor frequency). The motor frequency range considered was between 40 and 60 Hz. Since the model used was 3D, hot spots were observed at the low part of near seal motor side for gas volume fraction above 3.5%. The employed methodology was able to determine the thermal operational map with a 5% average deviation from field data.
{"title":"Thermal Operational Map of an ESP-In-Skid Motor: A CFD Approach","authors":"Ribeiro Dc","doi":"10.23880/ppej-16000305","DOIUrl":"https://doi.org/10.23880/ppej-16000305","url":null,"abstract":"The production of oil in offshore wells has used artificial lifting methods in order to maintain or increase production. In this sense, several established methods for onshore production, such as electrical submersible pumping (ESP), have been implemented in offshore scenarios and, as a consequence, new challenges and needing improvements to optimize production in this type of environment had to be faced. Many studies concern the gas-liquid flow inside de pump but avoid include the motor and its thermal management. In this context, this study focused to assess the complex flow around an ESP motor installed in subsea skids on the seabed (Skid-ESP) through the analysis of their operational and geometric conditions using a computational fluid dynamics (CFD) tool. The main question is: is it possible to create a thermal operational map of the motor in function of motor frequency with CFD tools? The Volume-of-Fluid (VOF) model was applied together with a homogeneous heat transfer (shared temperature field among phases) coupled to the heat conduction inside motor. This approach is known as Conjugate Heat Transfer (CHT). The ESP motor is modeled as a homogeneous and isotropic body with constant volumetric heat generation. The flow analysis was performed applying the model on an industrial scale with incompressible oil and gas in in-situ conditions and considering the heat transfer between the fluid mixture and the its boundary conditions (seawater constant temperature of 4°C and variable motor heat flux as function of motor frequency). The motor frequency range considered was between 40 and 60 Hz. Since the model used was 3D, hot spots were observed at the low part of near seal motor side for gas volume fraction above 3.5%. The employed methodology was able to determine the thermal operational map with a 5% average deviation from field data.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-07-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124716273","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Mechanistic kinetic models were developed for the catalytic alkylation of toluene with methanol over H-ZSM–5 coated silicon carbide (SiC) foam catalyst at atmospheric pressure in the temperature range of 623–723 K, molar methanol to toluene ratio of 2:1 and at different catalyst weight to the toluene molar flow rate in the range 0.72–5.5 kg catalyst h/kg mol toluene in a stainless-steel flow reactor fabricated to house the ceramic foam blocks coated with catalyst. The kinetic models developed for the transformation were Langmuir-Hinshelwood-Hougen-Watson (LHHW) rate expressions based on a reaction mechanism, which involved the adsorption of reactants species on the active catalyst sites, surface reaction of the adsorbed species to produce products and desorption of products from the catalyst surface, assuming same kind of active sites on the catalyst. The optimization routine of Nelder-Mead simplex method was used to estimate the inherent kinetic parameters in the proposed models. The selection of the best kinetic model amongst the rival kinetic models was based on physicochemical and thermodynamic tests and statistical analysis was employed to further validate the best model. The rate-determining step for the alkylation of toluene with methanol over H-ZSM-5 coated silicon carbide foam catalyst was found to be the surface reaction between adsorbed toluene and adsorbed methanol. Excellent agreement was obtained between the experimental rate of reaction and conversion of toluene and the model predictions, with absolute relative residuals being at most 3.8% for conversion and 3.9% for rate of reaction. The activation energies and enthalpies of adsorption were predicted, as well as, their corresponding pre-exponential factors. The results of this study can be used for sizing the alkylation reactor for xylene production and optimization studies.
{"title":"Mechanistic Kinetic Models for Catalytic Alkylation of Toluene with Methanol for Xylene Production","authors":"Olafadehan Oa","doi":"10.23880/ppej-16000307","DOIUrl":"https://doi.org/10.23880/ppej-16000307","url":null,"abstract":"Mechanistic kinetic models were developed for the catalytic alkylation of toluene with methanol over H-ZSM–5 coated silicon carbide (SiC) foam catalyst at atmospheric pressure in the temperature range of 623–723 K, molar methanol to toluene ratio of 2:1 and at different catalyst weight to the toluene molar flow rate in the range 0.72–5.5 kg catalyst h/kg mol toluene in a stainless-steel flow reactor fabricated to house the ceramic foam blocks coated with catalyst. The kinetic models developed for the transformation were Langmuir-Hinshelwood-Hougen-Watson (LHHW) rate expressions based on a reaction mechanism, which involved the adsorption of reactants species on the active catalyst sites, surface reaction of the adsorbed species to produce products and desorption of products from the catalyst surface, assuming same kind of active sites on the catalyst. The optimization routine of Nelder-Mead simplex method was used to estimate the inherent kinetic parameters in the proposed models. The selection of the best kinetic model amongst the rival kinetic models was based on physicochemical and thermodynamic tests and statistical analysis was employed to further validate the best model. The rate-determining step for the alkylation of toluene with methanol over H-ZSM-5 coated silicon carbide foam catalyst was found to be the surface reaction between adsorbed toluene and adsorbed methanol. Excellent agreement was obtained between the experimental rate of reaction and conversion of toluene and the model predictions, with absolute relative residuals being at most 3.8% for conversion and 3.9% for rate of reaction. The activation energies and enthalpies of adsorption were predicted, as well as, their corresponding pre-exponential factors. The results of this study can be used for sizing the alkylation reactor for xylene production and optimization studies.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-07-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116953297","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Hydraulic fracturing has become a critical component of global petroleum and natural gas development, with most the countries around the globe, for example, Canada, India, England, and China actively pursuing the implementation of this technology to increase oil production after declination as well as tap into this new source of energy. Hydraulic fracturing has created jobs and increased revenue in several states across the country. However, as with any advanced technology, there are concerns about its long-term environmental impact. Thus, many researchers and technicians continuously conduct advanced studies to inform industries about any new or upcoming regulations. In this study, a mini-review of the fracking process is considered an important section of the petroleum and natural gas industries. Moreover, researchers demonstrated knowledge about the frac systems and different hydraulic fracturing fluids that are utilized for a fracking job which were different from one fracking system to another in addition to the nature of the reservoir formation. It is a significant factor that production engineers take into consideration when applying hydraulic fracturing to enhance oil or gas production and treat the formation damage, as well. Since the formation damage considers the most critical issue affecting oil and gas production due to fine migration.
{"title":"Hydraulic Fracturing Process Systems and Fluids: An Overview","authors":"Yehia F","doi":"10.23880/ppej-16000306","DOIUrl":"https://doi.org/10.23880/ppej-16000306","url":null,"abstract":"Hydraulic fracturing has become a critical component of global petroleum and natural gas development, with most the countries around the globe, for example, Canada, India, England, and China actively pursuing the implementation of this technology to increase oil production after declination as well as tap into this new source of energy. Hydraulic fracturing has created jobs and increased revenue in several states across the country. However, as with any advanced technology, there are concerns about its long-term environmental impact. Thus, many researchers and technicians continuously conduct advanced studies to inform industries about any new or upcoming regulations. In this study, a mini-review of the fracking process is considered an important section of the petroleum and natural gas industries. Moreover, researchers demonstrated knowledge about the frac systems and different hydraulic fracturing fluids that are utilized for a fracking job which were different from one fracking system to another in addition to the nature of the reservoir formation. It is a significant factor that production engineers take into consideration when applying hydraulic fracturing to enhance oil or gas production and treat the formation damage, as well. Since the formation damage considers the most critical issue affecting oil and gas production due to fine migration.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-07-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129259373","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Alongside the process of blending naphtha, fuel anhydrous ethyl alcohol is an additive recurrently used to adjust commercial properties such as the octane index of gasolines during its formulation. This additive is environmentally recommended due to the promotion of decarbonization in gasolines that is evidenced in its consumption with the reduction of CO2 emissions into the atmosphere, compared to the consumption of other gasolines. There are several ways to obtain the respective additive, the research leads to obtaining it from the Angolan grass (Brachiaria purpurascens "Forsk" Stapf). Angola grass has a low fiber and protein content, thus becoming with low preference in the choice for animal feed and has a significant content of nonnitrogen extractives giving it a high energy potential to be raw material for biofuel production Through an experimental study and on a laboratory scale, alcohol was produced, then the quantities of the two components of the mixture were determined using additive calculations, and then mixed in samples of Straight run (SR) gasolines direct distillation produced in Luanda Refinery. Next, octane index tests were performed in the final mixture by the RON method following ASTM D22699 and adulteration potencies were verified in the samples. The octane index defined to be reached was 95 octane and it was proven that alcohol produced from Angola grass has the potential to promote improvements in octane index, as we found increases in the octane index of additive gasoline shows. We recorded an improvement of the rate of 91% for sample 1 namely the mixture of anhydrous alcohol of grass and light gasoline (SR) of the Luanda Refinery and finally an improvement in the order of 81% for sample 2 namely the mixture of anhydrous alcohol of heavy gasoline grass of the Luanda Refinery. However, it is demonstrating in the first instance starting methodologies for the additive of gasoline samples, and in the second instance the "effect" of a fuel anhydrous alcohol derived from a "differentiated matter" called Angola grass, when used as an additive in direct distillation gasoline, which is concluded to be positive.
{"title":"Evaluation of the Additive Power of Ethanol Obtained from Angola Grass in Direct Distillation Gasoline Samples, Case Study: Straight Run (SR) Gasoline Produced at Luanda Refinery","authors":"Morais Pg, Q. En, J. Lf","doi":"10.23880/ppej-16000304","DOIUrl":"https://doi.org/10.23880/ppej-16000304","url":null,"abstract":"Alongside the process of blending naphtha, fuel anhydrous ethyl alcohol is an additive recurrently used to adjust commercial properties such as the octane index of gasolines during its formulation. This additive is environmentally recommended due to the promotion of decarbonization in gasolines that is evidenced in its consumption with the reduction of CO2 emissions into the atmosphere, compared to the consumption of other gasolines. There are several ways to obtain the respective additive, the research leads to obtaining it from the Angolan grass (Brachiaria purpurascens \"Forsk\" Stapf). Angola grass has a low fiber and protein content, thus becoming with low preference in the choice for animal feed and has a significant content of nonnitrogen extractives giving it a high energy potential to be raw material for biofuel production Through an experimental study and on a laboratory scale, alcohol was produced, then the quantities of the two components of the mixture were determined using additive calculations, and then mixed in samples of Straight run (SR) gasolines direct distillation produced in Luanda Refinery. Next, octane index tests were performed in the final mixture by the RON method following ASTM D22699 and adulteration potencies were verified in the samples. The octane index defined to be reached was 95 octane and it was proven that alcohol produced from Angola grass has the potential to promote improvements in octane index, as we found increases in the octane index of additive gasoline shows. We recorded an improvement of the rate of 91% for sample 1 namely the mixture of anhydrous alcohol of grass and light gasoline (SR) of the Luanda Refinery and finally an improvement in the order of 81% for sample 2 namely the mixture of anhydrous alcohol of heavy gasoline grass of the Luanda Refinery. However, it is demonstrating in the first instance starting methodologies for the additive of gasoline samples, and in the second instance the \"effect\" of a fuel anhydrous alcohol derived from a \"differentiated matter\" called Angola grass, when used as an additive in direct distillation gasoline, which is concluded to be positive.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"46 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-04-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121559635","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
A decline curve analysis model has been developed for flow rate proportional to the logarithm of time. The logarithm of time model requires careful interpretation of initial time dependence of volumetric flow rate. Applications of the model to shale gas production and shale oil production are presented.
{"title":"Logarithm Model for Decline Curve Analysis","authors":"Fanchi Jr","doi":"10.23880/ppej-16000303","DOIUrl":"https://doi.org/10.23880/ppej-16000303","url":null,"abstract":"A decline curve analysis model has been developed for flow rate proportional to the logarithm of time. The logarithm of time model requires careful interpretation of initial time dependence of volumetric flow rate. Applications of the model to shale gas production and shale oil production are presented.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"19 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-04-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123319106","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Field and granulometric investigation of Patti Sandstone were carried out with a view towards establishing the lithological sequence, geological processes, textural characteristics and paleoenvironment of deposition of the sediments. Field study entailed basic field procedures and sedimentological descriptions which encompass physical factors such as textural parameter, composition, colour and structures; biological inference in terms of fossil content and chemical character in terms of chemical composition and post depositional diagenesis effect. Granulometric laboratory procedure includes weighing and sieving of samples with set of sieves; calculated cumulative percentages, software input of data to generate statistical parameters such as mean, standard deviation (sorting), skewness, kurtosis and ternary diagrams. Field observations show that the lower part of the outcrop section has alternation of claystone and shale; the mid-section shows coarsening-up sequence of shale, clay and sandstone facies of a retrogradational system, while the upper part is composed of intercalation of claystone and sandstone in repetitive pattern, various thicknesses and colours. The textural characteristics of the sandstone are generally coarse-fine grains, reddish to greyish in colour, rounded to subrounded and moderately to well sorted. Structurally, the outcrops are planar cross bedded, wavy laminated and concretional. Granulometric result categorized the sandstones into fine, medium and coarse grained particles; well sorted to moderately well sorted, characterized by lateral retrogradational sequence from the shoreline. The skewness varies from fine skewed, very fine skewed and symmetrical. Kurtosis values suggest multi-sourced particles deposited in marine and fluviatile paleoenvironments.
{"title":"Textural and Paleoenvironmental Characterization of the Campano-Maastrichtian Patti Sandstone, Southern Bida Basin, Northcentral Nigeria","authors":"Oladimeji Rg, Oladimeji Ao","doi":"10.23880/ppej-16000301","DOIUrl":"https://doi.org/10.23880/ppej-16000301","url":null,"abstract":"Field and granulometric investigation of Patti Sandstone were carried out with a view towards establishing the lithological sequence, geological processes, textural characteristics and paleoenvironment of deposition of the sediments. Field study entailed basic field procedures and sedimentological descriptions which encompass physical factors such as textural parameter, composition, colour and structures; biological inference in terms of fossil content and chemical character in terms of chemical composition and post depositional diagenesis effect. Granulometric laboratory procedure includes weighing and sieving of samples with set of sieves; calculated cumulative percentages, software input of data to generate statistical parameters such as mean, standard deviation (sorting), skewness, kurtosis and ternary diagrams. Field observations show that the lower part of the outcrop section has alternation of claystone and shale; the mid-section shows coarsening-up sequence of shale, clay and sandstone facies of a retrogradational system, while the upper part is composed of intercalation of claystone and sandstone in repetitive pattern, various thicknesses and colours. The textural characteristics of the sandstone are generally coarse-fine grains, reddish to greyish in colour, rounded to subrounded and moderately to well sorted. Structurally, the outcrops are planar cross bedded, wavy laminated and concretional. Granulometric result categorized the sandstones into fine, medium and coarse grained particles; well sorted to moderately well sorted, characterized by lateral retrogradational sequence from the shoreline. The skewness varies from fine skewed, very fine skewed and symmetrical. Kurtosis values suggest multi-sourced particles deposited in marine and fluviatile paleoenvironments.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"22 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-04-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122849366","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Activities of drilling wells are widely continued and increased all over the world either to develop the mature reservoirs or to discover new reserves. The majority of these wells experience numerous issues during drilling operations, resulting in financial losses and wasted time. This is referred to as non-productive time (NPT). Due to these difficulties, all of these concerns present a challenge to not only the drilling engineer or designer but also the company as well. All parties want also to keep the continuous improvement of their operations. Therefore, this paper aims to analyze most of the drilling issues appeared during drilling Zubair wells which are located in the Eastern Iraq. Furthermore, drilling time statistical study is done to differentiate between the various causes of Zubair wells' problems. A rate of penetration (ROP) benchmarking study is also done so as to determine the drilling performance relative to the best well. A comparison is performed to know the best well performance.
{"title":"Drilling Time Statistical Analysis and Benchmarking for Drilled Wells of Zubair Field","authors":"Al Gburi H, Halafawi M, Avram L","doi":"10.23880/ppej-16000302","DOIUrl":"https://doi.org/10.23880/ppej-16000302","url":null,"abstract":"Activities of drilling wells are widely continued and increased all over the world either to develop the mature reservoirs or to discover new reserves. The majority of these wells experience numerous issues during drilling operations, resulting in financial losses and wasted time. This is referred to as non-productive time (NPT). Due to these difficulties, all of these concerns present a challenge to not only the drilling engineer or designer but also the company as well. All parties want also to keep the continuous improvement of their operations. Therefore, this paper aims to analyze most of the drilling issues appeared during drilling Zubair wells which are located in the Eastern Iraq. Furthermore, drilling time statistical study is done to differentiate between the various causes of Zubair wells' problems. A rate of penetration (ROP) benchmarking study is also done so as to determine the drilling performance relative to the best well. A comparison is performed to know the best well performance.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"30 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-04-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128101701","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Matrix acidizing using acid gases is an under developed phenomenon in the oil and gas industry. For most petroleum engineers the most common acid gases are carbon dioxide (CO 2 ) and dihydrogen sulfide (H 2 S). CO 2 is mostly injected into oil reservoirs to achieve full/partial miscibility with the crude oil. In the process, CO 2 reacts with formation water to form carbonic acid (a weak acid). Many research papers discuss how carbonic acid reacts with carbonate minerals and causes dissolution. Another popular acid gas in the oil industry is H 2 S. H 2 S is produced as an associated/dissolved gas in crude oil. H 2 S has the ability to react with formation water to form hydrosulfuric acid (a weak acid). This research paper introduces other acid gases that react with formation water and generate strong acids. These gases are: Sulfur Trioxide (SO 3 ), Nitrogen Dioxide (NO 2 ), Hydrogen Chloride (HCl), Hydrogen Bromide (HBr) and Hydrogen Iodide (HI). It is understood that most reservoirs are water wet or intermediate wet. Acid gas injection would change the pH of the water film around the oil globule in the pore. pH of the water in most reservoirs typically ranges between 5.5 and 8.5. Lowering the pH of the water that coats the pore, will initiate the acid treatment and reduce the presence of carbonates within the rock. This would result in an increase in porosity and permeability within the reservoir. Some visual examples of stimulating the reservoirs using acid gases are also discussed in this research paper. Acid gas injection would be considered a solution to many issues in our reservoirs. It would allow for recovery from vuggy pores (also known as isolated pores) in carbonate formations. It would also enhance unconventional reservoirs such as shale oil reservoirs (knowing that some of those shale oil reservoirs have higher carbonate content). Furthermore, in our conventional reservoirs we produce from the larger pores leaving behind a lot of oil in tight pores, acid gas injection would open up some of those tight pores. Acid gas is matrix acidizing tool, that petroleum engineers need to enhance the reservoir rock properties.
{"title":"Acid Gas Injection into Petroleum Reservoirs: A Review","authors":"A. Shazly","doi":"10.23880/ppej-16000280","DOIUrl":"https://doi.org/10.23880/ppej-16000280","url":null,"abstract":"Matrix acidizing using acid gases is an under developed phenomenon in the oil and gas industry. For most petroleum engineers the most common acid gases are carbon dioxide (CO 2 ) and dihydrogen sulfide (H 2 S). CO 2 is mostly injected into oil reservoirs to achieve full/partial miscibility with the crude oil. In the process, CO 2 reacts with formation water to form carbonic acid (a weak acid). Many research papers discuss how carbonic acid reacts with carbonate minerals and causes dissolution. Another popular acid gas in the oil industry is H 2 S. H 2 S is produced as an associated/dissolved gas in crude oil. H 2 S has the ability to react with formation water to form hydrosulfuric acid (a weak acid). This research paper introduces other acid gases that react with formation water and generate strong acids. These gases are: Sulfur Trioxide (SO 3 ), Nitrogen Dioxide (NO 2 ), Hydrogen Chloride (HCl), Hydrogen Bromide (HBr) and Hydrogen Iodide (HI). It is understood that most reservoirs are water wet or intermediate wet. Acid gas injection would change the pH of the water film around the oil globule in the pore. pH of the water in most reservoirs typically ranges between 5.5 and 8.5. Lowering the pH of the water that coats the pore, will initiate the acid treatment and reduce the presence of carbonates within the rock. This would result in an increase in porosity and permeability within the reservoir. Some visual examples of stimulating the reservoirs using acid gases are also discussed in this research paper. Acid gas injection would be considered a solution to many issues in our reservoirs. It would allow for recovery from vuggy pores (also known as isolated pores) in carbonate formations. It would also enhance unconventional reservoirs such as shale oil reservoirs (knowing that some of those shale oil reservoirs have higher carbonate content). Furthermore, in our conventional reservoirs we produce from the larger pores leaving behind a lot of oil in tight pores, acid gas injection would open up some of those tight pores. Acid gas is matrix acidizing tool, that petroleum engineers need to enhance the reservoir rock properties.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"47 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"1900-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133963693","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Ceramic fracture proppants are extensively used for enhancing oil and gas well productivity in low-permeability reservoirs. Previous work reported attracting-oil-repelling-water (AORW) property of oil-wet proppants at the faces of fractures. Because of lack of method for measuring contact angle of proppant packs, the terms water-wet proppant and oil-wet proppant were defined on the basis of observations of liquid droplets on the surfaces of proppant packs without quantitative measurement. An innovative method was developed in this study to determine the contact angles of fracture proppant packs. The effect of oil contact angle of oil-wet fracture proppant pack on the competing water/oil flow from sandstone cores to the packs was investigated. It was found that, for a given fracture proppant pack, the sum of the water contact angle and oil contact angle measured in the liquid-air-solid systems is less than 180 degrees, i.e., the two angles are not supplementary. This is believed due to the weak wetting capacity of air to the solid surfaces in the liquid-air-solid systems. Both water and oil contact angles should be considered in the classification of wettability of proppant packs. Fracture proppant packs with water contact angles greater than 90 degrees and oil contact angles significantly less than 90 degrees can be considered as oil-wet proppants. Reducing oil contact angles of oil-wet proppants can increase capillary force, promote oil imbibition into the proppant packs, and thus improve the AORW performance of proppants. Fracture proppant packs with water contact angles less than 90 degrees and oil contact angles less than 90 degrees may be considered as mixed-wet proppants. Their AORW performance should be tested in laboratories before they are considered for well fracturing operations.
{"title":"Effect of Fluid Contact Angle of Oil-wet Ceramic Fracture Proppant on the Water Flow from Sandstones to Proppant Packs","authors":"Guo B","doi":"10.23880/ppej-16000295","DOIUrl":"https://doi.org/10.23880/ppej-16000295","url":null,"abstract":"Ceramic fracture proppants are extensively used for enhancing oil and gas well productivity in low-permeability reservoirs. Previous work reported attracting-oil-repelling-water (AORW) property of oil-wet proppants at the faces of fractures. Because of lack of method for measuring contact angle of proppant packs, the terms water-wet proppant and oil-wet proppant were defined on the basis of observations of liquid droplets on the surfaces of proppant packs without quantitative measurement. An innovative method was developed in this study to determine the contact angles of fracture proppant packs. The effect of oil contact angle of oil-wet fracture proppant pack on the competing water/oil flow from sandstone cores to the packs was investigated. It was found that, for a given fracture proppant pack, the sum of the water contact angle and oil contact angle measured in the liquid-air-solid systems is less than 180 degrees, i.e., the two angles are not supplementary. This is believed due to the weak wetting capacity of air to the solid surfaces in the liquid-air-solid systems. Both water and oil contact angles should be considered in the classification of wettability of proppant packs. Fracture proppant packs with water contact angles greater than 90 degrees and oil contact angles significantly less than 90 degrees can be considered as oil-wet proppants. Reducing oil contact angles of oil-wet proppants can increase capillary force, promote oil imbibition into the proppant packs, and thus improve the AORW performance of proppants. Fracture proppant packs with water contact angles less than 90 degrees and oil contact angles less than 90 degrees may be considered as mixed-wet proppants. Their AORW performance should be tested in laboratories before they are considered for well fracturing operations.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"1900-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131266783","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
The article presents a description of the designs of wells intended for the production of high-viscosity oil. The main problems associated with the planning and deployments of architecture, construction of high-viscosity oil wells are described. World experience in well construction is presented. Vertical wells are usually used for primary cold production and cyclic steam or steam flooding processes. On the other hand, increased reservoir contact may require deviated, horizontal, or multilateral wells. In the case of steam-assisted gravity drainage (SAGD) and some solvent injection processes, the recovery process may require a well-placed pair of horizontal wells. Advanced drilling and real-time measurement technologies reviewed. Geo mechanical factors are studied when considering the implementation of any steam or thermal processes in the field. Examples of construction of multilateral wells in various combinations are shown depending on the field development strategy and for maximum reservoir drainage. The main recommendations for the placement of wells are proposed.
{"title":"Constructing a Heavy Oil Well","authors":"Shemelina On","doi":"10.23880/ppej-16000300","DOIUrl":"https://doi.org/10.23880/ppej-16000300","url":null,"abstract":"The article presents a description of the designs of wells intended for the production of high-viscosity oil. The main problems associated with the planning and deployments of architecture, construction of high-viscosity oil wells are described. World experience in well construction is presented. Vertical wells are usually used for primary cold production and cyclic steam or steam flooding processes. On the other hand, increased reservoir contact may require deviated, horizontal, or multilateral wells. In the case of steam-assisted gravity drainage (SAGD) and some solvent injection processes, the recovery process may require a well-placed pair of horizontal wells. Advanced drilling and real-time measurement technologies reviewed. Geo mechanical factors are studied when considering the implementation of any steam or thermal processes in the field. Examples of construction of multilateral wells in various combinations are shown depending on the field development strategy and for maximum reservoir drainage. The main recommendations for the placement of wells are proposed.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"21 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"1900-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126947246","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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