Pub Date : 2022-02-01DOI: 10.1016/j.upstre.2022.100065
Mulya M. Nur , Tawfik A. Saleh
This work reports on the synthesis of allyl-activated carbon modified with polyacrylic and then aminated by melamine. The obtained melamine-modified polyacrylic grafted activated carbon (C-g-AM) was then characterized for structural and morphological properties. The synthesized C-g-AM was characterized by several tools. This was followed by an evaluation of the inhibitive ability of the material by performing various inhibition tests, including shale recovery, anti-swelling, and immersion tests. 2 wt% C-g-AM effectively decreased water invasion into shale, because the combination of activated carbon as a core-center particle with the melamine–polyacrylic acid component is absorbed on clay surface through hydrogen bonds and electrostatic interactions.
{"title":"Melamine-modified polyacrylic grafted on activated carbon and its efficiency for shale inhibition","authors":"Mulya M. Nur , Tawfik A. Saleh","doi":"10.1016/j.upstre.2022.100065","DOIUrl":"10.1016/j.upstre.2022.100065","url":null,"abstract":"<div><p><span>This work reports on the synthesis of allyl-activated carbon modified with polyacrylic and then aminated by melamine. The obtained melamine-modified polyacrylic grafted activated carbon (C-g-AM) was then characterized for structural and morphological properties. The synthesized C-g-AM was characterized by several tools. This was followed by an evaluation of the inhibitive ability of the material by performing various inhibition tests, including shale recovery, anti-swelling, and immersion tests. 2 wt% C-g-AM effectively decreased water invasion into shale, because the combination of activated carbon as a core-center particle with the melamine–polyacrylic acid component is absorbed on clay surface through </span>hydrogen bonds and electrostatic interactions.</p></div>","PeriodicalId":101264,"journal":{"name":"Upstream Oil and Gas Technology","volume":"8 ","pages":"Article 100065"},"PeriodicalIF":0.0,"publicationDate":"2022-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87607926","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}
Pub Date : 2022-02-01DOI: 10.1016/j.upstre.2022.100067
Uttam Gupta , Akshaya Kumar Mishra
Production of wax associated light crude is quite difficult as the pressure drops from the reservoir to production facility are quite large. This often leads to the precipitation and deposition of common organic solids (wax). These solids may deposit on surfaces, collect in low-energy regions or increase the effective viscosity of the flowing fluid. The two types of wax crystal studied which are microcrystalline and macro crystalline waxes. Microcrystalline waxes (naphthene or isoparaffinic) are produced by de-oiling of petroleum. Macrocrystalline waxes (Paraffins) consists of long straight chain saturated hydrocarbons (linear alkanes). Proper knowledge of wax crystal type would help in understanding fluid flow dynamics and simulate it accordingly. It also helps in prevent blockage and select an effective wax inhibitor in the treatment of wax precipitation and deposition. Therefore, its necessary to analyze the behavior and property of waxy crude. The current study determines different physical & microscopic properties along with the chemical composition of the crude sample obtained from Cambay Basin. Fourier Transform Infrared spectroscopy (FTIR) is used to identify chemical component with its composition. The behavior of the crudes is studied in static and dynamic conditions with different temperatures and shear rates. The crude oil shows a decrease in viscosity with increasing temperature and shear rate. The paperwork also investigates the use of Cross-Polarized Microscopy (CPM) to determine whether crude oil shows microcrystalline or macrocrystalline wax behavior.
{"title":"Study of microcrystalline and macrocrystalline structure based on Cambay basin crude oils","authors":"Uttam Gupta , Akshaya Kumar Mishra","doi":"10.1016/j.upstre.2022.100067","DOIUrl":"https://doi.org/10.1016/j.upstre.2022.100067","url":null,"abstract":"<div><p>Production of wax associated light crude is quite difficult as the pressure drops from the reservoir to production facility are quite large. This often leads to the precipitation and deposition of common organic solids (wax). These solids may deposit on surfaces, collect in low-energy regions or increase the effective viscosity of the flowing fluid. The two types of wax crystal studied which are microcrystalline and macro crystalline waxes. Microcrystalline waxes (naphthene or isoparaffinic) are produced by de-oiling of petroleum. Macrocrystalline waxes (Paraffins) consists of long straight chain saturated hydrocarbons (linear alkanes). Proper knowledge of wax crystal type would help in understanding fluid flow dynamics and simulate it accordingly. It also helps in prevent blockage and select an effective wax inhibitor in the treatment of wax precipitation and deposition. Therefore, its necessary to analyze the behavior and property of waxy crude. The current study determines different physical & microscopic properties along with the chemical composition of the crude sample obtained from Cambay Basin. Fourier Transform Infrared spectroscopy (FTIR) is used to identify chemical component with its composition. The behavior of the crudes is studied in static and dynamic conditions with different temperatures and shear rates. The crude oil shows a decrease in viscosity with increasing temperature and shear rate. The paperwork also investigates the use of Cross-Polarized Microscopy (CPM) to determine whether crude oil shows microcrystalline or macrocrystalline wax behavior.</p></div>","PeriodicalId":101264,"journal":{"name":"Upstream Oil and Gas Technology","volume":"8 ","pages":"Article 100067"},"PeriodicalIF":0.0,"publicationDate":"2022-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"109183793","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}
Pub Date : 2022-02-01DOI: 10.1016/j.upstre.2022.100070
{"title":"Erratum regarding missing Declaration of Competing Interest statements in previously published articles","authors":"","doi":"10.1016/j.upstre.2022.100070","DOIUrl":"https://doi.org/10.1016/j.upstre.2022.100070","url":null,"abstract":"","PeriodicalId":101264,"journal":{"name":"Upstream Oil and Gas Technology","volume":"8 ","pages":"Article 100070"},"PeriodicalIF":0.0,"publicationDate":"2022-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2666260422000081/pdfft?md5=8b780c2e6940f15d691c89f731f84038&pid=1-s2.0-S2666260422000081-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"109183794","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2022-02-01DOI: 10.1016/j.upstre.2022.100069
Tawfik A. Saleh
Water-based mud (WBM) is an environmentally acceptable drilling fluid. However, it makes shale to be prone to swelling owing to its interaction with active clays. Shale swelling makes drilling to be difficult, so, additives are added to inhibit shale swelling, and improve rheological and filtration properties. The use of conventional additives particularly organic and inorganic compounds are not suitable at extreme conditions of drilling. Other materials like nanomaterials have emerged as promising alternatives used under such conditions. This review aims to highlight in detail the essential types of inhibitors and the evolvement of nanoparticles in enhancing drilling fluid properties.
{"title":"Advanced trends of shale inhibitors for enhanced properties of water-based drilling fluid","authors":"Tawfik A. Saleh","doi":"10.1016/j.upstre.2022.100069","DOIUrl":"10.1016/j.upstre.2022.100069","url":null,"abstract":"<div><p>Water-based mud (WBM) is an environmentally acceptable drilling fluid. However, it makes shale to be prone to swelling owing to its interaction with active clays. Shale swelling makes drilling to be difficult, so, additives are added to inhibit shale swelling, and improve rheological and filtration properties. The use of conventional additives particularly organic and inorganic compounds<span><span> are not suitable at extreme conditions of drilling. Other materials like nanomaterials have emerged as promising alternatives used under such conditions. This review aims to highlight in detail the essential types of inhibitors and the evolvement of </span>nanoparticles in enhancing drilling fluid properties.</span></p></div>","PeriodicalId":101264,"journal":{"name":"Upstream Oil and Gas Technology","volume":"8 ","pages":"Article 100069"},"PeriodicalIF":0.0,"publicationDate":"2022-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86768227","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}
Pub Date : 2022-02-01DOI: 10.1016/j.upstre.2022.100064
Subhrajyoti Bhattacharyya, Aditya Vyas
The main objective of this paper is to develop a novel machine learning based model that can accurately predict the decline curves and EUR (Estimated Ultimate Recovery) for new wells based on the data collected from nearby wells. This is because decline curves are easier and faster alternative to complex reservoir simulators which perform computationally expensive operations. In contrast to this, decline curves require only a few parameters in the equation which can be easily collected from the existing data of the wells. In this study, first we collected the well data corresponding to well parameters such as initial monthly oil flow rate (), well completion parameters (i.e., no. of fracturing stages, completed length, amount of proppant used, amount of fracturing fluid used), well location parameters (TVD Heel-Toe Difference), reservoir fluid properties (Oil API Gravity, initial 24 h period Gas-Oil Ratio (GOR), initial 24 h period Gas Produced, initial 24 h period Oil Produced), flowing tubing pressure, casing pressure tubing size,choke size from publicly available databases of the Eagle Ford Shale formation Texas RRC (Railroad Commission of Texas). Wells were selected randomly and only those wells were finally included for the study whose data of the all the required parameters were available. The model parameters were estimated by fitting the production data to the decline curve models. Artificial Neural Network (ANN) was employed to build Machine learning models as a function of the above well parameters for the corresponding model parameters. The decline curves for new or existing wells were rapidly predicted using these models. In order to estimate the predictive accuracy of these models when applied to new or test wells cross validation technique such as k-fold cross validation was employed. These models were also used to predict EUR for the test wells. Additionally, feature selection was also done using algorithms such as Chi Square Test (χ2) and Minimum Redundancy Maximum Relevance (MRMR) Algorithm to determine the relative importance of predictor variables in predicting EUR. The predictor variables were successfully linked to SEDM (Stretched Exponential Decline Model) decline curve parameters (n and τ) in a random set of oil field well data. The relative influences of various well parameters were also examined to determine the hidden relationship between them. The novelty in this study lies in the algorithm and dataset that we used for the rate decline prediction in Eagle Ford data set. Although, this paper has referenced some previous papers where machine learning has been used to make prediction, but this paper presents use of new algorithm as well as a new dataset. As more data gets available, there is definitely extr
{"title":"Machine learning based rate decline prediction in unconventional reservoirs","authors":"Subhrajyoti Bhattacharyya, Aditya Vyas","doi":"10.1016/j.upstre.2022.100064","DOIUrl":"10.1016/j.upstre.2022.100064","url":null,"abstract":"<div><p><span>The main objective of this paper is to develop a novel machine learning based model that can accurately predict the decline curves and EUR (Estimated Ultimate Recovery) for new wells based on the data collected from nearby wells. This is because decline curves are easier and faster alternative to complex reservoir simulators which perform computationally expensive operations. In contrast to this, decline curves require only a few parameters in the equation which can be easily collected from the existing data of the wells. In this study, first we collected the well data corresponding to well parameters such as initial monthly oil flow rate (</span><span><math><msub><mi>q</mi><mi>i</mi></msub></math></span><span>), well completion parameters (i.e., no. of fracturing stages, completed length, amount of proppant<span><span> used, amount of fracturing fluid used), well location parameters (TVD Heel-Toe Difference), reservoir fluid<span><span> properties (Oil API Gravity, initial 24 h period Gas-Oil Ratio (GOR), initial 24 h period Gas Produced, initial 24 h period Oil Produced), flowing tubing pressure, casing pressure tubing size,choke size from publicly available databases of the </span>Eagle Ford Shale<span> formation Texas RRC (Railroad Commission of Texas). Wells were selected randomly and only those wells were finally included for the study whose data of the all the required parameters were available. The model parameters were estimated by fitting the production data to the decline curve models. Artificial Neural Network (ANN) was employed to build Machine learning models as a function of the above well parameters for the corresponding model parameters. The decline curves for new or existing wells were rapidly predicted using these models. In order to estimate the predictive accuracy of these models when applied to new or test wells </span></span></span>cross validation technique such as k-fold cross validation was employed. These models were also used to predict EUR for the test wells. Additionally, feature selection was also done using algorithms such as Chi Square Test (χ2) and </span></span><span>Minimum Redundancy Maximum Relevance (MRMR) Algorithm</span><svg><path></path></svg><span><span> to determine the relative importance of predictor variables in predicting EUR. The predictor variables were successfully linked to SEDM (Stretched </span>Exponential Decline<span> Model) decline curve parameters (n and τ) in a random set of oil field well data. The relative influences of various well parameters were also examined to determine the hidden relationship between them. The novelty in this study lies in the algorithm and dataset that we used for the rate decline prediction in Eagle Ford data set. Although, this paper has referenced some previous papers where machine learning has been used to make prediction, but this paper presents use of new algorithm as well as a new dataset. As more data gets available, there is definitely extr","PeriodicalId":101264,"journal":{"name":"Upstream Oil and Gas Technology","volume":"8 ","pages":"Article 100064"},"PeriodicalIF":0.0,"publicationDate":"2022-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90347742","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}
Pub Date : 2022-02-01DOI: 10.1016/j.upstre.2021.100061
Fabiane S. Serpa , Gabriela M. Silva , Lucas F.L. Freitas , Elvio B. Melo Filho , Jailton F. Nascimento , Leonardo S. Pereira , Giancarlo R. Salazar-Banda , Gustavo R. Borges , Cláudio Dariva , Elton Franceschi
Monoethylene glycol (MEG) is a thermodynamic inhibitor of gas hydrate formation used in the oil industry. Regeneration of MEG for reinjection in wells is necessary to minimize operating costs due to the large amounts of this additive employed. However, this scenario favors the precipitation of inorganic salts from the produced water, mainly calcium carbonate (CaCO3). This work is devoted to evaluating the CaCO3 precipitation in water + MEG mixtures (0–50 vol.% MEG) at different concentrations of reacting salts (0.01–0.1 mol L−1) and temperatures (25–60 °C). The focused beam reflectance measurement (FBRM) technique was used for inline monitoring of chord length and CaCO3 particles distribution in the suspension for 60 min. Optical microscopy was used to understand the particle precipitation phenomena. FBRM results show that the size distribution and the number of CaCO3 particles in the aqueous solution vary with time, temperature, reacting salts, and MEG concentrations. The higher the salt concentration, the larger both the size and number of precipitated chords. Temperature expressively affects salt precipitation. For a given concentration of MEG, the enhancement in temperature favors the increase in the amount and size of chords. Specifically, for 10% v/v of MEG solutions, the particle size increases from 8.0 ± 0.5 μm (at 25 °C) to 20.4 ± 2.1 μm (at 60 °C). Additionally, at 30% v/v of MEG in the solution, the particle size increases from 5.4 ± 0.4 μm (at 25 °C) to 15.5 ± 0.2 μm (at 60 °C). These outcomes are related to the reduction in CaCO3 solubility and the improvement in MEG viscosity with temperature. Optical microscopy measurements corroborate the FBRM data, thus demonstrating the influence of the parameters MEG concentration, ionic concentration, and temperature have on the number and size of precipitated carbonate crystals.
{"title":"An experimental study of calcium carbonate precipitation with hydrate inhibitor in MEG recovery unit","authors":"Fabiane S. Serpa , Gabriela M. Silva , Lucas F.L. Freitas , Elvio B. Melo Filho , Jailton F. Nascimento , Leonardo S. Pereira , Giancarlo R. Salazar-Banda , Gustavo R. Borges , Cláudio Dariva , Elton Franceschi","doi":"10.1016/j.upstre.2021.100061","DOIUrl":"10.1016/j.upstre.2021.100061","url":null,"abstract":"<div><p>Monoethylene glycol (MEG) is a thermodynamic inhibitor of gas hydrate formation used in the oil industry. Regeneration of MEG for reinjection in wells is necessary to minimize operating costs due to the large amounts of this additive employed. However, this scenario favors the precipitation of inorganic salts from the produced water, mainly calcium carbonate (CaCO<sub>3</sub>). This work is devoted to evaluating the CaCO<sub>3</sub> precipitation in water + MEG mixtures (0–50 vol.% MEG) at different concentrations of reacting salts (0.01–0.1 mol L<sup>−1</sup>) and temperatures (25–60 °C). The focused beam reflectance measurement (FBRM) technique was used for inline monitoring of chord length and CaCO<sub>3</sub> particles distribution in the suspension for 60 min. Optical microscopy was used to understand the particle precipitation phenomena. FBRM results show that the size distribution and the number of CaCO<sub>3</sub> particles in the aqueous solution vary with time, temperature, reacting salts, and MEG concentrations. The higher the salt concentration, the larger both the size and number of precipitated chords. Temperature expressively affects salt precipitation. For a given concentration of MEG, the enhancement in temperature favors the increase in the amount and size of chords. Specifically, for 10% v/v of MEG solutions, the particle size increases from 8.0 ± 0.5 μm (at 25 °C) to 20.4 ± 2.1 μm (at 60 °C). Additionally, at 30% v/v of MEG in the solution, the particle size increases from 5.4 ± 0.4 μm (at 25 °C) to 15.5 ± 0.2 μm (at 60 °C). These outcomes are related to the reduction in CaCO<sub>3</sub> solubility and the improvement in MEG viscosity with temperature. Optical microscopy measurements corroborate the FBRM data, thus demonstrating the influence of the parameters MEG concentration, ionic concentration, and temperature have on the number and size of precipitated carbonate crystals.</p></div>","PeriodicalId":101264,"journal":{"name":"Upstream Oil and Gas Technology","volume":"8 ","pages":"Article 100061"},"PeriodicalIF":0.0,"publicationDate":"2022-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87188078","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}
Pub Date : 2021-09-01DOI: 10.1016/j.upstre.2021.100050
Ranjan K. Bhagobaty, Mintu Borkataky
Essential oils of medicinal and aromatic plants have been known to possess inherent anti-microbial properties. In the present study field application of lemongrass essential oil (hydrosol form) was undertaken as substitute to conventionally used synthetic bactericides in an Oil Collecting Station located in Assam, India. Results obtained during the course of the three-month long field assessment has successfully demonstrated that Lemongrass essential oil (hydrosol form) can be used as a bactericide to arrest growth of harmful corrosion causing sulphate reducing bacteria in produced water co-produced with oil and gas during the primary processing of crude at the Oil Collecting Station.
{"title":"Application of Lemongrass essential oil as a bactericide for produced water treatment in an Oil Collecting Station of North-East, India","authors":"Ranjan K. Bhagobaty, Mintu Borkataky","doi":"10.1016/j.upstre.2021.100050","DOIUrl":"https://doi.org/10.1016/j.upstre.2021.100050","url":null,"abstract":"<div><p>Essential oils of medicinal and aromatic plants have been known to possess inherent anti-microbial properties. In the present study field application of lemongrass essential oil (hydrosol form) was undertaken as substitute to conventionally used synthetic bactericides in an Oil Collecting Station located in Assam, India. Results obtained during the course of the three-month long field assessment has successfully demonstrated that Lemongrass essential oil (hydrosol form) can be used as a bactericide to arrest growth of harmful corrosion causing sulphate reducing bacteria in produced water co-produced with oil and gas during the primary processing of crude at the Oil Collecting Station.</p></div>","PeriodicalId":101264,"journal":{"name":"Upstream Oil and Gas Technology","volume":"7 ","pages":"Article 100050"},"PeriodicalIF":0.0,"publicationDate":"2021-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1016/j.upstre.2021.100050","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"137164010","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}
Pub Date : 2021-09-01DOI: 10.1016/j.upstre.2021.100058
Debashree Dutta , Borkha Mech Das
Applications of nanoparticles (NPs) in petroleum drilling are the state-of-the art for nanotechnology and petroleum technology. Highlighting the role of iron oxide NPs as an additive and substitute to commercial additives, the research aims in formulation of a novel nano based drilling fluid (NDF) by meticulously studying the rheological and filtration properties. The research emphasizes on two perspectives of high cost of NPs and enhancement of properties of drilling fluid with maximum feasibility to explore the reservoirs of Upper Assam basins. Chemical reduction method was employed for synthesizing iron oxide NPs and characterized by ultraviolet visible spectrophotometer and particle size analyzer. Rheological and filtration properties of the NDF were conducted by addition of iron oxide NPs from 5 wt% to 40 wt%. The research presents the formulation of a smart drilling fluid using NPs as a sole additive replacing other commercial ones. NDF, so far has not been used in the reservoirs of Upper Assam Basins owing to economic factors and real-time feasibility. Apart from unleashing the various reasons for compatibility of NDF in such reservoirs, the research also highlights the practical limitations encountered during mud formulation and field use.
{"title":"Development of smart bentonite drilling fluid introducing iron oxide nanoparticles compatible to the reservoirs of Upper Assam","authors":"Debashree Dutta , Borkha Mech Das","doi":"10.1016/j.upstre.2021.100058","DOIUrl":"10.1016/j.upstre.2021.100058","url":null,"abstract":"<div><p>Applications of nanoparticles (NPs) in petroleum drilling are the state-of-the art for nanotechnology and petroleum technology. Highlighting the role of iron oxide NPs as an additive and substitute to commercial additives, the research aims in formulation of a novel nano based drilling fluid (NDF) by meticulously studying the rheological and filtration properties. The research emphasizes on two perspectives of high cost of NPs and enhancement of properties of drilling fluid with maximum feasibility to explore the reservoirs of Upper Assam basins. Chemical reduction method was employed for synthesizing iron oxide NPs and characterized by ultraviolet visible spectrophotometer and particle size analyzer. Rheological and filtration properties of the NDF were conducted by addition of iron oxide NPs from 5 wt% to 40 wt%. The research presents the formulation of a smart drilling fluid using NPs as a sole additive replacing other commercial ones. NDF, so far has not been used in the reservoirs of Upper Assam Basins owing to economic factors and real-time feasibility. Apart from unleashing the various reasons for compatibility of NDF in such reservoirs, the research also highlights the practical limitations encountered during mud formulation and field use.</p></div>","PeriodicalId":101264,"journal":{"name":"Upstream Oil and Gas Technology","volume":"7 ","pages":"Article 100058"},"PeriodicalIF":0.0,"publicationDate":"2021-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84828688","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}
Pub Date : 2021-09-01DOI: 10.1016/j.upstre.2021.100060
Samwel Daud Lupyana , Mtabazi Geofrey Sahini , Saada Msafiri Kattiba , Jun Gu
Plants extracts contain a wide range of organic components and have been used as admixtures in modifying different cement properties. In this study, aqueous extract of Euphorbia Tirucalli (ET) as bio-admixture was characterized and tested for potential use in the preparation of well cement slurry. Several tests such as setting time tests, fluid loss tests, rheological properties of well cement slurries incorporating different proportions of the ET and the reference slurries without ET were conducted and evaluated. Phytochemical composition of ET was investigated by using Gas Chromatography-Mass Spectrometer (GCMS) analytical technique. Interactions between the bio-admixture and cement components during hydration were also characterized by Fourier Transform-Infrared (FT-IR) spectroscopic technique. GC–MS analysis indicates the presence of the palmitic acid groups such as hexadecanoic acid, methyl ester, n-Hexadecanoic acid and 9-Hexadecanoilc acid and the fatty acid components commonly known as linoleic acid. Incorporation of the bio-admixture shows to enhance fluid loss properties and slurry rheology. Also, the bio-admixture indicates promoting retardation of cement hydration due to increase in setting times with increase in mix proportions. These properties indicated to be dependent to the bio-admixture concentration. FT-IR spectroscopic investigations suggests possible interaction between bio-admixture and the ionic species in the cement slurry.
{"title":"Use of phyto-based polymeric material as chemical admixture in well cement slurry formulation","authors":"Samwel Daud Lupyana , Mtabazi Geofrey Sahini , Saada Msafiri Kattiba , Jun Gu","doi":"10.1016/j.upstre.2021.100060","DOIUrl":"10.1016/j.upstre.2021.100060","url":null,"abstract":"<div><p>Plants extracts contain a wide range of organic components and have been used as admixtures in modifying different cement properties. In this study, aqueous extract of <em>Euphorbia Tirucalli</em> (<em>ET</em>) as bio-admixture was characterized and tested for potential use in the preparation of well cement slurry. Several tests such as setting time tests, fluid loss tests, rheological properties of well cement slurries incorporating different proportions of the <em>ET</em> and the reference slurries without <em>ET</em> were conducted and evaluated. Phytochemical composition of <em>ET</em> was investigated by using Gas Chromatography-Mass Spectrometer (GCMS) analytical technique. Interactions between the bio-admixture and cement components during hydration were also characterized by Fourier Transform-Infrared (FT-IR) spectroscopic technique. GC–MS analysis indicates the presence of the palmitic acid groups such as hexadecanoic acid, methyl ester, n-Hexadecanoic acid and 9-Hexadecanoilc acid and the fatty acid components commonly known as linoleic acid. Incorporation of the bio-admixture shows to enhance fluid loss properties and slurry rheology. Also, the bio-admixture indicates promoting retardation of cement hydration due to increase in setting times with increase in mix proportions. These properties indicated to be dependent to the bio-admixture concentration. FT-IR spectroscopic investigations suggests possible interaction between bio-admixture and the ionic species in the cement slurry.</p></div>","PeriodicalId":101264,"journal":{"name":"Upstream Oil and Gas Technology","volume":"7 ","pages":"Article 100060"},"PeriodicalIF":0.0,"publicationDate":"2021-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74925307","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}
Pub Date : 2021-09-01DOI: 10.1016/j.upstre.2021.100056
Mykhaylo Myslyuk , Nazar Zholob
Using the methods of design of experiments, filtration properties of the bentonite-free mud system that contains xanthan gum, starch, sodium and potassium formate salts, calcium carbonate and Alevron agent at temperature range of 130–170 °C, differential pressure of 1–5 MPa and initial permeability of ceramic filters of 0.95–7.20 D were studied. Regression models were built for the НТНР filtration loss and permeability of a ceramic filter after mud cake build-up depending on mud additives concentrations, temperature, differential pressure and initial filter permeability, which provide high accuracy of experimental data approximation.
{"title":"Investigation of filtration properties of a formate-based mud system under high temperature conditions","authors":"Mykhaylo Myslyuk , Nazar Zholob","doi":"10.1016/j.upstre.2021.100056","DOIUrl":"10.1016/j.upstre.2021.100056","url":null,"abstract":"<div><p><span><span>Using the methods of design of experiments, filtration properties of the bentonite-free mud system that contains </span>xanthan gum, </span>starch<span>, sodium and potassium<span> formate salts, calcium carbonate and Alevron agent at temperature range of 130–170 °C, differential pressure of 1–5 MPa and initial permeability of ceramic filters of 0.95–7.20 D were studied. Regression models were built for the НТНР filtration loss and permeability of a ceramic filter after mud cake build-up depending on mud additives concentrations, temperature, differential pressure and initial filter permeability, which provide high accuracy of experimental data approximation.</span></span></p></div>","PeriodicalId":101264,"journal":{"name":"Upstream Oil and Gas Technology","volume":"7 ","pages":"Article 100056"},"PeriodicalIF":0.0,"publicationDate":"2021-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87877265","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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