Abstract :- Drilling fluids Play a vital role in hole Cleaning suspension of cuttings, prevent caving, and ensure the tightness of the well wall. Moreover they also help in cooling and lubricating the drilling tool, transfer the hydraulic power and carry information about the nature of the drilled formation by raising the cuttings from the bottom to the surface, using a simple mixture of water and clays, to complex mixtures of various specific organic and inorganic products as additives. These additives improve fluid rheological properties and filtration capability, allowing bits to penetrate heterogeneous geological formations The mud used in this work is barite and bentonites at different samples to know the difference in their specific gravity, viscosity, surface tension, and pH of the samples when chemical additives are added.
This document discusses drilling fluids and their properties. It provides an overview of the principal functions of drilling fluids, which include subsurface pressure control, cuttings removal and transport, suspension of solid particles, sealing of permeable formations, stabilizing the wellbore, preventing formation damage, cooling and lubricating the bit, transmitting hydraulic horsepower to the bit, facilitating collection of formation data, partial support of the drill string and casing weights, controlling corrosion, and assisting in cementing and completion. It also discusses drilling fluid classifications, properties such as viscosity and rheology, and key components of drilling fluids.
This document provides information about drilling fluids used in oil and gas drilling operations. It discusses the key components and functions of drilling fluids, including bringing cuttings to the surface, controlling subsurface pressures, lubricating and cooling the drill bit. It also describes various types of drilling fluids like water-based muds, calcium muds, lignosulphonate muds, and KCl/polymer muds. The document discusses the role of clays and colloid chemistry in drilling fluids and outlines the properties and uses of different clay minerals.
This document discusses the environmental sustainability of drilling fluids. It outlines various additives used in drilling fluids and their potential environmental effects, such as barite containing heavy metals that can impact aquatic life. Alternatives to traditional additives are proposed, such as using bacteria or biodegradable compounds. The document also covers drilling fluid waste management and disposal options like biosorption to reduce the impact of waste before disposal. It concludes that a balance is needed between well drilling requirements and environmental considerations when developing more sustainable drilling fluid solutions.
This document discusses sustainable drilling fluid solutions. It begins with basic terminology used in drilling fluids like mud types, additives, and functions of mud. Water-based mud and oil-based mud are compared, noting that WBM is less toxic and can meet environmental issues but is not stable above 400°F, while OBM is stable above 400°F but more toxic. New developments in bio-polymers are discussed that can viscosify drilling fluids with less toxicity and better stability. In conclusion, water-based muds with bio-polymers are the most sustainable option while also addressing environmental concerns related to drilling fluids.
This document summarizes a presentation about drilling fluids. It defines drilling fluid as a mixture of clay and chemicals pumped through a drill bit to provide hydrostatic pressure, suspend cuttings, cool and lubricate the bit, and provide information from the wellbore. The presentation covers the types of drilling fluids, their functions, additives used, and rheological properties measured. It also describes the drilling fluid circulation system and discusses drilling fluid considerations and emergency remedies.
The formulation of drilling fluid is one of the most important aspects in drilling engineering. This is because the drilling fluid is capable of lubricating and cooling the drill bit and drill string as well as carrying cuttings out of the borehole. All of these functions require appropriate viscosity of drilling fluid to facilitate pumping, circulate the cuttings, and transfer them to the surface.
The document discusses various factors to consider when selecting drilling fluids, including abnormal pressures, active clays, high temperatures, drilling and hole cleaning efficiency, rate of penetration, cuttings transport, cuttings properties, hydraulics, formation damage, corrosion, lubricity, and gas hydrates. It provides details on each of these factors and how they relate to drilling fluid selection. The document also discusses solid control in drilling fluids, including methods such as settling, dilution, mechanical separation, and chemical treatment to control solids based on particle size.
Field Lubricity Measurements Correlate with Improved Performance of Novel Wat...jerianasmith
A significant function of drilling fluids is reduction of frictional forces between the wellbore and the drill string. New techniques in drilling and completions are being used to drill horizontal wells in unconventional resources.
This document discusses drilling fluids and their properties. It provides an overview of the principal functions of drilling fluids, which include subsurface pressure control, cuttings removal and transport, suspension of solid particles, sealing of permeable formations, stabilizing the wellbore, preventing formation damage, cooling and lubricating the bit, transmitting hydraulic horsepower to the bit, facilitating collection of formation data, partial support of the drill string and casing weights, controlling corrosion, and assisting in cementing and completion. It also discusses drilling fluid classifications, properties such as viscosity and rheology, and key components of drilling fluids.
This document provides information about drilling fluids used in oil and gas drilling operations. It discusses the key components and functions of drilling fluids, including bringing cuttings to the surface, controlling subsurface pressures, lubricating and cooling the drill bit. It also describes various types of drilling fluids like water-based muds, calcium muds, lignosulphonate muds, and KCl/polymer muds. The document discusses the role of clays and colloid chemistry in drilling fluids and outlines the properties and uses of different clay minerals.
This document discusses the environmental sustainability of drilling fluids. It outlines various additives used in drilling fluids and their potential environmental effects, such as barite containing heavy metals that can impact aquatic life. Alternatives to traditional additives are proposed, such as using bacteria or biodegradable compounds. The document also covers drilling fluid waste management and disposal options like biosorption to reduce the impact of waste before disposal. It concludes that a balance is needed between well drilling requirements and environmental considerations when developing more sustainable drilling fluid solutions.
This document discusses sustainable drilling fluid solutions. It begins with basic terminology used in drilling fluids like mud types, additives, and functions of mud. Water-based mud and oil-based mud are compared, noting that WBM is less toxic and can meet environmental issues but is not stable above 400°F, while OBM is stable above 400°F but more toxic. New developments in bio-polymers are discussed that can viscosify drilling fluids with less toxicity and better stability. In conclusion, water-based muds with bio-polymers are the most sustainable option while also addressing environmental concerns related to drilling fluids.
This document summarizes a presentation about drilling fluids. It defines drilling fluid as a mixture of clay and chemicals pumped through a drill bit to provide hydrostatic pressure, suspend cuttings, cool and lubricate the bit, and provide information from the wellbore. The presentation covers the types of drilling fluids, their functions, additives used, and rheological properties measured. It also describes the drilling fluid circulation system and discusses drilling fluid considerations and emergency remedies.
The formulation of drilling fluid is one of the most important aspects in drilling engineering. This is because the drilling fluid is capable of lubricating and cooling the drill bit and drill string as well as carrying cuttings out of the borehole. All of these functions require appropriate viscosity of drilling fluid to facilitate pumping, circulate the cuttings, and transfer them to the surface.
The document discusses various factors to consider when selecting drilling fluids, including abnormal pressures, active clays, high temperatures, drilling and hole cleaning efficiency, rate of penetration, cuttings transport, cuttings properties, hydraulics, formation damage, corrosion, lubricity, and gas hydrates. It provides details on each of these factors and how they relate to drilling fluid selection. The document also discusses solid control in drilling fluids, including methods such as settling, dilution, mechanical separation, and chemical treatment to control solids based on particle size.
Field Lubricity Measurements Correlate with Improved Performance of Novel Wat...jerianasmith
A significant function of drilling fluids is reduction of frictional forces between the wellbore and the drill string. New techniques in drilling and completions are being used to drill horizontal wells in unconventional resources.
Introduction to Drilling Fluid /or Mud used to drill Oil and Gas Wells into the sub-surface Hydrocarbon Reservoir. Overview of the rheological properties and general description.
This document analyzes the genetic factors that can lead to low resistivity reservoirs. It identifies six main factors: 1) low amplitude structure where differentiation of oil and water is poor, leading to high water saturation and low resistivity; 2) complex pore structure that increases fixed water content and decreases resistivity; 3) additional electrical conductivity from clays like montmorillonite that reduces resistivity; 4) thin sand-mud interlayers that limit logging tool resolution; 5) reservoirs containing conductive minerals like pyrite; and 6) low salinity formation water enhancing clay conductivity effects. The document concludes more research is needed on logging evaluation and identification methods for low resistivity reservoirs.
IJERA (International journal of Engineering Research and Applications) is International online, ... peer reviewed journal. For more detail or submit your article, please visit www.ijera.com
Determining the Sand Content in Various Compositions of Drilling MudIRJESJOURNAL
Abstract :- Drilling is an important part of the oil industry and penetration rate must be enhanced to ensure speedy completion of drilling operation. Weight on bit, Rotary speed, drill bit type, formation characteristics and mud properties are the basic factors that affect the penetration rate of a bit. Regular determination of the sand content of drilling mud is necessary because these particles can be highly abrasive, and can cause excessive wear of pump parts, drill bits, and pipe connections, excessive sand may also result in the deposition of a thick filter cake on the walls of the hole, or it may settle in the hole around the tools when circulation is temporarily halted, interfering with the operation of drilling tools of settling casing. The sand content test for set is used in the test for sand content determination using Bariod sand content set.
This document discusses various types of formation damage that can occur including plugging by solid particles, plugging by formation solids, clay swelling, dispersion of clayey platelets, water block, emulsion formation, precipitation of inorganic scales, precipitation related to acidizing, mechanical damage, paraffin deposition, precipitation of asphaltene, wettability alteration, reduced relative permeability, sludge formation, damage by bacteria, polymer invasion, and gas breakout. Formation damage refers to any process that reduces permeability in the formation near the wellbore and decreases productivity over time. Common causes include invasion of foreign solids or fluids, changes in wettability, mineral precipitation, and bacterial growth. Proper design of completion and stimulation methods
Hydraulic fracturing involves pumping water mixed with proppant and additives into wells at high pressure to create fractures in rock formations and stimulate oil and gas production. The first successful hydraulic fracturing jobs occurred in the 1940s and 1950s. The process involves pad, slurry, and flowback stages. Parameters like in-situ stress, elastic properties, and fluid properties are considered for fracturing design. Fluid additives are used to carry proppant into the fracture and improve fluid properties. Pre-fracturing tests like step-rate and pump-in/flowback tests help determine fracture and closure pressures. Hydraulic fracturing has enabled production from tight shale and coalbed methane reservoirs.
Analyzing Effects of Various Kinds of Multi-Wall Carbo Nanotubes (MWCNT) on P...crimsonpublisherscojrr
Due to the significance and unique properties of Multi-Wall Carbon Nanotubes (MWCNT), in the present investigation, the viability of these materials in the Water-Based Mud (WBM) is assessed. The impacts of various kinds of MWCNT, mud additives and surfactants on the rheological properties, water loss and drilling fluid stability of the WBM are experimentally investigated. The results have demonstrated various kinds of MWCNT, additives, and surfactants have affected the rheological properties of the WBM. Adding MWCNT and Polyethylene Glycol (PEG) alone or together decrease the terms of rheological properties performance as subsequent order CNT; CNT + PEG; PEG. Surface modified carbon nanotube (Functionalize Carbon Nano Tube [FCNT]) improves rheological properties of the WBM and increases the shale recovery. All in all, the presence of Multi-Wall Carbon Nanotubes increases the efficiency of polymers and improves the rheological properties and performance of the water base mud.
International Journal of Engineering Research and Applications (IJERA) is an open access online peer reviewed international journal that publishes research and review articles in the fields of Computer Science, Neural Networks, Electrical Engineering, Software Engineering, Information Technology, Mechanical Engineering, Chemical Engineering, Plastic Engineering, Food Technology, Textile Engineering, Nano Technology & science, Power Electronics, Electronics & Communication Engineering, Computational mathematics, Image processing, Civil Engineering, Structural Engineering, Environmental Engineering, VLSI Testing & Low Power VLSI Design etc.
This document discusses hydraulic fracturing, which is a well stimulation technique used to increase production from low permeability reservoirs. It involves injecting fluid into the wellbore at high pressure to create fractures in the rock formation. Proppants, such as sand or ceramic beads, are placed in the fractures to keep them open after pressure is removed. Key aspects covered include fracture modeling, optimization of fracture size and conductivity, candidate well selection, and a case study showing production increases from hydraulic fracturing treatment.
The document discusses the use of calcium carbonate as an additive in drilling fluids. It notes that calcium carbonate can be used to increase the density of drilling fluids, control fluid losses, and prevent formation damage. The document also outlines how calcium carbonate is used specifically as a weighting agent, in drill-in fluids, and as a lost circulation material to seal fractures and cracks in formations.
Drilling fluids are absolutely essential during the drilling process and considered the primary well control.
Know more now about such a very important component of the drilling process.
Rheology of Fluids Hydraulic Calculations & Drilling Fluid (Mud) Filtration T...Shaoor Kamal
This document summarizes two experiments conducted to investigate the rheology of drilling fluids and their filtration properties. In Experiment 2, the rheological behavior of two mud samples (Mud A and Mud B) was analyzed using a viscometer. Both muds exhibited similar shear thinning properties and were best described by the Herschel-Bulkley and power law rheological models. In Experiment 3, the filtration properties of the two muds were examined by measuring filter cake buildup and fluid invasion over time. Key results showed that the muds had similar rheology and filtration behavior.
Prevention of dynamic sag in deepwater invert emulsion fluidamrhaggag
This document summarizes laboratory and field testing of a new sag-preventing organophilic clay (SPOC) additive for controlling barite sag in invert emulsion drilling fluids for deepwater wells. Laboratory tests showed the SPOC improved low-shear rheology and reduced sag compared to conventional organoclays. Field tests in two deepwater Gulf of Mexico wells demonstrated the SPOC, combined with a conventional organoclay, maintained rheology while minimizing sag during drilling and extended well logging periods. The SPOC additive successfully controlled barite sag in challenging deepwater drilling applications.
DAMAGE ISSUES IMPACTING THE PRODUCTIVITY OF TIGHT GAS PRODUCING FORMATIONS; Formation Damage; Fracturing/Refracturing; Hydraulically Fractured; Tight Gas Reservoir; Economic Tight Gas Reservoir Production
The slides are related to the new type of mud usage technologies that are basicllay not used for common purposes. These slides have a complete description of aphron and synthetic muds that we are using in the petroleum industry during the drilling phase in our we can say performance drilling
Damage control technology of oil-based drilling fluid for shale and tight san...eSAT Journals
Abstract In drilling fluid systems, oil-based drilling fluid have advantages of protecting reservoir and keeping borehole stability in traditional recognition, it also have advantages of high temperature resistance, salt and calcium resistance, good lubricity and low damage, these all let oil-based drilling fluid as an important mean of complex formation drilling for high temperature deep well, high angle directional well, horizontal well and so on. But oil-based drilling fluid has the following damage: drilling fluid invade into formation and cause wettability change of rock surface; oil phase enter into formation and cause the reduce of effective flow area; emulsion block formation; migration of oil-wet solid-phase particles, solid-phase particle invasion and so on would also bring many damages to formation. This study analyzed the current situation and challenge of oil-based drilling fluid, put forward solutions, and provided some references for reservoir protection of oil-based drilling fluid.
Keywords: Oil-Based Drilling Fluid, Reservoir Protection, Wettability, Oil-Phase Trapping
This paper discusses how controlling interfacial tensions between fluids and solids using micro-solution technologies can optimize production from mature, low pressure, under saturated, and low permeability reservoirs. Laboratory testing showed that treating a drilling fluid with micro-solutions reduced filtercake lift-off pressures from 10,000 kPa to 37 kPa and allowed 100% permeability regain. Field trials of wells drilled with micro-solution treated fluids showed better initial production and flow rates compared to analog wells drilled with untreated fluids. The micro-solutions reduce interfacial tensions by over 50%, improving flowback and optimizing permeability to hydrocarbons.
Determining Loss of Liquid from Different Types of Mud by Various Addictives ...IRJESJOURNAL
Abstract :- Filtration is used in many industries to separate water from the solid. It is important to find fluid loss in drilling, cementing, fracturing, and almost every other type of downhole treatment design. The filter cake characterization is very essential for well selection of drilling fluid problems and formation damage. Therefore this study is taken up to experimentally investigate the effect of different concentrations of CMC, Starch, Wood fibers, Soda ash, Caustic soda, Bentonite and Barite on filtration loss and formation damages. Three different samples are used in this study at different concentration and a comparison is made. Although the discussion presented here is confined to fluid loss during drilling. Water-based drilling mud’s including Bentonite is wellknown and is being widely used in the petroleum industry. Among the important functions of water-based drilling fluid were to form filter cake on the wall of the well bore, prevent water leakage, and maintain the stability of the well wall. The properties of the water-based drilling fluid, such as the rheology and filtration loss, are affected by the fluid loss additive. Polymers, which are nontoxic, degradable, and environment friendly, are the best choice to be used as drilling fluids additives.
- The document discusses reservoir characteristics including rock and fluid properties that are important to understand for optimal hydrocarbon recovery. Techniques like seismic data, well logging, and testing provide valuable data to build reservoir models.
- Key rock properties that impact hydrocarbon storage and flow include porosity, permeability, and wettability. Core analysis in the lab and well logs provide data on these properties.
- Understanding fluid properties like phase behavior under reservoir conditions of pressure and temperature is also important for predicting production performance and fluid composition.
This document discusses reservoir characteristics, rock and fluid properties, and drive mechanisms. It provides information on:
1) Techniques like seismic data, well logging, core analysis, and well testing that are used to understand the reservoir and develop an accurate reservoir model.
2) Reservoir characteristics including rock type, porosity, permeability, and factors that allow hydrocarbon accumulation like sufficient pore space and traps.
3) Rock properties such as porosity, permeability, and how they impact fluid flow.
4) Fluid properties including phase behavior under varying pressures and temperatures, properties of different fluid types, and sampling techniques.
5) Common experiments done to analyze reservoir fluids using pressure-volume-temperature cells
Introduction to Drilling Fluid /or Mud used to drill Oil and Gas Wells into the sub-surface Hydrocarbon Reservoir. Overview of the rheological properties and general description.
This document analyzes the genetic factors that can lead to low resistivity reservoirs. It identifies six main factors: 1) low amplitude structure where differentiation of oil and water is poor, leading to high water saturation and low resistivity; 2) complex pore structure that increases fixed water content and decreases resistivity; 3) additional electrical conductivity from clays like montmorillonite that reduces resistivity; 4) thin sand-mud interlayers that limit logging tool resolution; 5) reservoirs containing conductive minerals like pyrite; and 6) low salinity formation water enhancing clay conductivity effects. The document concludes more research is needed on logging evaluation and identification methods for low resistivity reservoirs.
IJERA (International journal of Engineering Research and Applications) is International online, ... peer reviewed journal. For more detail or submit your article, please visit www.ijera.com
Determining the Sand Content in Various Compositions of Drilling MudIRJESJOURNAL
Abstract :- Drilling is an important part of the oil industry and penetration rate must be enhanced to ensure speedy completion of drilling operation. Weight on bit, Rotary speed, drill bit type, formation characteristics and mud properties are the basic factors that affect the penetration rate of a bit. Regular determination of the sand content of drilling mud is necessary because these particles can be highly abrasive, and can cause excessive wear of pump parts, drill bits, and pipe connections, excessive sand may also result in the deposition of a thick filter cake on the walls of the hole, or it may settle in the hole around the tools when circulation is temporarily halted, interfering with the operation of drilling tools of settling casing. The sand content test for set is used in the test for sand content determination using Bariod sand content set.
This document discusses various types of formation damage that can occur including plugging by solid particles, plugging by formation solids, clay swelling, dispersion of clayey platelets, water block, emulsion formation, precipitation of inorganic scales, precipitation related to acidizing, mechanical damage, paraffin deposition, precipitation of asphaltene, wettability alteration, reduced relative permeability, sludge formation, damage by bacteria, polymer invasion, and gas breakout. Formation damage refers to any process that reduces permeability in the formation near the wellbore and decreases productivity over time. Common causes include invasion of foreign solids or fluids, changes in wettability, mineral precipitation, and bacterial growth. Proper design of completion and stimulation methods
Hydraulic fracturing involves pumping water mixed with proppant and additives into wells at high pressure to create fractures in rock formations and stimulate oil and gas production. The first successful hydraulic fracturing jobs occurred in the 1940s and 1950s. The process involves pad, slurry, and flowback stages. Parameters like in-situ stress, elastic properties, and fluid properties are considered for fracturing design. Fluid additives are used to carry proppant into the fracture and improve fluid properties. Pre-fracturing tests like step-rate and pump-in/flowback tests help determine fracture and closure pressures. Hydraulic fracturing has enabled production from tight shale and coalbed methane reservoirs.
Analyzing Effects of Various Kinds of Multi-Wall Carbo Nanotubes (MWCNT) on P...crimsonpublisherscojrr
Due to the significance and unique properties of Multi-Wall Carbon Nanotubes (MWCNT), in the present investigation, the viability of these materials in the Water-Based Mud (WBM) is assessed. The impacts of various kinds of MWCNT, mud additives and surfactants on the rheological properties, water loss and drilling fluid stability of the WBM are experimentally investigated. The results have demonstrated various kinds of MWCNT, additives, and surfactants have affected the rheological properties of the WBM. Adding MWCNT and Polyethylene Glycol (PEG) alone or together decrease the terms of rheological properties performance as subsequent order CNT; CNT + PEG; PEG. Surface modified carbon nanotube (Functionalize Carbon Nano Tube [FCNT]) improves rheological properties of the WBM and increases the shale recovery. All in all, the presence of Multi-Wall Carbon Nanotubes increases the efficiency of polymers and improves the rheological properties and performance of the water base mud.
International Journal of Engineering Research and Applications (IJERA) is an open access online peer reviewed international journal that publishes research and review articles in the fields of Computer Science, Neural Networks, Electrical Engineering, Software Engineering, Information Technology, Mechanical Engineering, Chemical Engineering, Plastic Engineering, Food Technology, Textile Engineering, Nano Technology & science, Power Electronics, Electronics & Communication Engineering, Computational mathematics, Image processing, Civil Engineering, Structural Engineering, Environmental Engineering, VLSI Testing & Low Power VLSI Design etc.
This document discusses hydraulic fracturing, which is a well stimulation technique used to increase production from low permeability reservoirs. It involves injecting fluid into the wellbore at high pressure to create fractures in the rock formation. Proppants, such as sand or ceramic beads, are placed in the fractures to keep them open after pressure is removed. Key aspects covered include fracture modeling, optimization of fracture size and conductivity, candidate well selection, and a case study showing production increases from hydraulic fracturing treatment.
The document discusses the use of calcium carbonate as an additive in drilling fluids. It notes that calcium carbonate can be used to increase the density of drilling fluids, control fluid losses, and prevent formation damage. The document also outlines how calcium carbonate is used specifically as a weighting agent, in drill-in fluids, and as a lost circulation material to seal fractures and cracks in formations.
Drilling fluids are absolutely essential during the drilling process and considered the primary well control.
Know more now about such a very important component of the drilling process.
Rheology of Fluids Hydraulic Calculations & Drilling Fluid (Mud) Filtration T...Shaoor Kamal
This document summarizes two experiments conducted to investigate the rheology of drilling fluids and their filtration properties. In Experiment 2, the rheological behavior of two mud samples (Mud A and Mud B) was analyzed using a viscometer. Both muds exhibited similar shear thinning properties and were best described by the Herschel-Bulkley and power law rheological models. In Experiment 3, the filtration properties of the two muds were examined by measuring filter cake buildup and fluid invasion over time. Key results showed that the muds had similar rheology and filtration behavior.
Prevention of dynamic sag in deepwater invert emulsion fluidamrhaggag
This document summarizes laboratory and field testing of a new sag-preventing organophilic clay (SPOC) additive for controlling barite sag in invert emulsion drilling fluids for deepwater wells. Laboratory tests showed the SPOC improved low-shear rheology and reduced sag compared to conventional organoclays. Field tests in two deepwater Gulf of Mexico wells demonstrated the SPOC, combined with a conventional organoclay, maintained rheology while minimizing sag during drilling and extended well logging periods. The SPOC additive successfully controlled barite sag in challenging deepwater drilling applications.
DAMAGE ISSUES IMPACTING THE PRODUCTIVITY OF TIGHT GAS PRODUCING FORMATIONS; Formation Damage; Fracturing/Refracturing; Hydraulically Fractured; Tight Gas Reservoir; Economic Tight Gas Reservoir Production
The slides are related to the new type of mud usage technologies that are basicllay not used for common purposes. These slides have a complete description of aphron and synthetic muds that we are using in the petroleum industry during the drilling phase in our we can say performance drilling
Damage control technology of oil-based drilling fluid for shale and tight san...eSAT Journals
Abstract In drilling fluid systems, oil-based drilling fluid have advantages of protecting reservoir and keeping borehole stability in traditional recognition, it also have advantages of high temperature resistance, salt and calcium resistance, good lubricity and low damage, these all let oil-based drilling fluid as an important mean of complex formation drilling for high temperature deep well, high angle directional well, horizontal well and so on. But oil-based drilling fluid has the following damage: drilling fluid invade into formation and cause wettability change of rock surface; oil phase enter into formation and cause the reduce of effective flow area; emulsion block formation; migration of oil-wet solid-phase particles, solid-phase particle invasion and so on would also bring many damages to formation. This study analyzed the current situation and challenge of oil-based drilling fluid, put forward solutions, and provided some references for reservoir protection of oil-based drilling fluid.
Keywords: Oil-Based Drilling Fluid, Reservoir Protection, Wettability, Oil-Phase Trapping
This paper discusses how controlling interfacial tensions between fluids and solids using micro-solution technologies can optimize production from mature, low pressure, under saturated, and low permeability reservoirs. Laboratory testing showed that treating a drilling fluid with micro-solutions reduced filtercake lift-off pressures from 10,000 kPa to 37 kPa and allowed 100% permeability regain. Field trials of wells drilled with micro-solution treated fluids showed better initial production and flow rates compared to analog wells drilled with untreated fluids. The micro-solutions reduce interfacial tensions by over 50%, improving flowback and optimizing permeability to hydrocarbons.
Determining Loss of Liquid from Different Types of Mud by Various Addictives ...IRJESJOURNAL
Abstract :- Filtration is used in many industries to separate water from the solid. It is important to find fluid loss in drilling, cementing, fracturing, and almost every other type of downhole treatment design. The filter cake characterization is very essential for well selection of drilling fluid problems and formation damage. Therefore this study is taken up to experimentally investigate the effect of different concentrations of CMC, Starch, Wood fibers, Soda ash, Caustic soda, Bentonite and Barite on filtration loss and formation damages. Three different samples are used in this study at different concentration and a comparison is made. Although the discussion presented here is confined to fluid loss during drilling. Water-based drilling mud’s including Bentonite is wellknown and is being widely used in the petroleum industry. Among the important functions of water-based drilling fluid were to form filter cake on the wall of the well bore, prevent water leakage, and maintain the stability of the well wall. The properties of the water-based drilling fluid, such as the rheology and filtration loss, are affected by the fluid loss additive. Polymers, which are nontoxic, degradable, and environment friendly, are the best choice to be used as drilling fluids additives.
- The document discusses reservoir characteristics including rock and fluid properties that are important to understand for optimal hydrocarbon recovery. Techniques like seismic data, well logging, and testing provide valuable data to build reservoir models.
- Key rock properties that impact hydrocarbon storage and flow include porosity, permeability, and wettability. Core analysis in the lab and well logs provide data on these properties.
- Understanding fluid properties like phase behavior under reservoir conditions of pressure and temperature is also important for predicting production performance and fluid composition.
This document discusses reservoir characteristics, rock and fluid properties, and drive mechanisms. It provides information on:
1) Techniques like seismic data, well logging, core analysis, and well testing that are used to understand the reservoir and develop an accurate reservoir model.
2) Reservoir characteristics including rock type, porosity, permeability, and factors that allow hydrocarbon accumulation like sufficient pore space and traps.
3) Rock properties such as porosity, permeability, and how they impact fluid flow.
4) Fluid properties including phase behavior under varying pressures and temperatures, properties of different fluid types, and sampling techniques.
5) Common experiments done to analyze reservoir fluids using pressure-volume-temperature cells
DRILLING FLUIDS FOR THE HPHT ENVIRONMENTMohan Doshi
A BRIEF REVIEW OF THE DRILLING FLUIDS FOR DRILLING HPHT WELLS. HPHT WELLS ARE NOT BUSINESS AS USUAL AND THE SAME APPLIES TO HPHT DRILLING FLUIDS. THE FLUID CHEMISTRY AND THE FLUID COMPOSITION HAVE TO BE TAILORED TO MEET THE RIGORS OF THE HIGH TEMPERATURE ENVIRONMENT
The document discusses permeability and describes permeability as a property that measures how easily fluids can move through pore spaces in a material. It then discusses several methods to test permeability, including laboratory methods like the constant head and falling head permeability tests, and field methods like pumping tests. Finally, it outlines some common uses of permeability testing, such as determining suitability of soil for construction or wastewater treatment systems.
This document discusses fluid loss additive in water based mud. It begins with an introduction that describes the functions and importance of drilling fluids. It then discusses the preparation and extraction of cellulose from rich gourd loofah as a potential fluid loss additive. The document presents the results of formulating different mud samples with varying concentrations of rich gourd cellulose and compares them to a standard mud containing polyanionic cellulose. It found that rich gourd cellulose performed better at reducing fluid loss and improving rheological properties compared to the standard.
Viscosity and yield point exp. by jarjis
Experiment Number 5: Yield Point.
Koya University.
Faculty of Engineering.
Drilling Lab
Supervised By Muhammad Jamal
Determine Plastic Viscosity, Apparent Viscosity, And Yield point of a drilling fluid (mud) by using Fann VG viscometer.
=============
This a report about Filtration. written by Jarjis Muhammad, Petroleum Engineering Dep. Koya University. For more Information please contact me: www.facebook.com/Jarjis.shaqlawaee
1. Hydraulic Fracturing and It’s Process 2
What is hydraulic fracturing? 2
Hydraulic Fracturing Process 3
2. Importance and Application of Hydraulic Fracturing in Shale Formation 4
Importance of Hydraulic Fracturing 4
Hydraulic Fracturing in Shale Formation 5
3. Inflow Performance Relationship (IPR) 6
1. What is IPR and uses of IPR? 6
2. List three main factors affecting IPR? 7
3. Explain inflow and outflow performance? 7
4. Artificial Lift Method and Its Application 8
Application of Artificial Lift 8
Hydraulic pumps 9
Beam pumps 10
5. Electric Submersible Pumps 12
6. Gas Lift Method 13
Determination of Mud and Rheology of Biodiesel Using Xantan Gum and PAMIRJESJOURNAL
Abstract :- The idea behind the current work is to determining the mud and biodiesel rheology (surface
tension, viscosity) by using Xanthan Gum and PAM (polyacrylamide) (-CH2CHCONH2-).The mud used in this
work is barite and bentonites at different samples to know the difference in their specific gravity, viscosity,
surface tension, and PH of the samples when chemical additives are added. And comparing this value with the
oil based mud’s which is prepared with biodiesel to reduce the impact of toxicity and make the environment
friendly drilling fluids.
IRJET- Dispersive Soils-Characterization, Problems and RemediesIRJET Journal
This document discusses dispersive soils, which are soils that easily disperse or break apart when exposed to flowing water. Dispersive soils can cause problems for earth structures and embankments. The document describes various tests that can identify dispersive soils, including the crumb test, double hydrometer test, and pinhole test. It also discusses how the mineralogy and chemistry of soils, particularly the presence of sodium ions, can cause soils to disperse. Remedies for stabilizing dispersive soils include adding amendments to change the soil chemistry.
1. The document discusses a study on the effect of contamination on water-based drilling mud. Salt (NaCl) was added to fresh water mud at 0.1% to study its effects.
2. Testing found that adding NaCl increased the mud density to 9.08 ppg and maintained a pH of 8. Filtrate volume was measured at 22 cc after 30 minutes. Mud cake thickness was recorded as 3.42 mm.
3. The plastic viscosity was 6 cP, apparent viscosity was 20 cP, and yield point was 28 lb/100ft2. Gel strengths were 30 lb/100ft2 at 10 seconds and 31 lb/100ft2 at 10 minutes.
This document discusses drilling fluids and their applications. It begins by introducing drilling fluids as the "blood" of drilling operations, accounting for over 20% of operating costs. It then discusses the types of drilling fluids (water-based muds, oil-based muds, synthetic-based muds), their functions, properties, composition, classifications based on rheological models, design, and the effects of high pressure and high temperature on fluid properties. The document provides a comprehensive overview of drilling fluids to understand their formulation and optimization for drilling operations.
International Journal of Engineering Research and Applications (IJERA) is an open access online peer reviewed international journal that publishes research and review articles in the fields of Computer Science, Neural Networks, Electrical Engineering, Software Engineering, Information Technology, Mechanical Engineering, Chemical Engineering, Plastic Engineering, Food Technology, Textile Engineering, Nano Technology & science, Power Electronics, Electronics & Communication Engineering, Computational mathematics, Image processing, Civil Engineering, Structural Engineering, Environmental Engineering, VLSI Testing & Low Power VLSI Design etc.
The document discusses drilling fluids, including their types, functions, properties, and additives. There are two main types of drilling fluids: water-based and oil-based. Drilling fluids must perform several key functions, such as controlling subsurface pressures, removing cuttings from the wellbore, lubricating the drill bit, and maintaining wellbore stability. Various additives are used to achieve the desired properties, including weighting agents, viscosifiers, filtration control agents, and lost circulation materials. The selection of drilling fluids requires consideration of formation and drilling conditions.
The document discusses drilling fluids, including their types, functions, properties, additives, and equipment/design considerations. The key types are water-based and oil-based muds. Drilling fluids must perform critical functions like controlling subsurface pressures, removing cuttings from the wellbore, lubricating the drill bit, and maintaining wellbore stability. Achieving these functions depends on optimizing properties like density, viscosity, and gel strength through the use of various additives like weighting agents, viscosifiers, and filtration control materials. Careful fluid selection and design is needed based on formation data and drilling conditions.
This document provides information on various topics related to well planning and design, including:
- Well data requirements such as detailed lithology, formation fluids, reservoir data, and pressure data.
- Global basin screening, basin analysis, play analysis, prospect analysis, rock types, and reactive formations.
- Exploration strategy, including global basin analysis, basin analysis, play analysis, prospect analysis, and prospect volume estimation.
- Pore pressure and fracture pressure determination, including leakage tests to estimate the fracture gradient at casing seats.
This document discusses drilling fluids, including their types, functions, properties, and additives. It covers the main types of drilling fluids as water-based and oil-based, and their key functions such as removing cuttings from the wellbore, maintaining wellbore pressure and stability, lubricating and cooling the drill bit. The most common additives are described, including weighting materials to increase mud density, viscosifiers to suspend cuttings and materials, and other additives that control filtration, rheology, alkalinity and other properties. Selection of the appropriate drilling fluid depends on formation data and requirements for each well section.
This document provides an overview of drilling fluids. It discusses the key functions of drilling fluids, including transporting cuttings to the surface, cleaning the drill bit, providing hydrostatic pressure, preventing fluid loss, and lubricating and cooling the drill string. It also describes common drilling fluid types like water-based and oil-based muds. Important drilling fluid properties are defined, such as density, viscosity, gel strength, and fluid loss. Common drilling fluid additives and their purposes are explained. Hazards that can be addressed by proper fluid selection and properties management are also outlined.
Abstract This case study examines the formation damage that occurred i.pdfatozbazar
Abstract This case study examines the formation damage that occurred in an oil field located in
the Casanare region of Colombia. The oil field had been producing oil for several years, but the
operators noticed a significant decline in production rates. The investigation revealed that the
well was suffering from severe formation damage, which was caused by the accumulation of
drilling fluids and other contaminants in the reservoir. To address the formation damage, the
operators implemented a variety of remediation techniques, including acid stimulation, matrix
acidizing, and hydraulic fracturing. These techniques were designed to dissolve the contaminants
in the reservoir and increase the permeability of the formation, allowing oil to flow more easily
to the wellbore and to the understanding of formation damage mechanisms. The Ruba field is
one of the largest oil fields in Colombia and has been in production since the 1980 s. The oil
extracted from the Ruba field is a heavy crude oil, which requires more advanced refining
techniques to produce high-quality fuels. The Ruba field is operated by several major oil
companies, including Ecopetrol, the national oil company of Colombia. The concept of skin and
formation damage play a vital role in productivity of an oil well. The effect of formation damage
zone on the well flowing pressure was introduced to the original solution of diffusivity equation.
Formation damage reduces the well production. Skin defines as the area of reduced permeability
near the wellbore due to the invasion of drilling fluid into the reservoir rock. Classifying damage
requires a lot of work to determine correctly the main reason of it. In general, fluids can interact
with reservoir rock and cause formation damage that impedes hydrocarbon production. Tight
sandstone reservoir with well-developed natural fractures has a complex pore structure where
pores and pore throats have a wide range of diameters; formation damage in such type of
reservoir can be complicated and severe. Reservoir rock samples with a wide range of fracture
widths are tested through a several step core flood platform, where formation damage caused by
the drilling or fracturing fluid, where any unintentional fluid impedance in or out of a wellbore is
referred to as damage to formation. This general definition includes the flow restriction caused
by reduced permeability in the near wellbore region. Formation damage Description and
classification: The history of damage removal is a process that begins with the identification of
the issue. This usually involves looking through the various sources of information related to the
well, such as drilling records, completion designs, and operator experiments. The desired
purpose is to identify the causes of the formation damage and how it could be fixed. Where the
types of formation damage location of damage extent and screening of damage, and effect of
damage on well production or injection. Well development and res.
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Determination of Effect Bentonite and Additives On Drilling Fluids
1. International Refereed Journal of Engineering and Science (IRJES)
ISSN (Online) 2319-183X, (Print) 2319-1821
Volume 6, Issue 3 (March 2017), PP.22- 28
www.irjes.com 22 | Page
Determination of Effect Bentonite and Additives On Drilling
Fluids
Dr. A. Rajesh Kanna1,*
,Preethi2
,Syed Majid Ahmed Savi3
,Mujtaba Ahmed
Khan3
,Mohammed Abdul Rahman Khan3
1
Professor & HOD, Department Of Petroleum Engineering, LORDS Institute Of Engineering & Technology,
Hyderabad, India
2
Assitant Professor, Department Of Petroleum Engineering, LORDS Institute Of Engineering & Technology,
Hyderabad, India.
3
Undergraduate Student, Department Of Petroleum Engineering, LORDS Institute Of Engineering &
Technology, Hyderabad, India.
Abstract :- Drilling fluids Play a vital role in hole Cleaning suspension of cuttings, prevent caving, and ensure
the tightness of the well wall. Moreover they also help in cooling and lubricating the drilling tool, transfer the
hydraulic power and carry information about the nature of the drilled formation by raising the cuttings from the
bottom to the surface, using a simple mixture of water and clays, to complex mixtures of various specific
organic and inorganic products as additives. These additives improve fluid rheological properties and filtration
capability, allowing bits to penetrate heterogeneous geological formations The mud used in this work is barite
and bentonites at different samples to know the difference in their specific gravity, viscosity, surface tension,
and pH of the samples when chemical additives are added.
Keywords: - Mud, Mud rheology, Viscosity, Density, Drilling Fluid, Fluid Loss.
I. INTRODUCTION
Drilling deeper, longer and more challenging wells has been made possible by improvements in drilling
tech- nologies, including more efficient and effective drilling fluids. Drilling fluids, also referred to as drilling
mud, are added to the wellbore to facilitate the drilling process by suspending cuttings, controlling pressure,
stabilizing ex- posed rock, providing buoyancy, and cooling and lubricating. As early as the third century BC,
the Chinese were us- ing drilling fluids, in the form of water, to help permeate the ground when drilling for
hydrocarbons. The term “mud” was coined when at Spindle top in the US. Drillers ran a herd of cattle through a
watered-down field and used the resulting mud to lubricate the drill. While the technology and chemistry of
drilling fluids have become much more complex. Drilling fluids are essential to drilling success, both
maximizing recovery and minimizing the amount of time it takes to achieve first oil. The cost of the fluid
system often represents one of the single greatest capital outlays in drilling an oil well. To minimize the cost of
fluids and to ensure an efficient drilling program, the fluid properties must be maintained continuously during
the drilling operation. In addition, the high temperature & high pressure conditions faced in ultra-deep oil & gas
drilling environments pose major challenges for the fluids used in drilling operations. The degradation of
drilling fluids in these environments reduces drilling efficiency by slowing the rates of penetration & creates
severe problems that lead to leaving be- hind most of the oil unrecovered.
The rotational viscometer has been designed which permits the measurement of the rheological
properties of drilling muds and other non-Newtonian fluids under conditions equivalent to those in a deep
borehole (350˚F, 10,000 psi). The important mechanical features of this instrument are described, and its design
criteria are dis- cussed [1]. The flow equations for the novel configuration of the viscometer are derived and the
calibration procedures are described. The date and their interpretation, resulting from measurement of the flow
properties. and static gel strengths of homoionic montmorillonite suspensions at high temperatures and
pressures, are presented. Data are also presented for the flow behavior of typical drilling fluids at high
temperatures and pressures. The pressure losses in the drill pipe and the annulus de- pend critically upon the
flow parameters of the drilling fluid. Their work demonstrates the need to measure these parameters under
bottom-hole conditions in order to obtain a reliable estimate of the pressure losses in the mud system. Bentonite
is employed by industry to perform a multitude of jobs [3]. Certain industrial applications become apparent from
an understanding of the composition and structure of bentonite, and the properties they create. These properties
are utilized chiefly when the material is suspended in a liquid, usually water; or as a dried powder or granule.
Most industrial applications involve the swelling property of bentonite to form viscous water suspensions.
Depending upon the relative proportions of clay and water, these mixtures are used as bonding, plasticizing, and
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suspending agents. Bentonite disperses into colloidal particles and, accordingly, provide large surface areas per
unit weight of clay. This large surface area is a major reason why bentonite functions so well in stabilizing
emulsions, or as a medium to carry other chemicals. Bentonites react chemically with many organic materials to
form compounds which are used chiefly as gelling agents in a variety of organic liquids. Bentonite is selected
for each industrial need on the basis of type and quality. This selection is based principally on physical
properties, and chemistry of the bentonite becomes involved only to the extent that it influences the physical
properties. Drilling fluids are used in drilling operations to cool and lubricate the drill bit, remove rock debris
and drill cuttings from the site and to counteract down hole formation pressures. Research is being conducted to
develop nanoparticle-amended drilling fluids with enhanced functionalities. Such enhancements include
improved rheological, thermal, mechanical, magnetic and optical profiles. These drilling fluids will have close
to real time responsiveness (for example viscosity) to changing conditions down hole.
II. DRILLING FLUID
Drilling fluid or drilling mud is a component which was initially used to circulate cuttings from the
borehole to the surface. Other functions of drilling fluid are maintain wellbore stability, prevent formation fluids
flowing into the wellbore, and control formation pressure [1].
III. WATER-BASED MUD (WBM)
Water itself can be used as a drilling fluid. However, to maintain a better circulation of the Cuttings,
WBM requires some degree of viscosity. The viscosity of WBM is generated by the addition of clay or
polymers. There are two main purposes of adding clay which are first, increasing viscosity of the mud so that
improves the lifting capacity of cuttings and second, Building a filter cake (mud cake) in permeable zones to
prevent fluid loss [1].
IV. VISCOSITY
The viscosity of a fluid is a measure of its resistance to gradual deformation by shear stress or tensile
stress .For liquids, it corresponds to the informal concept of "thickness"; for example, honey has a much higher
viscosity than water. Viscosity is a property of the fluid which opposes the relative motion between the two
surfaces of the fluid in a fluid that are moving at different velocities. When the fluid is forced through a tube, the
particles which compose the fluid generally move more quickly near the tube's axis and more slowly near its
walls; therefore some stress is needed to overcome the friction between particle layers to keep the fluid moving.
For a given velocity pattern, the stress required is proportional to the fluid's viscosity. A fluid that has no
resistance to shear stress is known as an ideal fluid. Zero viscosity is observed only at very in super fluids.
Otherwise, all fluids have positive viscosity, and are technically said to be viscous or viscid. In common
parlance, however, a liquid is said to be viscous if its viscosity is substantially greater than that of water, and
may be described as mobile if the viscosity is noticeably less than water. A fluid with a relatively high viscosity,
such as pitch, may appear to be a solid.
pH
pH a numeric scale used to specify the acidity or basicity of an aqueous solution. It is approximately
the negative of the base 10 logarithm of the molar concentration, measured in units of moles per liter, of
hydrogen ions. More precisely it is the negative of the logarithm to base 10 of the activity of the hydrogen ion.
Solutions with a pH less than 7 are acidic and solutions with a pH greater than 7 are basic. Pure water is neutral,
at pH 7, being neither an acid nor a base. Contrary to popular belief, the pH value can be less than 0 or greater
than 14 for very strong acids and bases respectively
Filtration
Filtration occurs any time a permeable formation is exposed to a mud at a pressure higher than the
formation pressure. The pressure causes filtrate to flow into the rock and deposit mud solids on the walls of the
borehole. Thus, filtration causes two distinctly different types of problems-those due to filtrate invasion and
those due to filter cake deposition. The problems caused by filtrate invasion are not drilling problems, but are
formation evaluation and completion problems. Excessive fluid loss may cause flushing of the zone around a
wellbore to the extent that logging and formation test information is incorrect. This is normally not a problem
with weighted muds where filtration control is necessary for control of filter cake deposition. In clear water or
low solids muds, excessive flushing may present problems. Another problem is invasion of a formation by a
liquid that will greatly reduce the formation permeability. Consequently, the volume of filtrate lost is not as
important as the type of filtrate. From the standpoint of the drilling operation, the filter cake is of more concern
than the volume of filtrate. The filter cake has a direct bearing on such problems as differential pressure
sticking, torque and drag, lost circulation, and poor primary cement jobs. Our basic aim is to minimize the
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thickness and permeability of the deposited cake. High solids content can cause the fluid loss to be low but
result in a thick cake. (Baker Hughes 2011).
Density
The starting point of pressure control is the control of mud density. The weight of a column of mud in
the hole necessary to balance formation pressure is the reference point from which all pressure control
calculations are based. The required weight of the mud column establishes the density of the mud for any
specific case. Fortunately, density is one of our most accurate measurements. With a simple mud balance we are
able to weigh a mud to the nearest 0.1 lb. / gal, which is equivalent to 5.2 psi per 1000 ft. of mud column.
Bentonite: - Prehydrated bentonite is used to viscosify KCl-Polymer Muds. Bentonite also provides a
colloidal solid that can improve filter cake quality in freshly- prepared muds. Since bentonite will dehydrate
from the high salt content of the mud and lose viscosity over time, constant additions of bentonite may be
needed. When feasible, API “Nontreated” bentonite is recommended because it provides a noticeable reduction
in material requirements and also provides better mud performance.
Fig.1 Bentonite
PAM (polyacrylamide)
PAM is a polymer (-CH2CHCONH2-) formed from acrylamide subunits. It can be synthesized as a
simple linear-chain structure or cross-linked, typically using N.N methylenebisacrylamide. In the cross-linked
form, the possibility of the monomer being present is reduced even further. It is highly water-absorbent, forming
a soft gel when hydrated, used in such applications as polyacrylamide gel electrophoresis, and can also be called
ghost crystals when cross-linked, and in manufacturing soft contact lenses. In the straight-chain form, it is also
used as a thickener and suspending agent [2].
Fig.2 PAM (Polyacrylamide)
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Carboxymethylcellulose
Cellulosic polymers are added for filtration control. When chloride concentrations are below 50,000
mg/L, either technical-grade or regular- grades CMC are used for filtration control rather than PAC. High-
viscosity CMC is generally not used because it can have a deflocculating effect; therefore, pilot testing should
always be performed prior to treatment.
Fig.3 CMC
Starch:
Starch or amylum is a polymeric carbohydrate consisting of a large number of glucose units joined
by glycosidic bonds. This polysaccharide is produced by most green plants as an energy store. It is the most
common carbohydrate in human diets and is contained in large amounts in staple foods such
as potatoes, wheat, maize (corn), rice, and cassava.
Fig.4 Starch
V. EXPERIMENTAL PROCEDURES
1. Viscosity
To measure the viscosity we have two methods 1 is marsh funnel for higher quantity and method 2
viscosity cup for low quantity up to 100ml in the work we have used viscosity cup method for 100ml.prepare
the sample as required and pour the fluid in the cup by closing its hole which is present at the bottom of the cup
with the finger .now remove the finger and start the stopwatch and note the time required to empty the cup [3].
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Fig.6 Viscosity cup
2. pH
pH can be measured by two ways one litmus paper and pH meter.
Fig.7 pH meter
3. Density
To find density of any fluid mud balance can be used keep the scale on the fulcrum with the help of
knife edge now fill the cup with fluid and place the lid on it so that extra fluid flow out of the cup move the rider
according water bubble so the it comes in center now note the readings of the rider [4].
Fig. 8 Mud Balance
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Filtration
Fig.9 Filter press equipment
III Observations
Table 1
Table 2
Samples Sample 1 Sample 2 Sample 3 Sample 4 Sample 5 Sample 6
Bentonite 5gm 5gm 5gm 5gm 5 gm 5 gm
Barite 10gm 10gm 10gm 10gm 10gm 10gm
Water 150ml 150ml 150ml 150ml 150ml 150ml
Pam 5gm 10gm N/A N/A N/A N/A
Cmc N/A N/A 2 gm 4gm N/A N/A
Starch N/A N/A N/A N/A 5gm 10gm
Vicosity 18.94 22.33 130 139.3 16.94 21.20
PH Value 7.5 7.5 6.5 7 7 7.5
Specific
Gravity
1.54&96lb/cuft 1.89&106lb/cu
ft
1.081/122
lb/cuft
1.91&148
lb/
cu ft
1.03&64lb/cuft 1.21&72
lb/cuft
Fluid
Loss(ml)
12 11 0 2 0 4
IV RESULTS
According to the studies difference between adding bentonite and other additives, we got standard
readings. But when comparison of Bentonite and additives CMC has more viscosity than PAM and Starch.
Whereas pH Comparison PAM was found to be the highest and also fluid Loss in CMC is very Low compared
to other additives.
V CONCLUSION
Optimized drilling involves the selection of operating conditions that will require the least expense in
reaching the desired depth, without sacrificing requirements of personnel safety, environmental protection and
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productivity. Correct formulation of drilling fluid and its additives will be based on its relative ability to drill the
formations anticipated, while affording effective hole cleaning and well-bore stabilization. Based on this,
formulation 2 and 4 are preferable for cost effective and optimal design. The water based mud can be used in
low fluid loss region where as oil based can be used in high fluid loss region. The water based mud can be used
in high formation pressure region.
REFERENCE
[1] API (2004): Specification for Drilling–Fluid Materials, API Specification 13A, sixteenth Edition,
February, 2004.
[2] Baker Hughes (2011) Rheological properties, (synthetic-based mud)
[3] Trevor L. Hughes (2006), Schlumberger-Doll Research, Old Quarry Road, Ridge field.
[4] Z. Jiangeng (2011), Drilling and completion fluid, Editorial Board of Drilling and completion fluid,
Hebei China.