This document provides an overview of perforation for oil and gas wells. It discusses key objectives and components of perforation including shaped charges, explosives, perforating guns, and efficiency factors. It also covers well and reservoir characteristics relevant to perforation and provides equations for calculating perforation skin effects on well performance. The high-level goal of perforation is to establish communication between the wellbore and formation while maintaining reservoir inflow capacity.
This document discusses different types of well completion methods including open hole completion and cased hole completion. Open hole completion involves setting the production casing just above the pay zone and leaving the bottom hole uncased, allowing maximum exposure but inability to isolate zones. Cased hole completion involves cementing and perforating the production casing/liner selectively, allowing isolation of zones but risk of formation damage. Common cased hole methods are liner completions, selective perforations of casing, and cemented production tubing. Flow methods include casing flow, tubing and annulus flow, and single/multiple tubing flows.
Drill stem test (DST) is one of the most famous on-site well testing that is used to unveil critical reservoir and fluid properties such as reservoir pressure, average permeability, skin factor and well potential productivity index. It is relatively cheap on-site test that is done prior to well completion. Upon the DST results, usually, the decision of the well completion is taken.
The document discusses acid fracturing, which involves injecting acid at pressures greater than the reservoir's fracture pressure. This connects the wellbore to the natural fracture system and improves production from low permeability reservoirs. Acid fracturing is mostly used in carbonate reservoirs, where fractures are initiated using a fracturing fluid pad followed by acid. Conductivity is achieved through etching of rock minerals on the fracture faces. Factors like fluid leak-off, reaction rate, and temperature affect the etched fracture length. Simulation tools can be used to design treatment schedules to optimize fracture conductivity and length based on reservoir properties and fluid characteristics. Acid fracturing faces challenges like fracture closure and requires proper additive selection. It is widely applied in deep, hard carbon
The reservoir (rock porosity and permeability)salahudintanoli
Reservoir rock is the one of the important component in petroleum system i.e without it petroleum system is impossible. This presentation contain all necessary information regarding reservoir rock.
Introduction to Reservoir Rock & Fluid PropertiesM.T.H Group
This document discusses reservoir rock properties and how core samples are used to characterize reservoirs. Reservoir rocks must have porosity and permeability to store and transmit fluids. Core samples provide information on lithology, porosity, permeability and other properties essential for evaluating a reservoir's fluid storage and flow capabilities. Whole core samples are most representative but sidewall cores provide additional data points. Both core types are analyzed to understand factors like relative permeability needed for reservoir modeling and production forecasting.
The document discusses artificial lift, which refers to methods used to raise oil and gas from wells when the natural reservoir pressure has declined. It describes several types of artificial lift systems including beam pumping (also called sucker rod pumping), electric submersible pumps, gas lift, and plunger lift. Beam pumping is the most common type and involves using the up and down motion of a pump jack at the surface to actuate a downhole pump via sucker rods. Over 1 million oil wells worldwide use some type of artificial lift, with more than 750,000 relying on beam/sucker rod pumping. The document provides details on how beam pumping systems work and factors to consider when selecting artificial lift methods.
This document was produced as part of my final year project of training to obtain a petroleum engineering diploma.
The aim of this project is to make a comparative study between continuous and intermittent gas lift systems based on real data from an oil well in Algeria, and to choose the system best suited to increase the production of the well.
This study was carried out by a manual design using the method of “fixed pressure drop” for the continuous gas lift system and “fallback gradient” method for intermittent gas lift system.
We were able to determine at the end of this study that the system best suited to the current conditions of our well would be the intermittent gas lift system and we also proposed that it should be combine with the "plunger lift " system in order to increase the efficiency of the intermittent gas lift system by eliminating problems linked to the phenomenon of" fallback " thus increase the production of our wells.
This document contains slides from a presentation on well completions fundamentals. It discusses various aspects of well completions such as bottom hole completion techniques including perforated, open hole and liner completions. It also discusses perforations, the production string including tubing, packers and Christmas trees. The upper hole completion involves installing the production tubing, packers and the Christmas tree. Multiple completion configurations allow accessing multiple pay zones including single string and parallel string options. Horizontal and multilateral well completions also require specialized techniques and equipment.
This document discusses different types of well completion methods including open hole completion and cased hole completion. Open hole completion involves setting the production casing just above the pay zone and leaving the bottom hole uncased, allowing maximum exposure but inability to isolate zones. Cased hole completion involves cementing and perforating the production casing/liner selectively, allowing isolation of zones but risk of formation damage. Common cased hole methods are liner completions, selective perforations of casing, and cemented production tubing. Flow methods include casing flow, tubing and annulus flow, and single/multiple tubing flows.
Drill stem test (DST) is one of the most famous on-site well testing that is used to unveil critical reservoir and fluid properties such as reservoir pressure, average permeability, skin factor and well potential productivity index. It is relatively cheap on-site test that is done prior to well completion. Upon the DST results, usually, the decision of the well completion is taken.
The document discusses acid fracturing, which involves injecting acid at pressures greater than the reservoir's fracture pressure. This connects the wellbore to the natural fracture system and improves production from low permeability reservoirs. Acid fracturing is mostly used in carbonate reservoirs, where fractures are initiated using a fracturing fluid pad followed by acid. Conductivity is achieved through etching of rock minerals on the fracture faces. Factors like fluid leak-off, reaction rate, and temperature affect the etched fracture length. Simulation tools can be used to design treatment schedules to optimize fracture conductivity and length based on reservoir properties and fluid characteristics. Acid fracturing faces challenges like fracture closure and requires proper additive selection. It is widely applied in deep, hard carbon
The reservoir (rock porosity and permeability)salahudintanoli
Reservoir rock is the one of the important component in petroleum system i.e without it petroleum system is impossible. This presentation contain all necessary information regarding reservoir rock.
Introduction to Reservoir Rock & Fluid PropertiesM.T.H Group
This document discusses reservoir rock properties and how core samples are used to characterize reservoirs. Reservoir rocks must have porosity and permeability to store and transmit fluids. Core samples provide information on lithology, porosity, permeability and other properties essential for evaluating a reservoir's fluid storage and flow capabilities. Whole core samples are most representative but sidewall cores provide additional data points. Both core types are analyzed to understand factors like relative permeability needed for reservoir modeling and production forecasting.
The document discusses artificial lift, which refers to methods used to raise oil and gas from wells when the natural reservoir pressure has declined. It describes several types of artificial lift systems including beam pumping (also called sucker rod pumping), electric submersible pumps, gas lift, and plunger lift. Beam pumping is the most common type and involves using the up and down motion of a pump jack at the surface to actuate a downhole pump via sucker rods. Over 1 million oil wells worldwide use some type of artificial lift, with more than 750,000 relying on beam/sucker rod pumping. The document provides details on how beam pumping systems work and factors to consider when selecting artificial lift methods.
This document was produced as part of my final year project of training to obtain a petroleum engineering diploma.
The aim of this project is to make a comparative study between continuous and intermittent gas lift systems based on real data from an oil well in Algeria, and to choose the system best suited to increase the production of the well.
This study was carried out by a manual design using the method of “fixed pressure drop” for the continuous gas lift system and “fallback gradient” method for intermittent gas lift system.
We were able to determine at the end of this study that the system best suited to the current conditions of our well would be the intermittent gas lift system and we also proposed that it should be combine with the "plunger lift " system in order to increase the efficiency of the intermittent gas lift system by eliminating problems linked to the phenomenon of" fallback " thus increase the production of our wells.
This document contains slides from a presentation on well completions fundamentals. It discusses various aspects of well completions such as bottom hole completion techniques including perforated, open hole and liner completions. It also discusses perforations, the production string including tubing, packers and Christmas trees. The upper hole completion involves installing the production tubing, packers and the Christmas tree. Multiple completion configurations allow accessing multiple pay zones including single string and parallel string options. Horizontal and multilateral well completions also require specialized techniques and equipment.
This document discusses well testing and well test analysis software programs. It provides information on:
- The objectives of well testing including identifying fluid types and reservoir parameters
- Types of well tests including productivity tests for development wells and descriptive tests for exploration wells
- Popular well test software programs for analytical and numerical analysis including Saphir, PanSystem, Interpret 2000, and Weltest 200
- An overview of the Weltest 200 program which links analytical and numerical well test analysis through different modules
- Using an example of liquid productivity or IPR testing to demonstrate how well test data is incorporated and analyzed in the software
This document discusses various artificial lift methods used to increase production from oil and gas wells as reservoir pressure declines. It describes the basic principles and components of common artificial lift techniques, including sucker rod pumps, gas lift, electrical submersible pumps, hydraulic jet pumping, plunger lift, and progressive cavity pumping. For each method, it provides information on advantages, limitations, and typical application ranges for operating parameters such as depth, production rate, temperature, and wellbore geometry. The document aims to provide an overview of different artificial lift options and considerations for selecting the appropriate production method.
The document discusses drill stem testing (DST), which is used to evaluate reservoir properties. It describes the key components of a DST tool, including pressure recorders, test valves, packers, and more. It also outlines the steps to design a DST plan, considering factors like the test interval, packer selection and location, choke selection, and more. Finally, it explains how to execute a DST, interpreting the pressure chart by describing the initial flow, initial shut-in, final flow, and final shut-in periods marked on a sample chart.
This document provides an overview of well control techniques. It discusses the importance of maintaining primary well control by keeping hydrostatic pressure greater than formation pressure. It describes what a kick is and types of kicks that can occur. Common causes of kicks include not keeping the hole full, insufficient mud density, swabbing, lost circulation, and poor well planning. Warning signs of a kick and methods for recognition are outlined. Finally, it discusses the objective of well control and some important well control concepts like determining reservoir pressure and selecting a well control method.
This document provides an overview of well completion processes and equipment. It describes common casing types like surface casing, intermediate casing, and production casing. It explains the functions of casing to protect the wellbore, isolate fluid zones, and provide a conduit for tools. The document outlines the typical steps in a well completion, including running and cementing casing, perforating, stimulating, gravel packing if needed, and installing tubing and a Christmas tree. It provides details on related equipment like centralizers, float shoes, and packers. The document is intended as an introduction to well completion concepts and components for educational purposes.
This document provides an introduction to well control from Kingdom Drilling Services. It discusses primary and secondary well control, including maintaining pressure and monitoring flows. Loss of primary control can occur through pressure changes or lost circulation. Secondary control indicators include increased flow rates or mud pit volume changes. Methods for controlling kicks include circulating or bullheading. The document also covers well control terms, blowout prevention, shallow well hazards, and lost circulation detection and remedies.
Reservoir rocks experience compaction when fluid is produced, causing a change in pore volume and effective stress. There are three types of compressibility - rock matrix (grain) compressibility measures change in grain volume, rock bulk compressibility measures change in total formation volume, and pore volume compressibility measures change in pore space. Accurately measuring and modeling compressibility is important for predicting changes in porosity and formation properties during production.
After drilling is completed, wells undergo completion procedures to prepare them for production. This involves setting production casing and cementing it through the target zone. Tubing is run inside the casing with a packer to isolate the production zone. A Christmas tree is installed to control flow. Completion types include open hole, liners, and perforated casing. Perforating creates holes through casing into the formation. Some formations require stimulation like acidizing to improve permeability or fracturing to create conductive fractures held open by proppant. This increases flow into the wellbore.
The extensive slide-pack starts with introducing physics and basics on geomechanics. A lot of stress and rock strength concepts are explored. Then it moves on to explain the importance of the discipline for drilling, injection, sanding. Apart from giving theory to understand more difficult content that follow, it throws in practical application and prepares good ground for further study of geomechanical literature.
Primary cementing involves pumping a cement slurry down the casing or drill pipe to isolate formations and support the casing. It is critical to well integrity. Some key points covered in the document include:
- Cementing is done after lowering casing to isolate formations and support the casing.
- Primary cementing techniques can include single-stage, multi-stage, or liner cementation depending on well conditions.
- Secondary cementing techniques like squeeze cementing are used to remedy issues with prior cement jobs or isolate specific formations.
- Cementing is a critical operation that requires careful planning and execution to achieve well integrity on the first attempt, as there are no second chances.
The document discusses various well completion methods and sand control techniques. It begins by explaining that well stimulation may be needed if the well's productivity has been impaired by the perforation or completion method. It then reviews different completion methods and their basic requirements to connect the reservoir, protect the casing, bring fluids to surface, provide safety measures, control sand, and provide zonal isolation. The document focuses on techniques for predicting and controlling sand production, including the use of screens, gravel packing, chemical consolidation, and frac and pack completions. It provides details on sieve analysis, gravel pack selection and sorting criteria.
This document provides an overview of well control procedures. It discusses causes of kicks such as swabbing or pumping light mud that can lead to underbalance. Primary well control relies on mud hydrostatic pressure, while secondary control uses a blowout preventer. Tertiary control involves pumping substances to stop downhole flow. Methods for killing a well are also presented, including the driller's method, wait and weight, volumetric, and bullheading. Kick detection equipment like the pit volume totalizer and flow indicator are also outlined.
This document provides information about gas lift optimization. It discusses the need for gas lift when wells are not producing through natural flow. Gas lift involves injecting natural gas into the well to lift fluids to the surface. The document outlines the basic principles of gas lift and gas lift systems. It describes how gas lift valves work and the process of unloading a well using multiple unloading valves. The goal of optimization is to find the optimal injection point and amount of gas injected to maximize oil production rates. Charts are provided showing well performance curves with injection rate versus oil rate.
This document discusses challenges and solutions related to deep water drilling. It describes different types of rigs used for deep water drilling at various water depths. Key challenges discussed include gas hydrates, reactive formations, low fracture gradients, large mud volumes, low flow line temperatures, and high rig costs. Solutions provided relate to additive selection, temperature and pressure management, casing design, logistics planning, and optimization to reduce costs and time.
WELL COMPLETION, WELL INTERVENTION/ STIMULATION, AND WORKOVERAndi Anriansyah
This document discusses various well completion, intervention, and workover topics including:
- Well completion involves preparing the well for production by installing equipment like casing and tubing.
- Open hole and cased hole completions are described, along with advantages and disadvantages of each.
- Well intervention operations like scale removal, acidizing, and sand cleaning are performed during production.
- Formation damage from fluids introduced into the well is also discussed.
- Stimulation techniques like acidizing and hydraulic fracturing aim to increase well productivity. The document outlines the processes, equipment, and evaluation of these operations.
- Other topics covered include intelligent well completions, perforating, sand control, squeeze cement
Fundamentals of Petroleum Engineering Module 4Aijaz Ali Mooro
The document provides an overview of drilling operations, including:
(1) The types of oil rigs used both on land and offshore such as jack-up rigs, semi-submersible rigs, and drillships.
(2) The components and functions of a rotary drilling system including the hoisting, rotating, and circulating equipment used to drill wells.
(3) Detailed descriptions of drilling procedures and potential problems that can occur.
The document outlines the life cycle of oil and gas wells, including planning, drilling, completion, production, and abandonment phases. It describes the planning process including well classification and formation pressure considerations. Key aspects of drilling are discussed such as rig types, crews, casing, and use of drilling mud to remove cuttings from the wellbore.
A drill stem test (DST) is used to test characteristics of a newly drilled well while the drilling rig is still on site. It can provide estimates of permeability, reservoir pressure, fluid types, wellbore damage, barriers and fluid contacts. There are three main methods to analyze DST data: Horner's plot method, type curve matching method, and computer matching. Type curve matching involves matching pressure change over time data from the DST to standard type curves to determine properties like permeability and skin factor. Gringarten type curves are commonly used and account for variations in pressure over time based on reservoir-well configurations.
This document provides an overview of basic well control procedures including:
- Kick detection and control methods like primary prevention and secondary detection and control
- Shut-in procedures such as hard, soft, and specialized shut-ins
- Well kill procedures including calculating initial and final circulating pressures, the wait-and-weight/engineer's method, and providing an example pump schedule.
It describes the key objectives and considerations for safely controlling a well when kicks occur and bringing the well pressure to a controlled state.
This document discusses drill bits used in oil and gas drilling. It describes the main types of drill bits including roller cone bits, natural diamond bits, PDC bits, and TSP bits. It explains how each type of bit cuts rock through different mechanisms like compression, grinding, or shearing. The document also provides details on bit design factors for both roller cone bits and PDC bits, including bearing assembly design, cutter design, nozzle placement, and more. It covers how to select the proper bit based on formation hardness and classify bits using the IADC system. Performance factors like WOB, RPM, mud properties, and hydraulic efficiency that influence bit performance are also summarized.
The document discusses the concept of skin factor in wellbore flow, which is a dimensionless quantity that describes flow efficiency. A positive skin factor indicates damage that restricts flow, while a negative skin indicates flow enhancement. Skin can result from various factors like partial completion, damage near the wellbore, hydraulic fracturing, or deviation of the well from vertical. Equations are provided to calculate the pressure drop and flow efficiency based on the skin factor. The total skin is the sum of individual skin components from different sources like damage, completion, deviation etc.
This document discusses the process of hydraulic fracturing. It begins with an overview of fracturing stages and materials used. It then covers in-situ rock stresses, fracture initiation theories, and fracture geometry models. The document discusses fracturing fluid systems and additives used. It also reviews proppant types and their strengths. Finally, it examines fracture conductivity and equivalent skin factor calculations used to evaluate fracturing results.
This document discusses well testing and well test analysis software programs. It provides information on:
- The objectives of well testing including identifying fluid types and reservoir parameters
- Types of well tests including productivity tests for development wells and descriptive tests for exploration wells
- Popular well test software programs for analytical and numerical analysis including Saphir, PanSystem, Interpret 2000, and Weltest 200
- An overview of the Weltest 200 program which links analytical and numerical well test analysis through different modules
- Using an example of liquid productivity or IPR testing to demonstrate how well test data is incorporated and analyzed in the software
This document discusses various artificial lift methods used to increase production from oil and gas wells as reservoir pressure declines. It describes the basic principles and components of common artificial lift techniques, including sucker rod pumps, gas lift, electrical submersible pumps, hydraulic jet pumping, plunger lift, and progressive cavity pumping. For each method, it provides information on advantages, limitations, and typical application ranges for operating parameters such as depth, production rate, temperature, and wellbore geometry. The document aims to provide an overview of different artificial lift options and considerations for selecting the appropriate production method.
The document discusses drill stem testing (DST), which is used to evaluate reservoir properties. It describes the key components of a DST tool, including pressure recorders, test valves, packers, and more. It also outlines the steps to design a DST plan, considering factors like the test interval, packer selection and location, choke selection, and more. Finally, it explains how to execute a DST, interpreting the pressure chart by describing the initial flow, initial shut-in, final flow, and final shut-in periods marked on a sample chart.
This document provides an overview of well control techniques. It discusses the importance of maintaining primary well control by keeping hydrostatic pressure greater than formation pressure. It describes what a kick is and types of kicks that can occur. Common causes of kicks include not keeping the hole full, insufficient mud density, swabbing, lost circulation, and poor well planning. Warning signs of a kick and methods for recognition are outlined. Finally, it discusses the objective of well control and some important well control concepts like determining reservoir pressure and selecting a well control method.
This document provides an overview of well completion processes and equipment. It describes common casing types like surface casing, intermediate casing, and production casing. It explains the functions of casing to protect the wellbore, isolate fluid zones, and provide a conduit for tools. The document outlines the typical steps in a well completion, including running and cementing casing, perforating, stimulating, gravel packing if needed, and installing tubing and a Christmas tree. It provides details on related equipment like centralizers, float shoes, and packers. The document is intended as an introduction to well completion concepts and components for educational purposes.
This document provides an introduction to well control from Kingdom Drilling Services. It discusses primary and secondary well control, including maintaining pressure and monitoring flows. Loss of primary control can occur through pressure changes or lost circulation. Secondary control indicators include increased flow rates or mud pit volume changes. Methods for controlling kicks include circulating or bullheading. The document also covers well control terms, blowout prevention, shallow well hazards, and lost circulation detection and remedies.
Reservoir rocks experience compaction when fluid is produced, causing a change in pore volume and effective stress. There are three types of compressibility - rock matrix (grain) compressibility measures change in grain volume, rock bulk compressibility measures change in total formation volume, and pore volume compressibility measures change in pore space. Accurately measuring and modeling compressibility is important for predicting changes in porosity and formation properties during production.
After drilling is completed, wells undergo completion procedures to prepare them for production. This involves setting production casing and cementing it through the target zone. Tubing is run inside the casing with a packer to isolate the production zone. A Christmas tree is installed to control flow. Completion types include open hole, liners, and perforated casing. Perforating creates holes through casing into the formation. Some formations require stimulation like acidizing to improve permeability or fracturing to create conductive fractures held open by proppant. This increases flow into the wellbore.
The extensive slide-pack starts with introducing physics and basics on geomechanics. A lot of stress and rock strength concepts are explored. Then it moves on to explain the importance of the discipline for drilling, injection, sanding. Apart from giving theory to understand more difficult content that follow, it throws in practical application and prepares good ground for further study of geomechanical literature.
Primary cementing involves pumping a cement slurry down the casing or drill pipe to isolate formations and support the casing. It is critical to well integrity. Some key points covered in the document include:
- Cementing is done after lowering casing to isolate formations and support the casing.
- Primary cementing techniques can include single-stage, multi-stage, or liner cementation depending on well conditions.
- Secondary cementing techniques like squeeze cementing are used to remedy issues with prior cement jobs or isolate specific formations.
- Cementing is a critical operation that requires careful planning and execution to achieve well integrity on the first attempt, as there are no second chances.
The document discusses various well completion methods and sand control techniques. It begins by explaining that well stimulation may be needed if the well's productivity has been impaired by the perforation or completion method. It then reviews different completion methods and their basic requirements to connect the reservoir, protect the casing, bring fluids to surface, provide safety measures, control sand, and provide zonal isolation. The document focuses on techniques for predicting and controlling sand production, including the use of screens, gravel packing, chemical consolidation, and frac and pack completions. It provides details on sieve analysis, gravel pack selection and sorting criteria.
This document provides an overview of well control procedures. It discusses causes of kicks such as swabbing or pumping light mud that can lead to underbalance. Primary well control relies on mud hydrostatic pressure, while secondary control uses a blowout preventer. Tertiary control involves pumping substances to stop downhole flow. Methods for killing a well are also presented, including the driller's method, wait and weight, volumetric, and bullheading. Kick detection equipment like the pit volume totalizer and flow indicator are also outlined.
This document provides information about gas lift optimization. It discusses the need for gas lift when wells are not producing through natural flow. Gas lift involves injecting natural gas into the well to lift fluids to the surface. The document outlines the basic principles of gas lift and gas lift systems. It describes how gas lift valves work and the process of unloading a well using multiple unloading valves. The goal of optimization is to find the optimal injection point and amount of gas injected to maximize oil production rates. Charts are provided showing well performance curves with injection rate versus oil rate.
This document discusses challenges and solutions related to deep water drilling. It describes different types of rigs used for deep water drilling at various water depths. Key challenges discussed include gas hydrates, reactive formations, low fracture gradients, large mud volumes, low flow line temperatures, and high rig costs. Solutions provided relate to additive selection, temperature and pressure management, casing design, logistics planning, and optimization to reduce costs and time.
WELL COMPLETION, WELL INTERVENTION/ STIMULATION, AND WORKOVERAndi Anriansyah
This document discusses various well completion, intervention, and workover topics including:
- Well completion involves preparing the well for production by installing equipment like casing and tubing.
- Open hole and cased hole completions are described, along with advantages and disadvantages of each.
- Well intervention operations like scale removal, acidizing, and sand cleaning are performed during production.
- Formation damage from fluids introduced into the well is also discussed.
- Stimulation techniques like acidizing and hydraulic fracturing aim to increase well productivity. The document outlines the processes, equipment, and evaluation of these operations.
- Other topics covered include intelligent well completions, perforating, sand control, squeeze cement
Fundamentals of Petroleum Engineering Module 4Aijaz Ali Mooro
The document provides an overview of drilling operations, including:
(1) The types of oil rigs used both on land and offshore such as jack-up rigs, semi-submersible rigs, and drillships.
(2) The components and functions of a rotary drilling system including the hoisting, rotating, and circulating equipment used to drill wells.
(3) Detailed descriptions of drilling procedures and potential problems that can occur.
The document outlines the life cycle of oil and gas wells, including planning, drilling, completion, production, and abandonment phases. It describes the planning process including well classification and formation pressure considerations. Key aspects of drilling are discussed such as rig types, crews, casing, and use of drilling mud to remove cuttings from the wellbore.
A drill stem test (DST) is used to test characteristics of a newly drilled well while the drilling rig is still on site. It can provide estimates of permeability, reservoir pressure, fluid types, wellbore damage, barriers and fluid contacts. There are three main methods to analyze DST data: Horner's plot method, type curve matching method, and computer matching. Type curve matching involves matching pressure change over time data from the DST to standard type curves to determine properties like permeability and skin factor. Gringarten type curves are commonly used and account for variations in pressure over time based on reservoir-well configurations.
This document provides an overview of basic well control procedures including:
- Kick detection and control methods like primary prevention and secondary detection and control
- Shut-in procedures such as hard, soft, and specialized shut-ins
- Well kill procedures including calculating initial and final circulating pressures, the wait-and-weight/engineer's method, and providing an example pump schedule.
It describes the key objectives and considerations for safely controlling a well when kicks occur and bringing the well pressure to a controlled state.
This document discusses drill bits used in oil and gas drilling. It describes the main types of drill bits including roller cone bits, natural diamond bits, PDC bits, and TSP bits. It explains how each type of bit cuts rock through different mechanisms like compression, grinding, or shearing. The document also provides details on bit design factors for both roller cone bits and PDC bits, including bearing assembly design, cutter design, nozzle placement, and more. It covers how to select the proper bit based on formation hardness and classify bits using the IADC system. Performance factors like WOB, RPM, mud properties, and hydraulic efficiency that influence bit performance are also summarized.
The document discusses the concept of skin factor in wellbore flow, which is a dimensionless quantity that describes flow efficiency. A positive skin factor indicates damage that restricts flow, while a negative skin indicates flow enhancement. Skin can result from various factors like partial completion, damage near the wellbore, hydraulic fracturing, or deviation of the well from vertical. Equations are provided to calculate the pressure drop and flow efficiency based on the skin factor. The total skin is the sum of individual skin components from different sources like damage, completion, deviation etc.
This document discusses the process of hydraulic fracturing. It begins with an overview of fracturing stages and materials used. It then covers in-situ rock stresses, fracture initiation theories, and fracture geometry models. The document discusses fracturing fluid systems and additives used. It also reviews proppant types and their strengths. Finally, it examines fracture conductivity and equivalent skin factor calculations used to evaluate fracturing results.
This document describes the case of a 60-year-old female patient presenting with abdominal pain and distension. On examination, she showed signs of peritonitis. Investigations including ultrasound and x-ray revealed free fluid and free gas in the abdomen, suggestive of a hollow viscous perforation. She was diagnosed with a perforated peptic ulcer of the duodenum and underwent exploratory laparotomy and Graham's patch repair. Post-operatively, she improved with treatment and was discharged on the 12th day.
This document discusses the effects of perforating horizontal wells in the Wilmington Oil Field case study. It outlines the objectives of investigating how perforation parameters affect horizontal well productivity. It describes shaped charge perforation technology and the components of perforating guns. It discusses factors that influence well productivity like skin effect and how perforations help reduce skin. Calculations for modeling perforation skin effects are presented. The conclusion recommends future reservoir simulations to improve understanding of complex reservoir structures and well performance.
The document discusses the functions and types of casing strings used in oil and gas wells. It describes the different casing strings like conductor casing, surface casing, intermediate casing, and production casing. It also covers casing design criteria like classifications based on outside diameter, length, connections, weight, and grade. The mechanical properties of casing are discussed in relation to withstanding tensile, burst, and collapse loads during drilling and production operations.
1) Stresses around a borehole deviate from the initial stress state of the formation due to removal of material and replacement with drilling fluid. Large deviations can cause failure.
2) Borehole failure criteria define the conditions under which failure occurs, such as when the stress deviation at the borehole wall exceeds the shear or tensile strength of the rock.
3) Models are presented for calculating stresses and predicting failure for vertical boreholes in isotropic and anisotropic formations, as well as for inclined boreholes using effective stress analysis.
83-87
Hydrogen
10-14
Nitrogen
0.1-2
Oxygen
0.1-1.5
Sulphur
0.5-6
The document discusses various topics related to energy production and consumption including:
- Energy production has steadily increased worldwide from 215 quadrillion BTU in 1970 to 417 quadrillion BTU in 2003, a 94% rise.
- The top three energy producing countries in 2003 were United States, Russia, and China.
- Energy consumption is directly related to quality of life as measured by factors like life expectancy, education, and GDP.
- Foss
The document discusses compaction and subsidence that can occur during oil and gas production due to a reduction in pore pressure. It describes how effective stress increases as pore pressure declines, causing the reservoir rock to compact. This compaction at the reservoir level can result in subsidence at the surface. Key factors that influence compaction and subsidence are identified as reservoir rock properties, thickness, pore pressure depletion, and areal extent. The ratio between subsurface compaction and surface subsidence is also addressed.
This document discusses concepts of failure in materials including tensile failure, shear failure, and failure criteria. It specifically examines the Mohr-Coulomb failure criterion, which states that failure depends on the material's cohesion and internal friction angle. The criterion can be represented on a Mohr's circle diagram, where failure occurs if the circle contacts the linear failure envelope line. Pore fluid pressure is also accounted for using effective stress. Triaxial tests are described that apply different confining pressures to measure failure properties over a range of stress conditions.
This document discusses drilling economics and optimization techniques. It covers topics such as drilling cost prediction, authorization for expenditure (AFE), drilling optimization techniques including drilling cost equations and breakeven calculations, and decision making using expected value calculations. Examples are provided for calculating cost per foot, determining breakeven points, and evaluating decisions using expected values.
The document discusses cement used in oil and gas wells. It covers cement composition, classes of cement, additives for controlling density, acceleration, retardation and viscosity. It also discusses cementing operations, equipment and performing a good cementing job. Key factors include casing centralization, pipe movement, drilling fluid viscosity, hole condition and achieving proper displacement velocity.
The document discusses different types of drill bits used in drilling operations, including drag bits and roller cutter bits. It describes the components and functioning of each type of bit. The document also covers drill bit classification systems used to categorize bits based on attributes like cutter type, profile, and intended formation. Drill bits are graded after use based on tooth wear, bearing wear, and gauge wear.
This document discusses drilling mud, including its types, composition, properties, functions, and laboratory/field testing. It describes water-based muds and oil-based muds as the two main types, and their components such as liquids, solids, and chemicals. Key properties covered include density, viscosity, filtration, and gel strength. Important functions of drilling mud include hole cleaning, pressure control, cooling and lubrication. Common laboratory tests to evaluate mud properties and performance include measuring density, rheology, filtration, sand content, resistivity, and pH.
This document provides a preface and overview for a textbook on petroleum production engineering. It discusses how modern computer technologies have revolutionized the petroleum industry and motivated the authors to write this textbook. The textbook is intended to provide production engineers with guidelines for designing, analyzing, and optimizing petroleum production systems using computer-assisted approaches. It covers topics like well performance, artificial lift methods, and production enhancement techniques across 18 chapters in 4 parts. The preface provides details on the intended audience, topics covered, and goals of presenting engineering principles through examples and companion computer programs.
Estimation of skin factor by using pressure transientMuhamad Kurdy
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4. INTRODUCTION
Objective of perforation is to establish
communication between the wellbore & the
formation.
This is achieved by making holes through the
casing, cement & into formation.
The inflow capacity of the reservoir must not
be inhibited.
5. Well productivity & injectivity depend
primarily on near-wellbore pressure drop
called Skin.
Skin is a function of:
Completion type
Formation damage
Perforation
Skin is high & productivity reduced when:
Formation damage is severe (drilling &
completion fluids invasion ranges from several
inches to a few feet)
Perforations do not extend beyond the invaded
6.
7. Deep penetration:
Increases effective wellbore radius
Intersects more natural fractures if present
Prevents/reduces sand production by reducing
pressure drop across perforated intervals.
High-strength formations & damaged
reservoirs benefit the most from deep-
penetrating perforations.
8. SHAPED CHARGED PERFORATION
The shaped charge evolved from the WW2
military bazooka.
Perforating charges consist of:
A primer
Outer case
High explosive
Conical liner connected to a detonating cord.
9. The detonating cord initiates the primer &
detonates the main explosive
The liner collapses to form the high-velocity
jet of fluidized metal particles that are
propelled along the charge axis through the
well casing & cement & into the formation.
10. The detonator is triggered by:
Electrical heating when deployed on wireline
systems or,
A firing pin in mechanically or hydraulically
operated firing head systems employed on
tubing conveyed perforating (TCP) systems
11.
12. The jet penetrating mechanism is one of
“punching” rather than blasting, burning,
drilling or abrasive wearing.
This punching effect is achieved by
extremely high impact pressures –
3 x 106 psi on casing
3 x 105 psi on formation.
These jet impact pressures cause steel,
cement, rock, & pore fluids to flow plastically
outward.
16. Elastic rebound leaves shock-damaged rock,
pulverized formation grains & debris in the
newly created perforation tunnels.
Hence, perforating damage can consist of
three elements:
A crushed zone
Migration of fine formation particles
Debris inside perforation tunnels.
17.
18.
19. The crushed zone can limit both productivity
& injectivity.
Fines and debris restrict injectivity & increase
pump pressure, which:
Decreases injection volumes
Impairs placement or distribution of gravel &
proppants for sand control or hydraulic fracture
treatments.
20. The extent of perforation damage is a
function of:
Lithology
Rock strength
Porosity
Pore fluid compressibility
Clay content
Formation grain size
Shaped-charge designs
21. EXPLOSIVES
Explosives used in perforation are called
Secondary high explosives.
Reaction rate = 22,966 – 30,000 ft/s.
Volume of gas produced = 750 – 1,000 times
original volume of explosive.
These explosives are generally organic
compounds of nitrogen & oxygen.
When a detonator initiates the breaking of
the molecules' atomic bonds, the atoms of
nitrogen lock together with much stronger
bonds, releasing tremendous amounts of
24. RDX is the most commonly used explosives
for shaped charges (up to 300 oF).
In deep wells when extreme temperature is
required & where the guns are exposed to
well temperatures for longer periods of time
HMX, PS, HNS or PYX is used.
25. It is important to respect the explosives used
in perforating operations.
They are hazardous.
Accidents can occur if they are not handled
carefully or if proper procedures are not
followed.
26. PERFORATING GUNS
Perforating guns are configured in several
ways.
There are four main types of perforating
guns:
Wireline conveyed casing guns
Through-tubing hollow carrier guns
Through-tubing strip guns
Tubing conveyed perforating guns
30. They have lower charge sizes &, therefore
lower performance, than all other guns.
They only offer 0o or 180o phasing
Maximum shot density of 4 spf on the 2-1/8”
OD gun & 6 spf on the 2-7/8” OD gun.
Due to the stand-off from the casing which
these guns may have, they are usually fitted
with decentralizing/orientation devices.
32. Charges have higher performance.
They also cause more debris, casing
damage & have less mechanical & electrical
reliability.
They also provide 0o or 180o phasing.
By being able to be run through the tubing,
underbalance perforating can possibly be
adopted but only for the first shot.
A new version called the Pivot Gun has
even larger charges for deep penetration.
35. Longer lengths can be installed.
Lengths of over 1,000 ft are possible
(especially useful for horizontal wells).
The main problems associated with TCP are:
Gun positioning is more difficult.
The sump needs to be drilled deeper to
accommodate the gun length if it is dropped after
firing.
A misfire is extremely expensive.
Shot detection is more unreliable.
36. PERFORATION EFFICIENCY &
GUN PERFORMANCE
Optimizing perforating efficiency relies
extensively on the planning & execution of
the well completion which includes:
Selection of the perforated interval
Fluid selection
Gun selection
Applied pressure differential
Well clean-up
Perforating orientation
37. API RP 19B, 1st Edition (Recommended
Practices for Evaluation of Well Perforators)
provide means for evaluating perforating
systems (multiple shot) in four ways:
Performance under ambient temperature &
atmospheric pressure test conditions.
Performance in stressed Berea sandstone
targets (simulated wellbore pressure test
conditions).
How performance may be changed after
exposure to elevated temperature conditions.
Flow performance of a perforation under specific
stressed test conditions
38. Factors affecting gun performance include:
Compressive strengths & porosities of
formations.
Type of charges used (size, shape).
Charge alignment.
Moisture contamination.
Gun stand-off.
Thickness of casing & cement.
Multiple casings.
39. It is necessary for engineers to obtain as
much accurate data from the suppliers & use
the company’s historic data in order to be
able to make the best choice of gun.
Due to the problem of flow restriction, the
important factors to be considered include:
Hole diameter to achieve adequate flow area.
Shot density to achieve adequate flow area.
Shot phasing, Penetration, Debris removal.
40.
41. Hole Size
The hole size obtained is a function of the
casing grade & should be as follows:
Between 6 mm & 12 mm for natural completions.
Between 15 mm & 25 mm in gravel packed
completions.
Between 8 mm & 12 mm if fracturing is to be
carried out & where ball sealers are to be used.
42. Shot Density
Shot density is the number of holes specified
in shots per foot (spf).
An adequate shot density can reduce
perforation skin & produce wells at lower
pressure differentials.
Shot density in homogeneous, isotropic
formations should be a minimum of 8 spf but
must exceed the frequency of shale
laminations.
43. A shot density greater than this is required
where:
Vertical permeability is low.
There is a risk of sand production.
There is a risk of high velocities & hence
turbulence.
A gravel pack is to be conducted.
Note: Too many holes can weaken the
casing strength.
44. Shot Phasing
Phasing is the radial distribution of
successive perforating charges around the
gun axis.
Simply put, phasing is perforation orientation
or the angle between holes.
Perforating gun assemblies are commonly
available in 0o, 180o, 120o, 90o & 60o
phasing.
47. The 0o phasing (all shots are along the same
side of the casing) is generally used only in
small outside-diameter guns.
60o, 90o & 120o degree phase guns are
generally larger & provide more efficient flow
characteristics near the wellbore.
Optimized phasing reduces pressure drop
near the wellbore by providing flow conduits
on all sides of the casing.
48. Providing the stand-off is less than 50mm,
180o or less, 120o, 90o, 60o is preferable.
If the smallest charges are being used then
the stand-off should not be more than 25mm.
If fracturing is to be carried out then 90o and
lower will help initiate fractures.
50. Penetration
In general, the deeper the shot the better, but
at the least it should exceed the drilling
damage area by 75mm.
However, to obtain high shot density, the
guns may be limited to the charge size which
can physically be installed which will impact
penetration.
51. WELL/RESERVOIR CHARACTERISTICS
Pressure differential between a wellbore and
reservoir before perforating can be described
by:
Underbalanced
Overbalanced
Extreme overbalanced (EOB)
52. Underbalanced Perforating
Reservoir pressure is substantially higher
than the wellbore pressure.
Adequate reservoir pressure must exist to
displace the fluids from within the production
tubing if the well is to flow unaided.
If the reservoir pressure is insufficient to
achieve this, measures must be taken to
lighten the fluid column typically by gas lifting
or circulating a less dense fluid.
53. The flow rates & pressures used to exercise
control during the clean up period are
intended to maximize the return of drilling or
completion fluids & debris.
This controlled backflush of perforating
debris or filtrate also enables surface
production facilities to reach stable
conditions gradually.
Standard differential pressure ≈ 200 – 400
psi.
Differential pressures up to 5,000 psi in low
54.
55. Overbalanced Perforating
Perforating when the wellbore pressure is
higher than the reservoir pressure.
This is normally used as a method of well
control during perforating.
The problem with this method is it introduces
wellbore fluid into the formation causing
formation damage.
Use clean fluid to prevent perforation
plugging.
Use of acid in carbonates.
56.
57.
58. Extreme Overbalanced Perforating
The wellbore is pressured up to very high
pressures with gas (usually nitrogen).
When the perforating guns are detonated the
inflow of high pressure gas into the formation
results in a mini-frac, opening up the
formation to increase inflow.
59. CALCULATIONS
A mechanism to account for the effects of
perforations on well performance is through
the introduction of the perforation skin effect,
sp in the well production equation.
For example, under steady-state conditions:
141.2 ln
e wf
e
p
w
kh P P
q
r
B s
r
60. Karakas and Tariq (1988) have presented a
semi-analytical solution for the calculation of
the perforation skin effect, which they divide
into components:
The plane-flow effect, sH
The vertical converging effect, sV
The wellbore effect, swb
The total perforation skin effect is then:
p H V wbs s s s
61. The Plane-flow Effect
rw = wellbore radius (ft).
r’w(θ) = effective wellbore radius (ft). It is a
function of the phasing angle θ.
lperf = length of perforation (ft)
ln w
H
w
r
s
r
for 0
4
for 0
perf
w
o w perf
l
r
a r l
62. Constant ao depends on the perforation
phasing.
a1a2a1b2b1c2c
63. The Vertical Converging Effect
1
10a b b
V D Ds h r
1 2log Da a r a 1 2Db b r b
1
2
perf V
D
perf H
r k
r
h k
1
shot density
perfh
perf H
D
perf V
h k
h
l k
64. a1, a2, b1 & b2 are obtained from the table
above.
kH = horizontal permeability
kV = vertical permeability
rperf = radius of perforation (ft)
sV is potentially the largest contributor to sp.
65. The Wellbore Effect
c1 & c2 are obtained from the table above.
1 2expwb wDs c c r
w
wD
perf w
r
r
l r
66.
67. REFERENCES
Gatlin, C.: “Drilling Well Completion,”
Prentice-Hall Inc., New Jersey, 1960.
ENI S.p.A. Agip Division: “Completion Design
Manual,” 1999.
Halliburton: “Petroleum Well Construction,”
1997.
Ott, W. K. and Woods, J. D.: “Modern
Sandface Completion Practices Handbook,”
1st Ed., World Oil Magazine, 2003.
68. Schlumberger: “Completions Primer,” 2001.
Golan, M. and Whitson, C. H.: “Well
Performance,” 2nd Ed., Tapir, 1995.
Karakas, M. and Tariq, S.: “Semi-Analytical
Productivity Models for Perforated
Completions,” paper SPE 18271, 1988.
Clegg, J. D.: “Production Operations
Engineering,” Petroleum Engineering
Handbook, Vol. IV, SPE, 2007.
Bellarby, J.: “Well Completion Design,” 1st
Ed., Elsevier B.V., 2009.