This document discusses challenges with horizontal drilling technology and maintaining accurate wellbore positioning data. As drilling rates have increased, downhole data transmission speeds have not kept pace, creating a "log jam" of data from the subsurface and hindering timely decision making. Other issues that can compound wellbore positioning errors include taking surveys only every 10-30 meters, sliding the drill pipe between surveys, and using simple radius of curvature models to calculate wellbore position. These practices can lead to significant cumulative errors in the reported wellbore location. The document suggests taking more frequent surveys on shorter intervals to improve positioning accuracy, though this requires stopping drilling and is discouraged by drillers focused on rate of return metrics.
This document provides an overview of dam safety efforts in Delaware. It discusses the evolution of dam safety regulations and programs in DE from the 1970s to present. It outlines the current prioritization process used by DelDOT to evaluate state-owned dams. It also describes the ongoing dam preservation program through the DNREC/DelDOT partnership, including data collection and analysis, modeling approaches, and planned upgrading projects. It highlights a computational fluid dynamics pilot project conducted for Silver Lake Dam that refined the spillway capacity and breach analyses.
Smart Fractured Reservoir Development StrategiesITE Oil&Gas
The document presents a strategy for smarter assessment of fractured reservoirs using discrete fracture network (DFN) modeling. The strategy integrates geological data to provide a rational description of the fractured rock conditions and connectivity. It provides a scalable approach to understand the effects of natural fracture networks on well trajectories, compartmentalization, completions and hydraulic fracturing. The modeling workflow includes characterizing fractures from well data, building 3D DFN models, simulating hydraulic fracturing and microseismicity, predicting stimulated rock volumes and production, and upscaling to the field scale. This integrated approach can help optimize development and reduce environmental risks.
Contoh Pekerjaan pemodelan gelombang dengan menggunakan CMS Wave yang dilakukan Coastal Inlet Research Program (CIRP)
M. Baharudin Fahmi
baharudinfahmi@gmail.com
Coastal Engineer
CaTS wireless monitoring technology allows for monitoring of abandoned wells, providing valuable reservoir data. During appraisal drilling, decisions must be made with limited data, increasing uncertainty around reservoir connectivity. CaTS sensors installed before well abandonment can monitor pressure and temperature for years, reducing uncertainty by detecting interference between producing and injection wells. This low-cost, wireless system transmits data to a seabed receiver without need for downhole cabling, avoiding integrity issues and simplifying permanent abandonment.
The document discusses velocity tools used in production logging, specifically focusing on spinners which measure fluid flow velocities. It provides background on spinners, including their history, types, basic working principles, and challenges in measurement. Graphical methods for interpreting spinner log data are also explained.
Bill Douglas has over 35 years of experience in piping design, engineering, and project management for offshore oil rigs, ships, and industrial facilities. He has extensive skills in AutoCAD, PDMS, and other piping software and has managed projects for CNOOC, KCA Deutag, ExxonMobil, and many others. Douglas holds safety and technical certificates and a Process Piping Design diploma from SAIT with honors.
This presentation was given at the EPA’s National Water Event 2019, which took place on 29 and 30 May 2019 in Galway. This presentation by Michael Goss from Irish Water is on addressing the challenges related to wastewater networks.
This document provides an overview of dam safety efforts in Delaware. It discusses the evolution of dam safety regulations and programs in DE from the 1970s to present. It outlines the current prioritization process used by DelDOT to evaluate state-owned dams. It also describes the ongoing dam preservation program through the DNREC/DelDOT partnership, including data collection and analysis, modeling approaches, and planned upgrading projects. It highlights a computational fluid dynamics pilot project conducted for Silver Lake Dam that refined the spillway capacity and breach analyses.
Smart Fractured Reservoir Development StrategiesITE Oil&Gas
The document presents a strategy for smarter assessment of fractured reservoirs using discrete fracture network (DFN) modeling. The strategy integrates geological data to provide a rational description of the fractured rock conditions and connectivity. It provides a scalable approach to understand the effects of natural fracture networks on well trajectories, compartmentalization, completions and hydraulic fracturing. The modeling workflow includes characterizing fractures from well data, building 3D DFN models, simulating hydraulic fracturing and microseismicity, predicting stimulated rock volumes and production, and upscaling to the field scale. This integrated approach can help optimize development and reduce environmental risks.
Contoh Pekerjaan pemodelan gelombang dengan menggunakan CMS Wave yang dilakukan Coastal Inlet Research Program (CIRP)
M. Baharudin Fahmi
baharudinfahmi@gmail.com
Coastal Engineer
CaTS wireless monitoring technology allows for monitoring of abandoned wells, providing valuable reservoir data. During appraisal drilling, decisions must be made with limited data, increasing uncertainty around reservoir connectivity. CaTS sensors installed before well abandonment can monitor pressure and temperature for years, reducing uncertainty by detecting interference between producing and injection wells. This low-cost, wireless system transmits data to a seabed receiver without need for downhole cabling, avoiding integrity issues and simplifying permanent abandonment.
The document discusses velocity tools used in production logging, specifically focusing on spinners which measure fluid flow velocities. It provides background on spinners, including their history, types, basic working principles, and challenges in measurement. Graphical methods for interpreting spinner log data are also explained.
Bill Douglas has over 35 years of experience in piping design, engineering, and project management for offshore oil rigs, ships, and industrial facilities. He has extensive skills in AutoCAD, PDMS, and other piping software and has managed projects for CNOOC, KCA Deutag, ExxonMobil, and many others. Douglas holds safety and technical certificates and a Process Piping Design diploma from SAIT with honors.
This presentation was given at the EPA’s National Water Event 2019, which took place on 29 and 30 May 2019 in Galway. This presentation by Michael Goss from Irish Water is on addressing the challenges related to wastewater networks.
1) Many African oil operators are focusing on improving recovery rates and extending the life of existing fields due to fluctuations in oil prices and declining drilling activity. Cost containment has also become a key focus.
2) 3D reservoir modeling is playing an important role in development decisions and mapping reservoir behavior to optimize field lifecycles and production. Challenges include seismic interpretation, rapid model updating, and strengthening reservoir modeling skills.
3) New technologies like model-driven interpretation and multi-realization workflows allow for faster, more accurate incorporation of data and uncertainties into integrated models, facilitating improved field development planning and production forecasts. This contributes to extending field life in Africa.
MASS MASTER METERING SOLUTION FOR USERS PAIN_ FCRI 2012 KS NR _2_Naimish Raval
1) The document discusses issues with traditional master metering technologies like turbine and positive displacement meters and how their performance can change over time or with different fluids.
2) It introduces Coriolis and ultrasonic metering technologies as alternatives for master metering that are more stable and accurate.
3) The inclusion of Coriolis meters in the API standards for master meter proving is a significant development that addresses users' needs for less costly and onerous proving methods.
Impact of Planning Decision Support Tools on Mining Operations ProfitabilitySchneider Electric
Changes in the mining industry business environment are leading to gradual changes in how the supply chain (from ore extraction at the mine to delivery at customer sites) is managed. Global demand is flattening and available supply is increasing. This means that complex planning business models that were developed in an era of supply “push” need to be altered to accommodate a market reality of demand driven “pull”. This white paper introduces a decision support methodology that results in reduced cost, improved throughput, enhanced quality, and increased profit.
The document discusses how Landmark's DecisionSpace platform provides a unified system for analyzing unconventional oil and gas assets. It includes Dynamic Frameworks to Fill workflow technology which automatically updates a 3D subsurface model as new well and seismic data is acquired, allowing operators to more precisely target sweet spots. This helps operators plan drilling campaigns and well placements to increase reservoir contact and reduce costs.
Changes in dam break hydrodynamic modelling practice - Suter et alStephen Flood
Abstract: Today, many organisations rely on hydrodynamic modelling to assess the consequences of dam break failure on downstream populations and infrastructure. The availability of finite volume shock-capturing schemes and flexible mesh schematisations in widely used software platforms imply that dam break modelling projects will be carried out differently in the future: Finite volume based platforms allow widespread application of shock-capturing methods and flexible mesh platforms can represent features in the study area more realistically and are more flexible thanks to varying mesh resolutions. Furthermore, the recent adoption of Graphics Processing Unit (GPU) technology in mainstream scientific and engineering computing will also significantly decrease computation times at relatively low cost.
This paper examines the application of finite volume, flexible mesh and GPU technologies to dam break modelling. One-dimensional (1D) modelling results are compared to those from two-dimensional (2D) finite difference and finite volume approaches. The results demonstrate that there are differences between modelling approaches and that the computational speeds of 2D simulations can be significantly reduced by the use of GPU processors.
Practical wellbore formation test interpretation; #120009 (2009)Tran Dang Sang
The document discusses practical interpretation of wellbore formation test (WFT) pressure data, which is important for defining proved reserves under new SEC regulations. It addresses issues like data quality from different tools, establishing high versus low confidence data, and examples of pressure trends that could indicate reservoir continuity. Topics covered include pretest pressure stability, depth correlation, gradient error, accuracy versus precision, interpreting gradients in low mobility environments, and avoiding compartmentalization. The author argues that integrated analysis of pressure trends with other data like fluid samples, geochemistry, and PVT properties provides a stronger case than pressure gradient analysis alone.
Torque and Drag: Concepts that Every Drilling and Completion Engineer Should ...pvisoftware
This white paper talks about torque and drag concepts that every drilling and completion engineer should know. With TADPRO, the risks associated with drilling and completing a well can be assessed and much of the risk can be remediated during pre-job planning.
Lyapichev. Problems in numerical analysis of CFRDs (ICOLD Bull.155)6 p.)Yury Lyapichev
The document discusses several challenges and developments in numerically analyzing concrete faced rockfill dams (CFRDs). It notes that until recently, CFRDs were designed based on experience rather than analysis. Accurate models have since shown issues like excessive compressibility of downstream rockfill adversely impacting the concrete face. The document also discusses modeling earthquakes, the need for structure-specific models in some cases, and ensuring nonlinear analysis convergence. Overall, it emphasizes the importance of numerical analysis as a tool to supplement—not replace—engineering judgment, especially for extrapolating lessons from incidents at high CFRDs.
Directional surveys acquired by Measurement While Drilling (MWD) are subject to many errors that are not easily
recognized by traditional Quality Control (QC) procedures. This commonly leads to inaccurate wellbore placement
and greater positional uncertainty. Common sources of MWD survey error are inaccurate geomagnetic references,
localized distortions in the natural magnetic field, poor instrument calibration, random sensor noise, magnetic mud,
and human error. Often times, such errors go unrecognized due to limitations in traditional single-station QC tests.
This is a significant problem because wellbore collision avoidance, geological modeling, and reservoir drainage are
all greatly affected by wellbore placement accuracy. Fortunately, most sources of MWD error can now easily be
identified and corrected through implementation of robust independent survey quality control processes. By using
web-based systems to facilitate this process, drillers can benefit from the most powerful quality assurance practices
which can be standardized across the industry regardless of service provider or vendor specific technologies.
Introduction
Well placement by MWD employs the use of orthogonally positioned
accelerometers and magnetometers to measure the orientation of the bottomhole assembly (BHA) relative to the Earth’s gravitational and magnetic fields
as shown in Figure 1. Taking survey measurements at regular intervals along
the well path enables computation of the wellbore trajectory through
minimum curvature interpolation.
UNDERSTANDING THE DRAINAGE PATTERNS & RECOVERY FACTORS USING LOGGINGiQHub
The document discusses methods for evaluating the success of refracturing operations. It indicates that the basic objective is to obtain the best stimulation treatment compatible with costs. By comparing logging measurements before and after refracturing, the near wellbore region can be indexed and the fracture water saturation profile determined. This profile shows where fracturing fluids went and is used to measure cluster efficiency and fracture complexity. Comparing pre-and post-refrac logs helps identify the best refracturing methodology and determine the potential of future refracturing projects. Flowback data can also be evaluated to determine the refracturing effective fracture volume.
This document summarizes the evolution of completion designs used by Total Austral in developing shale resources in the Vaca Muerta formation in Argentina over the past decade. It began with vertical exploratory wells to characterize the formation, followed by a short horizontal appraisal well. A pilot phase involved 12 horizontal wells to validate productivity from two zones, using plug-and-perf completions. Operational challenges were addressed. Subsequent phases increased lateral lengths, implemented new technologies like 4D seismic and chemical tracers, and optimized operations to increase production and reduce costs through testing of fracture parameters and improvements to water/proppant logistics and service reliability. The historical experience helped shift to more efficient best practices for unconventional well stimulation.
Optimizing completions in deviated and extended reach wells is a key to safe drilling and optimum
production, particularly in complex terrain and formations. This work summarizes the systematic methodology
and engineering process employed to identify and refine the highly effective completions solution used in ERW
completion system and install highly productive and robust hard wares in horizontal and Extended Reach Wells
for Oil and Gas. A case study of an offshore project was presented and discussed. The unique completion design,
pre-project evaluation and the integrated effort undertaken to firstly, minimize completion and formation damage.
Secondly, maximize gravel placement and sand control method .Thirdly, to maximize filter cake removal
efficiencies. The importance of completions technologies was identified and a robust tool was developed .More
importantly, the ways of deploying these tools to achieve optimal performance in ERW’s completions was done.
The application of the whole system will allow existing constraints to be challenged and overcome successfully;
these achievements was possible, by applying sound practical engineering principle and continuous optimization,
with respect to the rig and environmental limitation space and rig capacity.
Keywords: Well Completions , Deviated and Extended Rearch Wells , Optimization
Laubsher cave mining handbook de beers versionJULIO QUISPE
This document summarizes key aspects of geological investigations for cave mining projects:
- Geological investigations are ongoing from exploration to mine closure and provide critical input data for planning and operating the mine.
- Early-stage exploration programs should be designed with mining considerations in mind, with close collaboration between exploration and mining geology teams.
- Detailed core logging and structural analysis is important for rock mass classification and caveability assessment.
- Geological modeling and mapping at various scales is used to understand the regional context and 3D geometry of the deposit. Hard copy maps and sections remain important references in addition to digital models.
- Zones of different structural, density or chemical properties within the orebody must be defined,
This document summarizes a proposed new conceptual model called the Fracturing Impacted Volume (FIV) model as an alternative to the commonly used Discrete Fracture Network (DFN) model for modeling unconventional reservoirs. The FIV model accounts for the pressure-dependent permeability of the reservoir system and fluid loss during fracturing. It views fracturing as pressurizing the reservoir system within a spatial volume around the fracture, including microfractures and pores, rather than solely focusing on discrete fracture propagation. Laboratory tests on tight sandstone and shale cores show that reservoir permeability increases with pressure, supporting this conceptualization. The FIV model aims to provide a more effective way to understand fracturing mechanisms and improve simulation of fract
Seismic Applications Throughout the Life of the Reservoir
(C) July 2002 Oilfield Review
Projects: Seismic Reservoir Characterizationusing avo inversion for reservoir characterization
Operators are getting more from their reservoirs by combining high-quality seismic
images with conventional reservoir data. Asset teams use this calibrated seismic
information to gain detailed knowledge of reservoir properties, allowing them to
reduce risk at every stage in the life of their prospects.
Trine Alsos
Alfhild Eide
Statoil
Trondheim, Norway
Donatella Astratti
Stephen Pickering
Gatwick, England
Marcelo Benabentos
Nader Dutta
Subhashis Mallick
George Schultz
Houston, Texas, USA
Lennert den Boer
Calgary, Alberta, Canada
Michael Livingstone
Aberdeen, Scotland
Michael Nickel
Lars Sønneland
Stavanger, Norway
Juergen Schlaf
Phillips Petroleum Company
Stavanger, Norway
Pascal Schoepfer
Petroleum Development Oman
Muscat, Sultanate of Oman
Mario Sigismondi
Juan Carlos Soldo
Pecom Energía de Pérez Companc SA
Neuquén, Argentina
Lars Kristian Strønen
Statoil
Bergen, Norway
For help in preparation of this article, thanks to Mike
Bahorich, Apache Corporation, Houston, Texas, USA; Lee
Bell, Laurence Darmon, Olav Holberg, John Waggoner and
Bob Will, Houston, Texas; Phil Christie, Cambridge, England;
Doug Evans, Malcolm Francis, Michael French, Bob
Godfrey, Kim Hughes and Stephen McHugo, Gatwick,
England; and Ray Pratt, Amerada Hess, Olso, Norway.
ECLIPSE, FrontSim, MultiWave Array and RFT (Repeat
Formation Tester) are marks of Schlumberger.
This document provides a project report on radial drilling technology submitted by three students at the Maharashtra Institute of Technology, Pune, India in partial fulfillment of their Bachelor's degree in Petroleum Engineering. Radial drilling involves drilling small diameter horizontal laterals from existing vertical wells using high pressure water jets. The report covers the background and development of radial drilling technology, the process which involves milling casing and extending laterals with jetting, its advantages in improving reservoir connectivity and production. It also discusses the application of radial drilling to increase recovery from mature oilfields. The report aims to evaluate radial drilling as a low-cost technique to enhance oil recovery from existing reservoirs.
This article describes in a nut shell, the changing attitude of Oil and Gas
companies towards innovative drilling technologies in the down turn, some of the
important innovations in drilling technologies and its relevance to upstream oil and
gas, the pace of adoption of innovative drilling technologies in the upstream oil and
gas and the need for an optimistic future outlook.
This document discusses the design and management of packer testing programs for groundwater characterization at mining sites. It describes different types of packer testing methods including single vs double packer configurations, and injection, withdrawal, shut-in and falling head test types. Key considerations for designing a testing program include clearly defining data objectives, assessing data density needs, and planning the type, number and timing of tests based on drilling equipment, hole locations and other site activities. Flexibility is important as real-world constraints may influence testing approach. Overall, the document emphasizes upfront planning but also allowing for adaptive testing strategies to efficiently achieve hydrogeological characterization objectives.
This document summarizes a study evaluating mining methods for the 543-S copper deposit in Michigan's Keweenaw Peninsula. An underground cut-and-fill method was selected based on the deposit's geometry. A block model of the deposit was created from drill data. Economic analysis was conducted to determine optimal pit limits and underground development. The study concluded the deposit has potential for open-pit, underground, or hybrid mining and that cut-and-fill is reasonable given the deposit. Future work includes environmental monitoring and feasibility assessments.
A new soil tunnelling machine with waterjet technologyPatricia Faria
Atualmente, a hidrodemolição com jato d’água é uma tecnologia bem estabelecida na construção civil, especialmente para remoção de concreto. No entanto, o uso desta tecnologia em construções subterrâneas é ainda pouco explorado. Comparado com ferramentas de escavação convencionais (baseadas em atrito, fratura e desgaste), a hidrodemolição tem características vantajosas de maior relação potência-peso etaxas de avanço e causandomenor desgaste das partes mecânicas. Todas essas vantagens podem ter impactos significativos na concepção de uma nova geração de máquinas de perfuração de túneis, com menor custo e maior eficiência. Outra possibilidade é o do desenvolvimento de um projeto incremental de baixo custo, como um método parcialmente mecanizado com um escudo protetor e remoção do solo por meios manuais. O presente artigo descreve um método semi-mecanizadoinovador de escavação de túneis em solo que utiliza a tecnologia de jato d'água de alta pressão. Basicamente, o equipamento proposto compreende um escudo cilíndrico, com um sistema móvel de bicos de jato d’água e elementos de drenagem
1) Many African oil operators are focusing on improving recovery rates and extending the life of existing fields due to fluctuations in oil prices and declining drilling activity. Cost containment has also become a key focus.
2) 3D reservoir modeling is playing an important role in development decisions and mapping reservoir behavior to optimize field lifecycles and production. Challenges include seismic interpretation, rapid model updating, and strengthening reservoir modeling skills.
3) New technologies like model-driven interpretation and multi-realization workflows allow for faster, more accurate incorporation of data and uncertainties into integrated models, facilitating improved field development planning and production forecasts. This contributes to extending field life in Africa.
MASS MASTER METERING SOLUTION FOR USERS PAIN_ FCRI 2012 KS NR _2_Naimish Raval
1) The document discusses issues with traditional master metering technologies like turbine and positive displacement meters and how their performance can change over time or with different fluids.
2) It introduces Coriolis and ultrasonic metering technologies as alternatives for master metering that are more stable and accurate.
3) The inclusion of Coriolis meters in the API standards for master meter proving is a significant development that addresses users' needs for less costly and onerous proving methods.
Impact of Planning Decision Support Tools on Mining Operations ProfitabilitySchneider Electric
Changes in the mining industry business environment are leading to gradual changes in how the supply chain (from ore extraction at the mine to delivery at customer sites) is managed. Global demand is flattening and available supply is increasing. This means that complex planning business models that were developed in an era of supply “push” need to be altered to accommodate a market reality of demand driven “pull”. This white paper introduces a decision support methodology that results in reduced cost, improved throughput, enhanced quality, and increased profit.
The document discusses how Landmark's DecisionSpace platform provides a unified system for analyzing unconventional oil and gas assets. It includes Dynamic Frameworks to Fill workflow technology which automatically updates a 3D subsurface model as new well and seismic data is acquired, allowing operators to more precisely target sweet spots. This helps operators plan drilling campaigns and well placements to increase reservoir contact and reduce costs.
Changes in dam break hydrodynamic modelling practice - Suter et alStephen Flood
Abstract: Today, many organisations rely on hydrodynamic modelling to assess the consequences of dam break failure on downstream populations and infrastructure. The availability of finite volume shock-capturing schemes and flexible mesh schematisations in widely used software platforms imply that dam break modelling projects will be carried out differently in the future: Finite volume based platforms allow widespread application of shock-capturing methods and flexible mesh platforms can represent features in the study area more realistically and are more flexible thanks to varying mesh resolutions. Furthermore, the recent adoption of Graphics Processing Unit (GPU) technology in mainstream scientific and engineering computing will also significantly decrease computation times at relatively low cost.
This paper examines the application of finite volume, flexible mesh and GPU technologies to dam break modelling. One-dimensional (1D) modelling results are compared to those from two-dimensional (2D) finite difference and finite volume approaches. The results demonstrate that there are differences between modelling approaches and that the computational speeds of 2D simulations can be significantly reduced by the use of GPU processors.
Practical wellbore formation test interpretation; #120009 (2009)Tran Dang Sang
The document discusses practical interpretation of wellbore formation test (WFT) pressure data, which is important for defining proved reserves under new SEC regulations. It addresses issues like data quality from different tools, establishing high versus low confidence data, and examples of pressure trends that could indicate reservoir continuity. Topics covered include pretest pressure stability, depth correlation, gradient error, accuracy versus precision, interpreting gradients in low mobility environments, and avoiding compartmentalization. The author argues that integrated analysis of pressure trends with other data like fluid samples, geochemistry, and PVT properties provides a stronger case than pressure gradient analysis alone.
Torque and Drag: Concepts that Every Drilling and Completion Engineer Should ...pvisoftware
This white paper talks about torque and drag concepts that every drilling and completion engineer should know. With TADPRO, the risks associated with drilling and completing a well can be assessed and much of the risk can be remediated during pre-job planning.
Lyapichev. Problems in numerical analysis of CFRDs (ICOLD Bull.155)6 p.)Yury Lyapichev
The document discusses several challenges and developments in numerically analyzing concrete faced rockfill dams (CFRDs). It notes that until recently, CFRDs were designed based on experience rather than analysis. Accurate models have since shown issues like excessive compressibility of downstream rockfill adversely impacting the concrete face. The document also discusses modeling earthquakes, the need for structure-specific models in some cases, and ensuring nonlinear analysis convergence. Overall, it emphasizes the importance of numerical analysis as a tool to supplement—not replace—engineering judgment, especially for extrapolating lessons from incidents at high CFRDs.
Directional surveys acquired by Measurement While Drilling (MWD) are subject to many errors that are not easily
recognized by traditional Quality Control (QC) procedures. This commonly leads to inaccurate wellbore placement
and greater positional uncertainty. Common sources of MWD survey error are inaccurate geomagnetic references,
localized distortions in the natural magnetic field, poor instrument calibration, random sensor noise, magnetic mud,
and human error. Often times, such errors go unrecognized due to limitations in traditional single-station QC tests.
This is a significant problem because wellbore collision avoidance, geological modeling, and reservoir drainage are
all greatly affected by wellbore placement accuracy. Fortunately, most sources of MWD error can now easily be
identified and corrected through implementation of robust independent survey quality control processes. By using
web-based systems to facilitate this process, drillers can benefit from the most powerful quality assurance practices
which can be standardized across the industry regardless of service provider or vendor specific technologies.
Introduction
Well placement by MWD employs the use of orthogonally positioned
accelerometers and magnetometers to measure the orientation of the bottomhole assembly (BHA) relative to the Earth’s gravitational and magnetic fields
as shown in Figure 1. Taking survey measurements at regular intervals along
the well path enables computation of the wellbore trajectory through
minimum curvature interpolation.
UNDERSTANDING THE DRAINAGE PATTERNS & RECOVERY FACTORS USING LOGGINGiQHub
The document discusses methods for evaluating the success of refracturing operations. It indicates that the basic objective is to obtain the best stimulation treatment compatible with costs. By comparing logging measurements before and after refracturing, the near wellbore region can be indexed and the fracture water saturation profile determined. This profile shows where fracturing fluids went and is used to measure cluster efficiency and fracture complexity. Comparing pre-and post-refrac logs helps identify the best refracturing methodology and determine the potential of future refracturing projects. Flowback data can also be evaluated to determine the refracturing effective fracture volume.
This document summarizes the evolution of completion designs used by Total Austral in developing shale resources in the Vaca Muerta formation in Argentina over the past decade. It began with vertical exploratory wells to characterize the formation, followed by a short horizontal appraisal well. A pilot phase involved 12 horizontal wells to validate productivity from two zones, using plug-and-perf completions. Operational challenges were addressed. Subsequent phases increased lateral lengths, implemented new technologies like 4D seismic and chemical tracers, and optimized operations to increase production and reduce costs through testing of fracture parameters and improvements to water/proppant logistics and service reliability. The historical experience helped shift to more efficient best practices for unconventional well stimulation.
Optimizing completions in deviated and extended reach wells is a key to safe drilling and optimum
production, particularly in complex terrain and formations. This work summarizes the systematic methodology
and engineering process employed to identify and refine the highly effective completions solution used in ERW
completion system and install highly productive and robust hard wares in horizontal and Extended Reach Wells
for Oil and Gas. A case study of an offshore project was presented and discussed. The unique completion design,
pre-project evaluation and the integrated effort undertaken to firstly, minimize completion and formation damage.
Secondly, maximize gravel placement and sand control method .Thirdly, to maximize filter cake removal
efficiencies. The importance of completions technologies was identified and a robust tool was developed .More
importantly, the ways of deploying these tools to achieve optimal performance in ERW’s completions was done.
The application of the whole system will allow existing constraints to be challenged and overcome successfully;
these achievements was possible, by applying sound practical engineering principle and continuous optimization,
with respect to the rig and environmental limitation space and rig capacity.
Keywords: Well Completions , Deviated and Extended Rearch Wells , Optimization
Laubsher cave mining handbook de beers versionJULIO QUISPE
This document summarizes key aspects of geological investigations for cave mining projects:
- Geological investigations are ongoing from exploration to mine closure and provide critical input data for planning and operating the mine.
- Early-stage exploration programs should be designed with mining considerations in mind, with close collaboration between exploration and mining geology teams.
- Detailed core logging and structural analysis is important for rock mass classification and caveability assessment.
- Geological modeling and mapping at various scales is used to understand the regional context and 3D geometry of the deposit. Hard copy maps and sections remain important references in addition to digital models.
- Zones of different structural, density or chemical properties within the orebody must be defined,
This document summarizes a proposed new conceptual model called the Fracturing Impacted Volume (FIV) model as an alternative to the commonly used Discrete Fracture Network (DFN) model for modeling unconventional reservoirs. The FIV model accounts for the pressure-dependent permeability of the reservoir system and fluid loss during fracturing. It views fracturing as pressurizing the reservoir system within a spatial volume around the fracture, including microfractures and pores, rather than solely focusing on discrete fracture propagation. Laboratory tests on tight sandstone and shale cores show that reservoir permeability increases with pressure, supporting this conceptualization. The FIV model aims to provide a more effective way to understand fracturing mechanisms and improve simulation of fract
Seismic Applications Throughout the Life of the Reservoir
(C) July 2002 Oilfield Review
Projects: Seismic Reservoir Characterizationusing avo inversion for reservoir characterization
Operators are getting more from their reservoirs by combining high-quality seismic
images with conventional reservoir data. Asset teams use this calibrated seismic
information to gain detailed knowledge of reservoir properties, allowing them to
reduce risk at every stage in the life of their prospects.
Trine Alsos
Alfhild Eide
Statoil
Trondheim, Norway
Donatella Astratti
Stephen Pickering
Gatwick, England
Marcelo Benabentos
Nader Dutta
Subhashis Mallick
George Schultz
Houston, Texas, USA
Lennert den Boer
Calgary, Alberta, Canada
Michael Livingstone
Aberdeen, Scotland
Michael Nickel
Lars Sønneland
Stavanger, Norway
Juergen Schlaf
Phillips Petroleum Company
Stavanger, Norway
Pascal Schoepfer
Petroleum Development Oman
Muscat, Sultanate of Oman
Mario Sigismondi
Juan Carlos Soldo
Pecom Energía de Pérez Companc SA
Neuquén, Argentina
Lars Kristian Strønen
Statoil
Bergen, Norway
For help in preparation of this article, thanks to Mike
Bahorich, Apache Corporation, Houston, Texas, USA; Lee
Bell, Laurence Darmon, Olav Holberg, John Waggoner and
Bob Will, Houston, Texas; Phil Christie, Cambridge, England;
Doug Evans, Malcolm Francis, Michael French, Bob
Godfrey, Kim Hughes and Stephen McHugo, Gatwick,
England; and Ray Pratt, Amerada Hess, Olso, Norway.
ECLIPSE, FrontSim, MultiWave Array and RFT (Repeat
Formation Tester) are marks of Schlumberger.
This document provides a project report on radial drilling technology submitted by three students at the Maharashtra Institute of Technology, Pune, India in partial fulfillment of their Bachelor's degree in Petroleum Engineering. Radial drilling involves drilling small diameter horizontal laterals from existing vertical wells using high pressure water jets. The report covers the background and development of radial drilling technology, the process which involves milling casing and extending laterals with jetting, its advantages in improving reservoir connectivity and production. It also discusses the application of radial drilling to increase recovery from mature oilfields. The report aims to evaluate radial drilling as a low-cost technique to enhance oil recovery from existing reservoirs.
This article describes in a nut shell, the changing attitude of Oil and Gas
companies towards innovative drilling technologies in the down turn, some of the
important innovations in drilling technologies and its relevance to upstream oil and
gas, the pace of adoption of innovative drilling technologies in the upstream oil and
gas and the need for an optimistic future outlook.
This document discusses the design and management of packer testing programs for groundwater characterization at mining sites. It describes different types of packer testing methods including single vs double packer configurations, and injection, withdrawal, shut-in and falling head test types. Key considerations for designing a testing program include clearly defining data objectives, assessing data density needs, and planning the type, number and timing of tests based on drilling equipment, hole locations and other site activities. Flexibility is important as real-world constraints may influence testing approach. Overall, the document emphasizes upfront planning but also allowing for adaptive testing strategies to efficiently achieve hydrogeological characterization objectives.
This document summarizes a study evaluating mining methods for the 543-S copper deposit in Michigan's Keweenaw Peninsula. An underground cut-and-fill method was selected based on the deposit's geometry. A block model of the deposit was created from drill data. Economic analysis was conducted to determine optimal pit limits and underground development. The study concluded the deposit has potential for open-pit, underground, or hybrid mining and that cut-and-fill is reasonable given the deposit. Future work includes environmental monitoring and feasibility assessments.
A new soil tunnelling machine with waterjet technologyPatricia Faria
Atualmente, a hidrodemolição com jato d’água é uma tecnologia bem estabelecida na construção civil, especialmente para remoção de concreto. No entanto, o uso desta tecnologia em construções subterrâneas é ainda pouco explorado. Comparado com ferramentas de escavação convencionais (baseadas em atrito, fratura e desgaste), a hidrodemolição tem características vantajosas de maior relação potência-peso etaxas de avanço e causandomenor desgaste das partes mecânicas. Todas essas vantagens podem ter impactos significativos na concepção de uma nova geração de máquinas de perfuração de túneis, com menor custo e maior eficiência. Outra possibilidade é o do desenvolvimento de um projeto incremental de baixo custo, como um método parcialmente mecanizado com um escudo protetor e remoção do solo por meios manuais. O presente artigo descreve um método semi-mecanizadoinovador de escavação de túneis em solo que utiliza a tecnologia de jato d'água de alta pressão. Basicamente, o equipamento proposto compreende um escudo cilíndrico, com um sistema móvel de bicos de jato d’água e elementos de drenagem
A new soil tunnelling machine with waterjet technology
OGIAustralia - March 2015
1. International majors make waves in the Browse Basin.
MARCH 2015
■ AOG 2015: Who Has The Goods?
■ An Australian Pipe Dream
■ Why Midcaps Will Drive Growth
■ AOG 2015: Who Has The Goods?
■ An Australian Pipe Dream
■ Why Midcaps Will Drive Growth
991-994_Covers_0315_991-994_Covers_0315 2/17/15 5:44 PM Page 991
2. D
rilling technology advance-
ments over the past several
decades have been leveraged
in recent years to transform our in-
dustry and fuel the“Unconventional
Revolution.”These incremental devel-
opments in drilling technology
evolved gradually since the OPEC oil
embargo in 1973 and the subsequent
oil shock in 1979.These events and
other geopolitical developments
drove an explosion in global drilling
activity,especially for highly complex
offshore development projects that
required huge,upfront capital invest-
ments and pushed the limits of exist-
ing technology.
Thus,this“new age”of drilling
technology has led to more sophisti-
cated directional,then extended
reach,and now horizontal well
drilling programs throughout the
world,but especially in North Amer-
ica in unconventional resource plays.
Over and over again,technology bar-
riers have given way to allow today’s
advanced,highly demanding horizon-
tal well programs that commonly use
“manufacturing mode”processes for
achieving results never before antici-
pated or even believed possible.
Even with these incredible advance-
ments,the industry continues to inno-
vate and develop new drilling systems
for achieving faster and faster drilling
rates.But now,with these astonishing
Lessons learned from the horizontal drilling boom in North
America can be applied to onshore drilling in Australia.
A Path to Better
Horizontal Drilling
BY KC OREN,
Horizontal Solutions International
OGIAustralia.com | March 2015 HartEnergy.com68
Technology
68-73 TECH_Horizontal Drilling_68-73 TECH_Horizontal Drilling 2/17/15 5:42 PM Page 68
3. gains,the industry is hitting other
boundaries and facing conflicting limi-
tations due to interdependencies in
closed-loop drilling systems.The ques-
tion then becomes,can essential geo-
logical and drilling data needed to
support the evaluation of the targeted
strata keep up with rapid drilling rates?
If not,as a result,a new dilemma has
emerged for the integrated drilling,
geosciences and production engineer-
ing team.
Conundrum
Both drilling and geologic data for true
drilling-time decision support is essen-
tial,but when data is limited by
MWD/LWD data transmission speeds
for receiving the multitudes of varied
measurements topside,other issues
emerge as critical and limiting ele-
ments.Acquiring downhole data and
sending it uphole via binary data
transmission for informed decisions
by the team is an incredibly complex
operation,but skillfully and reliably
carried off by our drilling service com-
panies every day.
However,downhole data transmis-
sion speeds have not kept pace with
improved drilling rates,creating an
information“log jam”by limiting criti-
cal data flow from the subsurface.This
bottleneck further hinders the team’s
ability to make timely data assess-
ments for evaluation and then execu-
tion by the integrated asset team.
One challenge is low bandwidth
inherent to MWD/LWD transmission
systems—both from the multitude
of desirable petrophysical measure-
ments such as natural gamma ray and
azimuthal resistivity competing for the
binary data channel capacity (mud col-
umn pulses) and drilling data such as
azimuth,inclination,tool face orienta-
tion,bit vibration,downhole torque
and drag and continuous inclination.
The combination of petrophysical and
drilling data is essential to basic geo-
navigation principles and,ultimately,
in application of that analysis for
geosteering decisions for drilling
optimum horizontal wells.
But to make matters even worse,
geoscience and drilling disciplines’
competition for data channels is exac-
erbated by the real-world challenges
of binary data transmission rates
and signal attenuation through the
fluid (mud) column—this problem
becomes even more acute as we
achieve deeper drilling depths and
ever-increasing lateral lengths—thus
reducing achievable and useful data
rates even further.
Another factor is the applied
measurement system’s sonde position
well behind the bit,delaying the time
that the various sensors actually
measure their respective physical
properties downhole in relative posi-
tion to the drilling system,even
before they are processed and sent
uphole,further delaying the timeli-
ness of the information topside.
So,each of these noted individual
difficulties become worse when
combined collectively.And they are
even more severe as competition and
inherent tradeoffs between disciplines
create new challenges for the asset
team members as operators continue
to leverage technology to drill even
faster,deeper and further in their hor-
izontal well applications.
Exploring the tradeoffs
What’s not to like about these advance-
ments for drilling faster?As enviable as
this situation would have been in the
1980s or even the last decade,achiev-
ing the goal of optimising production
by leveraging drilling technology with
multimillion-dollar horizontal well-
bores is being questioned.
Are we possibly applying too much
technology,too soon,in our quest to
meet short-term departmental goals of
faster drilling rates (ROP) with less
non-productive time (NPT),while
missing the immediate objective of
high initial production (IP),and ulti-
mately,maximising estimated ultimate
recovery and achieving greatest possi-
ble rate of return on investment (ROI)?
March 2015 | OGIAustralia.com 69HartEnergy.com
Magnitude of error for well-maintained
survey instrumentation (MWD systems):
Azimuth: 0.75º to 2.0º
And human-introduced errors
can far exceed the survey tool’s intrinsic error!
Inclination: 0.25° to 0.75°Greater error in azimuth
Used by Permission - based upon
SPE 79917 Stockbausen and Lesso
TVD: +/-2 to 4' per 1000'
E/W: +/-3' per 1000'
N/S: +/-6' per 1000'
FIGURE 1: ELLIPSES OF UNCERTAINTY–SYSTEMATIC ERRORS
The magnitude of error of an MWD surveying system in Stockhausen’s and Lesso’s
research is demonstrated. (Source: Society of Petroleum Engineers)
68-73 TECH_Horizontal Drilling_68-73 TECH_Horizontal Drilling 2/17/15 5:42 PM Page 69
4. OGIAustralia.com | March 2015 HartEnergy.com70
Wellbore position
uncertainty
Problems with determining the
wellbore’s true pathway and precise
location at any given time is well un-
derstood and documented.Yet,many
companies do not fully consider this
issue when making critical decisions
in both the planning and execution
phases of drilling horizontal wells.
As has been documented in the
Society of Petroleum Engineers
paper by Stockhausen and Lesso
(SPE79917),the magnitude of error
of an MWD surveying system in their
research has been demonstrated and
is illustrated in Figure 1.
Fortunately,industry guidelines
for quantifying both systematic and
random errors are readily available in
the public domain for understanding
and managing the impact of these
inaccuracies and sometimes flawed
procedures.Stockhausen and Lesso’s
research cited these problems com-
mon to MWD systems,and raise the
possibility of further human-induced
errors and other drilling industry
“best practices”that have become
commonplace in achieving faster-
and-faster drilling rates,especially
for horizontal wells.
Current drilling practices
Figure 2 illustrates two common
drilling“best practices”that introduce
systematic error into the wellbore posi-
tion uncertainty formula.Drilling long,
course length intervals between survey
stations is one element leading to well
position modeling errors:surveys are
typically taken either every 10m or
30m depending upon the drilling inter-
val in the curve.
A second drilling practice further
introducing systematic error is sliding
after each connection (survey station)
and then rotating out the remaining
drilling interval until reaching the next
connection point where another survey
is then taken.The net of those two
common drilling practices is com-
pounding both errors (long survey
intervals and calculation errors in the
calculation model.)
This problem is shown in Figure 3,
with an exaggerated illustration using
the radius of curvature calculation
model.The resulting error is that the
calculated position is deeper than
the actual wellbore position in this
case.Once again,these errors are
compounding over the course of the
well and poor decisions may be possi-
bly based upon an inaccurate wellbore
location versus the true well path.
Furthermore,Stockhausen and
Lesso highlight that survey calculation
model assumptions,along with these
common survey interval and drilling
practices,are all sources contributing
to systematic error resulting in greater
and greater uncertainty.
Theminimumcurvaturesurveycal-
culationmodelshowninFigure4clearly
illustratesthatanyvector-basedcalcula-
tionmodelhasinherentlimitations
whenfittingasmoothradiusof curva-
ture.Inthiscase,asphericalcalculation
model (minimum curvature method)
acrossanundulatingwellborecourse
willyieldsubsurfacepositionalerrorsin
TVD(X),aswellasnorthing(Y)and
easting(X)positions.Thiserroris
cumulativeandmayrendersignificant
errorsasthewellisdrilledaheadtoTD.
One more procedure for reducing
wellbore position uncertainty for con-
sideration,and an opportunity to
improve confidence,is the recom-
mended best practice of taking more
surveys on shorter intervals.Unfortu-
nately,this requires drilling to stop,cir-
culate off-bottom and taking a full
directional survey more often as a
means to more precisely measure,cal-
culate and“track”a truer course of the
wellbore.Naturally,the mere mention
of“stop drilling”is frowned upon by
the drilling team—increasing NPT
and lowering ROP—key metrics that
will raise ire of any driller when these
benchmarks are negatively impacted.
But perhaps less impactful to the
drilling team is to at least apply this
practice (more surveys) at the end of
any drilling transition point between
“drilling states.”That is,a status-change
from either a rotary drilling (rotating)
to sliding (oriented TF) mode or from a
sliding to rotational drilling interval.
More frequent survey stations improve
the accuracy of tracking the position of
the wellbore,thereby increasing the
level of wellbore position certainty.
So,while taking more frequent sur-
veys has been documented and pro-
moted to improve definition of a
calculated wellbore path,it is still con-
flictive to achieving positive drilling
marks and,as a consequence,it is
greatly objectionable to the drilling
team,and is rarely followed.
A possible compromise is yet
another less impactful procedure that
calls for“rotating out”of a survey sta-
tion (after a drill pipe connection)
and once again rotating out after the
slide interval (curved section) before
Technology
Systematic survey practices
- 30' surveys in the curve
- 90' surveys in the lateral
Systematic drilling practices
- Survey, Slide, Rotate
Slide
Rotate
Result:
Compounding both errors
- Yielding measurement bias
and calcutated TVD error
FIGURE 2: SYSTEMATIC SURVEYS AND INDUSTRY “BEST PRACTICES”
There are two common drilling“best practices”that introduce systematic error into the
wellbore position uncertainty formula.(Source:Ryan Directional Services,a Nabors company)
Even with these
incredible
advancements,
the industry
continues to
innovate and
develop new
drilling
systems for
achieving
faster and
faster drilling
rates.
68-73 TECH_Horizontal Drilling_68-73 TECH_Horizontal Drilling 2/17/15 5:42 PM Page 70
5. HartEnergy.com March 2015 | OGIAustralia.com 71
making another connection.Simply
put,this process calls for“rotate-slide-
rotate”intervals between survey sta-
tions (connections).The amount of
sliding required depends upon the
amount of course correction or“steer-
ing”that is necessary.This simple
change in procedure as recommended
by Stockhausen and Lesso renders a
better survey calculation model result.
Thus yielding a more accurate repre-
sentation of the actual well path and
projected bit position while drilling.
Continuous inclination
While using these recommended
drilling best practices can be employed
to mitigate some of the wellbore path
uncertainty challenges,there is an even
better option:continuous survey data.
The goal of continuous survey mon-
itoring is similar.That is to overcome
the lack of directional survey data
(inclination and azimuth) between
survey stations,thereby reducing
uncertainty and more closely tracking
your true course along the way.
As Figure 5 illustrates,when contin-
uous inclination is tracked regularly
(shown in red),the constant inclina-
tion values relative to the survey station
measured inclination (blue line) are
markedly different in most cases.
The net result is then calculated
and dramatically confirms the
impact on drilling ahead “blindly”
without tracking inclination
changes at least intermittently.
Memory data improves
earth model
If continuous inclination is not a viable
option while drilling—perhaps due to
the service cost of this advanced sensor
package or simply the tradeoffs of
sharing desirable data channel band-
width due to drilling depths or other
factors—then,at a minimum,it is rec-
ommended that the memory data from
the MWD system be used to produce a
post-trip survey data file for comput-
ing a more accurate representation of
the well’s course.Simply,the inclination
data can be used to provide more fre-
quent survey stations and to update the
drilling path more accurately than oth-
erwise possible.
Likewise,petrophysical data gaps
due to slow transmission speeds,band-
width competition and fast drilling
rates can be overcome by infilling with
memory data from the LWD system
after it is brought to the surface.
TSP to the rescue
Fortunately,while these downhole
measurements are essential for
understanding the drilling formation
properties and a well’s physical posi-
tion in the subsurface while drilling,
these shortcomings can be at least par-
tially overcome in true drilling time.
By applying good geo-navigation tech-
niques for determining TSP of the
drilling system,the goal of“staying in
zone”can be mostly achieved.
Many directional drillers will argue
that they must have directional surveys
and an accurate wellbore position to
plot where they are in the subsurface
relative to a well plan and then for
making good drilling decisions relative
to a target line.While the former may
be true,if the ultimate goal is to stay
within a geologic window or targeted
formation zone,then the actual
position of the wellbore relative to a
geologic marker is the key geo-naviga-
tion parameter.
Inother words,pinpointing the well’s
truestratigraphicposition(TSP)and
drilling dip angle are reallythe critical
informationrequiredbythegeosteering
team.Thatis,theoperationsgeologist
inconcertwiththedrillingdataand
otherdrillingpersonnel’sprimary
objectiveistoknowthewellbore’s
Survey
Position
Model 1
Calculated Path
A slide section with a short radius of curvature followed by a rotary
section (no curvature). The actual wellbore
position will be shallower than calculated. Used with permission
(SPE 79917 Stockhausen and Lesso)
CalculatedRadiusofCurvature
Actual
Well
Path
Slide Radius of Curvature
Slide
FIGURE 3: SURVEY POSITIONED AT START OF THE SLIDE SECTION
The net of those two common drilling practices is compounding of both errors (long
survey intervals and calculation errors in the calculation model.) (Source: Society of
Petroleum Engineers)
A1
A2
I1
W E
N
DL
But the actual wellbore
is not a constant arc
Minimum Curvature Survey Calculation Method
assumes a constant arc between survey points
TVD error
builds with
depth
S
I2
VERT
EAST
NORTH
MD
DL
2 DL
2
FIGURE 4: ERROR BUILDS WITH DEPTH REGARDLESS
OF MODEL USED
This minimum curvature survey calculation model illustrates that any vector-based
calculation model has inherent limitations when fitting a smooth radius of curvature.
(Source: Ryan Directional Services,a Nabors company)
68-73 TECH_Horizontal Drilling_68-73 TECH_Horizontal Drilling 2/17/15 5:42 PM Page 71
6. OGIAustralia.com | March 2015 HartEnergy.com72
Technology
precisestratigraphicpositionand
drillingattituderelativetotheapparent
formationdipatanygivenmoment—
aprocessreferredtoasgeo-navigation.
The TSP modeling technique
employed by geo-navigation special-
ists is used to determine the relative
position of the logging sensor —typi-
cally a gamma ray detector housed
within the LWD system—in the sub-
surface by using log correlation tech-
niques within specialised software
that also provides the expert geo-nav-
igator with a means to swiftly deter-
mine apparent formation dip angle.
Using these data (TSP and apparent
dip),targeting decisions and recom-
mended borehole course corrections
may then be made; these steps are
collectively known as geosteering.
Still,these geo-navigation data
measurements (both petrophysical and
positional) as noted earlier are critical
for relating TSP back to the earth’s geo-
model for making sound,timely
geosteering decisions and keeping the
horizontal path in the optimal,targeted
production zone.Of course sound
industry geosteering best practices,
including recommended targeting
methodology,consider the many trade-
offs so as to not unnecessarily“chase”
formation changes and avoiding the
creation of new,potentially serious,
drilling and completion problems as a
consequence of an undulating and por-
poising wellbore.
Recommended targeting
best practice
The recommended methodology is
“vector-based”targeting.This tech-
nique uses TSP modeling results
along with the resulting apparent dip
calculations relative to current
drilling inclination.
Very simply,the current TSP and
apparent dip angles are compared
with the drilling orientation to deter-
mine an optimal target vector.The
result is a“zero vertical section”(VS0)
position at a specific TVD location
with a desired new inclination angle
for use by the DD.This gradual change
will occur over whatever course length
is required to softly“land”on the pre-
scribedVS0 at a given true vertical
depth (TVDy1) with the prescribed
vector line angle (inclination1).
Subsequently,as needed,the target
vector can then be easily updated as
needed.Again,over time,the DD will
again bring the well path onto a new
“landing vector”and well trajectory.
Right tools for the job
As is certainly the case for conventional
resource developments,not every
unconventional resource play is the
same.Every play has its own challenges
and inherent risk due to so many vari-
ables.Geologic risk may be due to
sparse data and little well control.Geo-
logic complexities that need to be con-
sidered are regional,local and even
well-specific structure,faulting and the
potential for changes in facies and other
formation unconformities.And there
are so many more challenges created by
insufficient and unavailable data to fur-
ther understand the uniqueness of each
unconventional resource play.
And over time these elements can
change in importance as play delin-
eation provides new geologic and
reservoir insight and other new data
that is brought to bear to provide a bet-
ter understanding of the resource in
place and evolving best practices that
may become available.
Ultimately, this new knowledge
can be leveraged for attaining
optimal economic and key corpo-
rate objectives for each of the stake-
holders.As such, the technology
deployed at the start of a project
could (should?) be different as the
play evolves. Be sure to deploy solu-
tions that can be scaled up or down
as new challenges arise or are met
with new information and technol-
ogy is put into play.
And very importantly is your
asset team’s organisation itself. The
group should operate like a well-
oiled machine that is in-sync with
each other’s goals at all times. This
is especially true “after hours,”
on nights and weekends, when
problems seem most likely to come
up.A clear definition of what are
appropriate responses to a given
situation during planning and exe-
cution of a program that meets
each of the most important criteria
of each discipline in the lineup
should include your service compa-
nies, as well as the reservoir and
production team members.
Be sure to scale your services solu-
tions and your asset team’s skills to
meet the demands and complexity of
each project.■
8800 9000 9200 9400 9600 9800 10000
Inclination
Measured Depth
Cont. Inclination
Survey Inclination
94
93
92
91
90
89
88
87
FIGURE 5: CONTINUOUS INCLINATION ENHANCES GEO-NAVIGATION
When continuous inclination is tracked regularly,the constant inclination values relative to the survey station measured inclination is
markedly different in most cases. (Source: Ryan Directional Services,a Nabors company)
Benefits Include:
• Never “blind” to true
inclination while
drilling ahead
• Better, more reliable
predictions at the bit
• More timely geo-
navigation and
geosteering DS
• Earlier directional
course corrections
• Reduced wellbore
tortuosity
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