The document discusses several innovations in oil and gas technology from the January 2020 edition of World Oil Magazine. It describes how various operators have used new technologies like ultra-deep resistivity services, dual drilling operations, acoustic logging tools, formation evaluation from cuttings, and horizontal lift systems to optimize operations, reduce costs, increase production and safely drill complex wells.
14 aneu applications of technological & engineering solutions edit Juan Carlos Bonapace
The document summarizes the application of technological solutions to stimulate an old vertical well (drilled in 1974) targeting the Vaca Muerta Formation in Neuquén Basin, Argentina. The objectives were to recondition the well using a swell packer and stimulate the entire Vaca Muerta section with 12 fracturing stages using pinpoint stimulation technique. Key steps included logging the well, setting a swell packer, and performing 12-stage fracturing of the Vaca Muerta formation using coiled tubing and a pinpoint technique to optimize stimulation of the target zone.
Conditioning Pre-existing Old Vertical Wells to Stimulate and Test Vaca Muerta Shale Productivity through the Application of Pinpoint Completion Techniques.
This document summarizes the use of liquid curable resin (LCR) systems to control proppant flowback in hydraulic fracturing operations in Argentina. Various operators applied LCR either during initial fracturing treatments by coating proppant on-site, or as remedial treatments by injecting resin into existing fractures. LCR treatments helped stop proppant flowback while maintaining production rates, reducing cleanout costs compared to untreated wells. Lessons showed resin concentration and additive selection are important to maximize proppant pack strength and conductivity. Field results demonstrated LCR treatments effectively control solids flowback to optimize well productivity.
Exploring Tight Gas Reservoir Using Intelligent Well TechnologyAbhinav Bisht
The document discusses exploring tight gas reservoirs economically using intelligent well completion (IWC) technology. Tight gas is found in low permeability rock and requires hydraulic fracturing and directional drilling to produce. IWC uses remotely operated valves for selective multi-stage fracturing of horizontal wells to improve efficiency. A case study describes how IWC and microseismic monitoring in China's Changbei Field helped optimize subsequent horizontal well completions in that field.
14 aneu applications of technological & engineering solutions edit Juan Carlos Bonapace
The document summarizes the application of technological solutions to stimulate an old vertical well (drilled in 1974) targeting the Vaca Muerta Formation in Neuquén Basin, Argentina. The objectives were to recondition the well using a swell packer and stimulate the entire Vaca Muerta section with 12 fracturing stages using pinpoint stimulation technique. Key steps included logging the well, setting a swell packer, and performing 12-stage fracturing of the Vaca Muerta formation using coiled tubing and a pinpoint technique to optimize stimulation of the target zone.
Conditioning Pre-existing Old Vertical Wells to Stimulate and Test Vaca Muerta Shale Productivity through the Application of Pinpoint Completion Techniques.
This document summarizes the use of liquid curable resin (LCR) systems to control proppant flowback in hydraulic fracturing operations in Argentina. Various operators applied LCR either during initial fracturing treatments by coating proppant on-site, or as remedial treatments by injecting resin into existing fractures. LCR treatments helped stop proppant flowback while maintaining production rates, reducing cleanout costs compared to untreated wells. Lessons showed resin concentration and additive selection are important to maximize proppant pack strength and conductivity. Field results demonstrated LCR treatments effectively control solids flowback to optimize well productivity.
Exploring Tight Gas Reservoir Using Intelligent Well TechnologyAbhinav Bisht
The document discusses exploring tight gas reservoirs economically using intelligent well completion (IWC) technology. Tight gas is found in low permeability rock and requires hydraulic fracturing and directional drilling to produce. IWC uses remotely operated valves for selective multi-stage fracturing of horizontal wells to improve efficiency. A case study describes how IWC and microseismic monitoring in China's Changbei Field helped optimize subsequent horizontal well completions in that field.
This document discusses the development of drilling technologies for shale gas. It begins with an introduction to shale gas deposits and the goals of optimizing shale gas drilling. Section 2 reviews new technical solutions for rigs, strings, bits, drilling fluids, casing, and development of testing laboratories. Section 3 discusses new drilling technologies like coiled tubing drilling, snubbing drilling, underbalance drilling, managed pressure drilling, slimhole hydraulic drilling, casing drilling, and expanding casing drilling. Section 4 covers designing trajectories for boreholes, including vertical, rotary steerable systems, and multilateral boreholes.
Oil and Gas Undergrond Storage Keystone Project.Jeffrey Pickett
The document discusses plans for an oil storage feasibility study at the Batson Salt Dome in Hardin County, Texas. It outlines the phases and tasks of the study, which include a geological review, cavern and well engineering design, regulatory requirements, an exploratory test well, and infrastructure needs. The study determined that two storage caverns and disposal wells could be used for underground oil storage. It provides details on the local geology, regulatory framework for underground storage in Texas, cost estimates for drilling a test well, and land requirements.
This document summarizes the use of a packerless, multistage fracture stimulation method called pinpoint fracturing (PPF) in Argentina. Key points:
1) PPF has been used to complete 22 wells with 193 fractures since 2006, allowing more selective stimulation and aggressive fracturing treatments.
2) The method uses coiled tubing to hydrajet perforate intervals and pump fracturing fluid down the annulus, isolating stages with sand or bridge plugs.
3) A case study describes applying PPF across 9 wells with 90 stages, reducing completion times compared to conventional methods using packers.
This document summarizes Juan Carlos Bonapace's presentation on proppant management challenges for developing unconventional reservoirs in Argentina. It discusses reservoir conditions, typical proppant types and amounts used, improvements to proppant supply logistics, laboratory testing of local Argentine sand as a potential proppant, and conclusions. Key points include closure stresses on proppant in Argentine reservoirs ranging from 1,000-5,000 psi, use of 3-4 mesh sizes and ceramic-sand blends for shales, potential for coating local sand to improve crush resistance for use at higher closure stresses, and cost-effective proppant alternatives being important to sustainable unconventional development.
OSL Consulting provides engineering solutions for the oil and gas industry. They have developed an innovative subsea separation package to enable the cost-effective development of tight gas fields. The package includes a self-contained subsea separation unit installed on the seabed that separates gas from solids. It reduces drilling costs compared to conventional topside facilities and addresses issues like solids production that impact pipeline integrity. The overall investment is approximately one-third less than a standard topside development.
Culzean HPHT: Lessons Learnt From Maersk Oil UK's 1st HPHT Exploration Well &...HPHT Wells Summit
The document discusses lessons learned from the Culzean HPHT exploration well and issues related to appraisal planning. It summarizes the exploration well results, noting that while objectives were achieved there were challenges around pore pressure and fracture gradients. It recommends a "HPHT heavy" design for the appraisal well using a deeper set 13 5/8" intermediate casing to facilitate testing from multiple zones and enable setting the 9 7/8" production casing as deep as possible. The objectives of the appraisal well are to acquire sufficient key data to ascertain economic development and detailed development design.
Adoption of the applied surface-backpressure types of managed pressure drilling (MPD) technologies in deepwater have mainly involved the use of a rotating control device (RCD). The RCD creates a closed drilling system in which the flow out of the well is diverted towards an automated MPD choke manifold (with a high-resolution mass flow meter) that aside from regulating backpressure also increases sensitivity and reduces reaction time to kicks, losses, and other unwanted drilling events. This integration of MPD equipment into floating drilling rigs to provide them with MPD capabilities, including the capacity to perform pressurized mud cap drilling (PMCD) and riser gas mitigation (RGM), has produced improvements not only in drillability and efficiency, but most importantly in process safety. Case histories on how MPD has performed will be presented on the following: • allowed drilling to reach target depth in rank wildcat deepwater wells that have formations prone to severe circulation losses and narrow mud weight windows; • increased drilling efficiency by minimizing non-productive time associated with downhole pressure-related problems and by allowing for the setting of deeper casing seats; • enhanced operational and process safety by allowing for immediate detection of kicks, losses and other critical downhole events. • provided riser gas mitigation capabilities that can detect a gas influx once it enters the drilling fluid stream, and not after it has already broken out above the rig blow-out preventers (BOPs).
This document summarizes a study evaluating different multistage hydraulic fracturing patterns in naturally fractured reservoirs using a coupled geomechanics fracture and flow model. The study models three fracturing patterns - conventional, zipper, and alternating - in a field case with multiple horizontal wells. Simulation results show the zipper pattern provides the highest long-term production rates and cumulative oil volume over 20 years compared to the other patterns. The zipper pattern is recommended as the optimal completion strategy for this type of reservoir.
This document summarizes a field study on using a liquid curable resin system to prevent proppant and formation sand production in high water cut, heavy oil wells in Argentina. The study involved hydraulic fracturing treatments using proppant coated with a low-temperature curable epoxy resin. Field results showed that the resin coating effectively stopped proppant and formation sand from being produced back while maintaining production rates. The resin treatment provided a reliable and cost-effective alternative to sand control screens for controlling solid flowback in marginal reservoirs.
Field development plan, rate of production,SYED NAWAZ
It gives you an idea about an impact of reservoir damage on production rate
Hello Everyone,
Follow my youtube channel "PETROLEUM UNIVERSE" https://lnkd.in/gjZgb7E
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Title: Maximizing the Opportunity in Multi-Layered Tight Sand Reservoirs in a Mature Field by Hydraulic Fracturing: A Case Study of Tight Sand Development Project in Thailand
PENNGLEN FIELD Development Plan (GULF of MEXICO)PaulOkafor6
A FDP designed with the goal to define the development scheme that allows the optimization of the hydrocarbon recovery at a minimal cost for project sanction
This was designed by MSc Students from the Institute of Petroleum Studies, UNIPORT/ IFP School, France
The field development plan aims to maximize oil recovery from the Sirri-A oil field located offshore Iran. Key objectives include developing a reservoir model, evaluating development strategies, and determining cash flows. The reservoir is a limestone formation from the Cretaceous period. Analysis shows it has an initial oil in place of 1.78 billion stock tank barrels and is primarily driven by water. Development scenarios include a base case, increased well counts, secondary water injection, and tertiary WAG injection. The WAG scenario recovers an estimated 52.3% of the oil in place.
Mud logging involves continuously monitoring drilling operations and analyzing drill cuttings to evaluate formations and detect hydrocarbons. Two common types of mud logging units are Drillbyte systems, which provide integrated wellsite data management, and Advantage units, which offer computerized, accurate data processing and presentation. Mud logging units contain sensors to monitor drilling parameters, gas detection systems like chromatographs, and materials for examining and describing drill cuttings. Mud logging personnel such as data engineers and mud loggers are responsible for operating equipment, collecting and analyzing data, and providing interpretations to help guide drilling operations.
Review of EOR Selection for light tight oil
Key Themes:
Upfront EOR Development Planning
Cash is king but Permeability Rules
Geology Selects Technology
Nanospheres, Steam Flooding, Misc Gas Flooding, EOR Selection Criteria
Breaking Paradigms in old Fields. Finding “the reservoir key” for Mature Fiel...Juan Diego Suarez Fromm
Two field examples will be presented, where after 50 years of development; fresh oil and gas were produced by changing some reservoir paradigms.
Upsides could be overlooked due to paradigms on field development. The successful one in terms of reserves and cost effective capital expenditure could be visualized as “finding the key for the field”. But as development takes place over many years (decades), the “key” should be a dynamic concept over time, correlated with technology availability, enabling us a better understanding of petroleum resources size, quality and distribution.
Hydraulic fracturing is necessary to produce economic quantities of gas from shale reservoirs with very low permeability. Complex fracture geometry is important to maximize contact between the fracture and reservoir. The fracturing process involves pumping fluid to create fractures, then a slurry of proppant to prop open the fractures. Proppant and fluid selection depends on factors like embedment and closure stress. While aspects like rate, volume, and proppant quantity can be controlled, the natural variations in shale make the exact fracture geometry and productivity impacts difficult to predict. Monitoring tools provide some insight into the fracture treatment results.
Comparative Analysis of Performance of Horizontal and Hydraulically Fractured...ziiishan
The document compares the performance of horizontal and hydraulically fractured vertical wells in a tight gas reservoir using numerical simulations. It describes constructing models of a horizontal well and two fractured vertical well cases in Eclipse reservoir simulation software. The models are used to simulate and compare production rates, decline curves, cumulative production, productivity indices and area open to flow between the well types under different fracture and well lengths. The conclusions found that increasing fracture or horizontal length increased production until economic limits. Productivity was higher for fractured wells but long fractures are impractical. Further work could consider varying additional parameters and including economic analysis.
Trenchless technologies comparing thrust boring with horizontal directional ...Tobiloba Omitola
Thrust boring and horizontal directional drilling (HDD) are trenchless construction methods for installing underground infrastructure with minimal surface disruption. Thrust boring involves drilling a borehole and inserting a steel casing simultaneously using an auger drill head. It is unsteerable. HDD involves drilling a steerable pilot bore, reaming it to size, and pulling the pipeline back through. Key factors in selecting between the two methods include soil conditions, required accuracy, and ability to steer around underground obstacles. Thrust boring is best for stable soils while HDD allows for navigation and is suitable for longer distances and avoiding existing utilities. Both methods seek to minimize environmental and community impacts compared to traditional trenching.
Marginal oil fields present economic challenges but can be profitably developed using unconventional techniques. The document outlines various unconventional techniques like horizontal drilling, hydraulic fracturing, tiebacks, and cable deployed ESPs that have been successfully used in case studies to reduce costs and increase production from marginal fields, making them economically viable. It also discusses the data and time constraints faced in developing marginal fields and how various conventional techniques can help optimize costs.
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
This white paper proposes a subsea separation system using cyclonic technology to improve the economic viability of developing tight, low reserve gas fields in the Southern North Sea. Computational fluid dynamics was used to verify that a cyclone unit could effectively separate solids from well fluids on the seabed. An accumulator would collect solid particles for removal by ROV, while a pipeline would transport separated gas to an offshore platform. Economic modeling indicated the proposed subsea system could reduce costs compared to conventional approaches, making marginal fields commercially feasible.
This document discusses the development of drilling technologies for shale gas. It begins with an introduction to shale gas deposits and the goals of optimizing shale gas drilling. Section 2 reviews new technical solutions for rigs, strings, bits, drilling fluids, casing, and development of testing laboratories. Section 3 discusses new drilling technologies like coiled tubing drilling, snubbing drilling, underbalance drilling, managed pressure drilling, slimhole hydraulic drilling, casing drilling, and expanding casing drilling. Section 4 covers designing trajectories for boreholes, including vertical, rotary steerable systems, and multilateral boreholes.
Oil and Gas Undergrond Storage Keystone Project.Jeffrey Pickett
The document discusses plans for an oil storage feasibility study at the Batson Salt Dome in Hardin County, Texas. It outlines the phases and tasks of the study, which include a geological review, cavern and well engineering design, regulatory requirements, an exploratory test well, and infrastructure needs. The study determined that two storage caverns and disposal wells could be used for underground oil storage. It provides details on the local geology, regulatory framework for underground storage in Texas, cost estimates for drilling a test well, and land requirements.
This document summarizes the use of a packerless, multistage fracture stimulation method called pinpoint fracturing (PPF) in Argentina. Key points:
1) PPF has been used to complete 22 wells with 193 fractures since 2006, allowing more selective stimulation and aggressive fracturing treatments.
2) The method uses coiled tubing to hydrajet perforate intervals and pump fracturing fluid down the annulus, isolating stages with sand or bridge plugs.
3) A case study describes applying PPF across 9 wells with 90 stages, reducing completion times compared to conventional methods using packers.
This document summarizes Juan Carlos Bonapace's presentation on proppant management challenges for developing unconventional reservoirs in Argentina. It discusses reservoir conditions, typical proppant types and amounts used, improvements to proppant supply logistics, laboratory testing of local Argentine sand as a potential proppant, and conclusions. Key points include closure stresses on proppant in Argentine reservoirs ranging from 1,000-5,000 psi, use of 3-4 mesh sizes and ceramic-sand blends for shales, potential for coating local sand to improve crush resistance for use at higher closure stresses, and cost-effective proppant alternatives being important to sustainable unconventional development.
OSL Consulting provides engineering solutions for the oil and gas industry. They have developed an innovative subsea separation package to enable the cost-effective development of tight gas fields. The package includes a self-contained subsea separation unit installed on the seabed that separates gas from solids. It reduces drilling costs compared to conventional topside facilities and addresses issues like solids production that impact pipeline integrity. The overall investment is approximately one-third less than a standard topside development.
Culzean HPHT: Lessons Learnt From Maersk Oil UK's 1st HPHT Exploration Well &...HPHT Wells Summit
The document discusses lessons learned from the Culzean HPHT exploration well and issues related to appraisal planning. It summarizes the exploration well results, noting that while objectives were achieved there were challenges around pore pressure and fracture gradients. It recommends a "HPHT heavy" design for the appraisal well using a deeper set 13 5/8" intermediate casing to facilitate testing from multiple zones and enable setting the 9 7/8" production casing as deep as possible. The objectives of the appraisal well are to acquire sufficient key data to ascertain economic development and detailed development design.
Adoption of the applied surface-backpressure types of managed pressure drilling (MPD) technologies in deepwater have mainly involved the use of a rotating control device (RCD). The RCD creates a closed drilling system in which the flow out of the well is diverted towards an automated MPD choke manifold (with a high-resolution mass flow meter) that aside from regulating backpressure also increases sensitivity and reduces reaction time to kicks, losses, and other unwanted drilling events. This integration of MPD equipment into floating drilling rigs to provide them with MPD capabilities, including the capacity to perform pressurized mud cap drilling (PMCD) and riser gas mitigation (RGM), has produced improvements not only in drillability and efficiency, but most importantly in process safety. Case histories on how MPD has performed will be presented on the following: • allowed drilling to reach target depth in rank wildcat deepwater wells that have formations prone to severe circulation losses and narrow mud weight windows; • increased drilling efficiency by minimizing non-productive time associated with downhole pressure-related problems and by allowing for the setting of deeper casing seats; • enhanced operational and process safety by allowing for immediate detection of kicks, losses and other critical downhole events. • provided riser gas mitigation capabilities that can detect a gas influx once it enters the drilling fluid stream, and not after it has already broken out above the rig blow-out preventers (BOPs).
This document summarizes a study evaluating different multistage hydraulic fracturing patterns in naturally fractured reservoirs using a coupled geomechanics fracture and flow model. The study models three fracturing patterns - conventional, zipper, and alternating - in a field case with multiple horizontal wells. Simulation results show the zipper pattern provides the highest long-term production rates and cumulative oil volume over 20 years compared to the other patterns. The zipper pattern is recommended as the optimal completion strategy for this type of reservoir.
This document summarizes a field study on using a liquid curable resin system to prevent proppant and formation sand production in high water cut, heavy oil wells in Argentina. The study involved hydraulic fracturing treatments using proppant coated with a low-temperature curable epoxy resin. Field results showed that the resin coating effectively stopped proppant and formation sand from being produced back while maintaining production rates. The resin treatment provided a reliable and cost-effective alternative to sand control screens for controlling solid flowback in marginal reservoirs.
Field development plan, rate of production,SYED NAWAZ
It gives you an idea about an impact of reservoir damage on production rate
Hello Everyone,
Follow my youtube channel "PETROLEUM UNIVERSE" https://lnkd.in/gjZgb7E
For weekly brushing of basics follow me on linkedin
https://lnkd.in/dqPYkwa
Follow and Subscribe only if you like and try to circulate among your friends
Title: Maximizing the Opportunity in Multi-Layered Tight Sand Reservoirs in a Mature Field by Hydraulic Fracturing: A Case Study of Tight Sand Development Project in Thailand
PENNGLEN FIELD Development Plan (GULF of MEXICO)PaulOkafor6
A FDP designed with the goal to define the development scheme that allows the optimization of the hydrocarbon recovery at a minimal cost for project sanction
This was designed by MSc Students from the Institute of Petroleum Studies, UNIPORT/ IFP School, France
The field development plan aims to maximize oil recovery from the Sirri-A oil field located offshore Iran. Key objectives include developing a reservoir model, evaluating development strategies, and determining cash flows. The reservoir is a limestone formation from the Cretaceous period. Analysis shows it has an initial oil in place of 1.78 billion stock tank barrels and is primarily driven by water. Development scenarios include a base case, increased well counts, secondary water injection, and tertiary WAG injection. The WAG scenario recovers an estimated 52.3% of the oil in place.
Mud logging involves continuously monitoring drilling operations and analyzing drill cuttings to evaluate formations and detect hydrocarbons. Two common types of mud logging units are Drillbyte systems, which provide integrated wellsite data management, and Advantage units, which offer computerized, accurate data processing and presentation. Mud logging units contain sensors to monitor drilling parameters, gas detection systems like chromatographs, and materials for examining and describing drill cuttings. Mud logging personnel such as data engineers and mud loggers are responsible for operating equipment, collecting and analyzing data, and providing interpretations to help guide drilling operations.
Review of EOR Selection for light tight oil
Key Themes:
Upfront EOR Development Planning
Cash is king but Permeability Rules
Geology Selects Technology
Nanospheres, Steam Flooding, Misc Gas Flooding, EOR Selection Criteria
Breaking Paradigms in old Fields. Finding “the reservoir key” for Mature Fiel...Juan Diego Suarez Fromm
Two field examples will be presented, where after 50 years of development; fresh oil and gas were produced by changing some reservoir paradigms.
Upsides could be overlooked due to paradigms on field development. The successful one in terms of reserves and cost effective capital expenditure could be visualized as “finding the key for the field”. But as development takes place over many years (decades), the “key” should be a dynamic concept over time, correlated with technology availability, enabling us a better understanding of petroleum resources size, quality and distribution.
Hydraulic fracturing is necessary to produce economic quantities of gas from shale reservoirs with very low permeability. Complex fracture geometry is important to maximize contact between the fracture and reservoir. The fracturing process involves pumping fluid to create fractures, then a slurry of proppant to prop open the fractures. Proppant and fluid selection depends on factors like embedment and closure stress. While aspects like rate, volume, and proppant quantity can be controlled, the natural variations in shale make the exact fracture geometry and productivity impacts difficult to predict. Monitoring tools provide some insight into the fracture treatment results.
Comparative Analysis of Performance of Horizontal and Hydraulically Fractured...ziiishan
The document compares the performance of horizontal and hydraulically fractured vertical wells in a tight gas reservoir using numerical simulations. It describes constructing models of a horizontal well and two fractured vertical well cases in Eclipse reservoir simulation software. The models are used to simulate and compare production rates, decline curves, cumulative production, productivity indices and area open to flow between the well types under different fracture and well lengths. The conclusions found that increasing fracture or horizontal length increased production until economic limits. Productivity was higher for fractured wells but long fractures are impractical. Further work could consider varying additional parameters and including economic analysis.
Trenchless technologies comparing thrust boring with horizontal directional ...Tobiloba Omitola
Thrust boring and horizontal directional drilling (HDD) are trenchless construction methods for installing underground infrastructure with minimal surface disruption. Thrust boring involves drilling a borehole and inserting a steel casing simultaneously using an auger drill head. It is unsteerable. HDD involves drilling a steerable pilot bore, reaming it to size, and pulling the pipeline back through. Key factors in selecting between the two methods include soil conditions, required accuracy, and ability to steer around underground obstacles. Thrust boring is best for stable soils while HDD allows for navigation and is suitable for longer distances and avoiding existing utilities. Both methods seek to minimize environmental and community impacts compared to traditional trenching.
Marginal oil fields present economic challenges but can be profitably developed using unconventional techniques. The document outlines various unconventional techniques like horizontal drilling, hydraulic fracturing, tiebacks, and cable deployed ESPs that have been successfully used in case studies to reduce costs and increase production from marginal fields, making them economically viable. It also discusses the data and time constraints faced in developing marginal fields and how various conventional techniques can help optimize costs.
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
This white paper proposes a subsea separation system using cyclonic technology to improve the economic viability of developing tight, low reserve gas fields in the Southern North Sea. Computational fluid dynamics was used to verify that a cyclone unit could effectively separate solids from well fluids on the seabed. An accumulator would collect solid particles for removal by ROV, while a pipeline would transport separated gas to an offshore platform. Economic modeling indicated the proposed subsea system could reduce costs compared to conventional approaches, making marginal fields commercially feasible.
The document summarizes the installation of an innovative "Capillary Conveyed" gas lift extension system in a well in Vietnam. The existing gas lift system was no longer effective due to declining reservoir pressures. The new system used a 0.75" diameter capillary string to extend the gas lift injection point deeper into the well. After installation, the well resumed production, flowing for 60 days at rates exceeding expectations before being placed on a production cycle. Cumulative production since was 43,000 barrels of oil, with an estimated payback of only 4 days for the installation. The installation demonstrated that the new technology can effectively reinstate production from wells with inefficient gas lift systems.
The document discusses technologies across the LNG value chain, including for gas production, liquefaction, storage, regasification, and transportation. It focuses on floating liquefied natural gas (FLNG) as an emerging technology that allows for offshore natural gas extraction and processing. Key points include:
- FLNG involves extracting gas offshore, processing and liquefying it on a floating facility, then offloading the LNG to tankers for transport.
- The major steps in FLNG gas processing and LNG production include gas reception, stabilization, acid gas removal, dehydration, liquefaction, and storage on the floating facility.
- Technologies that enable FLNG include 3D/4D seismic
Hybrid epb tunnelling in rio de janeiro 2015Abner Silva
This document summarizes the first experiences from tunneling works on the Metro Rio Line 4 project in Rio de Janeiro, Brazil. A 5.2 km long tunnel is being excavated using an innovative hybrid Earth Pressure Balance (EPB) tunnel boring machine (TBM). The first 470 meters of the tunnel passed through sandy soils. Conditioning the sands with polymer foam mixtures allowed the TBM to excavate smoothly in full-face EPB mode while maintaining stable face pressure and conveying mucks through the screw conveyor. Initial experiences showed the benefits of dry, stabilized muck for conveyance compared to wetter, plastic mixtures. No issues were encountered in transferring muck from the screw to the belt conveyor.
1) The document discusses conditioning an old vertical well drilled in 1974 in Argentina to stimulate and test productivity from the Vaca Muerta shale formation.
2) A pilot program was conducted on three wells, applying coiled tubing assisted pinpoint completions to independently stimulate small intervals, with 12 stages used over 130m.
3) The pilot was successful, with the wells producing oil naturally. It demonstrated the viability of the completion technique for stimulating older vertical wells in the Vaca Muerta shale.
This document provides an overview of a graduation project studying the SIMIAN field. It will integrate petroleum geology and exploration, drilling engineering, well logging, reservoir engineering, well testing, and production engineering. The study will include constructing structure contour maps, isopach maps, and calculating the original gas in place. It will also include determining the number of casing strings needed, designing the cement program, predicting drilling problems, and calculating the total drilling cost. Other aspects covered are making qualitative and quantitative log interpretations, identifying the reservoir driving mechanism, determining boundaries and properties from well testing, and selecting the optimum tubing size and gas processing method.
The document discusses various techniques to reduce the environmental footprint of unconventional gas drilling operations, including:
1) Prototype small footprint drilling rigs, multi-well pad drilling, and coiled tubing drilling to minimize land disturbance.
2) Centralized fracturing to hydraulically fracture multiple wells from a single location.
3) Innovative water management techniques like constructed wetland systems to treat produced water on-site.
4) Developing an "EFD scorecard" to measure drilling technologies' performance on issues like air, water, and waste management.
1) Statoil uses an extensive "toolbox" of improved oil recovery (IOR) techniques like water and gas injection, chemicals, and new well technologies to increase oil recovery from fields.
2) One promising new technology is through-tubing drilling and completion, which allows drilling and lining of wellbores simultaneously to improve efficiency and reduce costs.
3) Statoil is developing technologies like steerable drilling liners to further improve through-tubing operations and aims to enable "one-trip" drilling and cementing in the future to maximize oil recovery.
Drilling and Cementing to Isolate Productive Series and High Pressure Zones: ...Vusal Iskandarov
Drilling and Cementing to Isolate Productive Series and High Pressure Zones: A Successful Case History Enables Zonal Isolation in High Pressure Gas Well with Close PPFG margins in South Caspian Basin
The document describes a new downhole cavitation tool called the KROT-CT that uses hydrodynamic cavitation rather than piston-driven mechanics to generate strong vertical impacts on the drill bit. This allows it to overcome limitations of previous percussion tools by improving performance, flexibility, and reliability. The KROT-CT can help increase drilling rates in difficult conditions, borehole quality, footage drilled between trips, and rig efficiency while reducing vibrational stresses and non-productive time.
Custom offshore pipeline repair systems can reduce repair times and costs in Angola. An industry group studied how to adapt existing repair concepts for high-pressure pipelines in Angola's deep waters. They determined that creating a shared repair system for operators would lower costs compared to each operating their own. The system needs to handle a range of pipe sizes and depths up to 3,000 meters, and repair both single-walled and pipe-in-pipe pipelines using remote equipment. Insulation must be restored on repaired sections to prevent hydrates during repairs.
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.
Farhad Orak presented research on optimizing production from a field in South Pars gas field using nodal analysis and multilateral well design. The field contains four producing gas layers separated by anhydrite layers in a reservoir 400 meters thick. Conventional wells risk water coning issues on the flanks where lower layers are water-filled. The study models a dual opposed multilateral well using nodal analysis, finding production could be optimized to 114 million standard cubic feet per day by increasing tubing size to 6.18 inches, setting wellhead pressure to 2000 psi, assuming 5% water cut and a skin factor of +1. Recommendations include further investigating horizontal branch length and angle to increase reservoir exposure and controlling production
SRK provides underground mining expertise and services to optimize project value. They utilize an innovative planning methodology to select the appropriate mining method based on deposit characteristics and client goals. This methodology focuses on understanding the complete mining context to establish a robust plan. Case studies describe projects where SRK assisted with feasibility studies, mine planning, transition from open pit to underground, and evaluating mining methods to minimize risks and costs. SRK's services include ventilation design, backfill analysis, cost modeling, life-of-mine planning, and geotechnical analysis.
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2. Edition 1. Volume 1.
January 2020
Editor in Chief:
Miguel Lugo. 27,315,874
Social Networks
World Oil Magazine
@WorldOilMagazine
@WorldOilMagazine
3. WORLD MAGAZINE
INNOVATIONS & TECHNOLOGY
EDITORIAL
Both technology and fossil hydrocarbons (oil and
gas) are assets of high strategic value for any
particular society or nation. Technology, in the form
of products, processes and knowledge, is as old as
man and has a broad spectrum of application,
ranging from solutions for the best quality of life of
people.
The strategic importance of oil in modern times lies
in its civil uses. Most nations rely heavily on oil and
gas. And while the technology for its use is widely
developed and globalized, the technology for the
search, extraction and refining of oil is much less
widespread. It follows that not only the physical
resource (the barrels); but also the technology
necessary for the exploration, production and
refining of oil and gas; and the specialized human
talent and capable of administering these
technologies, are of the highest value. These three
elements are of great geopolitical influence and
having them is an advantage.
4. CONTENT:
CONTENT
Editorial 3
Operator Achieves 99.5 Percent Run Efficiency in
Complex Carbonate Reservoir
5
Successful Dual Drilling Operations Saves Aker BP
USD 1.2 Million with Zero HSE Issues 6
Top of Cement Identification in Ultra-Deepwater Well
Saves Operator USD 700,000
7
Tecpetrol Optimizes Location of Fracturing Zones
and Lateral Placement Using LithoFlex Service 9
HEAL System Increases Production More Than 75% from 25
Montney Shale Wells
10
SIMplus Retrievable Bridge Plug Installs Reliable Barrier
for Sealing Tubing Leak 11
COMMERCIAL SECTION 12
ENETRTAINMENT
5. WORLD MAGAZINE
INNOVATIONS & TECHNOLOGY
Operator Achieves 99.5 Percent
Run Efficiency in Complex
Carbonate Reservoir
EARTHSTAR® ULTRA-DEEP RESISTIVITY SERVICE GEOMAPS MULTIPLE OIL SATURATION
LAYERS AND FLUID CONTACTS, AND HELPS EXECUTE DIRECTIONAL PLAN WITHIN PAY
ZONE
A major oil and gas operator in southeast Asia
drilled extended-reach smart wells for oil
recovery in a narrow 10-kilometer x 2-kilometer
(6.2-mile x 1.2-mile) carbonate pinnacle
reservoir. These thin oil rim development wells
were challenging because of high uncertainty in
reservoir structural depth and production
performance, with no history or comparable
analogues as reference. Additionally, the
horizontal well placement was targeted at the
middle of the oil zone, with a specific standoff
from the gas-oil contact, which had high true
vertical depth (TVD) uncertainty.
The key performance indicators (KPIs) for
these wells included:
» Drilling the 8½-inch lateral drain with minimal
undulation for ease of running the completion
string
» Achieving all logging-while-drilling (LWD)
requirements across the target interval
» Delivering flawless execution with minimum
non-productive time
EARTHSTAR SERVICE ENHANCES RESERVOIR
UNDERSTANDING
The Halliburton Sperry Drilling team recommended
the EarthStar® ultra-deep resistivity service, which
features a high signal-to-noise ratio arising from
state-of-the-art engineering. This technology is
proven to detect and map reservoir structure and
fluid boundaries up
to 225 feet (68 meters) from the wellbore. For this
particular operation, the EarthStar service resolved
multiple complex fluid boundaries, delineating the
gas-oil boundary and also resolving two distinct
low-resistivity signatures – thus defining the oil-
water contact. Additionally, a detailed pre-well
model, using multiple offset wells and various
possible
geologic structural models, further assured the
operator that the EarthStar service would be able to
resolve the targets clearly.
ACCURATE WELL PLACEMENT AND
GEOMAPPING MAXIMIZE ASSET VALUE
The 12¼-inch hole sections of the Phase 1 drilling
campaign were landed geometrically at the mid-
point of the thin oil rim, based on a base-case, gas-
oil contact. Thereafter, the long 8½-inch horizontal
sections were drilled with minimal undulation within
the +/- 5-foot (1.5-meter) TVD target window, as
specified by the operator, to facilitate running the
completion string. The wells were executed
efficiently with each hole section being drilled
6. Successful Dual Drilling OperationsSaves Aker
BP USD 1.2 Million with Zero HSE Issues
THREE SIMULTANEOUS DUAL DRILLING OPERATIONS REDUCE WELL TIME AND
ATTAIN WORLD-FIRST RECORD
NORTH SEA, NORWAY
In collaboration with Aker BP,
Halliburton Sperry Drilling
planned and drilled two wellbores
at three different proximal
locations in the North Sea,
offshore Norway near Stavanger. A
prerequisite for each location was
to first drill a pilot hole to
evaluate
the presence of shallow gas.
Typically, the conductor hole is
drilled before a pilot hole,
followed by the opening of the
pilot hole for running the outer-
diameter (OD) casing.
The deepwater rig had a dual
derrick design, with full drilling
capacity in both derricks. Since
the derricks’ well centers were
approximately 33 feet (10 meters)
apart, it was decided in the
planning phase of pre-operations
to drill two wells simultaneously:
the “pilot-hole shallow-gas”
wellbore and the “main”
wellbore. While this initiative
was thought to be efficient and
time saving, it could also
potentially introduce risk factors.
OPTIMIZED
PROJECT
MANAGEMENT
AND EFFICIENT
EQUIPMENT
UTILIZATION HELP
TO REDUCE WELL
TIME AND BREAK
SIMOPS RECORD
7. Top of Cement Identificationin Ultra-Deepwater Well
Saves Operator USD 700,000
XBAT™ SERVICEPROVIDES ACCURATE TOP OF CEMENT EVALUATION
DURING CEMENTING OF LINER
OVERVIEW
Acoustic logging-while-drilling (LWD) tools
can be used to provide an assessment of
top
of cement (TOC), offering an alternative
to a conventional wireline cement bond
log (CBL). During the cementing of a
75⁄8-inch liner in an ultra-deepwater
Gulf of Mexico well, the operator could
not establish cement returns during
pumping operations.
The final differential pressure of 150 psi
during cementing was less than the
planned 180 psi, and, based upon the
cement lift pressure, the operator
anticipated the cement column to be
less than planned by approximately 150
feet (46 meters). Foreseeing cement
integrity issues, the operator planned to
perform a cement squeeze job following
a cleanout run, and also planned to use
a wireline CBL, run on a tractor, to
confirm the TOC.
XBAT™ SERVICE HELPS REDUCE WELL
TIME THROUGH EARLY TOC DETECTION
During the cleanout run to drill the
cement inside the liner, a complete fluid
displacement was performed. The XBAT
azimuthal sonic and ultrasonic LWD
service was included in the drill-out
assembly, and was used to log inside
the casing during both the trip-in pass
and
trip-out pass while the liner was
pressurized differentially. A wireline CBL
was run following the displacement, but,
since it was not possible to perform a
pressurized logging pass, the presence of
the microannulus could not be
confirmed.
8. Toc analysis performed inside 75⁄8-inch casing during the trip-in pass of a cement cleanout run (left) compared to the
trip-out pass (right). The trip-out pass occurred with lighter mud than the trip-in pass, following displacement of the
drilling fluid.
WAVEFORMS AND CASING ARRIVAL ANALYSIS CONFIRM TOC
The XBAT service acquired acoustic waveforms during the cleanout run inside
the liner to assist with the identification and confirmation of TOC acquired by
the wireline CBL.The tool was programmed
to fire two high-frequency monopole modes and to acquire data in memory at a
fast sample rate to ensure sufficient data density without the need to slow
down the tripping operations. TOC was identified at around X9,650 feet, based
on based upon four different datasets acquired from the two different firing
modes and from both trip-in and trip-out logging runs. The waveform analysis
and casing arrival analysis complemented each other in confirming the TOC
depth, and helped to identify a micro-annulus, in contrast to the wireline CBL
data, which was inconclusive.
As a direct result of the LWD analysis, the operator resumed normal drilling
operations in the next hole section without the need for the cement squeeze,
and confirmed the suitability of the XBAT service for future TOC evaluation
applications.
9. Tecpetrol Optimizes Location of Fracturing
Zones and Lateral Placement Using LithoFlex
Service
Optimize drilling and completion strategy with cost-efficient solution
The Vaca Muerta Formation in Neuquén, Argentina, contains complex Mesozoic shales
and is rich in tight oil and gas but requires multiple data sets to understand production
potential. Tecpetrol needed to evaluate production potential in a vertical well in the
formation to optimize drilling and completion design; however, well conditions
precluded running wireline. Tecpetrol sought a cost-efficient solution that would
provide an accurate evaluation of rock heterogeneity to assess production potential,
support hydraulic fracturing operations, and help place the lateral.
Evaluate rock heterogeneity from cuttings
Schlumberger recommended using the LithoFlex service to provide a cost-efficient near-
real-time formation evaluation using the HRDM, XRF, and DRIFTS components. Together,
these components provide accurate and comprehensive measurements of lithology,
mineralogy, and elemental composition from cuttings, enabling a well-informed
comparison of rock heterogeneity. By accurately capturing the geochemical fingerprint
in the vertical well, fracturing operations can be optimized, and the best productive
intervals can be used to guide lateral placemen
10. HEAL System Increases Production More
Than 75% from 25 Montney Shale Wells
The horizontal enhanced artificial lift system—
the HEAL System—guides production from the
horizontal section into a sized regulating string
(SRS) in the build section. Production flows up
the SRS, where it is conditioned into a
stabilized multiphase state, lowering fluid
density, lifting liquids, and mitigating slugs.
The conditioned flow is delivered to a vortex
separator, which separates gas and solids from
the liquid. The gas rises through the annulus
and conditioned liquids are drawn up the
vortex separator and delivered to the pump
located in the vertical section. Extremely
efficient downhole separation and consistent
flows minimize gas interference and gas
locking to maximize pump fillage; the system
also maintains a very low bottomhole
pressure, enhancing drawdown to increase
production. As a result of these benefits,
smaller pumping equipment can efficiently
achieve higher production rates, reducing unit
lifting costs.
Production rate increased in excess
of 75%
The HEAL System increased long-
term (>12 months) production by
more than 75% in the 25 wells,
compared with the previous
production decline trend. Average
incremental production was 18,400
BOE per well in the 12 months after
the system was installed. As a result,
the operator recovered the cost of
each HEAL System installation in just
2 to 4 months.
11. SIMplus Retrievable Bridge Plug Installs
Reliable Barrier for Sealing Tubing Leak
Diagnose and remediate leak in constrained operating conditions
An operator suspected possible communication between the casing and tubing in a
well offshore Venezuela. The typically limited space on the production platform
necessitated performing the diagnosis and remediation on slickline. However,
conducting well intervention techniques on conventional slickline could not provide
precise depth placement, much less real-time control and monitoring capabilities to
confirm operations.
Perform digital slickline operations with real-time control and monitoring
LIVE digital slickline services pair the simplicity and compact footprint of slickline
operations with real-time digital telemetry to deliver relevant downhole
measurement data to the surface in real time for significant improvements in control,
quality, and safety. These capabilities enable running real-time production logs on
LIVE PL digital slickline production logging services where previously memory logging
was the only option.
The SIMplus retrievable bridge plug is an expandable barrier that can be deployed on
slickline, electric line, coiled tubing, drillpipe, or tractor to install a high-performance
seal in fluid- and temperature-cycling environments. The SIMplus plug is the only plug
that can be mechanically set by conventional slickline jarring and has achieved a
14310:2008 grade V3 rating to provide operators with reliable conformance to the
most stringent well barrier criteria. Its advanced setting mechanism and large internal
diameter make it the ideal sealing solution for leak detection and remediation.