The document describes the tasks involved in preparing oil and gas PVT (pressure-volume-temperature) data for reservoir simulation. These include collecting representative fluid samples, selecting appropriate lab tests, developing equations of state models to represent the fluid properties, characterizing heptanes-plus, initializing fluid properties in the reservoir model, and generating black-oil PVT tables for black-oil simulations. The document provides guidance on best practices for each task to ensure accurate PVT data for reservoir modeling and forecasting.
CMG provides three reservoir simulation software packages: IMEX, GEM, and STARS. IMEX is a black oil simulator used for conventional reservoirs. GEM is a compositional simulator that can model complex fluid behavior, including processes where inter-phase mass transfer is important. STARS is an advanced simulator used for thermal modeling and complex reactions. It is the industry standard for modeling chemical EOR processes, including polymer flooding, low salinity flooding, and microbial EOR. CMG has extensive experience using STARS to model H2S bacterial souring through history matching and forecasting. Reservoir engineers can choose the appropriate CMG simulator based on the reservoir fluids and recovery process being modeled.
Introduction to CMG Reservoir Simulator.pdfMehdi Zallaghi
CMG provides reservoir simulation software including GEM, IMEX, STARS, CMOST and other components. GEM is a compositional simulator for modeling EOR using gas injection. IMEX is a black oil simulator for primary and secondary recovery. STARS models thermal recovery processes using steam or solvents. CMOST enables history matching, optimization and uncertainty analysis. Models are constructed using BUILDER and results are analyzed with RESULTS. CMG software provides an integrated workflow for reservoir characterization, modeling, prediction and validation.
EOR methods involve injecting various substances into oil fields to increase the amount of oil extracted. Primary recovery uses natural reservoir pressure to extract 5-10% of oil. Secondary recovery injects water or gas to extract an additional 25-30% of oil. Tertiary recovery injects different materials like steam, CO2, polymers or surfactants to extract another 20-30% of oil remaining after primary and secondary recovery. The three main EOR categories are thermal, gas, and chemical injection. Thermal injection uses heat to reduce oil viscosity while gas injection uses gases like CO2, nitrogen or natural gas to increase oil recovery. Chemical injection uses polymers, alkali or surfactants to improve oil mobility.
Overview of Reservoir Simulation by Prem Dayal Saini
Reservoir simulation is the study of how fluids flow in a hydrocarbon reservoir when put under production conditions. The purpose is usually to predict the behavior of a reservoir to different production scenarios, or to increase the understanding of its geological properties by comparing known behavior to a simulation using different geological representations.
The document provides an overview of reservoir engineering concepts related to waterflooding projects for oil recovery. It discusses primary, secondary, and tertiary recovery categories. For waterflooding projects specifically, it outlines key factors to consider like reservoir geometry, fluid properties, depth, lithology, fluid saturations, uniformity, and natural driving mechanisms. It provides details on evaluating these factors and their implications for project suitability and design.
This document discusses factors to consider when evaluating a reservoir's suitability for waterflooding. Key factors include reservoir geometry, fluid properties, depth, lithology, fluid saturations, uniformity, and original driving mechanism. Optimal waterflooding occurs when the reservoir is near bubble point pressure to reduce oil viscosity and increase mobility. Trapped gas saturation can also increase recovery by displacing residual oil from larger pores. Careful pressure control may allow optimal trapped gas to reduce residual oil saturation.
This document provides information about reservoir engineering. It discusses how reservoir engineers use tools like subsurface geology, mathematics, and physics/chemistry to understand fluid behavior in reservoirs. It also describes different well classes used for injection/extraction, environmental impacts of enhanced oil recovery, and various reservoir engineering techniques like simulation modeling, production surveillance, and evaluating volumetric sweep efficiency. Thermal and chemical enhanced oil recovery methods are explained, including gas, steam, polymer, surfactant, microbial and in-situ combustion injection.
CMG provides three reservoir simulation software packages: IMEX, GEM, and STARS. IMEX is a black oil simulator used for conventional reservoirs. GEM is a compositional simulator that can model complex fluid behavior, including processes where inter-phase mass transfer is important. STARS is an advanced simulator used for thermal modeling and complex reactions. It is the industry standard for modeling chemical EOR processes, including polymer flooding, low salinity flooding, and microbial EOR. CMG has extensive experience using STARS to model H2S bacterial souring through history matching and forecasting. Reservoir engineers can choose the appropriate CMG simulator based on the reservoir fluids and recovery process being modeled.
Introduction to CMG Reservoir Simulator.pdfMehdi Zallaghi
CMG provides reservoir simulation software including GEM, IMEX, STARS, CMOST and other components. GEM is a compositional simulator for modeling EOR using gas injection. IMEX is a black oil simulator for primary and secondary recovery. STARS models thermal recovery processes using steam or solvents. CMOST enables history matching, optimization and uncertainty analysis. Models are constructed using BUILDER and results are analyzed with RESULTS. CMG software provides an integrated workflow for reservoir characterization, modeling, prediction and validation.
EOR methods involve injecting various substances into oil fields to increase the amount of oil extracted. Primary recovery uses natural reservoir pressure to extract 5-10% of oil. Secondary recovery injects water or gas to extract an additional 25-30% of oil. Tertiary recovery injects different materials like steam, CO2, polymers or surfactants to extract another 20-30% of oil remaining after primary and secondary recovery. The three main EOR categories are thermal, gas, and chemical injection. Thermal injection uses heat to reduce oil viscosity while gas injection uses gases like CO2, nitrogen or natural gas to increase oil recovery. Chemical injection uses polymers, alkali or surfactants to improve oil mobility.
Overview of Reservoir Simulation by Prem Dayal Saini
Reservoir simulation is the study of how fluids flow in a hydrocarbon reservoir when put under production conditions. The purpose is usually to predict the behavior of a reservoir to different production scenarios, or to increase the understanding of its geological properties by comparing known behavior to a simulation using different geological representations.
The document provides an overview of reservoir engineering concepts related to waterflooding projects for oil recovery. It discusses primary, secondary, and tertiary recovery categories. For waterflooding projects specifically, it outlines key factors to consider like reservoir geometry, fluid properties, depth, lithology, fluid saturations, uniformity, and natural driving mechanisms. It provides details on evaluating these factors and their implications for project suitability and design.
This document discusses factors to consider when evaluating a reservoir's suitability for waterflooding. Key factors include reservoir geometry, fluid properties, depth, lithology, fluid saturations, uniformity, and original driving mechanism. Optimal waterflooding occurs when the reservoir is near bubble point pressure to reduce oil viscosity and increase mobility. Trapped gas saturation can also increase recovery by displacing residual oil from larger pores. Careful pressure control may allow optimal trapped gas to reduce residual oil saturation.
This document provides information about reservoir engineering. It discusses how reservoir engineers use tools like subsurface geology, mathematics, and physics/chemistry to understand fluid behavior in reservoirs. It also describes different well classes used for injection/extraction, environmental impacts of enhanced oil recovery, and various reservoir engineering techniques like simulation modeling, production surveillance, and evaluating volumetric sweep efficiency. Thermal and chemical enhanced oil recovery methods are explained, including gas, steam, polymer, surfactant, microbial and in-situ combustion injection.
This document is a book summarizing the state of the art in well test interpretation. It discusses the fundamentals of well testing including the diffusivity equation, wellbore storage effects, type curves, and controlling the downhole environment. It also reviews interpretation methodology, specialized test types like layered reservoirs and horizontal wells, and using downhole flow rate measurements to improve interpretations. The goal is to provide operators with the knowledge to design effective well testing programs to characterize reservoirs.
This document provides an overview of enhanced oil recovery (EOR) methods using gas injection. It discusses the main gas injection methods including miscible and immiscible processes. Key injection gases are carbon dioxide (CO2), nitrogen (N2), and natural gas. CO2 flooding has been widely used in the US and offers potential for combining EOR with CO2 storage. Economics of CO2-EOR and carbon capture and storage (CCS) are also reviewed. While gas injection is common, the number of N2 flood projects has declined with most current EOR relying on natural gas or CO2 if it is available. Offshore, EOR potential exists but is currently limited to gas and water-alternating-
This document discusses enhanced oil recovery (EOR) techniques used to extract crude oil beyond primary and secondary recovery methods. It defines EOR as any process that improves oil recovery beyond what conventional methods would produce. EOR techniques are divided into four categories: miscible flooding processes, chemical flooding processes, thermal flooding processes, and microbial flooding processes. Thermal processes are generally used for heavy oils while chemical and miscible processes target lighter oils. The document also outlines key recovery factors and terminology used in EOR like displacement efficiency, sweep efficiency, and mobility ratio.
The document is a report on enhanced oil recovery through caustic flooding submitted by Dhiman Kakati. It discusses the mechanisms of caustic flooding including reduction of oil-water interfacial tension through formation of in-situ surfactants. Experiments were conducted to measure the interfacial tension between Assam crude oil and an aqueous solution of 1% sodium bicarbonate using a spinning drop tensiometer. The results showed that interfacial tension remained constant for a fixed rotational speed but increased with increasing drop diameter. The report concludes that Assam crude oil would be responsive to caustic flooding based on the experimental observations and outlines some key factors for effective implementation of caustic flooding in oil reservoirs.
The document provides an overview of various chemical enhanced oil recovery (EOR) methods including polymer flooding, colloidal dispersion gels, alkaline flooding, alkaline-polymer flooding, surfactant-polymer flooding, and alkaline-surfactant-polymer flooding. It discusses the basics of each method, how they work to increase oil recovery, examples of their application, and screening criteria for determining applicability to different reservoirs. Key topics covered include the use of polymers to increase water viscosity and improve sweep efficiency, using alkalis and surfactants to lower oil-water interfacial tension, and combining methods such as polymer gels followed by chemical EOR to control conformance.
Seminar on water influx and well testingRupam_Sarmah
This document summarizes a seminar on water influx and well testing. It includes an acknowledgement, abstract, definitions of water influx, classifications of aquifer systems, recognition of natural water influx, and an introduction to well testing. Well testing objectives are to evaluate well conditions, obtain reservoir parameters, and determine productive zones. Common well tests include single-well and multi-well tests like drawdown, buildup, interference, and pulse tests.
There are three main types of oil recovery:
- Primary recovers oil using reservoir pressure
- Secondary uses water or gas injection to maintain pressure for additional oil recovery
- Tertiary (Enhanced Oil Recovery/EOR) introduces fluids like polymers to increase recovery by reducing viscosity and improving flow. EOR techniques like polymer flooding can increase production significantly, such as from 10 to 50 barrels per day. EOR represents a large market and revenues are growing. Proper management is needed to control environmental impacts of EOR produced water.
This document provides an overview and outline of a course on fundamentals of reservoir simulation. The course aims to review background on petroleum reservoir simulation and provide hands-on practice with Excel. The outline includes topics like flow equations for reservoirs, finite difference methods, single-phase and multiphase flow simulation. References are provided for additional reading.
This document provides an overview of fundamental reservoir fluid properties and concepts. It discusses sampling and analyzing reservoir fluids, classifying hydrocarbons and their phase behaviors. Key fluid properties like gas, liquid, and formation water characteristics are examined. Common hydrocarbon types and compositions in crude oil and natural gas are also outlined. Fundamental reservoir engineering concepts involving hydrocarbon reserves calculations and fluid flow are reviewed.
The efficiency of enhanced oil recovery method is a measure of the ability to provide greater hydrocarbon recovery than by natural depletion, at an economically attractive production rate.
Facebook Page: https://www.facebook.com/petroleumengineeringz
Blogspot: http://petroleumengineeringsociety.blogspot.com/
Master class presentation on artificial lift screening and selection. Prepared for Praxis' Interactive Technology Workshop on Artificial Lift, Dubai, September 2013.
Gas Lift Design: Comparative Study of Continuous and Intermittent Gas Lift (C...Nicodeme Feuwo
This document was produced as part of my final year project of training to obtain a petroleum engineering diploma.
The aim of this project is to make a comparative study between continuous and intermittent gas lift systems based on real data from an oil well in Algeria, and to choose the system best suited to increase the production of the well.
This study was carried out by a manual design using the method of “fixed pressure drop” for the continuous gas lift system and “fallback gradient” method for intermittent gas lift system.
We were able to determine at the end of this study that the system best suited to the current conditions of our well would be the intermittent gas lift system and we also proposed that it should be combine with the "plunger lift " system in order to increase the efficiency of the intermittent gas lift system by eliminating problems linked to the phenomenon of" fallback " thus increase the production of our wells.
- Reservoirs are classified based on the composition of hydrocarbons present, initial reservoir pressure and temperature, and the pressure and temperature of produced fluids.
- A pressure-temperature diagram is used to classify reservoirs and describe the phase behavior of reservoir fluids, delineating the liquid, gas, and two-phase regions.
- Based on the diagram, reservoirs are classified as oil reservoirs if the temperature is below the critical temperature, and gas reservoirs if above the critical temperature.
History matching was performed on the Snark Field reservoir simulation model to match production data. Sensitivity analysis identified the aquifer properties and a fault transmissibility as uncertain parameters. Tuning runs modified these properties, achieving a good match. Forecasts with injection wells predicted improved production. Future analysis in OFM will identify workover candidates and explain water breakthrough.
This document discusses concepts in applied reservoir engineering. It defines key reservoir terms like reservoir rock, cap rock, and reservoir fluids. It also covers rock and fluid properties important for reservoir characterization like porosity, permeability, and PVT properties. Methods for calculating original hydrocarbon in place are presented, including volumetric and material balance approaches. Determining reservoir drive mechanisms and predicting future performance through primary and secondary recovery methods are also summarized.
A Beginners Guide to using PVTSim for Multi-phase calculations for budding engineers.
Typical operations performed in PVTSim are
1. Fluid Database Creation – Composition based
2. Fluid Characterization - Based on Plus fractions
3. Fluids Flashing - Fluid Property Determination
4. Fluid Mixing – for e.g. mixing of various reservoir fluids for their resultant composition
5. Water Saturation of Reservoir Fluid Compositions (dry basis) to arrive at wet composition
6. Viscosity Tuning of Oils based on Laboratory Data (e.g., ASTM D 341, Viscosity vs. Temperature)
7. Hydrate Curve Generation
8. Inhibitor Dosing and Hydrate Curve Shift study
The document discusses enhanced oil recovery (EOR) methods, focusing on steam injection. It defines EOR as techniques for extracting more crude oil from reservoirs beyond primary and secondary recovery methods. Steam injection is a thermal EOR method that involves injecting steam into reservoirs to lower oil viscosity and produce more oil. There are two main steam injection techniques - cyclic steam stimulation (also called huff-and-puff) which alternates between steam injection and production from single or multiple wells, and steam flooding which continuously injects steam into reservoirs to displace oil towards production wells. The document outlines some advantages and disadvantages of steam injection and economic considerations.
Heavy Oil recovery traditionally starts with depletion drive and (natural) waterdrive with very low recoveries as a result. As EOR technique, steam injection has been matured since the 1950s using CSS (cyclic steam stimulation), steam drive or steam flooding, and SAGD (steam assisted gravity drainage). The high energy cost of heating up the oil bearing formation to steam temperature and the associated high CO2 footprint make steam based technology less attractive today and many companies in the industry have been actively trying to find alternatives or improvements. As a result there are now many more energy efficient recovery technologies that can unlock heavy oil resources compared with only a decade ago. This presentation will discuss breakthrough alternatives to steam based recovery as well as incremental improvement options to steam injection techniques. The key message is the importance to consider these techniques because steam injection is costly and has a high CO2 footprint
Johan van Dorp holds an MSc in Experimental Physics from Utrecht University and joined Shell in 1981. He has served on several international assignments, mainly in petroleum and reservoir engineering roles. He recently led the extra heavy-oil research team at the Shell Technology Centre in Calgary, focusing on improved in-situ heavy-oil recovery technologies. Van Dorp also was Shell Group Principal Technical Expert in Thermal EOR and has been involved with most thermal projects in Shell throughout the world, including in California, Oman, the Netherlands, and Canada. He retired from Shell after more than 35 years in Oct 2016. Van Dorp (co-)authored 13 SPE papers on diverse subjects.
The document discusses definitions and categories of petroleum reserves based on probabilities of production. It defines proven, probable, and possible reserves, which have 90%, 50%, and 10% certainty of being produced, respectively. Methods for estimating reserves are described, including volumetric analysis, decline curve analysis, and production forecasting based on projected prices, costs, and other factors.
Enhanced oil recovery techniques like miscible gas injection can be used to extract additional oil from reservoirs. Carbon dioxide flooding involves restoring reservoir pressure with water injection and then injecting CO2 to form a miscible front that dissolves in the oil. Cyclic CO2 stimulation uses repeated injection and production cycles to reduce oil viscosity. Nitrogen flooding works for light oil reservoirs by vaporizing oil components to create a miscible nitrogen front. The conditions for miscibility depend on pressure, temperature, and fluid compositions as represented on phase diagrams.
26_MAR_2013 Brian Moffatt - Reservoir Fluid PVT Analysis.pdfMohanadHussien2
The document discusses how to maximize the value of PVT (pressure-volume-temperature) data for reservoir appraisal and development planning. It outlines several key points:
1) PVT data quality control (QC) is important to identify potential errors from sampling, storage, and laboratory measurements that could affect development decisions.
2) When modeling PVT data, it is important to focus on matching key parameters like phase behavior that are most relevant to the reservoir conditions of interest.
3) Uncertainties in PVT data, if not properly addressed, could significantly impact development aspects like volumetric calculations, reservoir simulation modeling, and identification of flow assurance issues. Placing PVT data in the proper field context
The document summarizes key considerations for gas condensate PVT data and modeling. It discusses:
1) The importance of the gas Z-factor for calculating initial fluids in place and depletion recoveries.
2) How compositional variation data during depletion is needed to forecast condensate rates and recovery profiles, and to define gas cycling potential.
3) That EOS modeling requires accurate molar composition and C7+ properties data, and commonly uses pseudocomponents to reduce the number of components in the model.
This document is a book summarizing the state of the art in well test interpretation. It discusses the fundamentals of well testing including the diffusivity equation, wellbore storage effects, type curves, and controlling the downhole environment. It also reviews interpretation methodology, specialized test types like layered reservoirs and horizontal wells, and using downhole flow rate measurements to improve interpretations. The goal is to provide operators with the knowledge to design effective well testing programs to characterize reservoirs.
This document provides an overview of enhanced oil recovery (EOR) methods using gas injection. It discusses the main gas injection methods including miscible and immiscible processes. Key injection gases are carbon dioxide (CO2), nitrogen (N2), and natural gas. CO2 flooding has been widely used in the US and offers potential for combining EOR with CO2 storage. Economics of CO2-EOR and carbon capture and storage (CCS) are also reviewed. While gas injection is common, the number of N2 flood projects has declined with most current EOR relying on natural gas or CO2 if it is available. Offshore, EOR potential exists but is currently limited to gas and water-alternating-
This document discusses enhanced oil recovery (EOR) techniques used to extract crude oil beyond primary and secondary recovery methods. It defines EOR as any process that improves oil recovery beyond what conventional methods would produce. EOR techniques are divided into four categories: miscible flooding processes, chemical flooding processes, thermal flooding processes, and microbial flooding processes. Thermal processes are generally used for heavy oils while chemical and miscible processes target lighter oils. The document also outlines key recovery factors and terminology used in EOR like displacement efficiency, sweep efficiency, and mobility ratio.
The document is a report on enhanced oil recovery through caustic flooding submitted by Dhiman Kakati. It discusses the mechanisms of caustic flooding including reduction of oil-water interfacial tension through formation of in-situ surfactants. Experiments were conducted to measure the interfacial tension between Assam crude oil and an aqueous solution of 1% sodium bicarbonate using a spinning drop tensiometer. The results showed that interfacial tension remained constant for a fixed rotational speed but increased with increasing drop diameter. The report concludes that Assam crude oil would be responsive to caustic flooding based on the experimental observations and outlines some key factors for effective implementation of caustic flooding in oil reservoirs.
The document provides an overview of various chemical enhanced oil recovery (EOR) methods including polymer flooding, colloidal dispersion gels, alkaline flooding, alkaline-polymer flooding, surfactant-polymer flooding, and alkaline-surfactant-polymer flooding. It discusses the basics of each method, how they work to increase oil recovery, examples of their application, and screening criteria for determining applicability to different reservoirs. Key topics covered include the use of polymers to increase water viscosity and improve sweep efficiency, using alkalis and surfactants to lower oil-water interfacial tension, and combining methods such as polymer gels followed by chemical EOR to control conformance.
Seminar on water influx and well testingRupam_Sarmah
This document summarizes a seminar on water influx and well testing. It includes an acknowledgement, abstract, definitions of water influx, classifications of aquifer systems, recognition of natural water influx, and an introduction to well testing. Well testing objectives are to evaluate well conditions, obtain reservoir parameters, and determine productive zones. Common well tests include single-well and multi-well tests like drawdown, buildup, interference, and pulse tests.
There are three main types of oil recovery:
- Primary recovers oil using reservoir pressure
- Secondary uses water or gas injection to maintain pressure for additional oil recovery
- Tertiary (Enhanced Oil Recovery/EOR) introduces fluids like polymers to increase recovery by reducing viscosity and improving flow. EOR techniques like polymer flooding can increase production significantly, such as from 10 to 50 barrels per day. EOR represents a large market and revenues are growing. Proper management is needed to control environmental impacts of EOR produced water.
This document provides an overview and outline of a course on fundamentals of reservoir simulation. The course aims to review background on petroleum reservoir simulation and provide hands-on practice with Excel. The outline includes topics like flow equations for reservoirs, finite difference methods, single-phase and multiphase flow simulation. References are provided for additional reading.
This document provides an overview of fundamental reservoir fluid properties and concepts. It discusses sampling and analyzing reservoir fluids, classifying hydrocarbons and their phase behaviors. Key fluid properties like gas, liquid, and formation water characteristics are examined. Common hydrocarbon types and compositions in crude oil and natural gas are also outlined. Fundamental reservoir engineering concepts involving hydrocarbon reserves calculations and fluid flow are reviewed.
The efficiency of enhanced oil recovery method is a measure of the ability to provide greater hydrocarbon recovery than by natural depletion, at an economically attractive production rate.
Facebook Page: https://www.facebook.com/petroleumengineeringz
Blogspot: http://petroleumengineeringsociety.blogspot.com/
Master class presentation on artificial lift screening and selection. Prepared for Praxis' Interactive Technology Workshop on Artificial Lift, Dubai, September 2013.
Gas Lift Design: Comparative Study of Continuous and Intermittent Gas Lift (C...Nicodeme Feuwo
This document was produced as part of my final year project of training to obtain a petroleum engineering diploma.
The aim of this project is to make a comparative study between continuous and intermittent gas lift systems based on real data from an oil well in Algeria, and to choose the system best suited to increase the production of the well.
This study was carried out by a manual design using the method of “fixed pressure drop” for the continuous gas lift system and “fallback gradient” method for intermittent gas lift system.
We were able to determine at the end of this study that the system best suited to the current conditions of our well would be the intermittent gas lift system and we also proposed that it should be combine with the "plunger lift " system in order to increase the efficiency of the intermittent gas lift system by eliminating problems linked to the phenomenon of" fallback " thus increase the production of our wells.
- Reservoirs are classified based on the composition of hydrocarbons present, initial reservoir pressure and temperature, and the pressure and temperature of produced fluids.
- A pressure-temperature diagram is used to classify reservoirs and describe the phase behavior of reservoir fluids, delineating the liquid, gas, and two-phase regions.
- Based on the diagram, reservoirs are classified as oil reservoirs if the temperature is below the critical temperature, and gas reservoirs if above the critical temperature.
History matching was performed on the Snark Field reservoir simulation model to match production data. Sensitivity analysis identified the aquifer properties and a fault transmissibility as uncertain parameters. Tuning runs modified these properties, achieving a good match. Forecasts with injection wells predicted improved production. Future analysis in OFM will identify workover candidates and explain water breakthrough.
This document discusses concepts in applied reservoir engineering. It defines key reservoir terms like reservoir rock, cap rock, and reservoir fluids. It also covers rock and fluid properties important for reservoir characterization like porosity, permeability, and PVT properties. Methods for calculating original hydrocarbon in place are presented, including volumetric and material balance approaches. Determining reservoir drive mechanisms and predicting future performance through primary and secondary recovery methods are also summarized.
A Beginners Guide to using PVTSim for Multi-phase calculations for budding engineers.
Typical operations performed in PVTSim are
1. Fluid Database Creation – Composition based
2. Fluid Characterization - Based on Plus fractions
3. Fluids Flashing - Fluid Property Determination
4. Fluid Mixing – for e.g. mixing of various reservoir fluids for their resultant composition
5. Water Saturation of Reservoir Fluid Compositions (dry basis) to arrive at wet composition
6. Viscosity Tuning of Oils based on Laboratory Data (e.g., ASTM D 341, Viscosity vs. Temperature)
7. Hydrate Curve Generation
8. Inhibitor Dosing and Hydrate Curve Shift study
The document discusses enhanced oil recovery (EOR) methods, focusing on steam injection. It defines EOR as techniques for extracting more crude oil from reservoirs beyond primary and secondary recovery methods. Steam injection is a thermal EOR method that involves injecting steam into reservoirs to lower oil viscosity and produce more oil. There are two main steam injection techniques - cyclic steam stimulation (also called huff-and-puff) which alternates between steam injection and production from single or multiple wells, and steam flooding which continuously injects steam into reservoirs to displace oil towards production wells. The document outlines some advantages and disadvantages of steam injection and economic considerations.
Heavy Oil recovery traditionally starts with depletion drive and (natural) waterdrive with very low recoveries as a result. As EOR technique, steam injection has been matured since the 1950s using CSS (cyclic steam stimulation), steam drive or steam flooding, and SAGD (steam assisted gravity drainage). The high energy cost of heating up the oil bearing formation to steam temperature and the associated high CO2 footprint make steam based technology less attractive today and many companies in the industry have been actively trying to find alternatives or improvements. As a result there are now many more energy efficient recovery technologies that can unlock heavy oil resources compared with only a decade ago. This presentation will discuss breakthrough alternatives to steam based recovery as well as incremental improvement options to steam injection techniques. The key message is the importance to consider these techniques because steam injection is costly and has a high CO2 footprint
Johan van Dorp holds an MSc in Experimental Physics from Utrecht University and joined Shell in 1981. He has served on several international assignments, mainly in petroleum and reservoir engineering roles. He recently led the extra heavy-oil research team at the Shell Technology Centre in Calgary, focusing on improved in-situ heavy-oil recovery technologies. Van Dorp also was Shell Group Principal Technical Expert in Thermal EOR and has been involved with most thermal projects in Shell throughout the world, including in California, Oman, the Netherlands, and Canada. He retired from Shell after more than 35 years in Oct 2016. Van Dorp (co-)authored 13 SPE papers on diverse subjects.
The document discusses definitions and categories of petroleum reserves based on probabilities of production. It defines proven, probable, and possible reserves, which have 90%, 50%, and 10% certainty of being produced, respectively. Methods for estimating reserves are described, including volumetric analysis, decline curve analysis, and production forecasting based on projected prices, costs, and other factors.
Enhanced oil recovery techniques like miscible gas injection can be used to extract additional oil from reservoirs. Carbon dioxide flooding involves restoring reservoir pressure with water injection and then injecting CO2 to form a miscible front that dissolves in the oil. Cyclic CO2 stimulation uses repeated injection and production cycles to reduce oil viscosity. Nitrogen flooding works for light oil reservoirs by vaporizing oil components to create a miscible nitrogen front. The conditions for miscibility depend on pressure, temperature, and fluid compositions as represented on phase diagrams.
26_MAR_2013 Brian Moffatt - Reservoir Fluid PVT Analysis.pdfMohanadHussien2
The document discusses how to maximize the value of PVT (pressure-volume-temperature) data for reservoir appraisal and development planning. It outlines several key points:
1) PVT data quality control (QC) is important to identify potential errors from sampling, storage, and laboratory measurements that could affect development decisions.
2) When modeling PVT data, it is important to focus on matching key parameters like phase behavior that are most relevant to the reservoir conditions of interest.
3) Uncertainties in PVT data, if not properly addressed, could significantly impact development aspects like volumetric calculations, reservoir simulation modeling, and identification of flow assurance issues. Placing PVT data in the proper field context
The document summarizes key considerations for gas condensate PVT data and modeling. It discusses:
1) The importance of the gas Z-factor for calculating initial fluids in place and depletion recoveries.
2) How compositional variation data during depletion is needed to forecast condensate rates and recovery profiles, and to define gas cycling potential.
3) That EOS modeling requires accurate molar composition and C7+ properties data, and commonly uses pseudocomponents to reduce the number of components in the model.
The document discusses thermodynamic modeling considerations for process simulation. It recommends selecting the Peng-Robinson equation of state model for most hydrocarbon and petrochemical systems due to its wide applicability range and enhancements. It also recommends specialty models like the Glycol Package for natural gas dehydration systems and the Amines Package for gas sweetening units using amines. Proper selection of the thermodynamic model is critical to obtain accurate simulation results.
Chromatographic Analysis of Natural Gas Liquids, sherry petrochemicalsherrylabs
The document discusses chromatographic analysis of natural gas liquids performed by Sherry Laboratories. Sherry Laboratories is an industry leader in independent third-party testing with 10 laboratories providing accredited analytical testing and technical expertise. The document focuses on Sherry's hydrocarbon laboratory and reference standards division, describing the analytical methods, sampling, transportation, and chromatographic analysis used to test natural gas and liquid hydrocarbon mixtures.
The document provides an overview of reservoir simulation and performance analysis methods. It discusses static and dynamic reservoir modeling, including history matching and prediction. The key points covered are:
1) Reservoir simulation involves building static and dynamic reservoir models to match historical production and predict future performance.
2) History matching is used to validate the simulation model by comparing calculated pressures, saturations, and production to historical data.
3) After achieving a match, the model can be used to predict future field performance under different development scenarios and identify new infill locations.
This document provides an overview of the key components and operation of the CHN628 elemental analyzer. It describes the high temperature combustion process used to oxidize samples, the separation and collection of combustion gases, helium/argon separation, infrared and thermal conductivity detection methods, and the software controls for method parameters, calibration, drift correction, and data management.
1) Neste Oyj operates two conventional oil refineries and two NEXBTL refineries in Finland and Singapore that process a combined 15 Mt/a of feedstock, with 76% consisting of waste or residue and 24% palm oil.
2) Neste uses an FCC-SIM model to correct mass flows and improve mass balance accuracy by reconstructing density corrections and identifying problems like inaccurate flow meters.
3) The FCC-SIM model helped identify a problem with the refinery's LP model that resulted in a $10 million per year change in profit by detecting shifts in yields, feedstocks, and gasoline blending.
Handling Difficult Samples in Karl Fischer AnalysisMetrohm USA
Analysis of moisture is becoming increasingly important to many different industries
Many of these reasons require not only a precise, but also accurate reading
For years, most moisture analyses have been conducted on a semi-quantitative or even qualitative level
This document summarizes water management and reservoir optimization services including: fluid and mechanical placements for water shut-off; scale treatment options; diagnostic and monitoring tools; reservoir modeling and simulation software; production optimization solutions; and engineering and operations analysis. Key services include water shut-off treatments, production logging, single-well reservoir modeling, streamline simulation for automatic water allocation, injector and producer optimization analysis, and reservoir sweep solutions to improve recovery.
A tandem mass spectrometry (TANDEM MS), also named as MS/MS, is a two-step technique used to analyze a sample either by using two or more mass spectrometers connected to each other or a single mass spectrometer by several analyzers arranged one after another.
This document provides instructions for building a well model using the PROSPER software. It discusses preparing input data by organizing it in an Excel file with separate sheets for completion, test, and PVT/IPR data. It also covers setting up the model type and fluid properties in PROSPER. PVT data from lab tests should be entered on the PVT input screen and used to calculate fluid properties under changing pressure and temperature conditions through correlation, matching, or direct entry of PVT tables. The overall objective is to accurately simulate well performance and predict production levels.
This document summarizes research evaluating various modified asphalt binders using the Multiple Stress Creep Recovery (MSCR) test. It finds that the shortage of styrene-butadiene-styrene (SBS) polymer, currently used to modify asphalt, is due to limited ethylene production. The MSCR test effectively discriminates between binders. Test results show asphalt rubber (AR) yielded the highest percent recovery and withstood creep the best, replicating SBS properties. The research concludes AR can be a valid alternative to SBS-modified asphalt from a performance perspective.
This is course on Plant Simulation will show you how to setup hypothetical compounds, oil assays, blends, and petroleum characterization using the Oil Manager of Aspen HYSYS.
You will learn about:
Hypothetical Compounds (Hypos)
Estimation of hypo compound data
Models via Chemical Structure UNIFAC Component Builder
Basis conversion/cloning of existing components
Input of Petroleum Assay and Crude Oils
Typical Bulk Properties (Molar Weight, Density, Viscosity)
Distillation curves such as TBP (Total Boiling Point)
ASTM (D86, D1160, D86-D1160, D2887)
Chromatography
Light End
Oil Characterization
Using the Petroleum Assay Manager or the Oil Manager
Importing Assays: Existing Database
Creating Assays: Manually / Model
Cutting: Pseudocomponent generation
Blending of crude oils
Installing oils into Aspen HYSYS flowsheets
Getting Results (Plots, Graphs, Tables)
Property and Composition Tables
Distribution Plot (Off Gas, Light Short Run, Naphtha, Kerosene, Light Diesel, Heavy Diesel, Gasoil, Residue)
Oil Properties
Proper
Boiling Point Curves
Viscosity, Density, Molecular Weight Curves
This is helpful for students, teachers, engineers and researchers in the area of R&D, specially those in the Oil and Gas or Petroleum Refining industry.
This is a "workshop-based" course, there is about 25% theory and about 75% work!
At the end of the course you will be able to handle crude oils for your fractionation, refining, petrochemical process simulations!
Soni Oyekan conducted research at Exxon in the 1970s to understand how rhenium promotes platinum catalysts used in naphtha reforming. Testing of various Pt/Re catalyst compositions generated data that others viewed as negative, but Oyekan and colleagues were able to develop new combination Pt/Re catalyst systems based on their analysis. Similarly, UOP recognized the potential of "negative" data on Pt/Sn catalysts to develop their breakthrough continuous catalyst regeneration (CCR) reforming process. CCR reforming is now the dominant technology in the industry, providing significant revenue to UOP and other licensors through widespread adoption. The key lesson is to critically analyze all data, including what
Heavy feedstocks present difficult operational challenges for refiners that can add to safety risks and reduce profitability. Processing heavy crudes safely and profitably can require development of new equipment or major changes in operating conditions.
Innovative new methods, which model heavier feedstock processing more accurately, enable refiners to adapt their processes more easily.
Register now to learn more about this important new technology.
Who should attend: Plant Managers, Process Engineers, Engineering Managers, Operations Managers, Process Design Engineers
View OnDemand at: www.real-time-answers.com/refinery
This document discusses polymerase chain reaction (PCR), its process and troubleshooting strategies. PCR is used to amplify a specific segment of DNA. It requires a DNA template, primers, DNA polymerase, nucleotides and buffer solution. The PCR process involves cycles of heating and cooling to denature and extend the DNA. Issues like contamination, reaction conditions, primer design and template quality can affect PCR results. Troubleshooting aims to optimize conditions, increase yield and specificity. It may involve adjusting magnesium concentration, annealing temperature, primer concentration, cycle number and ensuring high-quality reagents and template DNA. References on PCR optimization and troubleshooting techniques are also provided.
Laboratory and Theoretical investigations of petroleum reservoir fluid propri...Mohamed Lamoj
In this study, complete PVT lab experiments were done and then evaluate the most frequently used empirical black oil PVT correlations for application in the Middle East. Empirical PVT Correlations for Middle East crude oil have been compared as a function of commonly available PVT data. Correlations have been compared for: Bubble point pressure; solution gas oil ratio, oil formation volume factor, oil density, and oil viscosity. After evaluates the Empirical correlations the crude sample was characterized using different EOS to arrive at one EOS model that accurately describes the PVT behavior of crude oil produced.
This document provides an overview of applied fluid dynamics related to pumps. It discusses various pump types including positive displacement and kinetic pumps. Positive displacement pumps are further divided into rotary and reciprocal types. Rotary positive displacement pumps include gear, screw, progressive cavity, lobe and peristaltic pumps. Reciprocal positive displacement pumps include piston and diaphragm pumps. Kinetic pumps discussed are centrifugal and axial flow pumps. The document also covers pump performance parameters such as head, efficiency and NPSH. Cavitation is explained as a phenomenon caused by vapor bubbles forming due to a drop in pressure below the vapor pressure. Methods to calculate NPSHA and determine if cavitation will occur are presented along with an example problem.
Andreas Schleicher presents PISA 2022 Volume III - Creative Thinking - 18 Jun...EduSkills OECD
Andreas Schleicher, Director of Education and Skills at the OECD presents at the launch of PISA 2022 Volume III - Creative Minds, Creative Schools on 18 June 2024.
A Visual Guide to 1 Samuel | A Tale of Two HeartsSteve Thomason
These slides walk through the story of 1 Samuel. Samuel is the last judge of Israel. The people reject God and want a king. Saul is anointed as the first king, but he is not a good king. David, the shepherd boy is anointed and Saul is envious of him. David shows honor while Saul continues to self destruct.
🔥🔥🔥🔥🔥🔥🔥🔥🔥
إضغ بين إيديكم من أقوى الملازم التي صممتها
ملزمة تشريح الجهاز الهيكلي (نظري 3)
💀💀💀💀💀💀💀💀💀💀
تتميز هذهِ الملزمة بعِدة مُميزات :
1- مُترجمة ترجمة تُناسب جميع المستويات
2- تحتوي على 78 رسم توضيحي لكل كلمة موجودة بالملزمة (لكل كلمة !!!!)
#فهم_ماكو_درخ
3- دقة الكتابة والصور عالية جداً جداً جداً
4- هُنالك بعض المعلومات تم توضيحها بشكل تفصيلي جداً (تُعتبر لدى الطالب أو الطالبة بإنها معلومات مُبهمة ومع ذلك تم توضيح هذهِ المعلومات المُبهمة بشكل تفصيلي جداً
5- الملزمة تشرح نفسها ب نفسها بس تكلك تعال اقراني
6- تحتوي الملزمة في اول سلايد على خارطة تتضمن جميع تفرُعات معلومات الجهاز الهيكلي المذكورة في هذهِ الملزمة
واخيراً هذهِ الملزمة حلالٌ عليكم وإتمنى منكم إن تدعولي بالخير والصحة والعافية فقط
كل التوفيق زملائي وزميلاتي ، زميلكم محمد الذهبي 💊💊
🔥🔥🔥🔥🔥🔥🔥🔥🔥
Temple of Asclepius in Thrace. Excavation resultsKrassimira Luka
The temple and the sanctuary around were dedicated to Asklepios Zmidrenus. This name has been known since 1875 when an inscription dedicated to him was discovered in Rome. The inscription is dated in 227 AD and was left by soldiers originating from the city of Philippopolis (modern Plovdiv).
Information and Communication Technology in EducationMJDuyan
(𝐓𝐋𝐄 𝟏𝟎𝟎) (𝐋𝐞𝐬𝐬𝐨𝐧 2)-𝐏𝐫𝐞𝐥𝐢𝐦𝐬
𝐄𝐱𝐩𝐥𝐚𝐢𝐧 𝐭𝐡𝐞 𝐈𝐂𝐓 𝐢𝐧 𝐞𝐝𝐮𝐜𝐚𝐭𝐢𝐨𝐧:
Students will be able to explain the role and impact of Information and Communication Technology (ICT) in education. They will understand how ICT tools, such as computers, the internet, and educational software, enhance learning and teaching processes. By exploring various ICT applications, students will recognize how these technologies facilitate access to information, improve communication, support collaboration, and enable personalized learning experiences.
𝐃𝐢𝐬𝐜𝐮𝐬𝐬 𝐭𝐡𝐞 𝐫𝐞𝐥𝐢𝐚𝐛𝐥𝐞 𝐬𝐨𝐮𝐫𝐜𝐞𝐬 𝐨𝐧 𝐭𝐡𝐞 𝐢𝐧𝐭𝐞𝐫𝐧𝐞𝐭:
-Students will be able to discuss what constitutes reliable sources on the internet. They will learn to identify key characteristics of trustworthy information, such as credibility, accuracy, and authority. By examining different types of online sources, students will develop skills to evaluate the reliability of websites and content, ensuring they can distinguish between reputable information and misinformation.
How to Manage Reception Report in Odoo 17Celine George
A business may deal with both sales and purchases occasionally. They buy things from vendors and then sell them to their customers. Such dealings can be confusing at times. Because multiple clients may inquire about the same product at the same time, after purchasing those products, customers must be assigned to them. Odoo has a tool called Reception Report that can be used to complete this assignment. By enabling this, a reception report comes automatically after confirming a receipt, from which we can assign products to orders.
A Free 200-Page eBook ~ Brain and Mind Exercise.pptxOH TEIK BIN
(A Free eBook comprising 3 Sets of Presentation of a selection of Puzzles, Brain Teasers and Thinking Problems to exercise both the mind and the Right and Left Brain. To help keep the mind and brain fit and healthy. Good for both the young and old alike.
Answers are given for all the puzzles and problems.)
With Metta,
Bro. Oh Teik Bin 🙏🤓🤔🥰
Philippine Edukasyong Pantahanan at Pangkabuhayan (EPP) CurriculumMJDuyan
(𝐓𝐋𝐄 𝟏𝟎𝟎) (𝐋𝐞𝐬𝐬𝐨𝐧 𝟏)-𝐏𝐫𝐞𝐥𝐢𝐦𝐬
𝐃𝐢𝐬𝐜𝐮𝐬𝐬 𝐭𝐡𝐞 𝐄𝐏𝐏 𝐂𝐮𝐫𝐫𝐢𝐜𝐮𝐥𝐮𝐦 𝐢𝐧 𝐭𝐡𝐞 𝐏𝐡𝐢𝐥𝐢𝐩𝐩𝐢𝐧𝐞𝐬:
- Understand the goals and objectives of the Edukasyong Pantahanan at Pangkabuhayan (EPP) curriculum, recognizing its importance in fostering practical life skills and values among students. Students will also be able to identify the key components and subjects covered, such as agriculture, home economics, industrial arts, and information and communication technology.
𝐄𝐱𝐩𝐥𝐚𝐢𝐧 𝐭𝐡𝐞 𝐍𝐚𝐭𝐮𝐫𝐞 𝐚𝐧𝐝 𝐒𝐜𝐨𝐩𝐞 𝐨𝐟 𝐚𝐧 𝐄𝐧𝐭𝐫𝐞𝐩𝐫𝐞𝐧𝐞𝐮𝐫:
-Define entrepreneurship, distinguishing it from general business activities by emphasizing its focus on innovation, risk-taking, and value creation. Students will describe the characteristics and traits of successful entrepreneurs, including their roles and responsibilities, and discuss the broader economic and social impacts of entrepreneurial activities on both local and global scales.
2. PERA Tasks
• Collecting samples.
• Which PVT lab tests to use.
• Designing special PVT studies.
• Quality controlling PVT data.
• Heptanes-plus data and characterization.
• Initial EOS model.
• Tuning an EOS model.
• Viscosities.
• Fluid initialization.
• Minimizing number of EOS components.
• Black-oil PVT tables.
3. PERA Tasks
• Collecting samples.
• Which PVT lab tests to use.
• Designing special PVT studies.
• Quality controlling PVT data.
• Heptanes-plus data and characterization.
• Initial EOS model.
• Tuning an EOS model.
• Viscosities.
• Fluid initialization.
• Minimizing number of EOS components.
• Black-oil PVT tables.
4. PERA Tasks
• Collecting samples.
• Which PVT lab tests to use.
• Designing special PVT studies.
• Quality controlling PVT data.
• Heptanes-plus data and characterization.
• Initial EOS model.
• Tuning an EOS model.
• Viscosities.
• Fluid initialization.
• Minimizing number of EOS components.
• Black-oil PVT tables.
5. PERA Tasks
• Collecting samples.
• Which PVT lab tests to use.
• Designing special PVT studies.
• Quality controlling PVT data.
• Heptanes-plus data and characterization.
• Initial EOS model.
• Tuning an EOS model.
• Viscosities.
• Fluid initialization.
• Minimizing number of EOS components.
• Black-oil PVT tables.
6. PERA Tasks
• Collecting samples.
• Which PVT lab tests to use.
• Designing special PVT studies.
• Quality controlling PVT data.
• Heptanes-plus data and characterization.
• Initial EOS model.
• Tuning an EOS model.
• Viscosities.
• Fluid initialization.
• Minimizing number of EOS components.
• Black-oil PVT tables.
7. PERA Tasks
• Collecting samples.
• Which PVT lab tests to use.
• Designing special PVT studies.
• Quality controlling PVT data.
• Heptanes-plus data and characterization.
• Initial EOS model.
• Tuning an EOS model.
• Viscosities.
• Fluid initialization.
• Minimizing number of EOS components.
• Black-oil PVT tables.
8. PERA Tasks
• Collecting samples.
• Which PVT lab tests to use.
• Designing special PVT studies.
• Quality controlling PVT data.
• Heptanes-plus data and characterization.
• Initial EOS model.
• Tuning an EOS model.
• Viscosities.
• Fluid initialization.
• Minimizing number of EOS components.
• Black-oil PVT tables.
9. PERA Tasks
• Collecting samples.
• Which PVT lab tests to use.
• Designing special PVT studies.
• Quality controlling PVT data.
• Heptanes-plus data and characterization.
• Initial EOS model.
• Tuning an EOS model.
• Viscosities.
• Fluid initialization.
• Minimizing number of EOS components.
• Black-oil PVT tables.
10. PERA Tasks
• Collecting samples.
• Which PVT lab tests to use.
• Designing special PVT studies.
• Quality controlling PVT data.
• Heptanes-plus data and characterization.
• Initial EOS model.
• Tuning an EOS model.
• Viscosities.
• Fluid initialization.
• Minimizing number of EOS components.
• Black-oil PVT tables.
11. PERA Tasks
• Collecting samples.
• Which PVT lab tests to use.
• Designing special PVT studies.
• Quality controlling PVT data.
• Heptanes-plus data and characterization.
• Initial EOS model.
• Tuning an EOS model.
• Viscosities.
• Fluid initialization.
• Minimizing number of EOS components.
• Black-oil PVT tables.
12. PERA Tasks
• Collecting samples.
• Which PVT lab tests to use.
• Designing special PVT studies.
• Quality controlling PVT data.
• Heptanes-plus data and characterization.
• Initial EOS model.
• Tuning an EOS model.
• Viscosities.
• Fluid initialization.
• Minimizing number of EOS components.
• Black-oil PVT tables.
18. PERA Open-hole Samplers
MDT / RCI
• Potential Problems
• Oil-based muds.
• Oils -- OK for composition.
• Gas condensates – OK for composition.
• Surface cooling before removal.
• Bubblepoint suppression.
19. PERA
Post Sampling
but downhole
Fire-open valve
Fire-close valve
Dead volume
(<10cc) – initially
water filled
Manual close
valve
Piston
450cc MPSR
bottle
To pump and
formation
Prior to Sampling
MPSR
Fire-open valve
open
Fire-close valve
closed
Dead volume
(<10cc) – now gas
filled and the gas
will be lost
Manual close
valve now
operated to
extract MPSR
from MDT tool
Piston
450cc of 2 phase
hydrocarbon at
surface temp
and some
pressure
To pump and
formation
Post Sampling
Now at surface
Water from dead
volume
MPSR
Fire-open valve
operated to fill
Fire-close valve
operated post
filling
Dead volume
(<10cc) – now oil
filled
Manual close
valve
Piston
450cc of single
phase oil at res
temp and
pressure
To pump and
formation
Water from dead
volume
MPSR
MDT Sampling with MPSR bottles
20. PERA
Which PVT Lab Tests to Use
What are you simulating?
• Depletion.
• Water injection.
• Condensate blockage.
• Gas injection.
• Miscible.
• Immiscible.
21. PERA
Designing Special PVT Studies
• Condensate Blockage.
• Condensate viscosities.
• Miscible Gas Injection.
• Through-critical swelling test.
• Vro , compositions and K-values!
• Immiscible Gas Injection.
• Vaporization tests.
22. PERA
Quality Controlling PVT Data
• Compositions !!!
• Recombination.
• Extended GC.
• Mass-to-mole conversion.
• C7+ properties.
• Molecular weight and specific gravity.
• Use trend plots.
• Ps vs wt-% methane and/or C7+.
24. PERA
J-482BHS
1
10
100
80 100 120 140 160 180 200 220 240 260 280
Molecular Weight
Molar
Composition,
mol-%
Reported (GC)
Expontential Model
Expon. (Reported (GC))
Reported GC extended distribution
appears to be in serious error, being
much too "light" with apparent
M7+ = 130
DON'T USE GC DISTRIBUTION !!!
25. PERA
C7+ Data and Characterization
• Correlate MW and SG of C7+.
• Define trends & identify ”outliers”.
• Use TBP Data.
• Gamma distribution model fit.
• SCN MW-SG relationship.
• Downstream Assay data always available.
• Extended GC Data.
• Gamma distribution model fit.
• Ignore heaviest amount and MW.
30. PERA
Tuning an EOS Model
• Densities Don’t Need Regressing!
• What’s Left to Fit?
• Nothing but K-values ... but how ???
• Check Consistency!
• Monotonic K-values of hydrocarbons.
• Three-phase existence (from EOS model).
• Serious problem for EOS models!
31. PERA
Viscosities
• LBC (Lorenz-Bray-Clark / Jossi-Thodos)
• Need accurate densities.
• Modify C7+ Vc values.
• Make sure fraction viscosities are monotonic.
• LBC polynomial coefficients.
• BE CAREFUL!
• Pedersen.
• Better predictions than LBC.
• Regression - ?
32. PERA
Fluid Initialization
• Plot C6+ versus Depth.
• Initial Oil in Place plot.
• Use error bars.
• Depth and composition.
• Uncertainty Analysis.
• Use isothermal gradient model.
• Defines maximum compositional variation.
• Use constant composition.
• Defines minimum compositional variation.
33. PERA
0.2 0.4 0.6 0.8
-15000
-14000
-13000
-12000
-11000
IOIP / HCPV, (Sm3 / m3)
Depth,
ft
SSL
Reference Depth
Isothermal
Model
Field-Data Based
Initialization
GOC
34. PERA
10 15 20 25 30 35
-15000
-14000
-13000
-12000
-11000
C7+ Mole Percent
Depth,
ft
SSL
Reference Depth
GOC
Field-Data Based
Initialization
Isothermal
Model
38. PERA
Fluid Initialization
• Black-Oil vs Compositional.
• Use consistent EOS model.
• Use consistent surface process.
• Use solution GOR (Rs and Rv) for black-oil
model.
• Based on EOS model initialization.
39. PERA
Minimizing Number of EOS Components
• Basis of Comparison.
• Detailed & Tuned EOS model.
• Stepwise lumping procedure.
• Check entire relevant p-compositioni space.
• Depletion data.
• Gas injection data.
• Miscibility data.
• Delumping ?
• Detailed & Tuned EOS model.
42. PERA Split Factor
BOz Conversion
qg
qo
Sij
z2
zn
z1
.
.
.
=
=
2
1
j
j
ij
i q
S
z q1 = qg
q2 = qo
( ) ( ) i
s
s
s
oo
s
i
s
s
og
s
i1 x
R
r
1
k
)
R
(C
r
y
R
r
1
k
)
C
r
(1
S
−
+
−
−
+
=
( ) ( ) i
s
s
og
s
s
i
s
s
s
oo
i2 y
R
r
1
k
)
C
r
(1
R
x
R
r
1
k
)
R
(C
S
−
+
−
−
+
=
44. PERA North Sea Full-Field Model
A
B
E100-BO
E300-EOS
FFM
Platform
A
Process A
~ 30 Wells
Platform
B
Process B
~ 15 Wells
Gas
Injection
Different Surface
Processes (BO PVT)
in Regions A & B
45. PERA
Objective
• Run black-oil full-field reservoir model.
• Convert surface rates to compositional
streams.
• Connection level conversions.
• Summarize results.
• By well, platform, field.
• Annually, quarterly, cummulatives etc.
46. PERA
Full-Field Rate Forecast
(Following history match from 1987)
1.2E+06
1.4E+06
1.6E+06
1.8E+06
2.0E+06
2.2E+06
2.4E+06
2.6E+06
2000 2001 2002 2003 2004 2005
Time, Year
Gas
Rate,
Sm3/Day
1000
2000
3000
4000
5000
6000
7000
8000
Oil
Rate,
Sm3/Day
e100-bo Gas Rate
e100-bo Oil Rate
Changing Group Gas Rate due to reduced
contribution from neighbouring fields.