Apresentação de Victor Manuel Salazar Araque, da Computer Modelling Group, durante o evento promovido pelo Sistema FIEB, Fundamentos da Exploração e Produção de Não Convencionais: a Experiência Canadense.
Apresentação de Victor Manuel Salazar Araque, da Computer Modelling Group, durante o evento promovido pelo Sistema FIEB, Fundamentos da Exploração e Produção de Não Convencionais: a Experiência Canadense.
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.
Reserve Estimation of Initial Oil and Gas by using Volumetric Method in Mann ...ijtsrd
This research paper is focused to estimate the current production rate of the wells and to predict field remaining reserves. The remaining reserve depends on the production points that selected to represent the real well behavior, the way of dealing with the production data, and the human errors that might happen during the life of the field. Reserves estimating methods are usually categorized into three families analogy, volumetric, and performance techniques. Reserve Estimators should utilize the particular methods, and the number of methods, which in their professional judgment are most appropriate given i the geographic location, formation characteristics and nature of the property or group of properties with respect to which reserves are being estimated ii the amount and quality of available data and iii the significance of such property or group of properties in relation to the oil and gas properties with respect to which reserves are being estimated. In this research paper, the calculation of collecting data and sample by volumetric method are suggested to estimate the oil and gas production rate with time by using the geological configuration and the historical production data from CD 3700 3800 sand in Mann Oil Field. San Win "Reserve Estimation of Initial Oil and Gas by using Volumetric Method in Mann Oil Field" Published in International Journal of Trend in Scientific Research and Development (ijtsrd), ISSN: 2456-6470, Volume-3 | Issue-5 , August 2019, URL: https://www.ijtsrd.com/papers/ijtsrd27945.pdfPaper URL: https://www.ijtsrd.com/engineering/petroleum-engineering/27945/reserve-estimation-of-initial-oil-and-gas-by-using-volumetric-method-in-mann-oil-field/san-win
Reservoir engineering is the field to evaluate field performance by performing reservoir modeling studies and explore opportunities to maximize the value of both exploration and production properties to enhance hydrocarbon production.
The problem of water and gas coning has plagued the petroleum industry for decades. Water or gas encroachment in oil zone and thus simultaneous production of oil & water or oil & gas is a major technical, environmental and economic problems associated with oil and gas production. This can limit the productive life of the oil and gas wells and can cause severe problems including corrosion of tubulars, fine migration, hydrostatic loading etc. The environmental impact of handling, treating and disposing of the produced water can seriously affect the economics of the production. Commonly, the reservoirs have an aquifer beneath the zone of hydrocarbon. While producing from oil zone, there develops a low pressure zone as a result of which the water zone starts coning upwards and gas zone cones down towards the production perforation in oil zone and thus reducing the oil production. Pressure enhanced capillary transition zone enlargement around the wellbore is responsible for the concurrent production. This also results in the loss of water drive and gas drive to a certain extent.
Numerous technologies have been developed to control unwanted water and gas coning. In order to design an effective strategy to control the coning of oil or gas, it is important to understand the mechanism of coning of oil and gas in reservoirs by developing a model of it. Non-Darcy flow effect (NDFE), vertical permeability, aquifer size, density of well perforation, and flow behind casing increase water coning/inflow to wells in homogeneous gas reservoirs with bottom water are important factors to consider. There are several methods to slow down coning of water and/or gas such as producing at a certain critical rate, polymer injection, Downhole Water Sink (DWS) technology etc.
Shubham Saxena
B.Tech. petroleum Engineering
IIT (ISM) Dhanbad
In order to determine a field’s hydrocarbon in place it is necessary to model the distribution of fluids throughout the reservoir. A water saturation vs. height (Swh) function provides this for the reservoir model. A good Swh function ensures the three independent sources of fluid distribution data are consistent. These being the core, formation pressure and electrical log data. The Swh function must be simple to apply, especially in reservoirs where it is difficult to map permeability or where there appears to be multiple contacts. It must accurately upscale the log and core derived water saturations to the reservoir model cell sizes.
This presentation clarifies the often misunderstood definitions for the free-water-level, transition zone and irreducible water saturation. Using capillary pressure theory and the concept of fractals, a practical Swh function is derived. Logs and core data from eleven fields, with very different porosity and permeability characteristics, depositional environments and geological age are compared. This study demonstrated how this Swh function is independent of permeability and litho-facies type and accurately describes the reservoir fluid distribution.
The shape of the Swh function shows that of the transition zone is related more to pore geometry rather than porosity or permeability alone. Consequently, this Swh function gives insights into a reservoir’s quality as determined by its pore architecture. A number of case studies are presented showing the excellent match between the function and well data. The function makes an accurate prediction of water saturations even in wells where the resistivity log was not run due to well conditions. The function defines the free water level, the hydrocarbon to water contact, net reservoir and the irreducible water saturation for the reservoir model. The fractal function provides a simple way to quality control electrical log and core data and justifies using core plug sized samples to model water saturations on the reservoir scale.
Reservoir simulation modeling of the surfactant flooding using Schlumberger Petrel Simulation modeling software.
Definition and Process Description
Surfactant Conservation (Mass Balance) Equations
Simulation Solution Vector
Surfactant Effects;
Treatment of PVT data
Treatment of SCAL data
Modeling the Change in Wettability
Surfactant Keywords Summary
Simulation Model Construction
Sensitivities Runs & Simulation Results
Conclusions
I hope this presentation helps you to understand why we use acidizing process and calculations needed to perform the optimum acidizing .
Any questions contact me at karim.elfarash@std.suezuniv.edu.eg
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.
New Approach to Design Capillary Pressure Curves, which Would Improve Simulat...Faisal Al-Jenaibi
This presentation is discussing New Approach to Design Capillary Pressure Curves, which Would Improve Simulation Models Initialization and shorten History Match time consumed.
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.
Reserve Estimation of Initial Oil and Gas by using Volumetric Method in Mann ...ijtsrd
This research paper is focused to estimate the current production rate of the wells and to predict field remaining reserves. The remaining reserve depends on the production points that selected to represent the real well behavior, the way of dealing with the production data, and the human errors that might happen during the life of the field. Reserves estimating methods are usually categorized into three families analogy, volumetric, and performance techniques. Reserve Estimators should utilize the particular methods, and the number of methods, which in their professional judgment are most appropriate given i the geographic location, formation characteristics and nature of the property or group of properties with respect to which reserves are being estimated ii the amount and quality of available data and iii the significance of such property or group of properties in relation to the oil and gas properties with respect to which reserves are being estimated. In this research paper, the calculation of collecting data and sample by volumetric method are suggested to estimate the oil and gas production rate with time by using the geological configuration and the historical production data from CD 3700 3800 sand in Mann Oil Field. San Win "Reserve Estimation of Initial Oil and Gas by using Volumetric Method in Mann Oil Field" Published in International Journal of Trend in Scientific Research and Development (ijtsrd), ISSN: 2456-6470, Volume-3 | Issue-5 , August 2019, URL: https://www.ijtsrd.com/papers/ijtsrd27945.pdfPaper URL: https://www.ijtsrd.com/engineering/petroleum-engineering/27945/reserve-estimation-of-initial-oil-and-gas-by-using-volumetric-method-in-mann-oil-field/san-win
Reservoir engineering is the field to evaluate field performance by performing reservoir modeling studies and explore opportunities to maximize the value of both exploration and production properties to enhance hydrocarbon production.
The problem of water and gas coning has plagued the petroleum industry for decades. Water or gas encroachment in oil zone and thus simultaneous production of oil & water or oil & gas is a major technical, environmental and economic problems associated with oil and gas production. This can limit the productive life of the oil and gas wells and can cause severe problems including corrosion of tubulars, fine migration, hydrostatic loading etc. The environmental impact of handling, treating and disposing of the produced water can seriously affect the economics of the production. Commonly, the reservoirs have an aquifer beneath the zone of hydrocarbon. While producing from oil zone, there develops a low pressure zone as a result of which the water zone starts coning upwards and gas zone cones down towards the production perforation in oil zone and thus reducing the oil production. Pressure enhanced capillary transition zone enlargement around the wellbore is responsible for the concurrent production. This also results in the loss of water drive and gas drive to a certain extent.
Numerous technologies have been developed to control unwanted water and gas coning. In order to design an effective strategy to control the coning of oil or gas, it is important to understand the mechanism of coning of oil and gas in reservoirs by developing a model of it. Non-Darcy flow effect (NDFE), vertical permeability, aquifer size, density of well perforation, and flow behind casing increase water coning/inflow to wells in homogeneous gas reservoirs with bottom water are important factors to consider. There are several methods to slow down coning of water and/or gas such as producing at a certain critical rate, polymer injection, Downhole Water Sink (DWS) technology etc.
Shubham Saxena
B.Tech. petroleum Engineering
IIT (ISM) Dhanbad
In order to determine a field’s hydrocarbon in place it is necessary to model the distribution of fluids throughout the reservoir. A water saturation vs. height (Swh) function provides this for the reservoir model. A good Swh function ensures the three independent sources of fluid distribution data are consistent. These being the core, formation pressure and electrical log data. The Swh function must be simple to apply, especially in reservoirs where it is difficult to map permeability or where there appears to be multiple contacts. It must accurately upscale the log and core derived water saturations to the reservoir model cell sizes.
This presentation clarifies the often misunderstood definitions for the free-water-level, transition zone and irreducible water saturation. Using capillary pressure theory and the concept of fractals, a practical Swh function is derived. Logs and core data from eleven fields, with very different porosity and permeability characteristics, depositional environments and geological age are compared. This study demonstrated how this Swh function is independent of permeability and litho-facies type and accurately describes the reservoir fluid distribution.
The shape of the Swh function shows that of the transition zone is related more to pore geometry rather than porosity or permeability alone. Consequently, this Swh function gives insights into a reservoir’s quality as determined by its pore architecture. A number of case studies are presented showing the excellent match between the function and well data. The function makes an accurate prediction of water saturations even in wells where the resistivity log was not run due to well conditions. The function defines the free water level, the hydrocarbon to water contact, net reservoir and the irreducible water saturation for the reservoir model. The fractal function provides a simple way to quality control electrical log and core data and justifies using core plug sized samples to model water saturations on the reservoir scale.
Reservoir simulation modeling of the surfactant flooding using Schlumberger Petrel Simulation modeling software.
Definition and Process Description
Surfactant Conservation (Mass Balance) Equations
Simulation Solution Vector
Surfactant Effects;
Treatment of PVT data
Treatment of SCAL data
Modeling the Change in Wettability
Surfactant Keywords Summary
Simulation Model Construction
Sensitivities Runs & Simulation Results
Conclusions
I hope this presentation helps you to understand why we use acidizing process and calculations needed to perform the optimum acidizing .
Any questions contact me at karim.elfarash@std.suezuniv.edu.eg
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.
New Approach to Design Capillary Pressure Curves, which Would Improve Simulat...Faisal Al-Jenaibi
This presentation is discussing New Approach to Design Capillary Pressure Curves, which Would Improve Simulation Models Initialization and shorten History Match time consumed.
Changes in dam break hydrodynamic modelling practice - Suter et alStephen Flood
Abstract: Today, many organisations rely on hydrodynamic modelling to assess the consequences of dam break failure on downstream populations and infrastructure. The availability of finite volume shock-capturing schemes and flexible mesh schematisations in widely used software platforms imply that dam break modelling projects will be carried out differently in the future: Finite volume based platforms allow widespread application of shock-capturing methods and flexible mesh platforms can represent features in the study area more realistically and are more flexible thanks to varying mesh resolutions. Furthermore, the recent adoption of Graphics Processing Unit (GPU) technology in mainstream scientific and engineering computing will also significantly decrease computation times at relatively low cost.
This paper examines the application of finite volume, flexible mesh and GPU technologies to dam break modelling. One-dimensional (1D) modelling results are compared to those from two-dimensional (2D) finite difference and finite volume approaches. The results demonstrate that there are differences between modelling approaches and that the computational speeds of 2D simulations can be significantly reduced by the use of GPU processors.
DSD-INT 2018 Latest developments in hydrology - hydrodynamic modelling using ...Deltares
Presentation by Arthur van Dam (Deltares) at the Delft3D - User Days (Day 1: Hydrology and hydrodynamics), during Delft Software Days - Edition 2018. Monday, 12 November 2018, Delft.
Hec ras flood modeling little river newburyportWilliam Mullen
This narrated PowerPoint presentation describes a HEC-RAS 2-D unsteady-flow flood model set up for the tidally-influenced Little River in Newburyport and Newbury, Massachusetts. It describes the steps in developing inputs to the HEC-RAS model including using HEC-HMS rainfall-runoff modeling and GIS in developing inputs to HEC-HMS. The HEC-RAS model was calibrated using the Mother's Day flood of May 2006. The HEC-RAS model may be used to evaluate impacts associated with proposed changes in culvert sizes or changing embankment elevations near or at problem flood areas and can also be used to determine the changes in river hydraulics associated with sea level rise and climate change.
DSD-INT 2023 Fast compound flood modelling using reduced complexity model - d...Deltares
Presentation by Roel de Goede (Deltares, Netherlands) at the Symposium on Emulating 2D flood modelling, during the Delft Software Days - Edition 2023 (DSD-INT 2023). Wednesday, 27 September 2023, Delft.
1. ADNOC Main Challenges With the Current
Simulation Modeling Workflows
AbuDhabi 2013
ADNOC/Schlumberger Simulation Workshop
5th December 2013
Faisal Al-Jenaibi
2. General Simulation Modeling Areas of Concern
Static Model:
Stratigraphic and Layering Framework.
Petrophysical Parameters Distribution (permeability, porosity, RRT’s ..etc).
Fluids-in-Place & Water Saturation Modeling.
Vertical/Lateral Transmissibility across Faults.
Upscaling Technology.
Dynamic Model:
Simulation Model, Size and Resolution.
Definition of Transition Zone, SCAL framework issues.
Transition phase between history & prediction modes (VFP’s tables).
High Permeability Streaks and thin Barriers Intervals.
Dual Porosity & Dual Permeability Models.
Upscale/Downscale Sector Model from/to Full Field Model.
Variable “Sor” per RRT based on Wettability.
Streamline Technology.
2/20
3. General Simulation Modeling Areas of Concern
Static Model:
Stratigraphic and Layering Framework.
Petrophysical Parameters Distribution (permeability, porosity, RRT’s ..etc).
Fluids-in-Place & Water Saturation Modeling. (Part-1)
Vertical/Lateral Transmissibility across Faults.
Upscaling Technology.
Dynamic Model:
Simulation Model, Size and Resolution.
Definition of Transition Zone, SCAL framework issues. (Part-2)
Transition phase between history & prediction modes (VFP’s tables).
High Permeability Streaks and thin Barriers Intervals.
Dual Porosity & Dual Permeability Models.
Upscale/Downscale Sector Model from/to Full Field Model.
Variable “Sor” per RRT based on Wettability.
Streamline Technology.
3/20
4. Part-1: Fluids-in-Place & Water Saturation Modeling
Distribute of the FIP’s in the static model should be linked with:
Geological features i.e. (sedimentology, faults, facies, layers pinchout , seismic, ..etc).
Honor and distribute porosity logs profiles.
Classification of RRT’s groups (MICP’s, pore throat distribution, ..etc). Plot “PERM-PORO
relationship vs. RRT’s groups”.
Wells Sw_log is the main reference parameter need to be honored and matched,
well-by-well to ensure appropriate FIP’s estimation.
End-Point-Scaling approach to be used only with absent of SCAL data.
PORO
PERM
Sw_log
HeightaboveFWL
4/20
5. Part-1: Water Saturation Model
Simple approach to smoothen cells water saturation nearby FWL
Iteration - 00
co-krigging “stochastic” approach used to distribute
Sw_log data in the static model
Iteration - 01
5/20
8. Part-2: The Current Height Function “Pc’s Curves” Design
4 Wells, Sw-Logs data
Depth,ft
The height function curves represent thick transition zone.
Massive volume of water is mobile at very early time.
8/20
9. Part-2: Height Function “Pc’s Curves” Design
Facts:
• Many wells which reported with high Sw_log data have
produced dry oil during production test although they
were completed nearby water zone.
• High porosity & permeability rock type will have lower
capillarity force i.e. (Pc curve) than low porosity &
permeability rock type.
• Due to high heterogeneity in carbonate reservoir, single
Pc curve per rock type might not be enough to reflect
Sw_log data.
9/20
10. SW
HeightaboveFWLdepth(ft)
0 1
Transition Zone
Oil Zone
Oil Dry Limit
FWL Depth
The Current Pc’s Design
Part-2: Height Function “Pc’s Curves” Design
The Current Kr’s Design
SW
Kr’sCurves
0 1
FWL Depth
SwcrSwirr Sor
1
Swcr
In order to slow down water movement in transition zone, either by use:
(1) Unphysical Swcr’s “Simulator Parameter”
(2) Very low Krw’s values
(3) Unsupported permeability multiplier
Swirr
10/20
11. SW
HeightaboveFWLdepth(ft)
0 1
Water Zone
Transition Zone
Oil Zone
Oil Dry Limit
FWL Depth
The Current Pc’s Design
SW
HeightaboveFWLdepth(ft)
0 1
Water Zone
Transition Zone
Oil Zone
High PORO
High PERM
Low PORO
Low PERM
Oil Dry Limit
FWL Depth
The Proposed Pc’s Design
Part-2: Height Function “Pc’s Curves” Design
11/20
12. Part-2: The Proposed Height Function “Pc’s Curves” Design
4 Wells, Sw-Log data
Depth,ft
PC’s Curves Should:
• Address the
thickness of the
transition zone.
• Provide excellent
match with initial
Sw_log data.
• Assist in
achieving better
history match.
• Contribute in
model stability.
• Optimize
saturation tables.
• Eliminate Swcr’s
usage.
• Address
wettability issues.
12/20
13. Part-2: Dynamic Model Initialization, Case Study-Aug
Static Model “Sw_log” Dynamic Model “Sw_pc”
Co-krigging “stochastic” approach
used to distribute Sw_log data in the
static model
Generate 12 drainage Pc’s curves to
replicate Sw_log data into dynamic
model
Sw_log vs. Sw_pc
Excellent replication of “Sw” static model in the dynamic model has been achieved following
applied ADNOC the proposed new Pc’s curves design.
13/20
14. Part-2: Dynamic Model Initialization, Case Study-Aug
Static Model
“Sw_log”
Dynamic Model
“Sw_pc”
Water Saturation
Cross-Section
14/20
15. Part-2: Dynamic Model Initialization, Case Study-Aug
Pc’s Curves Examples
Best RRT Intermediate RRT Tight RRT
A total of 194 saturation
tables were used in the
Current dynamic model
A total of 24 saturation
tables were used in the
updated dynamic model:
12 Drainage Pc’s
12 Imbibition Pc’s
15/20
18. Part-2: History Match , Case Study-Nov
18/20
Following to implement ADNOC workflow to design Pc’s curves in 2 weeks time
frame, massive field GOR and WCT were enhanced.
19. Conclusions
The current technical challenges and concern issues, which are related to
modeling activities, are subject for farther integrated workflows that are
requiring very promising technologies and powerful tools in order to address
them in batter and practical ways.
The proposed Pc’s curves design showed very encourage results with respect to
reproduce static water saturation model into dynamic model at high quality,
while contribute in model stability and respect more physics.
Due to the complexity of AbuDhabi reservoirs, with the high uncertainty levels
present in most of them, more resolution models are needed to be constructed
to reflect reservoirs production behaviors in more accurate mode.
Sharing lessons learned with regard to modeling activities and implemented
workflows is essential to maximize knowledge and experiences exchange,
while moving into close collaboration to overcome technical challenges.
19/20
