bluuebunny/crossref_metadata_2025_split huggingface dataset:
Model Ranking and Optimization of Fractured Reservoir Using Streamline Simulation, Case Study a Gas Condensate Reservoir
Authors: Askari Amir Abbas , Bashiri Golamreza , Kamali Mohammad Reza 
Published: May 2009

Abstract
Nowadays the oil and gas industry is increasingly facing the difficulties associated with fields characterized by the presence of natural fractures. These difficulties are due to uncertainties in geological model especially in the fracture distributions. To successfully address these challenges, it is paramount to improve the characterization and simulation of those reservoirs. This can only be performed through the fully integration of all available data for generating stochastic DFN model and then using streamline simulation approach for fast history matching.
In this paper, using interpretation of image logs closely was related best productive zones with open fractures and then their correlation with other parameters (including lithology and petrophysical logs) were determined through reservoir. Three main fracture direction set were defined by fold-related fractures. A discrete fracture network (DFN) was generated using inferred parameters from outcrops, FMI logs and cores. Then, permeability of DFNs developed was calibrated with available well test permeability. After that, a streamline simulation due to high computation speed, high accuracy and good visualization was used to repeated history matching multiple equi-probable of a dual porosity model in gas condensate reservoir. So, with running streamline simulation, three realizations (High, Medium and Low) ranked based on the objective function values. In final, comprehensive history matching will be done as optimally for the three-selected realizations.
The overall goal in this study was to develop representative fluid flow simulation model for reservoir management as gas cycling scheme in enhanced condensate recovery. This method due to using actual fracture parameters has great application in the high resolution fractured reservoir modeling for model ranking, screening and optimum dynamic model calibration for reduction of the history matching effort without fabricated by reservoir engineer.
Fracture Lineament Validation using Streamline Simulation in a Giant Middle East Field: An Innovative Approach
Authors: Al-Najem Abdullah A. , Al-Thuwaini Jamil S. , Al-Omair Abdulatif , Jilani Syed Z. 
Published: May 2009

Abstract
With the advancement in streamline simulation technology in modeling fractured reservoir and streamline associated well allocation factors, now it can be used as an effective tool to validate fracture lineament through visualization of streamline-based flow pattern and injection allocation between each injector and producers. Such capability has made streamline based history matching very attractive and more reliable in expediting history matching of simulation project.
The objectives of the study are to improve the history match by validating fracture lineaments and then optimize Injection-Production Ratio (IPR). This study involves the conversion of a finite difference black oil Dual-Porosity Dual-Permeability (DPDP) history matched model into a Dual-Porosity Single-Permeability (DPSP) streamline simulation model and history match results are improved. Based on field-wide streamline flow patterns map, the field is divided into several independent regions. Within these regions, the fluid flow patterns between individual producers and injectors are also identified by the generated streamlines. In addition, an injector efficiency software is used to calculate actual water contribution of each injector to each producer from the well allocation file generated by the streamline simulator.
This paper documents the procedure on imporoving water cut matches by validating fracture lineaments. This novel procedure involves the tracking of water saturation and Time of Flight (TOF) of injected water along streamlines, its respective main contributing injectors, fracture/matrix cells carrying the flow, fracture cells to be connected and/or disconnected with other fracture cells and where fracture/matrix cells require permeability enhancement or reduction.
After improving the history match level, Injection Production Ratios (IPR) are optimized and considerable amount of incremental oil production is obtained.
The Use of Capacitance-Resistive Model for Estimation of Fracture Distribution in the Hydrocarbon Reservoir
Authors: Delshad M. , Bastami A. , Pourafshary P. 
Published: May 2009

Abstract
Capacitance-resistive model is a new method to quantify communication between vertical wells in a reservoir. This method is based on the contribution of each injector on each producer. Capacitance-resistive method uses production and injection rate data to develop and calibrate a model to predict the future performance of the producer wells. The proposed procedure uses a nonlinear signal-processing model to provide information about the connectivity between wells and presence of flow barriers and fractures.
In this paper, we present a new method to estimate the fracture distribution in the reservoir using Capacitance-resistive model.
We focused on the analysis of the relation between each injector/producer pair. We analyzed the connectivity weight factor of each injector and the neighboring producers to quantify the fracture distribution at each section of the reservoir. Hence, the developed model provides the fast estimation of the fracture distribution using only the flow rate data.
The developed model has been tested for different synthetic fractured reservoir case studies. The results are in good agreement in comparison with the fine grid numerical simulation results. It showed that our new approach has the capability to compute the fracture distribution much faster and cheaper than the numerical simulations.
By the new developed model, it is possible to estimate the fracture distribution easily and accurately in reservoirs, which has an important role in the field development, drilling new wells and future injection schedule.
Minimum Miscibility Pressure Determination for Systems Carbon Dioxide + Heavy Hydrocarbon (N-Eicosane) + Light Gas (Ethane or Propane) Using Peng-Robinson Equation of State
Authors: Al-Marri Salem S. 
Published: May 2009

Abstract
An important parameter used to determine the feasibility of miscible displacement is the minimum miscibility pressure (MMP). In oil recovery, gas injection can be a very efficient method for improving the productivity of the wells, particularly in the case when miscibility develops during the displacement process. Extensive use of carbon dioxide mixed with light hydrocarbon such as ethane and propane for this purpose has the secondary benefits of being a temporary means of sequestering these green house gases. MMP at which a gas should be injected into the reservoir in order to obtain a multicontact miscible displacement has consequently attained a very important status in enhanced oil recovery studies. MMP can be estimated from phase equilibria data using pseudo-ternary conceptualization of Benham et al. The full advantages of the use of carbon dioxide as a selective solvent can only be realized through knowledge and understanding of its phase behavior and equilibria with different hydrocarbons. In this paper binary and ternary phase equilibrium studies involving a heavy hydrocarbon such as n-eicosane, light hydrocarbon such as ethane and propane with carbon dioxide was performed. Peng-Robinson equation of state with binary interaction parameters were applied to represent vapor-liquid equilibria and to optimize the representation with minimum use of ternary parameters. The experimental data obtained was used to predict the MMP using pseudo-ternary conceptualization of Benham et al. and examine its variation with nature and amount of light hydrocarbons in the injected gas.
Integrating Reservoir Characterization and Fracturing Analysis to Understand the Pressure Transient Response of Frac Packed Wells
Authors: Al-Naimi Khalid , Al-Thawad Faisal , BinAkresh Saud , Bartko Kirk 
Published: May 2009

Abstract
The Unayzah-A in field T is an Aeolian sandstone formation with high sanding tendency requiring stimulation using the frac pack technique. Modified Isochronal Tests (MIT) and pressure buildups (PBU) were conducted on several wells in field T, to assess the reservoir and to evaluate the frac pack technique. During the analysis of the MITs and PBUs, several consistent trends were observed in the pressure derivative plots of field T wells, such as the absence of the fracture signature and the decrease of reservoir quality away from the wellbore. This consistency in the behavior of the pressure derivative was investigated in this study. Analytical and numerical well testing models, reservoir characterization, and fracturing analysis assisted in investigating the observations in PBUs. The investigation showed that to capture a fracture in the pressure derivative plot of high permeability formation, the fracture half length has to be extremely long, and there should be significant contrast between the fracture and the formation conductivities. The investigation also showed that the created fracture and the reservoir heterogeneity due to changes in geologic facies dictate the shape of the pressure derivative plot.
This paper will discuss how the reservoir characterization and the fracturing analysis were used to help in analyzing the pressure transient response of frac packed wells. Two pressure buildups (PBUs) and four MITs were used in this study. This paper will also shed some light on the frac pack results, and the non-Darcy flow effect.
Productivity of Fractal Reservoirs
Authors: Jelmert Tom Aage 
Published: May 2009

Abstract
A fractal reservoir may be thought of as having a spatial dimension that falls between the Eucledian space dimensions 1, 2 and 3. This concept may be unfamiliar to many. The objective of this study is to show that a model based on a fractal concept may be a useful complement to conventional models. To this end we investigate the productvity of wells in fractal reservoirs. The productivity index has a clear economic significance. Unfamiliar ways of characterizing rock properties are discussed by use of simplified models.
For clarity, we discuss steady state flow in a naturally fractured reservoir. A steady state condition depends on a constant pressure outer boundary. We investigate analytical solutions. These include the conventional ones as special cases. The application of the proposed solutions will be in well testing, estimation of natural flow, economic modelling and reservoir characterization.
The fractal model leads to rock properties of powerlaw dependence on the spatial variable. We find that this description may reflect the length scale of the elementary volume, REV. Fracture architecture; changing flow area and stress sensitivity may also contribute to powerlaw dependency. The analytical solutions obtained are valid for any reservoir that may be characterized by simple powerlaw expressions whether fractal or not.
We find that equation for the flow efficiency of a fractal reservoir depends on three dimensionless parameters. The flow efficiency is sensitive to a parameter (the difference between the fractal dimension and the conductivity index), dimensionless distance and skin.
Performance of Thermal Recovery Processes in a Middle Eastern Reservoir
Authors: Algharaib Meshal , Alajmi Abdullah , Gharbi Ridha 
Published: May 2009

Abstract
Primary oil recovery is usually very low which leaves large quantities of oil retained by capillary and viscous forces. Enhanced Oil Recovery (EOR) techniques are used to recover these retained hydrocarbons volumes. Thermal recovery is an EOR technique which is usually used to enhance oil production from heavy oil reservoirs. In thermal recovery methods, hot fluids, such as steam or hot water, are injected into hydrocarbon strata to reduce the retaining forces responsible for oil entrapment and enhance recovery efficiency. In Middle East, heavy oil deposits are encountered in many countries. The maturity status of the current major oil producing fields in addition to the current high energy demands are main contributors to the current interest in developing heavy oil resources. Therefore, the need to predict the performance of thermal EOR processes in these heavy oil accumulations is of a major importance.
The targeted reservoir in this study occurs at shallow depths, ranging from 500 – 1000 feet and is widely spread. Apart from two cyclic steam stimulation pilots conducted during the 80';s, this reservoir was left undeveloped for the past years due to the high sulfur content and extraction cost. The findings of these pilots indicate the suitability of this reservoir to thermal recovery methods. In this paper, the performance of hot water flooding, in a sector area of the targeted reservoir is simulated under different well arrangements. Various reservoir/design parameters were considered to evaluate the cumulative oil recovery in terms of the cumulative heat injected. The results show some cases where the economics of thermal recovery applications can be improved by a proper heat management. Moreover, the paper highlights the functional relationships between cumulative oil recovery and cumulative heat injected under the investigated reservoir/design parameters.
Optimal Transformations for Multiple Regression: Application to Oil Viscosity Correlation Above and Below Bubble Point Pressures
Authors: Al-Marri Salem S. 
Published: May 2009

Abstract
Reservoir oil viscosity is one of the important reservoir fluid properties used for many petroleum engineering calculations such as evaluating hydrocarbon reserves, planning enhanced oil recovery methods, calculating fluid flow rate through reservoir rocks, etc. Therefore, achieving an accurate reservoir oil viscosity value is very crucial for petroleum engineers. Viscosity of reservoir oil can be obtained by a laboratory measurements and empirical correlations. Many of the common correlations in use were developed using data collected from different regions of the world.
The literature contains many different viscosity models, the viscosity models found in the literature range from highly theoretical to simple empirical correlations. Two typical viscosity correlations are applicable to both liquid and gas phases; the Corresponding States Method (CSM), semi-empirical, and the empirical Lohrenz-Bray-Clark (LBC) method. In this paper, the applicability of both models were tested to predict the experimental viscosity measurements for pure n-eicosane, ethane/n-eicosane, propane/n-eicosane binary systems. After normal quality checks, nonlinear multiple regression with linear partial correlation coefficient techniques were applied to develop friction theory and binary interaction parameter were used to modify the representation of friction theory model. The comparisons among LBC, Corresponding State Principle (CSP), general model of friction theory and modified friction theory (using binary interaction parameter) were performed. Based on the error statistical analysis results, the developed friction theory model has shown to provide accurate estimates of viscosity in all pressure regimes.
Practical Application of CFP Technology to Resolve Complex Near Surface Problems and to Estimate Velocity-Depth Model
Authors: Almomin Ali , El-Marhfoul Bouchaib 
Published: May 2009

Abstract
Complex topography and highly variable weathering layers in the near surface can severely degrade the quality of seismic data and result in a distorted structural image of the deeper subsurface reflectors. The objective of this work is to compare seismic image quality after application of the Common Focus Point (CFP) redatuming with images generated using more conventional static techniques. The CFP method resolves near surface effects on seismic data by considering the wave propagation phenomena, based on data-driven focusing operators, independent of any velocity model.
Focusing operators are required to describe the kinematic phenomena of the wave field as it passes through the near surface. The focusing operators are automatically estimated using a parametric inversion procedure that assumes the focusing operators can be described with a smooth parameterization. Using these operators, a complete wave field redatuming can be performed moving the data recorded at the surface to a new datum underneath the complex near surface. The results represent data as it would have been measured underneath the complex near surface, with the sources and receivers on the datum reflector. In a second step, these focusing operators can be input to a tomographic inversion process to obtain a velocity-depth model. This model can then be used for converting the redatumed results to depth.
The results from the CFP-based redatuming showed significant improvements over results from traditional statics methods for both synthetic and real data. The continuity of the deeper reflection events was improved and a more reliable time image was obtained of the deeper structure.
Advanced Processing of Walkaway VSP Data, Offshore India
Authors: Jindal Nidhi , Jyothi Prativadi , Tiwari Sanjay , Biswal Ajoy , Sanghvai Pranaya , Barakat Saleh 
Published: May 2009

Abstract
Walkaway VSP (WVSP) data plays a major role in reservoir delineation and characterization. High-resolution VSP data can be integrated with surface seismic data to provide detailed descriptions of formation properties and identification of reservoir compartments, which are not possible with surface seismic data alone. This present study is from an area in the deep water of the Krishna-Godavari basin. Advanced processing of deep water WVSP data has been done to delineate the small scale faults, if any, which may interfere with the fluid flow and cannot be clearly visible on surface seismic data and to understand compartmentalization and fluid continuity within the zone of interest.
From the WVSP pre-survey modeling, 28 geophone levels at 10 meter receiver spacing and 2 profiles of 8 km. length were designed. A vector migration algorithm was applied to image the 3 component VSP data, to enhance the image quality. Multiple-View migration has been applied, which produces a much wider image zone then conventional VSP migration using primary reflections only.The image result presented in this paper shows how the walkaway VSP is able to identify detailed stratigraphic and structural geological features with greater resolution than surface seismic data.
Lessons Learned from 100 Intelligent Wells Equipped with Multiple Downhole Valves
Authors: Mubarak Saeed , Dawood Naseem , Salamy Salam 
Published: May 2009

Abstract
The last decade has been marked by the emergence of intelligent field technologies. Many E&P companies have moved from the piloting and trial-testing mode towards strategic implementation demonstrating that these technologies have shown their capabilities. While the current deployment of these technologies represents only a small fraction of the overall installation, the trend is indicative of the shifting of attitudes and preferences within companies. Among those companies, Saudi Aramco has deployed fit-for-purpose technologies such as intelligent wells equipped with multiple downhole valves, as part of its best-in-class practices (Figure 1). Continuous assessment of these technologies is important to provide reassurance on their values.
The resulting performance of this technology is a function of multiple factors spanning from reservoir parameters, completion schemes to surface infrastructure. Understanding and assessing the impact of these factors is complex due to the wide variation of variables.
This article summarizes the lessons learned from more than one hundred deployments in wells equipped with multiple downhole valves. These lessons illustrate the advantages of these applications and should provide insight for improved performance. As there is no "one size fits all," then proper design should be emphasized for maximum effectiveness.
Materials Selection for Smart Well Completions in Conjunction with Expandable Casing Technology
Authors: Choi Ho Jin 
Published: May 2009

Abstract
Materials selection is critical to ensure the life expectancy and cost-effectiveness of smart well completions in conjunction with expandable casing technology in Saudi Aramco re-entry multilateral oil wells for effective hydrocarbon recovery. Linking these two leading-edge technologies, Saudi Aramco has successfully completed more than 20 oil producing wells since 2004. Knowing well corrosivity and corrosion resistance of materials is critical in selecting cost-effective downhole equipment. This paper proposes a guideline for materials selection of downhole production tubing in oil and gas producing re-entry wells for maximum reservoir contacts, based on results of field and laboratory corrosion studies in sweet and sour services.
First Saudi Aramco Use of Retrievable Downhole Pressure and Temperature Gauges Monitoring System: A Cost Effective Technology Solution to Manage Maturing Oil and Gas Fields
Authors: Chatriwala Shaizad A. , Al-Subaie Fehaed M. , Al-Shehri Dhafer A. , Soremi Adeyinka X. , Reaux James 
Published: May 2009

Abstract
The trial test of Wireline Retrievable Side Pocket Surface Read-Out Permanent Downhole Monitoring System (SPSRO-PDHMS) was successfully conducted in a newly drilled well in a giant oil field in Saudi Arabia. In the wireline retrievable PDHMS system, the downhole gauges sit in a side pocket mandrel; if the downhole gauges malfunction, they can be retrieved and replaced easily with wireline. Conventionally these gauges are run on tubing and in case of gauge failure, a workover rig is required to replace the malfunctioning gauge (there are 6 wells with malfunctioned/failed gauges in the operated field). The WL retrievable option would eliminate the $500,000 rig cost per well to replace malfunctioning or damaged gauges.
Smart well- Benefits, Types of Sensors, Challenges, Economic Consideration, and Application in Fractured Reservoir
Authors: Pari M. Nadri , Kabir A. H. , Motahhari S. Mahdia , Behrouz Turaj 
Published: May 2009

Abstract
Smart Well technology has seen rapid evolution in the last decade because of technological advancements. Proper knowledge of this technology, with some risk mitigating techniques, makes several benefits to an oil company including the capability of drilling longer horizontal and extended reach wells, particularly snake wells with great reduction in cleanup, reservoir management and water and gas breakthrough concerns. Even in some cases unexpected benefits have been discovered from this technology.
Sensors are considered to be the heart of smart well completion. There are different types of sensors in the oil industry including wellbore internal sensors and casing external sensors. Some of these sensors are used for wellbore measurement and some for imaging the distribution of reservoir attributes away from the well. In this paper we will investigate all types of sensors either developed sensors and emerging sensors to measure pressure, temperature, flow Rate, noise, phase composition, pH, water cut, gas fraction and capacitance. However commonly used ones are P, T and flow rate sensors. Others are still emerging technologies. It is possible to use permanent sensors named pressure, resistivity, acoustic on outside wall of the casing as well to estimate permeability, porosity, saturation and monitor near wellbore water / flood front encroachment.
Although Smart Well technology has shown several benefits but it possesses some challenges regarding their reliability and cost effectiveness and implementation phases. As a result, many companies tend to apply this technology with caution knowing that the cost of a smart completion can easily be three to four times more than a conventional completion.
In this paper we present a comprehensive review of state-of-the-art Smart Well technology including all benefits, different types of sensors, challenges, economic consideration and application in fractured reservoir.