bluuebunny/crossref_metadata_2025_split huggingface dataset:
Prediction of Rock Mechanical Parameters for Hydrocarbon Reservoirs Using Different Artificial Intelligence Techniques
Authors: Abdulraheem A. , Ahmed M. , Vantala A. , Parvez T. 
Published: May 2009

Abstract
Rock mechanical parameters of reservoir rocks play an extremely important role in solving problems related to almost all operations in oil or gas production. A continuous profile of these parameters along the depth is essential to analyze these problems which include wellbore stability, sand production, fracturing, reservoir compaction, and surface subsidence. The mechanical parameters can be divided into three main groups, viz., elastic parameters, strength parameters, and in-situ stresses. Even the profile of in-situ stresses with depth is estimated using logs with elastic parameters as an essential input. The focus of this work is on the prediction of elastic parameters and their variation with the depth of a given reservoir.
For an isotropic medium, there are two independent elastic parameters, viz., Young's modulus and Poisson's ratio. Generally, logging data consisting of density, compressional and shear wave velocities are used to estimate these parameters. However, these data provide dynamic elastic properties which are different from static values, especially in case of Young's modulus.
To get continuous rock samples throughout the depth of the reservoir and conduct triaxial tests to determine the static values of these parameters is extremely expensive. Consequently, static values of Young's modulus and Poisson's ratio obtained from laboratory testing on rock samples acquired from selected intervals are used to calibrate the dynamic data obtained from logs. However, since the rock layers vary in their properties with depth, a realistic estimation of static elastic values of the rock is still a challenge. The problem is more prominent in limestone rocks compared to sandstone rocks. Further, shear velocity data is not always available from well logs, making the problem more difficult.
An extensive experimental program was carried out first to obtain the static values of elastic parameters of reservoir rock samples at reservoir conditions of high pressure. Log data consisting of different variables such as density, velocity, and porosity from the same wells were also obtained.
Three artificial intelligence methods viz. Neural Network, Fuzzy Logic and Functional Network, were used to obtain a continuous profile of static elastic parameters along the depth. The results obtained from these approaches were compared using log inputs. The strengths of each of these approaches are also discussed.
3D Reservoir Geomechanical Modeling in Oil/Gas Field Production
Authors: Koutsabeloulis Nick , Zhang Xing 
Published: May 2009

Abstract
The pore pressure, stress state and geological structures as well as their evolution during an oil/gas field life have widespread influence on implications for wellbore stability, hydraulic fracturing, fault-reactivation, early water-cut, top surface subsidence, reservoir compaction and water/gas flooding. These events have a significant impact on reservoir performance and their effects need to be taken into account in production surveillance, analysis and forecasting. A coupled reservoir geomechanical modeling approach is developed, using the static and dynamic models of VISAGETM System, to compute the change in reservoir pore pressure and stress state, the evolution of reservoir properties, the development of potential fracturing and the reactivation of existing faults. This geomechanical modeling consists of an initial stress simulation prior to production and a coupled reservoir simulation due to depletion and/or injection activities. A very representative initial stress state can be simulated using this approach and can be well calibrated with stress measurements from wireline logs, borehole breakouts and regional stress. Based on the simulated initial stress state, the change in pore pressure due to depletion and/or injection is used to compute the change in effective stress and associated reservoir deformation. The production history and observed reservoir deformation in the past can be simulated. Reservoir performance and associated reservoir deformation can also be predicted in the future production. A full field study using the VISAGETM System was performed to help assess the integrity of the development plan in South Arne field, North Sea. The predicted stress and strain changes that were induced by production/injection were used to assess the wellbore stability, potential for faults reactivation, cap rock integrity and rock fracturing. This study demonstrates that coupled geomechanical modeling lends direct support to drilling operations and reservoir management.
A Porothermoelastic Wellbore Model in Oil and Gas Saturated Naturally Fractured Porous Media
Authors: Nair Rajesh , Abousleiman Younane 
Published: May 2009

Abstract
The impact of initial oil saturation and presence of fractures on hole stability has been analyzed using a three-dimensional, fully-coupled multi-phase finite element model. The model accounts for thermo-hydro-mechanical coupling as well as solubility of gas in oil and evaporation of oil into gas in both the rock matrix and fractures. In addition, the viscosities of the oil and gas phases, formation volume factors for oil and gas, gas-oil solubility ratio, oil volatility ratio and the saturations are assumed to be dependent on the temperature. The model is verified with analytical solutions for the limiting case of a medium saturated with a single fluid. A parametric study is carried out varying the initial oil saturation and fracture parameters and the changes to the stress state around the wellbore are assessed. A preliminary analysis of failure study shows that the presence of fractures and lower initial oil saturation increases the failure potential.
Drilling and Completing Horizontal Wells in Unconsolidated Sandstone Reservoir in Saudi Arabia; A Rock Mechanics View
Authors: Rabaa Ali S. , Abass H. H. , Mousa Talal S 
Published: May 2009

Abstract
Drilling horizontal wells is a common practice for Saudi ARAMCO in most of its oil and gas reservoirs of Saudi Arabian clastic and carbonate fields. A comprehensive study of rock mechanical properties with detailed analysis of the in-situ stress field was conducted to evaluate well stability during drilling and completion across a friable eolian oil-bearing sandstone reservoir. This paper discusses the application and implementation of the study to successfully drill and complete development horizontal wells in a challenging sandstone reservoir.
All horizontal wells were completed with different type of sand screens including Premium and Expandable Sand Screen (ESS). It is vital to obtain a near-gauge hole during drilling for a maximum stability of the screen during the life of a well. It is therefore important to prevent excessive compressive shear failure at the wellbore wall and avoid instability problems during drilling and completion. Therefore, an optimum confining pressure to the wellbore surface needs has been derived. The recommended mud type and weight windows derived from the study have been employed while drilling producers but not with injectors. The correlation between the mud weights and the in-situ stress magnitude will be discussed.
Well stability during drilling and long term screen integrity is dependant on the well azimuth relative to the in-situ stress field. The azimuth of the maximum horizontal stress, SHmax, was determined to generally line up in the E-W direction. The wellbore stability problems experienced in this direction as well as those drilled normal to it (i.e., N-S), will be addressed.
In regards to stability of very weak and friable formation intervals (such as those encountered in the, dunes and sand sheet facies), the operational practices are focused on creating gauged hole with least erosion effect as a critical measure to deploy the ESS; thus, ensuring successful completion and sustained production. The effect of mud on rock strength was evaluated during the foregoing study; therefore, results from using oil-base mud will be discussed and compared to results from the wells drilled with water-based mud.
Performance of Hot Water Injection in Heterogonous Reservoirs using Multilateral Wells
Authors: Alajmi Abdullah F. , Gharbi Ridha , Algharaib Meshal 
Published: May 2009

Abstract
The use of multilateral wells in the oil industry has increased rapidly during the last decade. The main reason for this upsurge is that these wells provide large contact areas with the reservoir and therefore better recovery performance is achieved. In addition, the availability of new technologies in recent years has substantially reduced the cost of drilling these wells. In fact, in many areas of the world, drilling multilateral wells is becoming the norm when deciding to drill new wells. Furthermore, the continuous growth in the world oil demand stimulates the oil producers to develop all kind of resources including heavy oil reserves. The significant heavy oil accumulations already existed in the world has led to a greater emphasis on their development using thermal EOR methods. This study investigates numerically the performance of using multilateral well configurations in recovering heavy oil from heterogeneous reservoirs using hot water flooding. In order to cover a wide range of heterogeneity, a series of reservoir permeability maps, each with different permeability structures and variations, were generated stochastically. In each of these heavy oil reservoirs, extensive three-dimensional, fine-mesh simulation runs were performed using different configurations of multilateral wells. The oil recovery performance obtained by hot water flooding was compared to that obtained by conventional water flooding in all these reservoirs. The objective was to determine the functional relationships between the oil recovery performance and several design parameters including: (1) degree of heterogeneity (2) well configurations, and (3) viscosity ratio. Results show that these parameters play important roles in the displacement behavior of heavy oil using multilateral wells, with reservoir heterogeneity having a more significant effect. The study suggests that there exist critical values of these parameters under which hot water floods can be more effective than conventional water floods. The paper will present these conditions in detail and situation where the performance of hot water floods can be ineffective.
Nano-Technology - Its Significance in Smart Fluid Development for Oil and Gas Field Application
Authors: Amanullah Md. , Al-Tahini Ashraf M. 
Published: May 2009

Abstract
Nanotechnology application can revolutionalise the additive characteristics and behaviour by tuning particle properties to meet certain operational, environmental, and technical requirements. Hence, the nanotechnological research leading to create some tailored made nanoparticles could be a promising step change research for smart fluids development for different industrial applications. These particles are ultra fines in nature, usually larger than an atom cluster but smaller than ordinary micro particles and thus have very high specific surface area with enormous area of interactions. Due to nano-scale particle dimension, the nano-type fluid additives have both external as well as internal inhibition potential, require a very low additive concentration and thus expected to provide superior fluid properties at a drastically reduced additive concentration.
Nano-particles with high thermal stability and affinity to acid gases such as H2S and CO2 will help meet the technical challenges of sour gas environment, deep and geothermal drilling and thus expected to complete a well economically and safely with a drastic reduction in oil and gas exploration and exploitation risk. Identification, screening, selection, and/or development of nontoxic, environment friendly and biodegradable nano-particle-based drilling fluids are expected to meet the current as well as the future environmental norms and regulations for drilling and production in deep water and sensitive environments.
This paper provides a detailed description of the likely benefits of emerging nano-particle-based additives in smart fluid design for oil and gas field application, especially for a new generation of drilling and drill-in, completion, stimulation, fracturing, etc fluids for trouble-free drilling, completion and production of oil and gas resources.
Technology and Team-Based Approach Yields Saudi Arabia's Longest Fully Cemented Horizontal Liner
Authors: Ramos Marlio Campos , Hussein Sameh , Wedewer Kirby , Dieker Ansgar 
Published: May 2009

Abstract
Saudi Aramco's "M" Field is located offshore and will be developed using over 300 wells with a combination of land and offshore drilling facilities.
Well number M-A is a land-based, power water injector well, drilled to an offshore bottomhole location. The resulting well design dictated directionally drilling an extended-reach well with an 8-1/2-in. horizontal-hole section over 13,900 ft (4237 m) in length.
It was apparent from the outset that directionally drilling the 8-1/2-in. section was going to be extremely challenging. Once drilled, running and cementing the 7-in. liner would present a host of additional difficulties. To ensure a successful outcome, Saudi Aramco assembled a dedicated team of Operator and Service personnel to review all aspects of this openhole section and resulting liner running operations.
The latest in directional drilling technology was used to ensure the exacting directional control needed to deliver the wellbore. In addition, running the over 14,400-ft- (4389-m)-long liner required the use of new and innovative liner hanger technology to overcome any challenges encountered during liner deployment.
This paper will outline the planning, methods, and equipment applied to deliver the resulting 8-1/2-in. hole section, and successfully deploy Saudi Arabia's longest-ever cemented 7-in. liner.
New Completion Methodology to Improve Oil Recovery and Minimize Water Intrusion in Reservoirs Subject to Water Injection
Authors: Sierra Leopoldo , East Loyd , Kulakofsky David 
Published: May 2009

Abstract
Water injection during the early stage of a new reservoir's development is gaining popularity around the world. This is especially true in Saudi Arabia where water injection is used to improve oil recovery and for pressure maintenance by placing short or long horizontal water-injection wells around the reservoir flanks.
For cases where water-injection wells are placed in reservoir flanks, some of the producing wells are perforated transversally oriented to the water-injection wells to improve the oil recovery around the involved areas. For this specific exploitation strategy, there is a potential risk of water channeling from the injector to the producing well toe which, once it happens, might jeopardize recovery efficiency.
For the referenced exploitation strategy, a new completion methodology considering the placement of a fracture barrier at the toe of the producing well to delay water intrusion and improve recovery efficiency is proposed. This paper discusses the process to create the fracture barrier and the benefits of the completion methodology supported with extensive simulations for the different scenarios.
Innovative Approach for Water Injection Trees Integrity
Authors: Al-Rufaie Yousef A. , Al-Tammar Hasan I. , Al-Kady Alaa 
Published: May 2009

Abstract
The majority of the PWI wellheads injection trees in the Ghawar field have already passed their half-life time designated by the manufacturer and others have even completed their life cycle. Several operating factors were considered during the initial design stages of these trees based on the operating circumstances. The alloy (steel) of the PWIs composite trees have been selected to cope with the anticipated flow media, such as seawater, high injection pressures and rate (3,000 psig), frequent valve cycling and the life lasting expectancy was set for 20 years.
Nowadays, despite frequent valve care maintenance through the ongoing valve care program, the integrity of these valves has become susceptible to failure more than ever. The failures are caused either internally due to seats ring and ball damage, or externally due to flange leaks due to "O" rings and groove damage. In addition to the harsh operating conditions, aging is also another major cause for valves' integrity deterioration.
The innovative idea is to utilize synthetic valve care sealants to temporarily stop valve internal leaks (internal passing) by injecting a sealant through the ball valve's upper and lower grease fittings that are directly related to valve seats and sealing area, Fig. 2. The dual function of the lubricants/sealants is to clean hard deposits4, lubricate sealing elements and fill-in the internal channels and grooves. By doing so, the seats get pushed against the ball valve body sealing area, resulting in 100% pressure seal from both directions. The above stated idea is in use now as we speak, and has proven its practicality in the field to resolve valve leakage issues and make job executions arrangements simple and cost-effective.
Long Term Evaluation of a New Liquid Resin Additives used for Fracture Conductivity Enhancement in a Gas Producer Screenless Completion, Jauf Reservoir, Saudi Arabia
Authors: Leal Jairo , Solares J. Ricardo , Al-Ghurairi Fadel , Sierra Leopoldo 
Published: May 2009

Abstract
Jauf is a high pressure/high temperature gas producer sandstone reservoir, which exhibits a high sanding tendency in some zones throughout the reservoir. To combat the sanding tendency, Saudi Aramco has implemented two screenless sand control strategies by performing the indirect proppant fracturing process. The first or older strategy combines a number of techniques such as, indirect fracturing from oriented perforated thin consolidated zones, tip screenout design, use of a combination of resin coated proppant with fibers, forced closure, and a carefully controlled flowback procedure. The second strategy combines the indirect fracturing from oriented, perforated-thin consolidated zones, tip screenout design and the use of the new liquid resin additives.
Although a solids-free high rate gas production has been achieved in the majority of wells for which the first strategy was implemented, a high reduction in fracture conductivity in the form of positive skin has been detected from pressure buildup tests conducted in a number of fractured wells. Al-Ghurairi et Al (SPE 98088) explained the reasons for the positive skin and it was associated with partial penetration, given that the interval from which a fracture is initiated is usually perforated in high Young's Modulus rock and limited to 30-40 feet; thus the fracture is initiated away from the high sanding tendency zones and extended vertically into such zones. The other main component for the positive skin was attributed to the fibers used for proppant flow back control purposes, since it is well known through extensive industry testing, that the combination of proppant and fibers can reduce fracture conductivity in treated wells.
Supported by extensive lab testing showing that the combination of the two new resin additives, mixed with proppant, could provide effective solids and proppant flowback control without reducing fracture conductivity; the second strategy was implemented in the field, in December 2004. The initial outstanding results of this first pilot application were documented in the paper1 SPE 98088. After the initial evaluation the well was closed, up to the second quarter of 2006, to finish the surface production facilities.
This paper is a continuation of paper SPE 98088 and it discusses the long-term evaluation results and benefits of the new liquid additives used to improve and sustain the fracture conductivity.
Droplet Size Analysis of Emulsified Acid
Authors: Al-Mutairi S. H. , Nasr-El-Din H. A. , Hill A. D. 
Published: May 2009

Abstract
Emulsions have been used for many applications in the petroleum industry for many decades. Emulsified acid has been used in acid fracturing and well acidizing since 1933. A large number of fracturing treatments that used emulsified acid has been reported in the literature. Another fair number of researchers conducted lab experiments utilizing the emulsified acid. However, all of this work cannot be reproduced because of inadequate characterization of the emulsion. One essential way to characterize emulsions is by their droplet size. Various mixing modes and proportions produce emulsions with different size distributions for the dispersed phase. Those physical variations are believed to generate different properties (viscosity, stability, etc) of the emulsions.
The main objective of this paper is to provide a detailed description of the droplet size distribution of emulsified acids. Methods to measure and represent the data are the core of this section. We show that coarse or fine emulsions can be produced by selecting the mode of mixing and speed of shearing. Simple mixing and low shearing produce coarse emulsions whereas atomizing and high shearing produce fine emulsions. It is also demonstrated that the droplet size and specific surface area are affected by emulsifier concentration and acid volume fraction. Average droplet size decreases with increasing emulsifier concentration. The diameter also increases with increasing acid volume fraction. The specific surface area of the droplets increases with increasing emulsifier concentration and decreases with increasing acid volume fraction.
The change of droplet size has a practical impact on the stability, rheology and reactivity of emulsified acid. Good understanding and characterization of the emulsified acid by its size distribution will lead to advancements in this area.
High Speed Network for Intelligent Field Data Acquisition
Authors: Almadi Soloman , AL-Khabbaz Fouad , AL-Walaie Soliman , AL-Harbi Saad , AL-Amri Ali , AL-Gharairy Hussain 
Published: May 2009

Abstract
Process Control systems are embarking on a new wave of opportunities driven by Information Technology developments in infrastructure and system integration. Currently, most process and control systems consist of multiple, separate networks with limited interconnectivity. On the other hand, and due to the rapid developments of Information Technology, desktop computer system, Internet and Ethernet technologies are becoming increasingly suitable for use in the Manufacturing and Process Control sectors. This means that for the first time computer and communication structures based on Ethernet/Internet technology can be extended throughout the entire company. This paper provides an overview of the network, technology, and topologies utilized for an optimal High Speed Network for Oil and Gas Field Data Acquisition systems.
An Innovative Multi-Reservoir Permanent Downhole Monitoring System through a Single Well
Authors: Al-Omair Abdullatif , Ukaegbu Orji O. , Alshafie Muhammed , Shafiq Muhammad , Almarri Abdullah 
Published: May 2009

Abstract
This paper describes an innovative Down Hole Permanent Monitoring System (PDHMS) that allows real-time monitoring of bottom-hole pressure and temperature of two stacked reservoirs using one vertical observation well in a Saudi Aramco field.
Permanent monitoring of pressure and temperature enables reservoir engineers to assess the performance of the reservoir in areas such as flood front movement and pressure support maintenance. In this well a multi-reservoir dual gauge system was deployed to monitor pressure and temperature in two stacked carbonate reservoirs.
The standard dual-gauge system mandrel architecture requires below packer installation of the gauges which in turn increases the risk of leakage in the electric lines of the system. In this paper, we describe an innovative and potentially reliable digital permanent monitoring solution that uses the state-of-the-art welded system that aims to eliminate the risk of leakage.
Included in the paper are the design criteria, deployment methodology and the "lessons learned" from installation of this fully welded PDHMS.