bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Effects of Dynamic Loading on the Sand Management and Permeability of Shape Memory Polymer and Gravel Packs for Sand Management Applications
Authors: Carrejo N.. , Horner D. N. , Johnson S. H 
Published: September 2011

Abstract
Shape memory polymer (SMP) foam is being studied for use in downhole sand-management applications. The process involves machining the shape memory polymer into the desired final geometric shape profile. The shape profile is altered to the desired run-in profile. For reactive sand-management applications, the initial profile is a tubular shape with a diameter greater than the anticipated openhole diameter. The geometric shape is then altered to achieve the desired run-in diameter. When deployed downhole, the shape memory polymer must have good filtration characteristics and adequate permeability to provide efficient sand control without affecting well productivity. Foam permeability should be a minimum of 25 times greater than the formation permeability to minimize wellbore productivity risks. Filtration characteristics should prevent formation sand movement and have a minimal plugging risk.
During oil and gas production, the shape memory polymer provides an initial, minimal contact pressure to help stabilize the borehole. In the scenario of a collapsing wellbore, a dynamic strain test is needed to characterize the resulting effects on the permeability and filtration properties of this shape memory polymer. This paper discusses the development of a filtration test during dynamic loading, and presents the filtration results of shape memory polymer materials and conventional gravel pack techniques during dynamic strain loading.
Use of Zeta Potential to Maximize Sand Free Rate: A New Approach on Sand Control
Authors: Mendez Alfredo , Johnson Dan , Kakadjian Sarkis 
Published: September 2011

Abstract
There are several active and passive methods for controlling the production of formation sand. The main objective is to produce at the maximum sand-free rate without compromising the well’s hydrocarbon production and longevity of the completion system placed. This paper presents a new chemical method and the latest case histories from offshore reservoirs. The new method changes the zeta potential of solid surfaces, thus strengthening attraction between the particles to optimally align proppant, sand particles, fines, or coal fines. Laboratory tests are presented, showing the mechanism of zeta potential and lab tests performed on unconsolidated cores by internal and independent labs. Core flood tests consisted of measuring the permeability before and after the treatment and the formation sand retention. More than 100 jobs have been treated with this chemical solution, with positive and promising results. Operational procedures and recommendations are presented on several wells treated.
Fracture-Width Estimation for an Arbitrary Pressure Distribution in Porous Media
Authors: Todd B.. , Choudhary Y.. , Bhamidipati S.. 
Published: September 2011

Abstract
Accurate estimation of fracture width is necessary for successful hydraulic fracturing or FracPac treatments. This information becomes even more critical when most of the fluid leakoff is forced through the proppant pack and out through the tip of the fracture during hydraulic fracturing or FracPac treatments. With the development of new, low-leakoff fluid systems, the coupling of fluid flow through porous media and subsequent pressure responses must be incorporated in predicting fracture-width profile.
The generalized width equations, although well-known, are seldom solved for cases other than constant pressure throughout the fracture or for simple pressure distributions. This paper demonstrates how these complex fracture-width equations can be solved for an arbitrary pressure distribution in a simplified approach. The generalized width equations for fracturing calculate a fracture’s width along its length or radius, w(x) or w(r), given a pressure profile, p(x) or p(r).
Two main width techniques are discussed, one based on a modified Perkins-Krech approach and the other on a corrected Valko-Economides approach. A comparison to the Jaeger-Cook deflection equation is made. In the Perkins-Krech and the Jaeger-Cook cases, the method of superposition is used. In the Valko-Economides case, the pressure is fit with a polynomial equation, and the integration is carried out term by term. The results are comparable with a finite element analysis (FEA) model, and good agreement has been observed. Examples are presented on how these techniques can be set up in spreadsheets, allowing the engineer to investigate concepts like "dry tip" and stresses around a fracture perimeter.
Reservoir Simulation and Modeling Based on Pattern Recognition
Authors: Mohaghegh Shahab D. 
Published: September 2011

Abstract
In this paper a new class of reservoir models that are developed based on the pattern recognition technologies collectively known as Artificial Intelligence and Data Mining (AI&DM) is introduced. The workflows developed based on this new class of reservoir simulation and modeling tools break new ground in modeling fluid flow through porous media by providing a completely new and different angle on reservoir simulation and modeling. The philosophy behind this modeling approach and its major commonalities and differences with numerical and analytical models are explored and two different categories of such models are explained. Details of this technology are presented using examples of most recent applications to several prolific reservoirs in the Middle East and in the Gulf of Mexico.
AI-Based reservoir models can be developed for green or brown fields. Since these models are developed based on spatio-temporal databases that are specifically developed for this purpose, they require the existence of a basic numerical reservoir simulator for the green fields while can be developed entirely based on historical data for brown fields. The run-time of AI-Based reservoir models that provide complete field responses is measured in seconds rather than minutes and hours (even for a multi-million grid block reservoir). Therefore, providing means for fast track reservoir analysis and AI-assisted history matching are intrinsic characteristics of these models. AI-Based Reservoir Models can completely substitute numerical reservoir simulation models, work side by side but completely independent or be integrated with them in order to increase their productivity.
Advantages associated with AI-Based Reservoir Models are short development time, low development cost, fast track analysis and have the practical capability to quantify the uncertainties associated with the static model. AI-Based Reservoir Model includes a novel design tool for comprehensive analysis of the full field and design of field development strategies to meet operational targets. They have open data requirement architecture that can accommodate a wide variety of data from pressure tests to seismic.
In-Situ Mechanical and Functional Behavior of Shape Memory Polymer for Sand Management Applications
Authors: Yuan Y.. , Goodson J.. , Johnson M.. , Gerrard D.. 
Published: September 2011

Abstract
Pumping a gravel-slurry between a downhole screen and the rock matrix has been used to prevent production of undesirable solids or sand from the formation in traditional oil and gas completions. Recently developed expandable technology attempts to eliminate this operation by expanding metallic sand control screens against the wellbore. However, a problem with this process is borehole irregularity. It is desirable to have a smart downhole screen structure that is capable of self-expanding and conforming to the borehole surfaces in certain downhole conditions. Use of an advanced shape memory polymer structure offers breakthrough performance for sand management applications. Proper characterization and full understanding of the mechanical and functional behavior of the shape memory polymer structure in simulated downhole pressure, temperature, and fluid conditions is critical for successful applications.
This study used a high-pressure/high-temperature in-situ mechanical test system and test method to characterize the in-situ hot-wet mechanical and functional behavior of the shape memory polymer foam. This included deployment and contact pressure development functional properties, compressive and time-dependent stress-relaxation and creep properties. These properties were determined during immersion in a fluid environment at various temperatures under ambient pressure and 3,000-5,000 psi hydrostatic pressure. Effects of the test temperature, fluid condition and the hydrostatic pressure on mechanical and functional properties of the shape memory polymer foam were identified. Study results were used to establish the operational window of shaped memory polymer screen as a sand control solution.
Game-Changing Technology Developments for Improving Operational Efficiencies in Deepwater Well Completions
Authors: Kessler Calvin , Hill Jim , Earl Tyson 
Published: September 2011

Abstract
A new-generation electro-mechanical downhole power unit for setting and retrieving packers, bridge plugs, whipstocks, and other downhole devices has been recently developed and globally deployed. The new downhole power unit – Intelligent (DPU®-I system), is designed to operate at high temperatures and extreme high pressures (400°F, 30 Kpsi), while providing up to 100 Klbs of setting force. The high linear force for either setting or retrieving is independent of hydrostatic pressure and provides a cost-effective alternative to jointed-pipe interventions, which were previously required to obtain high setting forces. The e-line-conveyed DPU-I system, with its high setting force, has been successfully used numerous times in deepwater wells and has shown to save in excess of one day’s rig time for setting sump packers or other devices in ultra-deep well conditions compared to jointed-pipe intervention. New to the industry is the ability to monitor in real time at the wellsite and remotely via satellite communications the downhole line tension, tool acceleration, stroke length, the setting force, and the rate at which the force is being applied during the setting operation as well as the force at which the DPU-I system detaches from the downhole device. This allows well-completion experts to remotely monitor the setting or retrieval operations 24/7 and provides a record of the setting operation for risk mitigation and developing and improving best practices.
The slow-controlled setting operation enables the slips or other anchoring mechanisms in the device to be set and to fully engage the casing/tubing and elastomer sealing elements to conform to the casing or tubing ID, which is extremely critical in highly-deviated well conditions and when casing or tubing with high-rockwell hardness is used. Unlike setting devices that use explosives, military or governmental escorts are not required. Single-lift, heli-operations can be used. Radio silence operations are not required, and there is no non-productive time associated with tool re-dressing between runs. Tool sizes are available for well intervention from 2–3/8–in. tubing through all casing sizes and can be tractor conveyed in high-angle or horizontal wells.
Analysis and Performance Measurement of Axial Vortex Separator (SVA) for Liquids/Gas Mixture
Authors: Castellanos J.. , Quijada V.. , Kenyery F.. 
Published: September 2011

Abstract
Nowadays, the efficient separation of multiphase mixtures has a great importance in offshore installations where space is limited. In this case, the use of Compact Cyclonic Separators (CCS) has gained popularity because it is simple, compact, and economical to manufacture and operate. Its operation field is established on the basis of superficial velocities of liquid and gas within the separator, being limited by the occurrence of two phenomena: the Liquid Carry-Over (LCO) and the Gas Carry-Under (GCU) in the discharge pipes of gas and liquid respectively. Taking into account this two main phenomena, in the present experimental study was determined the operation field and performance of an Axial Vortex Separator (SVA) of 3’’ in diameter for a water-air mixture flow. SVA is composed by two vertical concentric tubes. The inner tube has a stator to generate a vortex centrifugal force which combined together with the buoyancy and gravity forces can separate the phases. SVA behavior was studied for different relative positions of the concentric tubes and two different angles from the stator blades. The experimental results were used to analyze the accuracy of mechanistic models available in literature for prediction of LCO and the flow patterns presented in the SVA. A good agreement was accomplished. Additionally, the operational envelope of SVA with 0% and 1% of LCO was determined. The SVA minimum separation efficiency in the experimental tests carried out was 99%.
Partially Separated Meta-Models with Evolution Strategies for Well Placement Optimization
Authors: Bouzarkouna Z. , Ding D.Y. , Auger A. 
Published: September 2011

Abstract
Finding the optimal location of non-conventional wells increases significantly the project’s Net Present Value (NPV). This problem is nowadays one of the most challenging problems in oil and gas fields development. When dealing with complex reservoir geology and high reservoir heterogeneities, stochastic optimization methods are the most suitable approaches for optimal well placement. However, these methods require in general a considerable computational effort (in terms of number of reservoir simulations, which are CPU time demanding).
This paper presents the use of the CMA-ES (Covariance Matrix Adaptation – Evolution Strategy) optimizer, which is recognized as one of the most powerful derivative free optimizers, to optimize well locations and trajectories. A local regression based meta-model is incorporated into the optimization process in order to reduce the computational cost. The objective function (e.g., the NPV) can usually be split into local components referring to each of the wells: it depends in general on a smaller number of principal parameters, and thus can be modeled as a partially separable function. In this paper, we propose to exploit the partial separability of the objective function into CMA-ES coupled with meta-models, by building partially separated meta-models. Thus, different meta-models are built for each well or set of wells, which results in a more accurate modeling.
An example is presented. Results show that taking advantage of the partial separability of the objective function leads to a significant decrease in the number of reservoir simulations needed to find the "optimal" well configuration, given a restricted budget of reservoir simulations. This approach is practical and promising when dealing with a large number of wells to be located.
Laterals Stimulation Method
Authors: Freyer R.. , Shaoul J. R. 
Published: September 2011

Abstract
Due to reduced availability of high quality reservoirs, more wells require stimulation. The current default method for stimulation is hydraulic fracturing, using either proppant or acid to keep the fracture open. In many environments, Proppant or Acid Fracturing is a good solution to increase productivity. Some of the unresolved challenges with fracture stimulation are reservoir related such as the uncertainty about whether the fracture will grow through different reservoir layers, potentially contacting unwanted water. Operational challenges are environmental, cost, operational complexity and availability of equipment and competent personnel. Onshore fracturing experience can build on the learning of hundreds of wells to optimize the fracture stimulation process, but this is not possible in an offshore environment.
A new completion based stimulation solution is developed to be simple and efficient without environmental impact and with significantly lower cost than current solutions. Several reservoirs have been simulated to investigate the long term production and recovery using the method. The relatively new well geometries require further understanding to apply the technology. A study on offshore well cost has been made.
Matrix Stimulation in the Candidate Wells Indicate Unexpected Performance Improvement in a Dolomitic Carbonate Reservoir
Authors: Hashemi A.. , Sajjadian S.. , Sajjadian V. A. , Karimi S.. 
Published: September 2011

Abstract
Field studied is one of the ramp types of carbonate reservoirs. The reservoir under studied consists of three layers which have been affected by Karstification. The flow test has been implemented after the perforation operation. The results have shown that the designed plateau can not be met i.e. the current field production by considering maximum efficient rate cannot manage the target production. By analyzing the Pressure Test Analysis some wells have been chosen as underperforming wells.
Matrix stimulation is one of the conventional methods to increase the productivity index of the formations. The expected production plateau in this dolomitic carbonate oil field in the south west of Iran is met by Matrix Stimulation. Based on the theoretical improvement of the Pressure Test Analysis (PTA), past experience in the field and reservoir sedimentology, the candidate wells are selected. The matrix stimulation technique is determined to theoretically reduce the skin factor to -2 or -3 as mentioned in the literatures. After well ranking, the stimulation campaign is practiced.
Field experience indicates unexpected production improvement due to heterogeneous dolomitic nature of the reservoir. A comprehensive study is conducted to find out the reasons of this 3 to 4-fold production improvement i.e. the log, core and drilling mud is compared and reservoir model is investigated. Moreover the welltest data before and after the stimulation are investigated. Before stimulation in build up data geochoke phenomena is detected while after stimulation is vanished. One well is penetrated to most heterogeneous section of the reservoir model and geochoke phenomena are simulated. Therefore the idea of removing geochoke phenomena around the wellbore is raised.
Novel High Speed Telemetry System with Measurements Along the String Mitigate Drilling Risk and Improve Drilling Efficiency
Authors: Veeningen D.. 
Published: September 2011

Abstract
Novel systems such as the wired-pipe or networked drillstring telemetry system have allowed broadband communication with downhole tools in various operating areas around the world, including in deepwater. Two capabilities are vital to offer operators and service companies with cost effective drilling and completion in challenging scenarios:
High speed: real-time, bi-directional data transfer at a rate of 57,600 bits per second (bps) enables downhole and subsurface conditions to be measured and controlled, Measurements all along the string: annular pressure and temperature measurements distributed at network nodes beyond just at the drill bit enable early warning of developing trouble events.
This paper describes cases where the broadband network provided downhole information for identifying poor hole cleaning, determining sweep efficiency, revealing cutting accumulation and recognizing pack offs early on.
Further, examples are described that improved drilling risk mitigation by the capability to measure as many as 45 different drilling dynamics parameters that are updated every few seconds revealing bit whirl, stick slip, lateral and axial movement while drilling trouble zones.
The successful mitigation of downhole vibration resulted in a 68% increase in time on bottom and a 58% increase in rate of penetration (ROP). Annular pressure evaluation all along the drillstring ensured adequate hole cleaning in challenging wellbores.
Effect of Initial Gas Saturation on Steam Assisted Gravity Drainage Process
Authors: P. Oskouei S. Javad , Maini B. , Moore R. G. , Mehta S. A. , Yazdani Ali 
Published: September 2011

Abstract
Cold Heavy Oil Production with Sand, CHOPS, is a primary recovery method commonly used in many Canadian heavy oil reservoirs. In spite of its commercial success, the oil recovery factors achievable with this process range between 5 to 20 percent. In order to recover more oil from primarily depleted reservoirs, Steam Assisted Gravity Drainage (SAGD) process can be considered. However, the performance of SAGD process is likely to be negatively affected by the initial gas saturation present in such depleted reservoirs. Unfortunately, no systematic study of the effect of initial gas saturation on SAGD performance has been reported.
This paper presents an experimental evaluation of the effect of initial gas saturation on SAGD performance using physical models. Different gas saturation levels were established in the model by modifying the model packing and saturating techniques. High pressure physical model experiments were carried out by injecting steam at controlled rate and producing the oil from the production well at constant pressure. The oil production behavior was analyzed to evaluate the effect of initial gas saturation on thermal efficiency of the process. Based on the results, it is possible to conclude that initial gas saturation of about 9 percent, or higher, accelerated heat dissipation and retarded the formation and growth of the steam chamber. Due to the higher relative permeability of steam in the gas saturated zone, it becomes difficult to confine the steam in a chamber as seen in the conventional SAGD. The temperature in the steam zone was noticeably below the steam saturation temperature and the oil production rate was substantially lower compared to similar test without the gas saturation. The results strongly suggest that SAGD would not be a viable option in Heavy oil reservoirs containing high free gas saturations.