bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Probabilistic Approach for Drilling Cost Engineering and Management Case Study: Hassi-Messaoud Oil Field
Authors: Saibi Mohamed 
Published: December 2007

Abstract
One of the major challenges facing drilling operations engineering and management today is the prevention of costs and schedule overruns. The nature of drilling operations with the diversity of parties involved in the different tasks from well conception up to the completion, the more and more sophisticated technology used, the pressure of time, the increasing regulatory of safety and environment requirements, the inflating costs in addition to the big uncertainty of this activity make difficult meeting the financial and timing targets set for the premeditated financial resource allocation.
The first objective of this paper is to provide the drilling manager with an efficient cost management and control tool that facilitates the management of the expenditures, and enables to take informed decision and corrective actions on the right time, by providing better understanding and awareness of the actual exposure to the cost overrun risks.
Cost control techniques can be adapted to the well construction process by using the information gathered from the offset wells to mitigate the effect of the uncertainty of nature. Many studies have been made on this issue; they can be classified into deterministic and probabilistic approaches. For the latest, little work has been carried out and it is still not widely and comprehensively used in practice in spite of its powerfulness.
The methodology used in this study consists, firstly, of analyzing data from offset wells to simulate and reproduce real life scenarios of possible cost outcomes based on Monte Carlo simulation combined with risk analysis to be applied in the planning phase of new wells, and secondly, of applying a real time control and continuous improvement processes in the execution phase. This paper illustrates the case study of Hassi-Messaoud oilfield in Algeria. This type of model facilitates the management tasks and save time and efforts, particularly when dealing with intensive drilling operations in major fields.
Accurate Real-Time Resistivity Interpretation in Vertical and Deviated Wells
Authors: Frenkel Michael A. 
Published: December 2007

Abstract
Real-time array resistivity data interpretation is normally performed by means of point-by-point 1D inversion. Such an approach is error-prone and causes productive zones to be overlooked. In this paper, we propose a real-time 2D and 3D interpretation process for array resistivity logs. This interpretation process is able to run in real-time by relying on a set of precalculated look up tables of tool responses and a hands-off interpretation procedure. We test the method on a benchmark model and a case study. Synthetic and field examples demonstrate the capability of the technology to deliver in real-time high quality results that are now achievable only with the interpretation capabilities of a log analysis center.
An Organosoluble Polymer for Outstanding Fluid Loss Control With Minimum Formation Damage
Authors: Guichard Bertrand , Valenti Andrea , Friedheim James , Lee John 
Published: December 2007

Abstract
Complex well configurations with long openhole sections are often left unprotected for a long time under various conditions. Oil-based and synthetic-based drilling fluids are very well suited for drilling these long sections down to reservoir formations, providing high rates of penetration, excellent lubrication properties, and wellbore stability. The enhancement in wellbore stability and lubricity as well as reduction in differential sticking, mud losses, and formation damage can be directly influenced by fluid-loss control and filtercake properties. As an example, formation damage is largely caused by solid invasion occurring during the first step of filtration, perhaps adversely affecting the porous media permeability/stability, and consequently, reservoir productivity. Both good fluid-loss control and minimum formation damage are required for drilling and completion fluids.
A synthetic polymer, based on a unique microgel structure, has been designed to provide excellent fluid-loss control and low formation damage in OBM/SBM. Optimization of polymer morphology and fluid solubility gives a very versatile and cost-effective fluid-loss additive.
The unique microgel structure allows the polymer particles to swell and stack up, forming a thin and efficient filter cake. The ability of the microgel particles to deform under shear stress allows them to be back-produced from the formation more effectively than non-deformable additives, thus reducing risks of formation damage in the pay zone. The polymer also may contribute to the rheology of the mud by providing low shear viscosity under demanding conditions.
This paper reviews the effectiveness of the organosoluble polymer by presenting evidence of low formation damage illustrated by good return permeability data from both field and laboratory applications. Finally, data will be presented on new developments based on similar chemistry, allowing applications into more extreme conditions of temperature.
Gauge, Cutting Structure, Torque Control Components—What Really Counts for Optimal Tool Face Control With FC Drill Bits?
Authors: Barton Steve , May Henry , Johnson Simon 
Published: December 2007

Abstract
Toolface Control is widely regarded as one of the greatest challenges when drilling directionally with a FC (Fixed Cutter) drill bit on a Positive Displacement Motor (PDM).
Toolface offset is proportional to the torque generated by the bit. FC bits, by nature, generate high levels of torque. If an external force acting on the bit causes a FC bit to over-engage, a large change in downhole torque is typically produced, which causes rotation of the drill string, and loss of toolface orientation. It is therefore desirable for a FC bit to produce a torque response that does not vary greatly with changes in the external forces applied.
This paper examines the effect of varied components of a FC drill bit to determine the key design requirements to deliver a smooth torque response and improved directional performance. This includes evaluation of the results from a comprehensive series of laboratory tests to determine the effectiveness of a number of varied, removable Torque Controlling Components (TCC). The goal was to establish a configuration that would provide predictable torque response to applied weight on bit, allowing cutting structures to be independently optimized for overall higher penetration rates.
A novel gauge geometry was engineered to reduce drag and deliver a smoother borehole. This would provide less torque when sliding and beneficial gauge pad interaction with the borehole when in rotating mode.
Field performance studies clearly demonstrate that matching TCC, an optimized cutting structure, and gauge geometry to a steerable assembly delivers smooth torque response and improved directional control. Benefits within rotary vertical applications are also demonstrated. Successful application has resulted in significant time and cost savings.
New Approach To Ensure Long-Term Zonal Isolation for Land Gas Wells Using Monobore Cemented Completion
Authors: Taoutaou Salim , Schreuder Ron , Bosma Martin , Schoenmakers Jules , Van der Vegt Rob , Stewart Dave 
Published: December 2007

AbstractCemented completion provides an excellent opportunity for low cost drilling techniques and simple well designs to reduce well delivery costs without impact on safety or well integrity. In this concept, the completion is run straight into the open hole and cemented in place.There is no need to run a liner and perform a traditional cleanup. The cement effectively replaces the production packer. Achieving a good cement job is essential to a successful operation. A failed cement job would require cutting and pulling of the completion before running a conventional completion and packer, unless there was a high confidence in the outcome of a remedial cement job. Therefore good conditions for cementing are a definite requirement.Gas production and gas storage wells are particularly demanding on the cement sheaths. A failure of the sheath through de-bonding, cracking or plastic deformation results in formation fluids to enter the annulus, which pressurises the well and makes it unsafe to operate, the consequences are either losing the well altogether or, at best, an expensive intervention.Advanced cement technology combined with state of the art software are used today to ensure a complete long-term zonal isolation of the cemented completion.The software can model the stresses in a particular well over its entire life, including changes to the formation properties, well completion parameters, formation in-situ stresses, and operating envelope and can compare the properties of different available cements to enable the optimum cement to be selected (hole size, cement sheath thickness).The following paper will describe the process and the engineered cement used to ensure integrity of the cemented completion and lists case histories of the 3 cemented Completions successfully cemented Onshore Netherlands.
Real-Time Simulation in Grid Environments: Communicating Data from Sensors to Scientific Simulations
Authors: Richard G. Duff , Yaakoub Y. El-Khamra 
Published: December 2007

Abstract
Across many fields of science and engineering computers now play a significant role in scientific discovery through both large scale simulation and real time data acquisition. As these scientific simulations increasingly require new levels of complexity and fidelity, and leveraging increasing computational capabilities, scientists are migrating their applications back and forth from workstations to supercomputers, high performance clusters, and new distributed grids of computers. For applications which depend on live real world data, the migration to varied and distributed resources provides additional challenges. This migration involves reassigning and testing individual sensor communications and data path integrity for the application before the application is ready for a real time operating environment.
This paper presents one general approach for communicating live real world data to simulations deployed on high-end computational resources. The architecture and design are presented for generic applications, before focusing on a particular scenario for drilling dynamics optimizations. In this scenario, simulations of drilling behavior depend on real time data from on-site (remote) sensors. Sensor data is streamed through to a simulation framework. The framework (available on a desktop computer or a supercomputer) displays relevant information, starts simulations with real time inputs then presents results and recommendations. For our application, we will use the Cactus Code (www.cactuscode.org) open-source high performance scientific computing framework as the simulation framework, and LabVIEW (www.ni.com/LabVIEW) as the data acquisition software. The advances in architecture portability allowed by the framework are summarized, and experiences of system uses are presented. Discussion will include opportunities found and learnings from using this platform in various environments highlighting drilling optimization.
A System for Continuous Reservoir-Simulation-Model Updating and Forecasting
Authors: Holmes J. C. , McVay D. A. , Senel O. 
Published: December 2007

Abstract
A significant body of work has demonstrated both the promise and difficulty of quantifying uncertainty in reservoir simulation forecasts. It is generally accepted that complete and reliable quantification of uncertainty should lead to better decision making and greater profitability. Many of the techniques presented in previous work attempt to quantify uncertainty without sampling the full parameter space, saving on the number of simulation runs, but inherently biasing and underestimating the uncertainty in the resulting forecasts. In addition, much of previous work has looked at uncertainty quantification in synthetic models and does not address the practical issues of quantifying uncertainty in an actual field. Both of these issues must be addressed in order to reliably quantify uncertainty in practice.
In this study a new approach to reservoir simulation is proposed whereby the traditional one-time simulation study is replaced with a continuous process potentially spanning the life of the reservoir. In this process, reservoir models are generated and run 24 hours a day, seven days a week, allowing many more runs than previously possible and yielding a more thorough exploration of possible reservoir descriptions. In turn, more runs enables better estimates of uncertainty in resulting forecasts. This is combined with real-time acquisition of production and pressure data, which is automatically integrated into simulation runs to allow the process to run continuously with little human interaction.
Two tests of this continuous simulation process were conducted. The first test was conducted on the Production with Uncertainty Quantification (PUNQ) synthetic reservoir. Comparison of our results with previous studies shows that the continuous approach gives consistent and reasonable estimates of uncertainty. The second test was conducted in real time on a live field. This test demonstrates the continuous simulation process and shows that it is feasible and practical for real world applications.
Gravel Packing Horizontal Wells in Reservoir Oil Flow Equalization Projects
Authors: de Magalh!es J. V. M. , de Oliveira T. J. L. , Fernandes P. D. , da Silva M. G. F. , Martins A. L. 
Published: December 2007

Abstract
Recent studies show that the flow along a horizontal well is not uniform or symmetrically distributed, as a larger volume of fluid enters the well near the heel. Flow equalization in horizontal wells is a state of the art strategy for assuring effective reservoir drainage and delaying the arrival of water breakthroughs. The idea is to provide a variable distribution of area open to flow along the horizontal section. The technique is applicable for several situations and is even more attractive in long horizontal section wells in heavy oil fields where friction losses in the well bore play an important role.
The concept of flow equalization has been successfully applied in onshore (slotted liners) and offshore (carbonate reservoirs) applications in Brazil. The next and most challenging step is to place gravel packs in wells where premium screens with non-uniform perforation distributions were made in the base pipe. The main issue is the excessive friction losses generated by the restricted cross flow near the heel of the well when the gravel is placed, which may generate pressures that overcome the usually low frac pressures in deepwater environments.
This article presents a case study for screen and gravel packing design for a typical deepwater application. Different screen base pipe perforation profiles are suggested and the gravel packing placement pressure was simulated. The strategy for optimizing flow equalization profiles with gravel packing pressures inside the operational window is defined by using an in house mechanistic model developed for OHGP operations.
The model was modified for this specific application, considering flow divergence during gravel placement and friction losses throughout the perforations. Results indicate that it is feasible to gravel packing screens in such scenarios and achieve attractive flow equalization results. It is important to highlight that this approach will make possible to promote an effective sand exclusion and to improve the reservoir drainage at the same time,.
Numerical Simulation of the Radial Viscoelastic flow of a Solids Free Drill in Fluid
Authors: Martins A. L. , Waldmann A. T. A. , Ribeiro D. C. , Massarani G. 
Published: December 2007

Abstract
Designing drill in fluids which can guarantee minimum invasion into the reservoir rock is a must for open hole completion wells. The industry has proposed several ideas to deal with the problem, most of them based on adding bridging agents to the fluid formulation. Such agents would block the pores near the well bore and, consequently, prevent additional fluid invasion into the rock, but often require acid treatment for their removal.
A different concept is proposed for controlling invasion in this article: designing a polymer based fluid which would generate extremely high friction losses when flowing through a porous media without generating extra losses while flowing in the well. In this case the fluid would present proper flow and solids transport properties in the well and would not invade the rock formation.
Previous studies by the authors showed that the viscoelastic behavior of fluids can be a major restriction to fluid invasion. This article deals with the optimization of viscoelastic parameters, such as the first normal stress difference and the extensional viscosity, for minimizing fluid invasion through oil reservoirs. The invasion analysis is based on a two phase (viscoelastic fluid + Newtonian oil) radial flow through porous media and supported by a commercial CFD package. Static and dynamic filtration phenomena are represented.
The arrival of this rheology controlled invasion concept brings to the polymer manufacturers a new challenge: the development of a highly viscoelastic polymer with non damaging behavior and adequate wellbore properties.
Investigation of a Single-Stage Sandstone Acidizing Fluid for High-Temperature Formations
Authors: Nasr-El-Din H. A. , Al-Anazi M. , Al-Zahrani A. , Samuel Mathew , Kelkar S. K. 
Published: December 2007

AbstractSandstone acidizing is very challenging because of the complex reactions that occur between the multiple-stage treatment fluids and the formation minerals. Such reactions are more likely to occur at elevated temperatures and can result in potentially damaging precipitation reactions. In conventional acid treatments, fluid is usually pumped in multiple stages of pre-flush, main fluid and over flush. The drawback of conventional sandstone acidizing treatments is that the success rate is generally low due to the uncertainty associated with the fluid-formation interactions.This paper presents the results of a laboratory investigation of a single-stage sandstone acidizing fluid designed to address some of the problems associated with conventional sandstone acidizing fluids. The application of the fluid system is sandstone reservoirs with bottom hole static temperatures greater than 200°F.Core flow tests demonstrated that the single acid system minimized the potential for precipitation due to secondary and tertiary reactions. This system did not cause sand deconsolidation, and maintained the integrity of sandstone cores. Corrosion tests conducted for low-carbon steel and 13 Cr coupons demonstrated that the fluid had lower corrosion rates.
Advances in Coiled Tubing Re-entry Access Bypassed Reserves on Alaska's North Slope
Authors: Madarapu R. , Lasley B. M. , Corson C. S. , Hinze I. , Carey S. 
Published: December 2007

Abstract
Technology improvements continue to advance the capabilities of coiled tubing directional drilling (CTDD). Alaska's North Slope, with its prevailing dedication to expanding the technological envelope, has served as a testing ground where advanced CTDD techniques mature into economically viable systems.
Even after over 500 successful CTDD sidetracks on the North Slope, impetus remains to further improve this economical drilling technique. Through a close working relationship between field operator and the service company, significant research and development has led to the introduction of novel tools and services to overcome the intrinsic hurdles of conventional CTDD.
Through a process of miniaturization and innovation, small-diameter systems have been developed for CTDD. The most recent introduction of tools and services includes rib steering technologies, bidirectional wireless mud pulse telemetry, gyro-based MWD services, and ultra-slim, high-resolution, real-time resistivity.
Straighter, longer horizontal laterals, improved steering, and real-time resistivity in openhole sizes as small as 2 3/4-in. ID has been achieved, consequently improving precision in geosteering within the narrowest of payzone.
This paper highlights two case histories describing CTDD technology, real-time formation evaluation, and multilateral drilling processes used to access previously unreachable oil-bearing rock on Alaska's North Slope. While proven in this region, CTDD advances are applicable in other mature fields for the economical extraction of additional reserves.
Technology and Capability requirements for Well-Centric Production Optimization
Authors: Lee Jaedong , Vachon Guy 
Published: December 2007

Abstract
One of the main challenges in the oil industry is to optimize production while reducing the development cost and maximizing reserves. Real-time optimization has been gaining ground to effectively face the challenge, and it has been applied in the Smart field or Digital field technology. Literature references two optimization loops, the reservoir-centric slow loop and the well-centric fast loop. Intelligent wells are focused on the fast loop and combine well-centric technologies with monitoring, data analysis, modeling, interpretation and automation to accelerate production, maximize recovery and reduce operating and capital expenditure cost. Their benefits include increased ultimate recovery, accelerated production and cost reduction. Intelligent well equipments can include intelligent completion system, artificial lift system, and automated chemical injection system.
Information regarding the optimal intelligent equipment configuration for a well at various points in its life requires the convergence of multiple talents pools. It is discovered in the well design process but it is unreasonable to expect all the relevant talent to be available during actual well operations. As a result, the well may not optimize production or add the value that was expected unless the knowledge is captured and used to assist making optimization decisions in real time. This knowledge is the linked to improved use of the data that is recorded and transmitted by downhole and surface sensors. Instead of closing the loop by human intervention, an intelligent optimization system will link stored knowledge to measurements. This will change the optimization activities from polling to interrupt-driven, and will advise when wells deviate from their expected behavior in ways that prompt diagnosis of problems early enough to avoid them.
This paper presents the technologies and capabilities come together to achieve intelligent optimization system.