bluuebunny/crossref_metadata_2025_split huggingface dataset:
Optimized Stimulation Solutions for a Mature Field in Kazakhstan
Authors: Utegalyev S. A. , Duzbayev S. K. , Kulbatyrov K. , Nadezhdin S. V. 
Published: December 2007

Abstract
Well stimulation techniques like hydraulic fracturing, which can involve large financial investments, call for a basin- or reservoir-specific approach to maximize production. Integrated solutions use a performance-based process that integrates petrophysical and reservoir characterization expertise with production and completion knowledge by developing and refining more complete interpretation and completion models based on comprehensive data. This process includes the current service standard of design, execution, and evaluation, but goes far beyond basic well stimulation, which has historically used limited data. Another important feature of the integrated solutions is a proper risk assessment based on available data. Often, especially in old fields, information is out of date, limited, or unavailable. Combining together available pieces of information through the structured process helps put together the "big picture," which subsequently provides the support for engineering decisions.
Case histories discussed in this paper illustrate how distributed teams of experts use improved models to develop solutions for old wells and future development that focuses on ultimate productivity throughout well or reservoir productive life, regardless of boundaries between various technical disciplines. Cases of application for fracturing in Nurzhanov field, Kazakhstan, are discussed.
Selection and Execution Criteria for Water-Control Treatments
Authors: Daneshy A. A. 
Published: December 2007

Abstract.
By and large, the oil and gas industry is not happy with the success rate of treatments performed for control of excessive water produced with oil and gas. As a result, aside from treatments to stop early water break-through caused by poor quality completions, the industry views the costs of excessive water production as more acceptable than the risk of losing or reducing oil and gas production. Part of the problem is lack of clarity as to where and when water flow can and should be controlled, and the treatment selections and design considerations that can lead to successful execution.
Paper divides the produced water into two separate categories, segregated and commingled. Commingled water is often best left alone and accepted as an unavoidable part of oil and gas production. The exception is when the oil content of part of the flow stream is very low compared with the companion water. Segregated water flow can be treated and controlled with several different types of treatment. The paper discusses these and offers choices based on reservoir conditions.
Another important factor contributing to success and failure of water control treatments is the placement conditions. The paper shows that most of these are done at rates high enough to fracture the formation and this situation substantially reduces the treatment effectiveness.
Real-Time Cementing Designs vs. Actual Jobs in Progress
Authors: Creel P. , McKenzie D. , Briney M. , Pipes H. 
Published: December 2007

Abstract
The cementing design process has been improved by using current technology to predict actual downhole conditions, allowing both the service provider and the well operator to manage fluid positions, critical circulating pressures and surface parameters while cementing casings in wells under stringent conditions.
This paper explains how design data and real-time simulation of cementing jobs can be used to make detailed predictions of many well parameters and provide information allowing adjustments to be made during the cementing operation to alter the outcome or help improve the performance of the job. These tools can allow the operator and service provider to (1) more accurately predict cement tops, (2) change casing programs, (3) control flow-back rates and pressures, (4) monitor equivalent circulating density (ECD) on specific zones, or (5) enable personnel to create a better design for other wells in the field.
The development of computer simulations to model surface and downhole conditions has been used for more than 26 years to improve and facilitate cementing operations under different and variable scenarios. By using this engineering computer program, many cementing failures can be prevented not only before the actual cementing operation is performed, but during the operation itself. Maintaining control and predicting problems is possible by taking into account all the monitored and calculated variables on a real-time mode and comparing the outputted prediction output with the pre-job design and the actual job in progress.
Demonstrated by examples and case studies, the simulation process performs many steps needed to give precision to predictions in placement calculations. The computational process gathers information, and with multiple logical sequences, provides the most suitable solution for the scenario being studied. Multiple design program runs may be completed without jeopardizing the integrity of the well. While designing a plan, several parameters can be changed to predict the job performance or end results. Modifications or changes in various operational events for performance predictions may be used in making recommendations. Recommendations may be altered by changing such components as cementing materials, placement methods and even casing configurations to help ensure a better performance based on pre-job investigations.
New Analysis of Step-Rate Injection Tests for Improved Fracture Stimulation Design
Authors: Lizak K. F. , Bartko K. M. , Self J. F. , Izquierdo G. A. , Al-Mumen M. 
Published: December 2007

Abstract
Prehydraulic fracture diagnostic pumping analysis has recently improved with the use of new analysis techniques such as G-Function derivative plots, after-closure analysis, and step-rate tests. This paper analyzes various types and combinations of step-rate injection tests from many different formations around the world to determine the usefulness of these tests. The analysis uses wells with both surface and bottomhole gauge data, and in some instances, compares the results of the two. The final results of the stimulation treatments are also compared to the prefrac analysis. While the results of these tests provide information on the presence of excess near-wellbore friction or tortuosity, what is often not taken into account is that this tortuosity often destroys the usefulness of these step-rate tests in providing much sought-after data such as accurate fluid efficiency and closure pressure numbers.
The focus of this paper will be on step-up and step-down analysis, with the result being a new type of graph that provides an indepth look at the quality of these tests in any given well. Often these tests are performed and erroneously analyzed because of the effects of tortuosity, with the end result being either the data is ignored or discarded. Techniques are provided for analyzing these tests and suggestions are given to improve the results obtained from these tests.
Lessons Learned From Combined Whipstock Operation: Set Whipstock/Mill Out/Cement Squeeze/Drill Out in One Trip
Authors: Williamson R. N. , Eaton L. F. , Harrell D. , Courville D. , Long J. 
Published: December 2007

Abstract
ConocoPhillips pre-drilled wells for the Magnolia tension leg platform (TLP) development in 2003 using a dynamically positioned semi-submersible drilling vessel1. The Magnolia field is located in 4,674 ft of water at Garden Banks (GB) block 783 in the Gulf of Mexico. During the pre-drilling phase, two wells were successfully sidetracked out of 13.625 in. casing in one trip using an extended gage, one trip whipstock system.
The first whipstock operation was through cemented pipe and the second was through uncemented pipe, which had communication to a shallower, weak formation. This paper focuses on whipstock operations through uncemented pipe and describes the planning and execution of the first successful attempt at setting a whipstock, milling the window, squeeze cementing the window, and drilling out cement and rathole – all on one trip while using synthetic base mud (SBM).
Due to the high spread rate cost of deepwater drilling, every effort is made to reduce critical path time while managing risk and safety. Typical whipstock operations through uncemented casing can require three or more round trips to prepare a window for drilling ahead. On the GB 783 A-4 BP1 well, window milling/cementing operations through uncemented casing were conducted in a single trip. The whipstock was oriented and set at 11,080 ft measured depth (MD) in a 54° angle hole. The window was milled, the assembly pulled above the window, and the openhole squeeze cemented. After waiting on cement to set, the cement was drilled out and a successful formation test achieved. An additional 130 ft of rathole was then drilled with the mills to place the stabilizers on the next drilling assembly below the whipstock. Operations from the start of running the whipstock until the mills were laid down took 2.6 days. A total of 1,861 lbm of metal shavings was safely recovered.
This paper highlights 1) whipstock installation and window cutting operations, 2) safety and operational best practices for removing, handling, and monitoring metal cuttings that, if not removed from the hole, can be problematic for subsea blowout preventer (BOP) systems, 3) equipment modification made to mitigate risk for cementing through a milling assembly, and 4) design considerations for achieving a successful squeeze.
Applying Radial Acoustic Amplitude Signals To Predict Intervals of Sand-Stuck Tubing
Authors: Siems G. , Boudreaux S. 
Published: December 2007

Abstract
The reuse of existing well bores is one cost saving technique employed by oil and gas producers in mature fields. This process usually requires the removal of tubing and packers to allow the well to be deepened or side-tracked. The tubing removal process is often made difficult due to its being stuck inside casing due to mechanical binding, or binding caused by dehydrated mud or sand in the annulus between the tubing and casing. Conventional direct and indirect methods of finding the stuck point(s) along an interval of tubing, such as Free Point Indicator Tools or Acoustic Attenuation measurements, have proven themselves useful in finding the point(s) where the tubing is stuck. However, when the sticking is due to uncompacted sand that has entered the annular space between the tubing and casing, these conventional stuck pipe indication methods are often inconclusive.
Technological advancements in the design and development of slim, 1-11/16 in. OD, radial cement bond tools allow the application of a new measurement to find sand-stuck tubing intervals. These tools provide up to six independent, short-spaced, acoustic attenuation measurements distributed radially around the tool body. When recorded inside tubing, their increased sensitivity to sound attenuation, as compared to conventional omni-directional amplitude signals, allows sand intervals along the outside of the tubing to be distinguished from intervals where little or no sand is present. This information is used to select the best depth to sever or back-off the free tubing in order to reduce the interval length and expense associated with the washover process required to remove the remaining tubing from the wellbore.
An overview of conventional stuck pipe recovery techniques is discussed along with a brief explanation of applied acoustic technology. A case example of a South Louisiana well is presented to demonstrate the application and illustrate the cost savings gained by use of this newest technology.
The Impact of Nonuniform Formation Damage on Long-Term Well Performance
Authors: Yildiz T. 
Published: December 2007

Abstract
Formation damage along well axis may be distributed unevenly. Especially in horizontal wells, the damage around the wellbore is highly non-uniform. The literature hosts many studies focusing on the effect of non-uniform skin distribution on the transient pressure behavior of horizontal wells. There are few studies concentrating on how the uneven distribution of the skin factor affects well productivity. Furui et al. and Frick and Economides presented simple models accounting for the non-uniform formation damage around horizontal wells.
In this study, we compare the simple heterogeneous skin distribution models against the results from a 3D multisegment model. We show that the non-uniform skin models proposed by Furui et al. and Frick and Economides for horizontal wells are incorrect although the methods are simple and easy to use. Additionally, we demonstrate that the horizontal well skin formulation suggested by Malekzadeh and Tiab is inaccurate.
Tuberculosis Control—A New Approach
Authors: Moreau J. -M. , Lawhorne L. 
Published: December 2007

Abstract
Although the incidence of TB is receding in western countries, several factors such as resistance to antibiotics and HIV epidemic have worsened the situation in many low-income countries. Meanwhile, the globalization process has increased the frequency of travel and contacts between individuals from low and high incidence areas, therefore increasing the exposure of non-infected individuals. This is especially true for some of the oil and gas operations e.g. offshore, where the layout of the living quarters is propitious for TB transmission. Although rare, any active case of TB occurring offshore has the potential for a high impact on operations. Recently in spite of a comprehensive screening program in place for high incidence country national employees, an active case occurred on a platform in the Gulf of Mexico. That case triggered a search for a better screening tool to ensure that no detectable active TB cases enter the work place. This paper will describe our findings.
Risk-Based Reliability Engineering Enables Improved Rotary-Steerable-System Performance and Defines New Industry Performance Metrics
Authors: Wand P. , Bible M. , Silvester I. 
Published: December 2007

Abstract
Rotary Steerable directional drilling and logging assemblies deliver significant value to operators through improved drilling efficiency, precise well placement and effective formation evaluation.
System failure is associated with a high cost and a high pain factor. Non-productive time (NPT) is used to re-run the failed bottom-hole-assembly (BHA); hole section objectives may be compromised and there is even the potential for loss of hole section, requiring a re-drill.
This paper describes a risk-based approach to quantify and improve the reliability and performance of directional drilling bottom hole assemblies.
Extensive field data gathered while drilling fifteen million feet of hole between 2003 to 2005 has been used to drive a reliability centered design and maintenance program with the objective of improving drilling performance, improving system reliability, increasing average rates of penetration and reducing NPT.
All aspects of service delivery are considered, including mechanical and electrical system component performance, repair and maintenance procedures, job design and field operating practice.
The approach has yielded measurable improvements in rotary steerable and logging while drilling bottom hole assembly reliability and performance.
Industry metrics such as mean time between failure (MTBF), feet drilled per circulating hour (FPCH), feet drilled between failure (FBF), failure free runs and operating efficiency (ratio of NPT to operating time) are considered, benchmarking current performance and setting performance expectations for existing and future downhole systems.
The industry has a need to standardize the method of evaluating downhole drilling system performance and to understand and quantify the benefits and risks associated with the application of a specific downhole system in a given downhole environment.
This paper proposes such a standard approach, using novel BHA performance measures and an assessment of BHA complexity and well difficulty.
Field-Proven Technology To Manage Dynamic Barite Sag
Authors: Dye W. , Mullen G. , Gusler W. 
Published: December 2007

Abstract
Barite sag is a well recognized, but poorly understood phenomenon in the drilling industry. Industry experts have offered a variety of measuring parameters, based upon empirical data that only partially correlate with the occurrence of barite sag. The development and introduction of robust, standardized well-site techniques to predict the onset of barite sag in dynamic flow has evaded the industry. The effect of shear rate and viscosity on dynamic barite sag has been studied and quantified using new and advanced technology. Changes in the potential for dynamic barite sag as a function of shear rate, hole angle, annular velocity and eccentricity correlate with ultra-low shear rate viscosity.
Field-proven technology has been developed to predict the potential for barite sag and to provide remedial measures through ultra-low shear rate viscosity modification. This technology was originally developed and validated in the field with invert-emulsion drilling fluids. Subsequent verification and validation work showed the technology was equally valid for water-based drilling fluids. This innovative technology is well-suited for use with a variety of commercially-available field viscometers and therefore lends itself towards widespread industry use. The paper will discuss the theoretical basis for this barite sag management technology and present the viscosity levels, with corresponding shear rates, required to manage dynamic barite sag. A case is made for use of this technology as an industry standard for barite sag management and is accompanied by full disclosure of the technology for peer review. Lastly, case histories are presented demonstrating the suitability of this technology in the field and ease-of-use at the well-site.
Malaria Visa: A Globally Accessible Malaria Training and Travel Preparedness Certification Process
Authors: Dockins R. O. , Moreau J. M. 
Published: December 2007

Abstract
Borrowed from the concept of the "Safety Passport" the "Malaria Visa" is an on-line training and certification process for use by non-immune personnel traveling to areas where Malaria is a health risk. The person completes the "visa" process prior to departure and carries a printed certificate showing the training dates, the intended destination locations, and certification that he or she has the proper supplies and equipment.
The process ensures all personnel receive the same information, standardizes program implementation, and streamlines arrival procedures in the destination locations.
Quantifying Productivity Loss and Permeability Alteration Due to Formation Compaction During Frac-Pack Treatment
Authors: Sarfare M. D. , Zaki K. S. , Abou-Sayed A. S. 
Published: December 2007

Abstract
The objective in Hydraulic Fracturing is to increase well productivity and enhance or accelerate hydrocarbon recovery. Yet in soft formations, where hydraulic fracturing provides the secondary benefit of sand control, FracPack operations may result in adverse effects. These effects are more prominent in Gulf of Mexico (GOM) deepwater fields, where sands are over-pressured and highly compactive. Porosity loss around the fractured well normally occurs during FracPacks. This paper addresses this issue and quantifies the permeability loss in FracPack treatments.
Forces or pressures applied on soft rock surfaces, like those occurring during a FracPack operation, generally lead to compaction (plastic deformation). Here, we exclude Water Pack and High-Leak-off treatments. These deformations are usually accompagned by higher treatment net pressures and wider fracture widths. In recent publications (1-2), fracture stiffness and propagation were addressed during FracPacks. Considerations of both factors provide new design basis for proppants and injection schedules to optimize treatments.
The current paper addresses the leak-off and compaction responses during FracPack jobs and post-fracture productivity. The fracturing process in soft formations can be explained as expansion of the formation at the fracture tip (propagation) and a compaction of the formation on either side of the fracture face (stiffness). The compaction and stiffening of the rock at the fracture sides have great influence when evaluating fluid flow response (leak-off or production). The compaction occurs at the expense of pore space/porosity reduction around the surfaces of the fracture and creation of an extended damage zone into the formation. Permeability damage and reduction in the productivity or injectivity index follows as a result of the compaction effects.
The reported work quantifies the three basic unknowns in this problem: 1) The extent of the compaction zone and what are the dominant controlling parameters. 2) How much reduction in porosity can be expected and how is it distributed within the compaction zone. 3) The expected impact on leak-off and productivity as a result of reduction in porosity and the corresponding permeability. Existing GOM field data relating permeability and porosity/compaction will also be discussed.
From Laboratory Research to Successful Practice: A Case Study of Carbonate Formation Emulsified Acid Treatments
Authors: Kasza P. , Dziadkiewicz M. , Czupski M. 
Published: December 2007

Abstract
After laboratory research the pilot treatment has been done. After obtaining positive results from this treatment, BMB oil field operator begun to use emulsified acid for small scale acidizing treatment on production wells. Six acidizing treatments have been performed using emulsified acid. Oil and gas production increase was achieved after each treatment. Significant oil and gas production increase and decrease of near wellbore pressure drop was noticed during the production process.
After positive results of emulsified acid treatment have been achieved on BMB oil field, this technology was successfully introduced in wells on another oil field located on the same carbonate formation