bluuebunny/crossref_metadata_2025_split huggingface dataset:
Steel Body PDC Bit Technology Demonstrates Performance Improvements
Authors: Smith L.M. , Perrin V.P. , Delwiche R. 
Published: December 2007

Abstract
New bit technology was used to create a series of steel body bits which incorporate proven PDC bit design features for improved performance. The bits have achieved field records in fully one-third of the applications in which they were introduced. The technology described includes all aspects of bit application, including new manufacturing processes, advanced design engineering, a unique nozzle configuration and use of a computerized rock compressive strength analysis program to refine application.
Field performance of steel body PDC bits is detailed and compared to conventional matrix body bits to illustrate the resulting performance improvements possible with proper steel body PDC bit application.
P. 271
Zirconium Citrate: A New Generation Dispersant for Environmentally Friendly Drilling Fluids
Authors: Nicora Luigi F. , Burrafato Giovanni 
Published: December 2007

Abstract
Despite their already widespread and successful use in several industrial branches, zirconium compounds are underexploited in the drilling industry and have a great potential for more applications1.
An innovative product based on zirconium citrate can control high temperature gelation of bentonite at temperature exceeding 400°F or increase the temperature stability of all kinds of lignites and lignosulfonates in dispersed muds. In polymer muds the use of this compound can strongly reduce the need for mud dilution by controlling unwanted increases in mud viscosity and is an effective means for stabilizing rheology during stopped circulation. This biodegradable and non toxic product looks promising as a replacement for potassium dichromate and Cr-lignosulfonates in high temperature applications. Laboratory studies and field experiences are described in this paper, together with ecotoxicity data.
Turbo Drilling Through Coiled Tubing Using Foam In Sub-hydrostatic Well : A Case History For Jotana Field In Cambay Basin, India
Authors: Kumar Manoj , Jain P.C. , Srivastava A.K. , Johari Anil 
Published: December 2007

Abstract
Several sub-hydrostatic wells have the problem of declining production due to build up of consolidation of produced sand fill and heavy scale deposits in the 5" or 7" casing. Conventional Coil Tubing Operation using high pressure jetting failed to clear the hard deposits. To meet this challenge innovative idea of Foam TURBO DRILLING with Coil Tubing was successfully carried out for the first time in oil fields of India. In the process 70% foam was used with suitable compatibility with the lithofacies encountered in Jotana field in the Cambay Basin. Suitable commercially available drill bit with P.D. motors was used to drill the deposits with the help of foam. A successful operation resulting in incremental production from Sub-hydrostatic well.
P. 365
The Use of QRA Technology in Drilling and Well Operations
Authors: Lewis D. B. , Brand P. R. , Maes M. A. 
Published: December 2007

Abstract
The use of a reliability based design philosophy relative to Oil County Tubular Goods is becoming more important as operators continue to push the limits of materials and equipment by driving than into ever environments and ever more unusual operating scenarios. The use of allowable or working stress design no longer serves the designer in these unusual situations. The means of determining the risk or reliability of the operating scenario is critical, from a safety viewpoint as well as from an optimized design viewpoint.
Quantitative Risk Analysis (QRA) provides the necessary tool for the optimization of a design while quantifying the associated risk of the design for a particular scenario. QRA can and does go beyond the conventional load combinations and standard operations. It is a powerful tool for allowing the operator to "put the pieces together differently".
In this paper, the QRA technology is discussed not only for design but analyzing problems and scenarios which is not the norm. It discusses how the technology can be applied on out of the ordinary operations and how these operations which are considered by the Industiy as unacceptable or unsafe can be achievable if one knows what the risk is and what is driving that risk.
Although QRA and total system reliability / assessment is in its infancy in drilling and well operations, in the years to come it will become one of the prominent technologies of the Oil and Gas Industry.
A System for Comprehensive Measurements of Pipe Wall Thickness and Diameter in Support of Risk-Based Tubulars Design
Authors: Aldin M. H. , Logan K. , Burres C. V. , McGill R. M. 
Published: December 2007

Abstract
In risk-based design of well casing and tubing, part of the calculations for burst and collapse reliability depend on the statistical distribution of the pipe wall thickness and ovality properties. It is not sufficient to have random or local (point-wise) readings of these parameters. Instead, the calculations must account for the actual minimum and average values as they occur statistically along each entire joint of pipe. This paper explains the methodology and results from the development of a data acquisition system designed to acquire and report comprehensive pipe wall and diameter measurements as part of the standard pipe inspection process.
An online data acquisition system with six analog input channels was developed to acquire and store wall and diameter data for tubulars with diameters between 4.5 in. and 20.0 in. This system was designed so that it would neither interfere with nor add any cost to the existing inspection process at ICO. The wall thickness measurement is incorporated into already existing ultrasonic inspection equipment. The system yields 600 wall readings per pipe revolution. With a typical advancement speed of 1.375 revolutions per inch of travel, this translates into over 160,000 wall readings per typical joint of pipe. Software, covered in this paper, processes and reduces this data to minimum and average wall values on a per-joint basis.
The diameter measurements are obtained from collimated light sources, which cast shadows onto optical sensing arrays. The pipe diameter is determined by the fraction of array elements not receiving light. This system also yields 160,000 readings per typical joint of pipe. Noise and inconsequential ovalities (ovalities over lengths less than 6 diameters) are removed, yielding a maximum and minimum ovality for each joint.
A Computationally Efficient Iterative Solver for Reservoir Models with Faults/Pinchouts
Authors: Chien Mark C.H. , Chun Dong H. 
Published: December 2007

Abstract
An incomplete Gaussian elimination of a reduced system (RS) is one of the most efficient preconditioners of an iterative linear solver for reservoir simulation models. The reduced system is formed from eliminating half the unknowns from problems whose matrices have regular red-black ordering. This precludes the application of the RS method to reservoir simulation models with faults and pinchouts, which incur irregular connections. This paper extends the method to solve Jacobian matrix generated from such a reservoir simulation model. A generalized minimum residual method is used to accelerate the solution.
P. 649
Seizing the Environmental High Road
Authors: Ebenhack Ben W. 
Published: December 2007

Abstract
In popular perception, fossil fuels are cast as nemeses of the environment. This sets up a false choice that traps too many of us, even in an industry well situated to know better and to say so. For us, this too often means accepting an adversarial role. We could instead take the high road.
In the real world, energy alternatives do not represent a dualistic either/or choice, but mixes of kinds of energy, used in particular times and places and under particular economic and technologic conditions. Lift the shroud of misconception and the real choices can be seen.
Renewability is often construed as an environmental benefit in and of itself, as well as an absolute characteristic of the commonly discussed "energy alternatives." This is not true. Similarly, talk of a "closed carbon cycle" for biomass fuels is critically flawed in the way it defines boundary conditions. If we further expose the flawed assumptions underlying the extrapolation of trends which overestimate the near term potential of popular energy alternatives, we can engage issues of energy for the future constructively.
Industry members gain nothing by denying the fundamental importance of the environment or the costs attributable to energy consumption. We gain something important by shifting the public debate away from false choices and to the real ones. In many lower income countries, for example, fossil fuel development can provide an environmental benefit, and the environmental costs of not using fossil fuels can be seen with particular clarity.
As we see and formulate the issues more clearly, we in the energy-producing industry can take a proactive stance in the evolution of energy mixes optimized for the context of time, space, environment, and economy.
P. 667
A Model to Predict Wireline Formation Tester Sample Contamination
Authors: Akram A.H. , Fitzpatrick A.J. , Halford F.R. 
Published: December 2007

Abstract
Wireline formation testers (WFT) collect fluid samples for PVT analysis through a probe set against the borehole wall. Filtrate contamination is reduced prior to sampling by either pumping the mixture of filtrate and reservoir fluid from the formation to the borehole or flowing the mixture into one or more WFT chambers. The cleanup is monitored at the surface. The time to reach the level of acceptable contamination (LAC) depends on the depth of invasion, pumpout rate and various fluid and rock properties.
Generalized guidelines predict time to first oil based on simple volumetrics but do not predict the rate of cleanup. Excessive cleanup time increases costs and the risk of differential sticking of the tool/cable. In some cases it may not be practical to attempt the operation as the LAC may take too long to achieve.
A numerical simulator was used to investigate the characteristics of the contamination level versus time curve and to define the variables governing cleanup.
The model was validated using data from five wells from two fields with differing rock and fluid properties. One hundred and fifty simulation runs were made with different invasion depths, flow rates, and rock and fluid properties.
An equation was developed for field use, that estimates filtrate contamination fw as a function of cleanout time t.
An alternative approach for WFT sampling is also suggested, using not one but two probes. With this method, both cleanup time and the final level of filtrate contamination can be substantially reduced.
P. 27
Formation Testers vs. DST - The Cost Effective Use of Transient Analysis to Get Reservoir Parameters
Authors: Frimann-Dahl C. , Irvine-Fortescue J. , Rokke E. , Vik S. , Wahl O. 
Published: December 2007

Abstract
The use of formation testers to get vertical pressure profiles, mobilities, in-situ fluid samples and vertical permeabilities is well known in the industry. Several tools are designed with multiple sample chambers and multiple probes to achieve the above objectives. In Norsk Hydro, there has been limited use of the mobility, k/μ, typically because this is a measurement in the "damaged zone". This measurement is also influenced by mud filtrate and is assumed normally to represent a too low value of permeability. The aim has therefore been to get a pressure transient that extends past the damaged zone and into virgin rock and fluid for a good permeability estimation. Data collected from the North Sea, using a single probe in open hole, proves radial flow after only short durations. Typically, a drawdown and buildup sequence lasts for one hour or less, and radii of investigations have been proven up to 90 meters. Permeabilities in good agreement with the average of core plugs over the same interval were obtained. Also, examples of pressure transients from several intervals in a low permeability turbidite sand will be shown to exhibit outer boundary effects at only short radii of investigations. In the examples shown, the welltests (DST) were cancelled because the objectives were met using the formation tester (FT).
Multi-resolution Analysis of Long-Term Pressure Transient Data Using Wavelet Methods
Authors: Kikani Jitendra , He Meiqing 
Published: December 2007

Abstract
Large bandwidth transmission systems have made it easier and convenient to routinely collect large data from permanent monitoring systems. To effectively manage, filter, reduce and interpret these large data sets requires sophistication and methodologies that have sound bases. The standard data reduction procedures are fraught with difficulties and have biased modes which give rise to aliasing effects. In fact, a two step process is recommended wherein noise filtering and behavioral filtering are separated and allowance is made for visualizing the data at different dyadic scales of resolution.
In this paper, the characteristics of simulated pressure transient data are investigated in the frequency domain. The power spectrum properties of both simulated data (with random noise added) and real data sets are studied. Wavelet transform is introduced to accomplish the time-frequency analysis of long- term pressure transient data. The characteristics of different family of bases of wavelets are studied, and a recommendation is made for use with pressure data. Application of wavelet transform in data denoising has been experimented with and the performance of different thresholds established. Two types of denoising methods are recommended for slowly changing pressure transient data. Multi-resolution approximation of the long-term pressure transient data using wavelet transform is also presented. Approaches for data culling are addressed.
P. 117
Integrating Pressure and Fractional Flow Data in Reservoir Modeling With Fast Streamline-Based Inverse Method
Authors: Wen Xian-Huan , Deutsch Clayton V. , Cullick A.S. 
Published: December 2007

Abstract
Generation of a reservoir model's spatial permeability distribution directly from historical multiple-well pressure and fractional flow rate data requires an inverse solution of the flow equations. This computation generally utilizes a gradient method to solve the minimization problem. A previously reported geostatistically-based inverse sequential self-calibration (S SC) technique has been shown to significantly reduce the computer time as compared to full inversion solutions and to yield excellent results for single-phase pressure.
In this paper we extend the SSC to jointly invert multiple well pressure and multiphase fractional flow data by:adapting a fast streamline simulator for the forward flow solution; andimplementing a new method for computing the sensitivity coefficients for fractional flow rate.
The method is fast and robust, and an important consequence of the method is that the spatial correlation structure is honored through the kriging equations in the SSC. This leads to well-behaved objective functions with low final values and preserves the prior model spatial characteristics.
The paper demonstrates the extended SSC for generating permeability realizations from production data using a synthetic reservoir model. The paper systematically compares the quality of the production data matches for inversion of pressure data alone, fractional flow rate data alone, and the combination of fractional flow rate and pressure data. For the synthetic model, pressure data alone provides coarse information primarily near the wells, whereas the fractional flow data provide more information on interwell spatial reservoir permeability. Inverting pressure and fractional flow data jointly lead to significant improvement of the representation of reservoir heterogeneity and reduction in uncertainty. The paper shows that the accuracy of reservoir performance predictions at wells can be dramatically improved by building the models using the historical production data from those wells. However, if only production data have been used to build a model, the results also indicate that the prediction capability may be limited for new wells drilled in areas outside the influence region of existing wells or under flow or well conditions different from those used for the inversion. Future research directions are discussed at the end.
P. 161
Advancing Horizontal Well Sand Control Technology: An OHGP Using Synthetic OBM
Authors: Gilchrist J.M. , Sutton L.W. , Elliott F.J. 
Published: December 2007

Abstract
This paper describes a Gulf of Mexico case history that successfully demonstrates a horizontal well can be drilled with synthetic oil based mud (SOBM), and gravel packed with aqueous fluids while still offering excellent well productivity and sand control integrity. The result significantly expands the application of open hole gravel packs to encompass a range of reservoir types and well trajectories thought to date to be unachievable.
Key aspects of delivering this technology are discussed in this paper: what major technical risks were identified, how these were managed through an intensive laboratory testing program, engineering, global resourcing, and teamwork put into this project.
In particular the following key achievements will be discussed in detail: the successful horizontal balanced displacement from SOBM to kill weight brine, back production of barite laden SOBM filter cake through the gravel pack with minimal productivity impairment, and some important data acquisition results designed to increase our insight into this well type.
P. 121
Harding A Field Case Study : Sand Control Strategy for Ultra High Productivity and Injectivity Wells
Authors: McKay G. , Bennett C. , Price-Smith C. , McLellan W. 
Published: December 2007

Abstract
The Harding field is the first horizontal well development by BP and partner's in the highly unconsolidated Balder Massive Sand. The field development utilizes a TPG 500 Jack-up Drilling and Production Unit in conjunction with a concrete Gravity Base Tank (GBT) providing oil storage of 500,000bbls (see Figure 1.0). A combination of the highly permeable, unconsolidated formation with active water/gas drives and viscous oil creates a high coning potential. This means that achieving and maintaining sand free production through optimal completion design was critical to the overall success of the development.
The first Phase of horizontal wells were drilled and completed for sand free, ultra-high rate production (&gt;30,000 BOPD/well, with PIs in excess of 1000 bbl/day/psi). High rate Water Injectors are required for vital voidage replacement and pressure support. Initial injection water requirements were provided by 2 dedicated Aquifer source wells.
This paper describes the strategy adopted and the factors considered in the development of the sandface completion design for Phase 1 of field life. The experience gained on Phase 1 have contributed to the design enhancements required for the more complex and challenging aspects of Phase II, which will include extended reach horizontal wells to neighboring satellite pools. These enhancements have been engineered taking into account the variations in reservoir quality, physical installation challenges and production profile requirements, in order to achieve continuing longevity and the high well PIs/IIs synonymous with the Harding Development.
Interaction Between Shale and Water-Based Drilling Fluids: Laboratory Exposure Tests Give New Insight Into Mechanisms and Field Consequences of KCl Contents
Authors: Horsrud P. , Bostrom B. , Sonstebo E.F. , Holt R.M. 
Published: December 2007

Abstract
To predict and cure borehole instabilities during drilling, it is important to have a profound understanding of the effects that the drilling fluid (in particular water-based muds) may have on shale behaviour. This paper focuses on the consequences of KCl exposure on smectite-rich shales. These effects have been studied by various experimental techniques, both under atmospheric and simulated downhole conditions. This has identified several particular effects as a consequence of potassium intruding the shale. One effect is that the shale shrinks, primarily due to cation exchange. This process increases the permeability and changes the deformability and possibly also the strength of the shale. Simulations of the shrinkage effect around a borehole show that the compressive stresses will decrease with increasing KCl concentration, and this improves the stability. Tensile stresses may eventually be generated in the formation at high concentrations. This enhances the possibility of borehole instability problems and also increases the rate of potentially damaging effects (pore pressure diffusion, ion transport). An important conclusion is that an optimum KCl concentration appears to exist.
Shale-fluid interactions were found to depend strongly on the test methods and procedures, calling for a careful review of methods used for optimum drill fluid design. The testing also revealed that the effect of potassium is fundamentally different from other cations upon exposure to shale.
P. 215
Compositional Simulation of Asphaltene Deposition and Plugging
Authors: Nghiem Long X. , Coombe Dennis A. , Ali S.M. Farouq 
Published: December 2007

Abstract
This paper describes the incorporation of an asphaltene deposition and plugging model in an Equation-of-State (EOS) compositional simulator. The precipitated asphaltene is represented as a pure solid. It is shown that this representation provides an efficient and satisfactory method for modelling the phase behavior of asphaltene, in both gas injection and pressure depletion processes. The precipitated asphaltene can deposit onto the rock surface through an adsorption process, or flow as a suspended solid in the oil phase. Compositional simulation of a typical gas injection core displacement and of a radial single-well primary depletion show that important phenomena and observations reported in the literature were reproduced adequately.
P. 129
The Impact of Formation Damage and Completion Impairment on Horizontal Well Productivity
Authors: Burton Robert C. , Hodge Richard M. 
Published: December 2007

Abstract
Horizontal, openhole completions, especially completions incorporating sand control, are prone to productivity impairment from a variety of sources. Often, the potential productivity of these wells is not achieved and in some cases, production is severely limited. This paper examines common sources of formation and completion damage that can lead to significant productivity impairment in horizontal, openhole completions and discusses techniques to overcome these problems.
A process to design horizontal wells for maximum productivity has been applied in a variety of locations including the North Sea, Gulf of Mexico, and the Far East. First, laboratory testing of drill-in fluids (DIF), sand control screens designs, and clean-up treatments is conducted under simulated downhole conditions. These results are used in an analytical model to predict horizontal well productivity. This modeling verifies critical well design features and assists in identifying drilling/completion products and techniques that minimize productivity impairment.
These studies show that a comprehensive testing, design, and evaluation protocol can be used to maximize horizontal well productivity and identify products and practices that cause productivity impairment. The modeling results and field cases illustrate the necessity of evaluating products and practices as a drilling and completion system, rather than selecting products on an individual performance basis. Also, the importance of properly designed and executed cleanup treatments to degrade/remove DIF filtercake is demonstrated. Finally, the benefit of post-auditing well performance to validate products and practices is shown.
P. 399