bluuebunny/crossref_metadata_2025_split huggingface dataset:
Matrix Acidizing of Water Injectors in a Sandstone Field in Saudi Arabia: A Case Study
Authors: Al-Anazi H. A. , Nasr-El-Din H. A. , Hashem M. K. , Hopkins J. A. 
Published: December 2007

Abstract
The aims of this study were to design a cost-effective stimulation treatment to remove formation damage from water injectors in a recently developed sandstone field in Saudi Arabia and enhance well injectivity, while maintaining formation integrity. This paper examines the design of the treatment, field monitoring, and analysis of acid returns. Core flow experiments were performed to screen various acid formulations, and evaluate acid additives.
The designed treatment was applied on several water injectors. Acid returns were analyzed to evaluate the effectiveness of each treatment. It was found that a preflush of 5wt% NH4Cl solution was effective in displacing potassium and sodium ions from feldspars and clay minerals compared to a preflush that contained hydrochloric acid only. A multi-stage treatment was designed to remove formation damage encountered in several water injectors in this field. The treatment significantly improved the injectivity index of the treated wells.
Design and Optimization for Sucker Rod Pumping System in Deviated Wells
Authors: Mo Y. , Xu J. 
Published: December 2007

Abstract
Commonly used methods for design and analysis of a rod pumping installation assumed a vertical well and ignored the well curvature effect, rod/tubing drag forces and fluid dynamics. These methods could cause substantial errors if they are used to diagnose and analyze the rod pumping system in the deviated wells. This paper presents a new and simplified model to design and evaluate the performance of rod pumping system. Using a 3D quasi-static model involving all the equilibrium equations and deflection equations, the rod loads displacements and stresses for each element are solved recursively. The lateral displacement of the rod is also considered in the model. The possible contact between the rod and tubing is estimated if the rod is supported at certain places, for example, where a centralizer is placed. Taking into account the well geometry, the rod centralizer effect, the fluid viscous effect, the Coulomb friction between rod and tubing, and all the components in the system, the model provides a useful and simple method to design the rod strings and spacing of the rod centralizers, to select the pumping mode for optimization of the system, and to evaluate the performance of a existing pumping system. An efficient computer code is developed. Finally, good agreement is indicated between the results and the actual measured data.
An Independent Operators' Challenge: Balancing Technology, Manpower and Capital
Authors: Eson Rod L. 
Published: December 2007

One thing has remained constant in the petroleum industry for the past fifty plus years is change. It is this ever changing landscape of the industry, which brings the biggest challenges, especially to independent operators. The petroleum industry is one of the most capital intensive industries in the world today. However, it does not matter how much money a company has if it does not have the right people to invest those dollars wisely. The third leg of the stool, to use an already overused analogy, is technology. We have seen giant strides made in 3D seismic, extended reach drilling, measurement and logging while drilling, multilateral wells, production surveillance systems and on and on. Even with the brightest people and a pot full of money, a company will soon loose it competitiveness if it does not stay up on the latest technological changes in the industry.
For nearly all independent operators capital is a scarce commodity. Capital is typically obtained through debt from banks or institutional investors or through equity by selling a part of the company through private or public placements. These capital dollars are used to secure the manpower and technology required to acquire properties, drill wells, and complete exploratory plays and a host of other things. If this is done with debt, the operator has repayment obligations, which eats into the capital. If this is done with equity, the growth of the company is shared with others. Each independent operator must look inside to see what type of company they are and what they want to be in the future. They must set a strategy for getting there and then balance the technology, manpower and capital available to them throughout the process.
Precise Fracture Initiation Using Dynamic Fluid Movement Allows Effective Fracture Development in Deviated Wellbores
Authors: Eberhard Michael J. , Surjaatmadja Jim , Peterson Ellis M. , Lockman Russell R. , Grundmann Steven R. 
Published: December 2007

Abstract
In deviated wellbores with long perforated intervals, conventional fracture initiation with wellbore pressurization often creates multiple fracture initiations, resulting in severe fracture tortuosity. When this happens, treatments are generally plagued with high injection pressures, low injection rates and, quite often, early screenouts.
One solution to the problem of multiple fractures is to use the fluid’s own dynamic movement to divert flow to a specific point. This method accurately positions and directs fracture initiation. With proper planning, a single fracture can be initiated and proppant can be easily placed without tortuosity effects.
This paper discusses the use of the dynamic fluid movement treatment in a well positioned on an incline through the pay section. Premature screenout had occurred when proppant first entered the formation on a previous treatment attempt, and fracture modeling indicated that multiple fractures were the apparent cause of the screenout. When the dynamic fluid movement method was used on a subsequent treatment, a fracture was initiated properly, and a large proppant treatment was placed successfully.
The Modelling of Advanced "Intelligent" Well – An Application
Authors: Yu S. , Davies D. R. , Sherrard D. W. 
Published: December 2007

Abstract
"Advanced wells" will find a wider application within the oil and gas production industry once their ability to improve project economics is more widely known. Further, the nature of the industry is such that the application of "Advanced wells" has to be justified on a case by case basis. Actual case histories will only become available very slowly since the projected lifetimes of such wells is normally at least 5 to 10 years. This process of industry acceptance of advanced wells can be speeded up by the approach presented in Reference [1] – developing confidence in the ability to model advanced wells by quantifying their economic benefit with industry proven software by the development and application of an accepted well modeling strategy.
In this paper, a simplified simulation model of a typical North Sea field case is used to illustrate the advanced well modeling methodology by quantifying the benefits of installing an "Intelligent" completion. Several "Intelligent" completions have been modeled in order to obtain an optimum production performance. These range from a simple Inflow Control Valve (ICV) completion in a slanted well to a multi-branch completion with ICVs and installation of down-hole water/gas separators.
We have been able to show that correct advanced "intelligent" well design can accelerate oil production and maximize oil recovery. The identified "intelligent" well completion and production policy was robust since it still maximized the project economic value for a range of typical geological and reservoir uncertainties. Simple economics indicated a pay back of 7-11 times (on a NPV basis) from the implementation of such an advanced well.
Expandable Tubulars: Field Examples of Application in Well Construction and Remediation
Authors: Daigle Chan L. , Campo Donald B. , Naquin Carey J. , Cardenas Rudy , Ring Lev M. , York Patrick L. 
Published: December 2007

Abstract
As the oil and gas industry has matured, three broad-reaching and long-standing issues that affect virtually every well have assumed heightened importance: conservation of hole size, hydraulic isolation of selected zones, and maximization of well life. All of these issues involve one of the industry’s most fundamental technologies, wellbore tubulars. Until recently, resolving these issues with conventional tubular technology was becoming ever more difficult, especially in deep-drilling and extended-reach applications, in wells utilizing liner hangers, and in aging wells containing deteriorating casing. A revolutionary new technology—expandable tubulars—has recently been introduced and has successfully addressed these issues in commercial applications.
The basic concept underlying expandable-tubular technology is simple: a mechanical expansion device, known as an expansion cone or mandrel, is propagated through downhole tubulars utilizing hydraulic pressure. The progress of the cone expands the tubulars to the desired internal and external diameters in a plastic deformation process known as cold drawing.
In drilling applications, a specially-designed liner hanger utilizing the new expandable-tubular technology conserves hole size by eliminating the need for a conventional liner hanger/liner hanger packer, and provides a superior pressure seal compared to the old technology. In cased wells, expandable casing is cladded to existing casing, either to repair or strengthen the existing casing, with minimal decrease in wellbore inside diameter (ID) and flow potential. Expandable tubular solutions have been successfully installed in the Gulf of Mexico, in U.S. inland wells, as well as in large-scale field trials.
This paper briefly describes the technical concepts upon which expandable tubulars are based and gives an overview of expandable-tubular applications. The paper then focuses on the most recent field installations, including systems installed during the first quarter of 2000. Discussions of field examples will contain customer objectives, job design, installation procedures, ultimate results and best practices learned.
Design of a Riser Recoil Control System and Validation Through Full-Scale Testing
Authors: Stahl M. J. , Hock C. J. 
Published: December 2007

Abstract
This paper discusses the development of a riser recoil control system for a state-of-the-art drilling vessel. This control system, designed using computer simulation, is capable of controlling riser recoil in water depths of 3,000 to 10,000 ft and a wide range of tensions. Two full-scale tests occurred in 6600 ft of water in the Gulf of Mexico. Data from the first test, using 400 kips overpull, showed that only minor adjustments to the computer program were required. A second test, with 800 kips of overpull and only 20 ft of telescopic joint stroke occurred two days later. We believe that a riser disconnect test under these conditions is unprecedented. Data from both tests demonstrated that the system functions as intended and that the analysis method is valid.
This work shows that computer simulation is a reliable method of developing robust solutions for riser recoil control. Similar analysis is also useful in simulating existing systems to determine operating limits and investigate potential enhancements.
Use of Java™ Technology for Web-Based Reservoir Engineering Applications
Authors: Fenwick Darryl H. 
Published: December 2007

Abstract
The increasing power, speed, and ease-of-use of the Internet has challenged industries to develop new methods for doing business. This paper focuses on the petroleum industry and how it can use new emerging technologies in an innovative manner to reduce cost and increase productivity. The paper first describes briefly the Java tools available with Java 2 platform and reviews how industries have used them to redefine their business models. The paper then focuses on an actual web-based reservoir engineering application. A web site is presented that provides several reservoir engineering applications (material balance equations, decline curve analysis, geomodeling packages), freely available to the public. The web site demonstrates concretely how emerging Internet technology can make available both simple and complex reservoir engineering applications using a simple web browser. A vision of the future of petroleum engineering software is presented, where every engineer with a browser and internet connection has access to a suite of petroleum engineering software products without need for software licenses, installations, or software updates.
Design and Analysis of a Multiphase Turbine for Compact Gas-Liquid Separation
Authors: Rawlins C. H. , Ross G. D. 
Published: December 2007

Abstract
The Rotary Separator Turbine (RST) utilizes unique technology to provide compact separation of oil and gas, while recovering energy wasted in conventional pressure let-down operations. The technology has been utilized for industrial refrigeration and geothermal applications since the early 1980’s, and has recently finished field evaluation and assessment on a deepwater tension leg platform in the Gulf of Mexico. The focus of this paper is on the operating principles and mechanisms of multiphase turbine technology and design parameters for installation as a separation or power generation system in new developments or in debottlenecking applications. Operational experience pertaining to separation efficiency, mechanical reliability, and power output in a live fluid environment will be highlighted.
Market Segmentation and Pricing Strategies in the North American Natural Gas Market
Authors: Garcia Percy , Vredenburg Harrie 
Published: December 2007

Abstract
This paper analyzes the marketing strategies followed by Canadian companies operating in the North American natural gas markets. It focuses on two elements of the marketing mix: (a) market segmentation and (b) pricing. The highly competitive natural gas markets of North America, strengthened by the deregulation process, the restructuring of electric utility industries, the advance in technological communications, and the global growing concerns on environmental issues, make market segmentation and pricing key elements in setting marketing strategies. The main findings of this research are: (a) the market segmentation is highly dependent on the availability of pipeline distribution and cost of transportation of gas; (b) decisions on market segmentation regarding types of customers are highly dependent on the highest netback that can be obtained; (c) pricing in the natural gas market of North America is highly affected by the availability of distribution pipelines, cost of transportation, period of contract with buyer companies and by the use of alternative energy sources by end-users; and (d) there is a direct relationship between geographical market segmentation and pricing. The factor that links these two variables is the availability of pipelines to move the gas to the markets.
Integrated Development Plan for a Naturally-Fractured Gas-Bearing Granite Reservoir
Authors: Hazlett W. G. , Snow P. W. , Gonten W. D. Von , Glasgow W. M. , Banks R. J. , Duncan C. S. 
Published: December 2007

Abstract
This paper describes the characteristics of and development plans for the PY-1 concession, a gas reservoir contained in a naturally-fractured granite formation. Over a several-year period, exploration and delineation wells were drilled offshore India. The paper covers all aspects of the integrated geoscience/engineering development study, including seismic, core and fracture analyses, well logging, well testing, and reservoir simulation. In addition, we include the offshore facilities, pipeline and onshore compression plans. The development plan was prepared by a team of engineers and geoscientists made up of both operating company personnel and contract and consulting personnel. The result of the study is a development plan for a granite reservoir. We conclude that highly-fractured granite formations should not be overlooked as potential reservoirs. This granite reservoir should provide a steady gas supply to any one of several commercial manufacturing facilities planned for the area.
Large-Scale Application of Wet-Gas Metering at the Oman Upstream LNG Project
Authors: Konopczynski M. R. , de Leeuw H. 
Published: December 2007

Abstract
This paper describes the application of wet gas flow measurement to over 35 wells in the Oman Upstream LNG project. This multiphase metering process uses permanently installed wet gas Venturi meters at each well location in combination with a tracer dilution technique. Standard single phase venturi flow rate calculations are corrected for the mixed phase flow by published correlations. The tracer dilution technique, which involves the injection of suitable tracers into the flow line followed by sampling of the liquids, is applied periodically to enable the liquid to gas ratios to be determined. In the present case, wells are involved with condensate/gas ratios ranging from 350 m3/million sm3 to 800 m3/million sm3.
Unique experience has been gained in implementing the wet gas metering process in a large scale installation, including the incorporation of the wet gas Venturi correction algorithm in the DCS system, the understanding of fluid PVT behavior and its effects on the calculations, and the optimal installation of venturi, tracer injection and fluid sampling hardware. To date the technique has provided results with an error of less than 10% for the gas phase. This continues to improve as more experience is gained and empirical data is collected. This paper describes the wet gas flow rate calculations, the sample production data supporting the validity of the technique, as well as a number of practical issues to be considered before applying this technique to continuous gas/condensate metering.
The current application demonstrates that wet gas flow measurement has been applied successfully to large scale multiphase metering of individual gas/condensate wells, thereby providing continuous production data for reservoir surveillance whilst eliminating the need for expensive test separators and associated manifolds.
Quantifying the Economic Impact of 4D Seismic
Authors: Waggoner J. R. 
Published: December 2007

Abstract
Time-lapse 3D, or 4D, seismic has been looked at by the industry for over a decade, with a growing number of successful cases being reported in the literature. Two of the most recent 4D case studies reporting success are Draugen in the Norwegian North Sea and Gannet-C on the UK continental shelf. Both have been technical successes, providing good images of time-lapse changes in the reservoir. These 4D results have changed drilling locations and reduced the risk associated with costly field development decisions.
The focus of this paper is quantifying the economic impact of 4D seismic. After reviewing some of the ways that 4D seismic can impact reservoir management, an economic model is developed that can quantify that impact. The decision tree models use Bayes’ Theorem to compute the modified probabilities resulting from the 4D seismic. The model indicates that, for the case of drilling an infill well, 4D seismic information adds considerable value to the project, even considering that the 4D information is not perfect.
Valuing and Comparing Oil and Gas Opportunities: A Comparison of Decision Tree and Simulation Methodologies
Authors: Mudford B. S. 
Published: December 2007

Abstract
Decision trees have been widely used in the petroleum industry for both economic evaluation and decision analysis. In recent times Monte Carlo simulation has begun to be used to value oil and gas projects and to analyze decisions. In this presentation I will compare and contrast decision tree and simulation methodologies for both economic valuation and decision analysis. As a starting point, I will take a typical Gulf of Mexico project from exploration through to development. The results of a decision tree analysis of the project and a Monte Carlo simulation of the project will be compared. When using decision trees, the expected monetary value (EMV) is usually calculated and used to value the opportunity. Frequently the impact of uncertainties on the EMV is not assessed. In contrast, with the simulation approach the full net present value (NPV) distribution is calculated along with the risk. We will show that, for the Gulf of Mexico project, a relatively complicated decision tree is needed if the EMV of the decision tree is to be close to the mean NPV calculated using the simulation. However, even when the EMV and mean NPV are close, the additional information about the NPV distribution that is part of the simulation output enables risk to be an explicit part of the decision-making process. Although decision tree methods can be extended to include an assessment of risk, since the form of the NPV distribution is not known when using decision trees, a true assessment of project risk is not available.
Successful West Delta Block 89 Redevelopment Utilizing Re-entries and Openhole Horizontal Gravel Packing
Authors: Vozniak J. P. , Dooley W. E. , Casto R. G. , Bologna G. J. , Beal T. M. , Smejkal K. D. 
Published: December 2007

Abstract
The redevelopment of West Delta Block 89 consisted of two re-entry wells completed as 6 ¾ in (172 mm) openhole gravel packs with 4 in (102 mm) pre-packed screens inside 500 ft (152 m) horizontal holes. These two wells were the first application of horizontal technology for Agip Petroleum in the Gulf of Mexico and more than doubled oil production at West Delta 89, while being under planned time and budgets.
This paper will demonstrate that with open communication during the planning and execution phases between operating personnel, service companies, and contract personnel, advanced technology can be employed successfully on the first attempt. Overcoming challenges such as complex directional profiles to ensure proper placement of horizontal wells in a thin oil column between a gas cap and water aquifer, high torque and drag, formation damage, hole cleaning, and completing relatively slim holes requiring sand control are discussed. An industry milestone was achieved on the second well when a steerable rotary assembly was used to kick off the directional well in a soft formation for the first time.
The results are summarized for the wells A-9 and A-21, and expand the use of re-entry drilling technology in complex directional trajectories, and openhole horizontal gravel packing (OHGP) in relatively slim holes. Applications exist in fields requiring an alternative to cased hole gravel packing and in field redevelopment projects where perceived marginal economics exist.
Field Case Studies of Pressure Transient Data from Complex Reservoirs
Authors: Guo Boyun , Westaway Peter , Jacquemont Jerome 
Published: December 2007

Abstract
Modern welltest analysis and interpretation techniques rely on a match between the actual reservoir pressure response and analytical models. For many well and reservoir configurations the analytical techniques are sufficient. However, recent advances in drilling and completion technology, coupled with the increased capabilities of modern pressure gauges to detect reservoir heterogeneities, are now severely challenging the available analytical well test models. In such complicated cases numerical welltest models are frequently required. This paper reviews some field cases studied using analytical and numerical techniques with the purpose of sharing with reservoir engineers and geologists the experience we have gained from complex reservoir analyses.
Pressure transient data analyses reviewed in this paper were from three complex reservoirs: 1) a partially penetrated oil reservoir with faults and aquifer support, 2) a layered oil reservoir with a horizontal wellbore, and 3) a gas storage reservoir with internal faults. We found that analytical models were useful for reservoir model diagnosis but inadequate for delivering reliable reservoir parameters for the more complex situations. With guidance from the analytical models, numerical welltest models helped us to gain insight into the structural complexities