bluuebunny/crossref_metadata_2025_split huggingface dataset:
Determining the Risk in Applying Multilateral Technology: Gaining a Better Understanding
Authors: Waddell Kevin K. 
Published: December 2007

Abstract
Traditionally, operators have reviewed experience from other job scenarios to assess feasibility when considering application of a technology. Therefore, when data concerning field usage is limited, as is the case for emerging technologies, new concepts that show promise of providing significant economic benefit are oftened abandoned. Generally, this is because of misconceptions concerning the associated risks of its usage. Since the assessment of the benefits of new technology cannot be based upon previous experience, an accurate method for understanding the "unknowns" of a new technique and analyzing the probable economic ramifications has been needed.
This paper will present a methodology that has been developed to overcome the assessment difficulties that accompany the use of new technology. This analytical process will attempt to quantify risk factors and determine event probabilities in the application of an emerging technology so that the unknowns previously supplied by experience can be predetermined in the application of new concepts. The process, its analytical concepts, and the model development that has been designed to assist operating companies in determining field applications for one of the new completion concept in the oilfield — multilateral technology — will be presented.
The analytical system discussed in this paper considers the difficulties in risk analysis for an emerging technology and uses the established techniques of "Quantitative Risk and Decision Tree" analysis and Monte Carlo / Latin Hypercube analytical simulation to correlate information that has been developed by operational and experience databases. The system facilitates the benchmarking of associated risk-weighted cost of system installation, determines "cutoff" points, and evaluates probable outcome impacts on the net present value (NPV) of a project.
Included in the paper are several examples and one case history. The information will provide a technique that will help answer questions raised in the process of risk assessment, not only for the specific area of multilateral technology to which it has been applied, but for other concepts as well.
Cementing through High Pressure Coiled Tubing on HPHT Khuff Gas Well Offshore Abu Dhabi
Authors: Mazen A. , Rouatbi R. , Zaki S. 
Published: December 2007

Abstract
Multizone selective production testing of a gas well is a time consuming and costly operation. A Khuff formation is a High Pressure High Temperature (HPHT) and high flow rate gas reservoir with the presence of H2S and CO2. Traditionally, the multizone zone selective production testing operations for Khuff gas wells were performed using conventional methods. The use of Coiled Tubing (CT) on Khuff gas wells was limited only to displacing wells to diesel prior perforating the Khuff reservoir.
This paper describes ADMA-OPCO experience to utilize a High Pressure Coiled Tubing (HPCT) package for the first time in Abu Dhabi and Offshore the Arabian Gulf to perform the different operations involved in the multizone selective production testing of a gas well with the objectives of safely reducing the operating time and costs.
Gas Conservation and Flaring Minimisation
Authors: Tarmoom Ihab Othman 
Published: December 2007

Abstract
Environmental issues have always been important in the oil and gas sectors and it has become more essential for this industry to control and minimize the undesirable emissions and discharges into the atmosphere. Abu Dhabi National Oil Company (ADNOC) has adopted new environmental guidelines to be followed by all the oil and gas affiliate companies in Abu Dhabi and in particular launched a strong campaign to conserve gas usage and minimize flaring with an ambitious objective of zero flaring.
ADNOC established a task force comprising representatives from all Abu Dhabi oil & gas companies in both upstream and downstream sectors of the industry to define, review and study gas flaring and gas conservation.
International consultants from all over the world were invited to participate in reviewing the companies facilities to cover the scope set by ADNOC which covers but not limited to the following study areas.
Recover and utilize the continuously flared gases Conserve and Rationalize gas usage. Identify areas were zero flaring could be achieved whilst maintaining the integrity, safety and reliability of the system.
This paper shall cover the outcome of the studies that were recently conducted. It addresses results that have been achieved to date, the areas where potential gas conservation and reduction of gas flaring have been identified. In addition, it will touch on the ambitious future ADNOC plans for achieving zero flaring.
Water and Gas Tracers at El Furrial Field
Authors: Vilela M. A. , Zerpa L. B. , Mengual R. 
Published: December 2007

Abstract
El Furrial field is an anticline structure that has been exploded since 1986. In order to keep pressure, a water injection program by the flanks of the reservoir was started in 1992. In 1995 four different radioactive tracers were injected through 14 wells, aiming at getting a correlation between producing well and injectors. In this paper the result of the water tracer program developed at El Furrial field is discussed; 14 tracers breakthrough at the producing wells, one of them in November 1996 and the others during 1997 and 1998.
Previous reservoir and geological studies were conducted determining the connection between wells and sands. With the tracer responses we have got new ideas about the correlation among wells, e.g. sealing faults, channeling between producing wells and injectors, barriers, etc. In this paper we match both results.
Additionally, in 1998 a gas injection program was started at the crest of the field. Together with gas injection, a gas tracer program was planed to be carrying out. Here, is presented the design of gas tracer injection for the 5 gas injecting wells.
How to Improve E&P Knowledge through Competency Model Development and Self-Learning Processes
Authors: Brandt R. , Vargas de Alamo N. , Rondón L. , García A. 
Published: December 2007

Abstract
This article summarizes the efforts made by the Production Business Unit of Petroleos de Venezuela, PDVSA-Producción, in the area of Competencies, with the aim of optimizing its levels of excellency in a globalized market each time more competitive and presenting price scenarios that are scarcely favorable.
In this regard, the strategic orientation established by the corporation is defined, indicating, as a fundamental element, the creation of the Competency Development and Maintenance Management – DMC. DMC's mission is to guarantee highly skilled personnel with the critical competencies required for complying on time the objectives of the Business Plan. Its vision is that of positioning PDVSA Production as a leading company in the development and maintenance of its personnel's competencies, while integrating the process of competency development into the processes of the business.
Concrete actions were taken by DMC in the areas of Recruiting and Training personnel, highlighting the design of a Competency Measurement tool – SADINAP -, as a fundamental support for handling managerial information.
The second part of the article refers to Virtual Technology as an element that facilitates the design and implementation of a virtual system of distance education – VLS – whose pilot phase is currently being developed. There is also particular emphasis on the role played in this project by the Communities of Knowledge through specialists who are considered as critical factors of success.
Lastly are mentioned the aspects related to a Program of Sustainable Self-development. This Program translates DMC's actions – oriented towards propelling the behavior in the organization in terms of acceptance or rejection – into the implementation of new training technologies or modalities, aiming to take on time actions oriented towards definitively establishing a self-development culture in the organization.
Sand Control in Open Hole Horizontal Wells-Case Histories and Developments
Authors: Rovina Paulo S. , Filho Everaldo Lima 
Published: December 2007

Abstract
The discovery of new fields in the Amazon forest and in deep water offshore Campos Basin, all of them consisted of unconsolidated sand, led Petrobras to adopt non conventional wells and sand control techniques. The main goals were to increase productivity, delay gas/water conning and support unconsolidated formations in water injection wells.
The first horizontal well was completed in December 94 in Rio Urucu field. Since there was only one zone to drain the barefoot completion was suitable to all fields.
This paper will describe the experience acquired running screens in 28 horizontal open hole wells in Brazil. Among them 19 have been producing oil and 1 injecting water. The other 8 haven't been connected yet to platforms so only results of production (or injection) tests will be reported.
Several improvements were made on the equipment, drilling fluid, procedures and in the well design due to the problems faced during the execution of the jobs.
As a result, the main objectives were achieved and new trends were established aimed at deep water fields development.
Recently, some horizontal wells have been gravel packed and better productivity indexes were reached. The main issues and results for those gravel packings (three jobs so far) will be mentioned.
A Fiber-Optic Inspection System for Prepacked Screens
Authors: Hamid Syed , Lester G. Scott , Adkins Darrell W. 
Published: December 2007

Abstract
Screens are one of the most critical components of a well completion. A screen failure is generally serious, requiring a workover, a sidetrack, or, in the worst case, abandonment of the well. Prepacked screens are used extensively in well completions primarily where there is an increased concern for sand control reliability. These screens have performed successfully in the industry with a few exceptions. One of the reasons for the varying degrees of performance is the difficulty in the inspection of this type of screen.
Performance of a prepacked screen depends on pack thickness and pack tightness (or density). The local pack thickness is dictated by the concentricity of the inner and outer jackets of the screen. Eccentricity between the inner and outer jackets leads to thin packs (on one side) resulting in high, localized fluid velocities, which tend to promote erosion of the screen. It is difficult to nondestructively measure the pack thickness and tightness. As a result, the screen must be inspected by the conventional method by shining light from inside and visually inspecting for defects. At best, this is a qualitative method that is inherently operator-dependent. To overcome these difficulties, a fiber-optics-based system has been designed and tested to inspect the prepacked screens. A mathematical model has also been developed to predict the passage of light through a pack of gravel.
Due to the availability of this inspection system, several modifications have been made in the screen manufacturing process that achieve previously unattainable concentricity and pack tightness. A large number (i.e., 550) of screens have been tested using this technique with excellent results. The different pack thicknesses and gravel sizes can be easily discerned with this inspection technique, which leads to a better quality product.
Use of the Combined Resistivity and Acoustic Image Logs in Designing Patterns of Injection and Producing Wells in a Waterflooding Project
Authors: Saavedra Benito , Basso Alejandro Lopez , Yarke Carlos , Breda Eduardo , D'Angiola Marta 
Published: December 2007

Abstract
This paper describes important structural and sedimentological conclusions obtained with the use of the combined images log (resistivity and acoustic) STAR which was run in the well LP -1404 of Los Perales - Las Mesetas field (San Jorge Basin-Argentina), and their application in the design of the pattern of injector and producer wells in a waterflooding project currently being implemented. A detail of those conclusions is the following: It was confirmed, with the study of the breakout in the acoustic image, the previous hypothesis that it was a structural scheme of tectonic inversion.The statistical study of the open and closed fractures identified mainly by the combination of the images produced by the transit time and the amplitude of acoustic wave, led to obtain the direction and angles of the identified fractures.The statistical study of the strata planes identified in both images let to obtain the angle and trend of the layers by structural effect, being possible then, to define the directions of sedimentation of the psamítics bodies that compose the reservoirs of the field, making the subtraction of the structural dip to those that belong to those sandstone levels.
The definitions of the main directions of the sand bodies that compose the reservoirs of the studied area and, with the breakout study, the directions of the current maximum and minimum stress of the block that belong the well LP - 1404 allowed to design the pattern of injector and producer wells in a waterflooding project currently being implemented. In the paper there are details of this study.
Cost Reduction in Downhole Completion Equipment Supply: A Case History
Authors: Watson Graeme , Hibberd Roger , Turner Will , Hidding Gert Jan 
Published: December 2007

Abstract
Effective coordination of the supply of downhole completion equipment is critical for oil and gas companies. The process usually includes planning, procurement, storage, call off and onshore preparation of completion components and assemblies. At current daily costs for rigs and fixed platforms, the consequences of late supply or failure of just one item can be significant and may exceed the original purchase cost of the entire completion.
Major completion components include subsurface safety valves, landing nipples, circulating devices, expansion joints, production packers, and seal assemblies. Hundreds of components may be handled due to variations in well type, well conditions, casing size, tubing thread, and individual well engineers' preferences. Accessory items such as pup joints, flow couplings, blast joints, and crossovers must also be coordinated. Involvement of several different suppliers can further complicate the process.
Two operating units of a major North Sea Operator have joined forces to implement a new approach to improve efficiency and reduce the overall cost of downhole completion equipment by issuing a joint, pan-European tender. European Community regulations were adhered to in generation of a "functional requirements" tender, as opposed to a full specification tender. This enabled potential suppliers to propose "fit for purpose" equipment which already has a proven track record rather than new designs, which would require testing to prove compliance with a client specific specification. Following the "functional requirements" tender, a commercial tender was completed. The commercial tender included options for the level of materials management covered by the service companies who satisfied the functional requirements.
Details of operating value drivers used to direct focus on potential cost savings are described as well as how total cost of ownership has been reduced to the benefit of both the end users and the lead suppliers.
Performance measures developed for the agreement are discussed, as well as how these measures reflect progress towards stated goals.
The authors feel that the processes and procedures presented in this paper have considerable potential benefit to other oil and gas operating companies.
Reservoir Conformance Approach and Management Practices for Improved Recovery Opportunities: Process and Case History
Authors: Soliman M. Y. , East L. , Gorell S. 
Published: December 2007

Abstract
The realization that the majority of the world's reserves exist in mature reservoirs has resulted in new urgency to develop methods to resolve excessive water production and improve recovery efficiency. Predicting water influx problems, selecting candidate wells for water control treatments, and justifying expenditures are critical factors for developing improved reservoir management strategies.
Optimum reservoir management strategies begin with an understanding of fluid flow behavior in the reservoir under both production and injection conditions. This understanding allows for the creation of conceptual models that illustrate the flow of fluids in reservoirs and serve as a means of communicating management strategies to all participating in operations and business functions. This concept emphasizes the use of the total reservoir approach.
This paper will present a technique that uses reservoir description to develop management strategies for improved reservoir recovery through application of conformance technology. "Conformance" — as used here — may be defined as the management and alteration of water and gas flows using the appropriate reservoir understanding to optimize hydrocarbon production. This approach clearly emphasizes the importance of forming multi-disciplinary teams to resolve excess water production problems. The teams are not only multi-disciplinary but also multi-company, including personnel from both the operating and service companies. The goals of the teams should be to: Build a reservoir model that incorporates the static and dynamic properties of the reservoirValidate the modelUse the model to illustrate the fluid movement in the reservoirDevelop a strategy for managing excessive water productionSelect treatment candidatesImplement the strategyEvaluate results.
The application of this "total" approach is illustrated with a case history. In this case history, reservoir data are discussed, and a conceptual model that describes a problematic water flow mechanism is developed. This model is then used to develop a reservoir management strategy that incorporates conformance technology to improve the existing recovery factor of 9.5% to an expected recovery factor of 40%.
Particle Size Distribution Selection of CaCO3 in Drill-In Fluids: Theory and Applications
Authors: Cargnel R. D. , Luzardo J. P. 
Published: December 2007

Abstract
Bridging agents are used in Drill-In fluids to prevent problems of massive loss circulation to the formation and formation damage through fine solids migration that invade the hydraulic flow channels of the reservoir rock. Also, thick cake build up that induces a differential sticking problem, as well as torque and drag of the drill string are avoided.
The first step when selecting the particle size distribution of bridging agents (specifically CaCO3) in Drill-In fluids is the petrophysical characterization and pore geometry determination of the rock. In consolidated sands, the criterion of selection of particle size of bridging agents is: 1/7 Dpore throat&lt;Dparticle&lt;1/3 Dpore throat. CaCO3 from different sources were selected with a particle size distribution within the described interval, determined by using a particle size distribution analyzer through LASER dispersion technique. In order to prove experimentally the effectiveness of the formed cake, dynamic filtration tests were conducted in aloxite synthetic cores previously characterized.
Determination of the pore and pore throat diameters were performed through S.E.M imaging technique. Verification of the particle size distribution of the CaCO3 to be used was carried out through LASER dispersion technique. Results of the dynamic filtration tests are reported.
Multilevel Injector/Producer Wells in Thick Heavy Crude Reservoirs
Authors: Fernandez Belkis , Ehlig-Economides Christine A. , Economides Michael J. 
Published: December 2007

Abstract
With modern drilling techniques it is now possible to drill wells with multiple branches emanating from the same vertical or even horizontal trunk. Several heavy crude reservoirs are very thick and had they contained light crudes, their vertical permeability could make them attractive for single horizontal wells. Unfortunately, the much higher viscosity of the reservoir fluid results in highly unfavorable mobility. Thus, drilling several horizontal branches at different levels of the reservoir would effectively create thinner drainage areas and this, in itself, would be attractive because in thin reservoirs the vertical mobility is far more forgiving. However, a clear benefit in heavy crudes is derived from thermal recovery and a scheme is suggested here, where either steam is injected at the top of the reservoir or hot water is injected at the bottom through a dedicated horizontal well injector. (From an operational point of view it is desirable to use the same vertical trunk for both injection, e.g., through the tubing and production through the annulus, or vice versa.) The optimization strategy is to estimate the desirable number and spacing of the producing laterals. The vertical spacing is not even, but instead, it depends on the crude oil viscosity, that, in turn, is affected by the heating process. We present in this work a methodology of multilevel well optimization and several case studies for different numbers of laterals and their vertical spacings.
Selecting the Appropriate Rodless PC Lift System for a Highly Deviated Wellbore
Authors: Chachula R. C. , Mann J. S. 
Published: December 2007

Abstract
The process of developing various versions of rodless progressing cavity (PC) lift systems has been a major area for technological research and development work at PanCanadian Petroleum Ltd. Inherent production problems associated with highly deviated wellbores experiencing solids, varying aromatics and emulsions is consistently burdening the oil industry, especially as lifting and well intervention costs rise in environmentally sensitive areas. Through a collaborative venture with REDA, new and innovative systems have been developed and implemented to combat and overcome these operational problems. The recent developments of rodless PC systems have provided operators with an alternative approach to producing reservoirs from a conventional perspective.
Field results from medium crude oil reservoirs located below Lake Newell in southeastern Alberta, Canada suggest that pump performance and annular drawdown is mainly impacted by wellbore configuration, high solution GOR's and reservoir fluid rheology mechanisms. Conventional electric submergible pumps (ESP) and gas lift have been the artificial lift systems of choice to produce the highly deviated wellbores contacting the reservoirs. However, due to the apparent producing inefficiencies and costly workovers, alternate innovative lift systems to optimize operations were necessary. This prompted the need to develop systems to reduce downhole operating expenditures while achieving pumped-off capabilities.
This paper describes the evolution of bottom motor driven PC units, the selection process utilized in determining the final prototype system deployed and the results of the field trial. Modifications made to the equipment design and techniques to optimize pumping operations is discussed. It is hoped that the conclusions derived will be of benefit to other projects contemplating alternate system designs from the traditional approach.