bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Structured Approach to Benchmarking Bit Runs and Identifying Good Performance for Optimization of Future Applications
Authors: Miller C. , Duerholt R. , Richards A. , Briggs N. 
Published: March 2009

Abstract
Performance analysis of large numbers of bit runs is often anecdotal and uses historical cost data. To this end, there are numerous problems with this approach. There is no uniform approach to identifying good performance. At best, the analysis provides an imprecise picture of overall performance. Large datasets need to be condensed into runs of interest. Difficulties arise when comparing multiple runs through long intervals with variable thicknesses of hard stringers. Since BHA, rig, and other costs change over time, it is problematic using historical cost per foot (CPF) data for the current target well. Finally, how does one determine if long slow runs or short fast ones are better since both could have the same CPF?
In this paper, the authors discuss a structured benchmarking method that can be applied regardless of the application or area studied. The basic process is simple and can be tailored to the requirements of different applications. The goal is to deliver a statistical benchmarking process that helps filter large sets of data and facilitates a consistent approach to bit performance analysis that is independent of historical cost data. A process flow chart is developed to guide engineers step-by-step through the benchmarking method. Good offsets are identified and included in the benchmarking population. Eligible bit runs are then ranked by a new key performance indicator (KPI): ROP*Distance Drilled. No historical cost data is included in the analysis. A detailed engineering study is then carried out on the identified best runs to develop recommendations for future applications. As the last step of the process, a financial analysis is carried out using cost data for the current well.
The paper will describe the use of this process to analyze bit performance in the operator's gas drilling operation and show how it allowed the identification of ‘true’ unbiased top performance. The benchmarking process standardizes performance analysis and ensures sound engineering principles are applied resulting in a better understanding of past performance and better recommendations for future applications.
Taking Advantage of Real Time Data in Upstream Operations
Authors: Wiemers Suzan 
Published: March 2009

AbstractExxonMobil Upstream has a standard global operations surveillance tool for new production sites which has been in use since 2003. The solution is a data historian which together with customized graphical user interfaces enables delivery of real time data to engineering, operations, and management desktops in startup production operations. The uptake success and popularity of this tool has led to expanded use in existing fields. A globalization project is now underway to ensure delivery to all key production assets by 2011 while continuing to deploy to new operations. Strategies and production examples presented in this paper exemplify "Digital Oilfield" principles: people, technology, processes. Business challenges solved with standard global technology solutions demonstrate successful operations at an enterprise level.
Quest for a Pragmatic Drilling Fluid Performance Index—Key to Improving Fluid Performance and Optimising Quality Well Delivery Economics
Authors: Osode Peter , Al Farsi Mohamed , Stevenson Eddie 
Published: March 2009

Abstract
Over the years there have been numerous attempts at establishing a key performance-measuring index (KPI) that would allow comparisons to be drawn with drilling activities in different locations. In the case of drilling fluids no model has gained any universal acceptance and measuring performance in this activity has typically been left to the ‘easy to acquire’ cost/m or cost/m3 per interval drilled on a campaign well basis within a specific field.
Drilling fluids cost across the oil industry range between 5–25% of the well construction costs. If we continue with the traditional cost focused indices then at the low end of this range there is no visible incentive to reduce costs and hence no drive to measure nor improve performance in many of our locations.
The real drivers to improve performance lie with the impact on the overall well performance and field development economics in terms of Non Productive Time (NPT) and deferred or impaired production and these can be significant. A pragmatic approach is being developed within Petroleum Development Oman (PDO) that embraces the importance of NPT data as a measure of drilling performance and addresses the issues of production performance of the well to identify well improvement opportunities.
This paper reviews the existing mud performance parameters and their drawbacks, presents a practical prediction technique for drilling mud cost based on existing offset field/well data which is less complex than the typical functional drilling cost models (Kaiser 2007)1 and describes how to integrate mud-related cost factors into a simple Mud Quality Index (MQI) equation. The underlying assumptions and limitations of the new KPI will also be discussed to determine any further improvements deemed necessary. Using real data from some PDO fields, MQI data was generated for a group of wells and compared to the old mud cost matrix data to show the disparity in the wells performance ranking based on the different KPIs. The KPI tool is expected to facilitate drilling fluids planning, design and management decision-making on the capital-intensive exploration, deep appraisal and development drilling projects when fully deployed.
An Integrated Approach Towards Building an Enterprise GIS System for Petroleum Industry
Authors: Puripanda Naresh Kumar , Shamsan Fahad 
Published: March 2009

Abstract
With rapid advancement in technology and familiarization with spatial imageries, Petroleum Industry users see the benefits of organizing and managing information geographically using GIS, especially for companies with huge data like Bapco. An Enterprise GIS System was initiated and being implemented within Bapco.
The enterprise GIS system will help to manage data related to all aspects of Bapco's business units in an effective manner. A number of feasibility studies & workshops like Business Change, System Benefits, Success Measures, Application / Data need assessment, Stake-Holder Meetings have been held. The GIS need assessment includes a review of user work requirements and identifies where GIS application can improve user productivity and quality. The information system includes data from Oil and Gas assets, production, transmission, marketing, exploration, refining, environmental etc. The Enterprise GIS System is expected to provide a cost-effective method to access, monitor, analyze and manage data that is spread in different areas within the company and bring them under one platform. This migration consolidated fragmented data into a centralized repository; integrating with external applications and work flow processes like Petrovision, Wellview, OGN, OFM, IP, Petrel, Geoframe, IESX, Gocad, Pipesim, etc; and serving data to the enterprise GIS System.
This paper discusses the approach adopted by Bapco towards building an Enterprise GIS System.
Best Cleanup Practices for an Offshore Sandstone Reservoir with ICD Completions in Horizontal Wells
Authors: Shahri Ali M. , Kilany Khalid , Hembling Drew , Lauritzen J. Eric , Gottumukkala Varma , Ogunyemi Olusegun , Moreno Oscar Becerra 
Published: March 2009

Abstract
Achieving effective cleanup while flowing back the well after drilling is key for maximizing productivity and minimizing near wellbore damage. This paper discusses the best practices for cleanup in a sandstone reservoir drilled with oil-based mud (OBM), and installed with inflow control device (ICD) completions. The findings are based on the evaluation of different cleanup methods: coiled-tubing deployed nitrogen kickoff, chemical treatments, artificial lift-electric submersible pump vs. natural flow, time spent on cleanup, and flow rate.
Applications include sand control completions run in open hole with ICDs over long horizontal sections. Results show that in relatively high darcy sands, using proper chemical treatments and spending more time for flow back with higher rates will maximize productivity and minimize near wellbore damage. Choosing the correct and effective cleanup method will minimize near wellbore skin, maximize productivity, effectively drain the reservoir and save intervention costs for cleanup.
Production Enhancement for Khafji Field Using Advanced Optimization Techniques
Authors: Al-Khaldi Mohammad A. , Ghoniem El-Sayed Ouda , Jama Ali Ahmed 
Published: March 2009

Abstract
The gas lift, by limited capacity of 25 MMSCF/D, was introduced for Khafji field in 1988 which could successfully sustain target rate until mid of 2004. Artificial Lift is part of the long term production sustainability solutions for Khafji Field necessitated by the increase of field water cut and depletion of reservoirs. In order to make up for production decline in Khafji Field and to sustain the field target rate and defer large investments associated with exploration and drilling new wells as well as commissioning new facility expansions, Production Optimization and de-bottlenecking of the existing production system was found to be the best cost effective solution. For that purpose, general optimization and gas lift allocation models have been built and applied for Khafji field as presented by Ghoniem et al1, 2.
This paper is an extension to the previous papers for Khafji Field cited above. The optimization approach presented in this paper is based on a field-wide production planning solution, which is achieved by combining steady-state multiphase network simulation with a nonlinear, multivariate optimization technique called Genetic Algorithm (GA) through a newly developed and commercially available optimization application called Avocet Gas Lift OptimizerTM.
The present work therefore represents the introduction of a new optimization platform for Khafji crude production and its results with a particular focus to:Building a comprehensive network model for Khafji Field (including wells and production facilities).Demonstrating production gain by the use of advanced optimization techniques (e.g.GA) to sustain field quota.Optimally distributing limited gas lift availability to Khafji Field to enhance production, while taking into multiple well and field constraints.

Introduction
Khafji field lies in the Arabian Gulf, 40 km east of Al-Khafji city, Saudi Arabia (Fig. 1).The field is composed of several reservoirs for sweet crude. The most prolific ones are 1st and 2nd Bahrain sand. Where, a strong and an active aquifer provides pressure support and water drive to 2nd Bahrain and to a lesser extent to 1st Bahrain. In addition, four other oil reservoirs are currently active namely Ahmadi limestone, B-limestone, Wara sand and Zubair sand which are commonly referred to as minor reservoirs.
In Khafji field, there are approximately a hundred wells which are already completed with gas lift injection system. Even though, many remaining gas lift wells are still producing naturally with lower rate, some others are currently being shut in. Thus, the most effective wells for gas lift operation were defined by performing lot of screening using gas lift allocation models.
Method to Generate Fullbore Images Using Borehole Images and Multi-Point Statistics
Authors: Hurley Neil F. , Zhang Tuanfeng 
Published: March 2009

Abstract
Borehole image logs, produced by tools lowered into a well, provide oriented electrical and acoustic maps of the rocks and fluids encountered in the borehole. Electrical borehole images in water-based (conducting) and oil-based (non-conducting) muds are generated from electrodes arranged in fixed patterns on pads that are pressed against the borehole wall. Depending on the borehole diameter, gaps nearly always occur between pads. Because of these gaps, it is common to have non-imaged parts of the borehole wall.
Fullbore images are complete, 360-degree views of the borehole wall. They are generated by "filling in the gaps" between the pads of borehole-image logs. This method uses the FILTERSIM algorithm of multi-point statistics to generate models, or realizations. Measured (incomplete) borehole images themselves are used as "training images." Recorded data are perfectly honored, i.e., the models are conditioned to the real data. Gaps are filled with patterns similar to those seen elsewhere in the log. Patterns in the gaps match the edges of the pads. The frequency distribution of continuously variable pixel colors in the gaps matches the distribution of pixel colors in the measured images.
Fullbore images facilitate visualization and interpretation of borehole-image logs. They can be used to draw closed contours around electrically resistive or non-resistive patches in the borehole wall. Fullbore images can be used to repair logs with bad electrodes, low pad pressure, or poor acoustic reflections. Therefore, they can be used to enhance any commercially available electrical or acoustic borehole images.
Expandable Sleeve Isolate Shallow Aquifers
Authors: van de Velden Mark , Al-Houqani Said , Al-Busaidy Hilal , Saltel Jean-Louis 
Published: March 2009

Abstract
A major Middle East Operator has adopted a new type of solid expandable tubular technology to isolate shallow aquifers as well as fractured formations. The technology is based on a steel wired balloon expanding a stainless steal into the well bore. The simplicity of the technology combined with a significantly increased expansion ratio has opened a whole range of new applications to materialize low cost wells. This paper will outline the two trial wells in which the technology was applied, review the benefits of expandable tubulars for these applications as well as looking in candidate selection. Particular emphasis is given on the Operator's experience with the technology.
Isolation of shallow aquifers and fractured formations while drilling has been a major challenge for many years in Oman. The requirement for zonal isolation of the shallow aquifers is often compromised by the total losses encountered. Often a cocktail of chemicals followed by multiple cement jobs are used to achieve the objective. The latter can be costly not to mention the extra time incurred and HSE exposure. Also failure to isolate aquifers also increases the risk of cross flow between fractured formations what has been a significant contributor towards free water corrosion of the surface casing strings as well as subsequent issues referring to un-cemented casing strings in thermal wells.
Inflating a sleeve into the formation has proved successful in terms of installation reliability, isolation of fractures and isolation of shallow aquifers. Well configuration based on expandable tubular solutions have improved well delivery times what is making this expandable technology a strong case for wells to be drilled in the coming years.
Identification and Characterization of Producing Fractures in Naturally Fractured Reservoirs Using PIWD
Authors: Berkat Ali , Kartobi Khelil , Cherif Mazouz M , Qutob Hani , Barakat Naiem 
Published: March 2009

Abstract
Early recognition of a fractured reservoir and an estimation of its rock characteristics, such as porosity and permeability, will influence the location and number of subsequent development wells and, therefore, is of major economic significance on the future development of the field.
Underbalanced drilling provides an unprecedented opportunity to examine a reservoir as it is being drilled. With proper data acquisition and engineering interpretation, underbalanced drilling allows us to measure and calculate the Productivity Index while Drilling – PIWD. This data helps us locate and identify geologic anomalies such as fractures, tight zones, pinch outs, discontinuities, and water zones. A better understanding of the fracture networks and their impact on the production is critical to optimize infill drilling and produce the remaining reserves in any reservoir. Also, PIWD graph is a good indicator of reservoir productivity characterization. The real time data obtained using this graph can clearly show what kind of reservoir is being drilled and what kind of production can be expected.
This paper reviews and analyzes oil production while Underbalanced Drilling of two wells in Hassi Messaoud field, Algeria. The interpretation of PIWD graphs demonstrates the existence of producing fractures. The results were confirmed during the Build-up test interpretation. Also, the image logs were correlated with production data to make sure they are in agreement. Every point on the image logs where signs of fractures were observed were studied and compared to the PIWD profile to establish a correlation type. This review is an attempt to examine the ability to predict the presence of fractures in future UBD wells in Hassi Messaoud field based on the production while drilling profile where image logs can not be run.
Meeting the Challenges of Natural Gas Market in Bahrain
Authors: Al-Mahroos Faisal , Al-Anaisi Abdulla 
Published: March 2009

Abstract
Natural gas is the main source of energy for the Kingdom of Bahrain and contributes more than 85 % of the total energy consumption in the country. The main source of gas is the Khuff reservoir which was discovered in 1948. These abundant gas reserves were stranded for 20 years as no commercial or monetization projects were forthcoming.
However the rapid increase in industrialization program since 1969, compelled a steep demand for electricity and hence the increase in gas production. The steady demand growth driven primarily by power sector will continue to increase by about 4% annually while the industrial sector will be supply constrained.
Maturation of both the gas supply and the emerging gas markets raise issues of concern on the supply side as well as the demand side.
On the supply side, drop of reservoir pressure results in lower well deliverability and loss of natural cooling effect while water encroachment will result in drop in wellhead pressure, gas souring and water production. These require huge investment to ensure adequate gas supply.
On the demand side, the uneven growth of power sector (which consumes most of the gas) and the fluctuations in peak gas consumption leads to large uncertainties in the development of the field. Technologies and efficiencies as well as the economic cycles also represent additional concerns on the demand side, in addition to the large lead times that are required to build facilities and acquire equipment.
Even to maintain the current levels of energy demand alternate sources of gas / energy supply have to be cultivated. As this will come at a certain cost, it will have a significant impact on the economy of the Kingdom.
This paper discusses the effects of all the above issues on this mature asset and draws conclusion from experience of Bahrain on sustaining the long term economic growth by effectively managing its domestic natural gas supply and demand balance.
Utilization of In-Situ Gas Lift System to Increase Production in Saudi Arabia Offshore Oil Producers
Authors: Warren Phillip , Logan Sami , Zubail Makki , Balto Abdulelah , Perez Simeon , Aramco Saudi , Villarreal Adrian , Becerra Oscar 
Published: March 2009

Abstract
This paper discusses the first Smart in-situ gas lift systems that were installed in three Saudi Arabia offshore wells. These Smart in-situ gas lift systems have proven to work in an offshore development environment for production enhancement. Implementation of this technology will extend the well life by allowing high water cut wells to produce, rather than become inactive, due to high hydrostatic back pressure in the wellbore. The selection of this system, which uses reservoir gas cap energy as compared to other artificial lift methods, resulted from economic considerations and operation simplicity in a non-electrified offshore field.
The primary focus of this paper will be to discuss the first in-situ gas lift equipment, completion installation procedures, field test results, operation principles utilizing the gas cap energy, production strategy and well performance using an online monitoring system, and reservoir management considerations for future installations within the field.
Initially, five conventional in-situ gas lift systems were installed in the field with problematic downhole sliding sleeve assemblies that required wireline intervention. As a result, Smart in-situ gas lift systems were recommended to allow auto opening of the downhole gas lift orifice valves from surface. These Smart systems have proven their durability over conventional systems, and will extend well life at a relatively higher water cut and maximize reservoir sweep efficiency.
Hanifa Exploration Potential on the Flank of the Bahrain Field
Authors: Qassim Naji , Pathak Ravi Kant , Al-Alawi Habib 
Published: March 2009

Abstract
The Jurassic Hanifa formation is known to be a very good regional source all over the Arabian Gulf and it is reported to be producing in some of the fields in the area. This study focuses on the Hanfia exploration potential especially around the flank of the Bahrain field. It has been observed that some of the wells in N.Eastern flank of the Bahrain field are showing some indication of oil in the Hanifa reservoir. Theoretically, stratigraphic porosity and permeability controlled traps are expected between NE Bahrain Wells and the Bahrain field.
Based on seismic attributes analysis and inversion as well as integration of well data the full potential of this formation is being assessed.

Introduction
The Jurassic petroleum systems of the Arabian Peninsula form one of the most prolific petroleum producing system in the world. Source rocks of this system extend throughout the eastern Arabian Peninsula and Arabian-Persian Gulf. Primary elements of this Jurassic petroleum system - source, reservoir and seal rocks—are of great areal extent. The regional extension of this petroleum system and formation of subtle structural closures and / or stratigraphic traps prior to, or coincident with hydrocarbon generation and migration are significant for prospect generation. Structures that trap hydrocarbons in this system in Arabian Peninsula are mostly 1) large, gentle anticlines formed from reactivated basement fault blocks, 2) salt domes and 3) structural traps resulting from combination of these two processes. Hanifa oil accumulation is also reported within stratigraphic traps due to facies change.
Hydrocarbon presence has been reported during drilling OF well #F #H n the Middle Jurassic section within Hanifa. Hydrocarbon shows were also reported within Hanifa at Well #C All the above wells are located at north-east flank of Awali. It is interesting to note that Hanifa section encountered at up dip Well #A was found to be water bearing.
This integrated study was initiated to outline the Hanifa prospect at Awali flank in general and north-east flank (Fig 1) in particular. The preliminary finding of the study as well as further G & G work envistaged to convert it into drillable prospects is documented in this study.