bluuebunny/crossref_metadata_2025_split huggingface dataset:
Integrating Casing Drilling and Conductor Sharing Technology To Optimize Brownfield Redevelopment Plans
Authors: Erivwo Ochuko , Roed Haakon , Javaid Muhammad Omer , Ngau Christie Usun , Pickup Duncan 
Published: October 2012

Abstract
An alliance was formed between PETRONAS Carigali and Schlumberger IPM to re-develop the mature Samarang field, offshore Malaysia. Integrated studies had identified opportunities to increase recoverable reserves in the 30 year old field by as much as 10% of STOIIP from infill drilling and EOR techniques. However, with 96 wells and 48 sidetracks already drilled, the number of additional slots that could economically be made available for potentially up to 33 new wells in the redevelopment campaign was limited.
Of the several options considered to address the challenge of limited slots, conductor sharing technology was preferred over multiple sidetracks and costly slot recoveries. The size constraint of the available 36 × 13-3/8 × 9-5/8 5ksi dual wellhead system was however a concern. Offset wells analyses showed losses, tight hole and stuck surface casing problems, with several casings set shallower than planned. These challenges had historically being mitigated with a shallow 18-5/8 casing to enable setting the 13-3/8 surface casing at planned depth. The elimination of this contingency casing implied increased exposure in getting the surface casings to bottom and was mitigated with the integration of directional Casing Drilling into the surface hole plans.
This paper presents the integration of Casing Drilling with Conductor Sharing technology in the phase 1 of the Samarang redevelopment project. It focuses on the key engineering considerations (casing API connection enhancement, geometrical separation, start-up rotary anti-collision etc) applied to address the concerns associated with the technology integration in a cost-sensitive environment. The paper also discusses the highlights, lessons learnt and recommendations from its successful execution. The unique integration of Casing Drilling and Conductor Sharing Wells in Samarang is believed to be the world's 1st combination of the technologies. It's success has provided opportunity to reduce construction costs for phase 2 of the project and opened up further well design optimization opportunities in the development of challenging brown fields.
Flow Capacity Evaluation in a Complex Carbonate Reservoir: Key to Understand Reservoir Productivity and Stimulation Effectiveness
Authors: Acharya Mihira N. , Kabir Mir R. , Al-Ajmi Saad H. , Dashti Qasem M. , Al-Anzi Ealian H. , Kho Djisan , Darous Christophe , Chakravorty Sandeep 
Published: October 2012

Abstract
Flow capacity evaluation in carbonate reservoirs is known to be challenging because of heterogeneity in the rock matrix. The original depositional texture and resulting pore structure is often altered by secondary diagenetic processes such as dissolution, leaching, cementation, and dolomitization, creating complicated pore systems with varying porosity to permeability relationship. Dolomitization in particular is known to be an important diagenetic process in carbonate reservoirs, typically enhancing porosity and permeability development and making the rock less susceptible to porosity reduction due to increasing effective stress during burial. Core data taken in deep carbonate reservoirs reveal a strong correlation between degree of dolomitization and reservoir quality.
Neutron-induced gamma-ray spectroscopy logging has proven to be a powerful tool for the evaluation of dolomite content, especially in wells drilled with barite-weighted mud where PhotoElectric Factor (PEF) is not reliable. Using methods developed on a core database, reservoir rock types can be identified and matrix permeability can be estimated from a combination of porosity and dolomite content derived from neutron-induced gamma-ray spectroscopy data and other common logs measurements. Predicted flow profiles and flow capacity of the reservoirs can be calculated from the estimated matrix permeability and can be verified by comparison with available production logs and test data.
Several examples will highlight the comparison between the predicted synthetic flow profiles and the flow profiles measured by production logs, as well as the comparison of estimated flow capacity with pressure transient analysis data. Such comparisons can be used to diagnose stimulation effectiveness, identify zones dominated by fractures, confirm solid bitumen effects, and identify zones with significant formation damage. Another important application is the selection of perforation and stimulation zones to achieve optimum production based on the expected permeability contrast. This integrated approach to flow capacity prediction is proving to be an effective tool in understanding the behavior of complex carbonate reservoirs.
Structured Mentoring: A Critical Component of a Global Talent Management Strategy
Authors: Rousseau Meta 
Published: October 2012

Abstract
Competing for market share in a dynamic international marketplace, the frontrunners are those who are able to build a skilled, global workforce through multi-faceted strategies that enable them to align training, mentoring, and coaching initiatives and implement cutting-edge practices such as social and mobile learning. Structured mentoring forms the foundation of a well-designed talent management strategy. Well-designed mentoring programs enable organizations to align and seamlessly integrate training, coaching and mentoringinitiatives into holistic, personalized offerings. It is through successful structured mentoring programs that organizations are able to sustain a uniquely skilled and internally motivated workforce that sets them apart from competition. In this paper, we will consider structured mentoring in context of seven topics:
Structured Mentoring Defined Value Added Through Structure Mentorship Types and Models The Structured Mentoring Process Structured Mentorship Teams The Structured Mentoring Program Toolkit Success Factors
Mobile Applications Development for Upstream Solutions
Authors: Al-Naim Hamad A. , Al-Qurtas Abdulrahman , Awan Mohammad , Rihabe Salim , Ibrahim Mohammad , Madani HusamAdDeen , Malik Pervaiz 
Published: October 2012

Abstract
The rapidly evolving tablet and mobile devices have proven their overwhelming popularity, not just as entertainment devices but as valuable productivity tools for enterprises and professionals. Furthermore, mobile computing is becoming an integral player in the Information Technology industry, thereby influencing the design of software applications required by oil and gas organizations.
The new generation of tablets and smartphones can be effectively utilized for real time data monitoring and reporting. This can be achieved through the deployment of Upstream software solutions, such as GIS supported reservoir performance monitoring applications, management reporting dashboards, and engineering analytical tools.
This paper provides an overview of an assessment project initiated by Saudi Aramco to evaluate the development and deployment of oil and gas Upstream software solutions on mobile devices. The assessment focused on capitalizing on the capabilities of these devices for adding business value and building in-house expertise in the area of mobile application development. The paper will summarize the assessment findings and recommendations for the future direction of applications development methodology and requirements.
Pushing The Limits Of Downhole Sand Control: E Field
Authors: Thilagalingam J. , Natasha M. S , Jadid M 
Published: October 2012

Abstract
The E Field, with depletion type reservoirs offshore Sabah, started first production in the early 1980's with no active sand control measures where all the wells, many of which were horizontal, were completed as cased hole and perforated. After some 25 years, most wells began to produce sand along with high gas production, causing supply curtailment with some wells requiring shut ins. A new development plan executed in August 2010 involved drilling five new wells from an existing platform to include active sand control as part of the overall strategy. Due to the costly gravel packing operation coupled with the potential high skin in such completion, a new sand control approach was adopted. The key to this approach was to limit the production drawdown to a certain level by maximizing the well productivity index (PI) through open hole completion and to avoid sand influx at the early stage. Stand alone screen (SAS) completion consisting of a selected screen of a specific slot size was installed in the open hole, acting as a second production barrier in the event sand influx occurs.
The geomechanic study on E field data suggested that with ongoing depletion, the new wells would exceed the critical drawdown pressure (CDP) and sand production is expected from day one as evident from sand production issues in the field. However, it was decided to test the limit of this study with consideration relying more on the inherent strength of the rock as reflected by the high unconfined compressive strength (UCS) data of over 5000psi and thus the wells were completed with SAS in open hole. Permanent downhole gauges (PDGs) were installed in all the SAS wells to monitor the production drawdown closely, especially during the initial production phase.
The target reservoir is semi-consolidated laminated sandstone with poorly sorted sand of uniformity coefficient (UC) value of over 15 and d10 finer size sand content of over 10%. Based on retention test results, the 175μm screen size was chosen as using the d10 particle size (92μm) option will likely result in excessive plugging during the projected sand failure phase. This alternative selection is effectively moving beyond the currently accepted screen selection criteria limits.
This paper highlights design considerations in E field aimed at optimising well productivity and reducing sand control cost by challenging current standards and limits commonly adopted in sand control completions. The well performance results following the revisit are also reviewed to support this unconventional approach. This is expected to contribute to the evolution of future sand control strategies. Lessons learnt during well cleanup and initial production phase with continuous monitoring from downhole PDGs are included to provide a holistic picture of this case study.
Torque and Drag Modeling Advanced Techniques and Troubleshooting
Authors: McCormick John , Liu Gefei 
Published: October 2012

Abstract
Extreme torque and drag (T&D), especially when unplanned, is a primary limiter to the reach of horizontal and extended-reach wells. Many engineers use T&D software models without a thorough understanding of how the input affects the calculations in the program. This paper describes best practices in complicated T&D modeling applications.
The discussion in this paper is applicable to wells with horizontal laterals, extended-reach wells, wells with difficult geometries, and all complicated well operations that require T&D models for planning and troubleshooting. Specifically applicable are operations that T&D programs have difficulty handling, such as running dual strings, expandable casing operations, drilling with casing, and jarring operations.
Most engineers involved in downhole operations from operators to service companies run either T&D models or base decisions related to their wells and operations on reports from these programs. Many of the engineers and managers in the oilfield can benefit from this guide on best practices for a commonly executed, but little understood, component to well planning.
Few papers address the practical application side of T&D modeling, and most engineers and managers have only a basic understanding of how to create a model or interpret the results. This paper disseminates technical information to increase global competence in a vital part of any challenging well drilled. Drilling extreme and challenging wells is becoming more common, and increased knowledge for T&D modeling and interpretation is needed.
Departure From the Norm in Polycrystalline Diamond Bit Design Allows Significant Performance Gains in Highly Erosive and Abrasive Formations
Authors: Deen Aron , Maw Jason , Knull Craig , Clegg John 
Published: October 2012

Abstract
PDC drill bits have grown from niche to mainstream products by gradual, subtle evolutions in design and materials technology. Occasionally, there have been more dramatic step changes in design or materials that have launched PDC bits into new applications. This paper will talk about such a step change: the design, manufacture and application of a contiguous blade of polycrystalline diamond. Rather than blades made up from individual cutters, as with a conventional PDC bit design, this bit has full-length, contiguous polycrystalline diamond coverage, without gaps between cutters on each blade. The advantages of this arrangement are many. Most obvious is the ability to drill erosive and/or abrasive formations without erosion. Often PDC bits, especially lighter set bits, can lose steel or matrix body material between the cutters due to erosion or abrasion, and this can be life-limiting. With no gaps between the cutters, this ceases to be a problem. Other possibilities include: bits for more conventional formations where a contiguous blade can be used instead of backup cutters, enhancing ROP and stability (Maw 2012). This represents a step change in bit design with the potential to redefine bit design across the applications spectrum.
This paper details some of the problems with the currently accepted PDC design paradigm, and proposes a novel solution to them by changing it. The hurdles in the way of making the concept a reality and their solutions are described, relating to new concepts in bit design, cutter selection, and new manufacturing process. The testing methodology used to prove the concept in the oil sands in northern Alberta, Canada, as well as the test results are presented. Finally, future planned developments based on the apparent advantages of the invention are forecast.
Results of the First Norne Field Case on History Matching and Recovery Optimization Using Production and 4D Seismic Data
Authors: Rwechungura Richard , Bhark Eric , Miljeteig Ola T. , Suman Amit , Kourounis Drosos , Foss Bjarne , Hoier Lars , Kleppe Jon 
Published: October 2012

Abstract
In preparation for the SPE Applied Technology Workshop, "Use of 4D seismic and production data for history matching and optimization – application to Norne (Norway)" held in Trondheim 14-16 June 2011, a unique test case (Norne E-segment) study based on real field data of a brown field offshore Norway was organized to evaluate and compare mathematical methods for history matching as well as methods on optimal production strategy and/or enhanced oil recovery.
The integrated data set provided an opportunity to discuss emerging and classical history matching and optimization methods after being tested using real field data. The participants of this comparative case study were expected to come up with a history matched model preferably using an integration of production and time-lapse seismic data and with an optimal production strategy for the remaining recoverable resources for the future period. Participants were allowed to suggest techniques to enhance recovery. Taking into account that the Norne benchmark case is a case study based on real data and no one exactly knows the true answer, participants and delegates were encouraged to discuss the methods, results and challenges during the course of the workshop, and thus in this case there are no winners or losers. Everyone who participated gained experience during the course of the exercise.
Participants were asked to history match the model until the end of 2004 and optimally predict the production (oil, water and gas rates) performance until the end of 2008. Participants were from different universities in collaboration with other research organizations namely Stanford University in collaboration with IBM and Chevron, TU Delft in collaboration with TNO, Texas A&M University, and NTNU in collaboration with Sintef. This paper summarizes the presented results from these groups and the outcome of the discussion of the workshop delegates.
The Challenges Facing Independent Companies Willing To Extract Crude Oil On The Periphery Of the Nariva Swamp, An Environmental Sensitive Area In Trinidad
Authors: Jaggernauth Deonarine J. 
Published: October 2012

Abstract
The Nariva Swamp (an Environmentally Sensitive Area in Trinidad) comprising 28,029 acres of wetland is located on the eastern side of the island. It is bordered by hilly terrain on the west and north sides, and the Atlantic Ocean on the east side. Several companies have extracted and continue to extract hydrocarbons from the Atlantic Ocean, and similarly on land in the southwest area.
The island of Trinidad was once part of South America, and separated maintaining its diversity of flora and fauna. Since it was difficult for these species to adapt, new sub-species emerged making areas like Nariva Swamp unique. The Nariva Swamp is one of the areas designated as a protective area to conform to the Ramsar Treaty of 1971. It is the largest fresh water ecosystem in Trinidad and is home to several species governed and protected by the Convention on International Trade in Endangered Species of Wild Fauna and Flora (CITES).
It is the belief of the geologists that there are substantial hydrocarbons located under the Nariva Swamp at depths greater than 3000 feet. They believe the northeast to southwest trends could substantiate their information. Independent companies have expressed the desire in exploring for these hydrocarbons, but due to the area being designated an ESA, the challenge will be to extract the hydrocarbons by using directional drilling on the periphery of the swamp to minimize interventions. In order to satisfy regulatory requirements for the local Environmental Management Authority (EMA) for any project approval, operators will have to demonstrate stringent environmental impact control measures that will be required for the drilling and production operations. This should include minimum environmental discharge, noise, and human activities using appropriate technologies. There are other sensitive areas in Trinidad where hydrocarbon extraction takes place with minimal disturbance to the environment that can provide the framework and necessary requirements for this area
To date one independent has undertaken the challenge to drill oil wells on the periphery of the swamp. The results have been mixed forcing remapping the area and looking at going deeper into the sedimentary formation.
Highly Accurate Prediction of Screenouts in the Eagle Ford Shale with the Screenout Index
Authors: Massaras Leon , McNealy Timothy 
Published: October 2012

Abstract
Development of unconventional resource plays, such as the Eagle Ford shale in south Texas, require that complex multiple hydraulic fracture stages be placed in the horizontal section of the wellbore to be economical. Operational complexity is presented during both the completion and the fracturing phases, which are performed in an orchestrated manner by many contributors. A screenout during one of the fracturing stages will place many of the contributors on a standby status, delays the placement of subsequent stages, and causes costs to increase substantially because of standby charges, wellbore cleanout costs, and lost production days.
The screenout index (SOI) is an empirical indicator developed by analyzing thousands of rate step-down tests (RSTs) from around the world, including hundreds from the Eagle Ford shale. Development of the SOI involved (1) following a specific four-step RST procedure, which requires the fourth rate change be about two times larger than the first rate change (to distribute measurement error over a larger span), (2) determining the instantaneous shut-in pressure (ISIP) in a specific and consistent manner, (3) calculating pressure gradients DP1 and DP4, (4) applying a rate correction to DP4, and (5) calculating the SOI = Corr. DP4/DP1.
The SOI provides an advanced warning of an imminent screenout. This is highly beneficial because it allows modification of the remaining steps of the fracture treatment design and preparation of various decision control options to be executed in the event a screenout occurs or extending the treatment becomes necessary.
Often, an SOI value of less than 0.5 indicates that a screenout is unlikely. If the SOI value is between 0.5 and 1.0, the chances of a screenout increase significantly. An SOI value larger than 1.0 signifies that a screenout is probable. The predictive accuracy of the SOI has been greater than 95%.
Modification of the design of the completion configuration and/or elimination of certain types of completions and procedures can help minimize and possibly eliminate screenouts.
The RCA Corrosion Attack in Once Through Steam Generators Tubes Failures: South Oman Steam EOR Case Study
Authors: Nengkoda Ardian , Supranto Supranto , Prasetyo Imam , Purwono Suryo , Amijaya Hendra , Suryono Sugeng 
Published: October 2012

Abstract
Steam EOR pilot project has been deployed in heavy oil field of Petroleum Development Oman, South Operation, and interestingly after more than a year operation, recently failed due to convection tubes ruptured at "Once Through" steam generator facility. It was found that more than 10 tubes have been affected. When the facility inspection deployed, more than 10 Kg unknown grayish color loose solid has been found in the internals part of the tubes. The quick preliminary interpretation narrowed to inorganic scale due to high hardness in the soft water that feeding to the generator, but later, after conducted comprehensive Root Cause Analysis (RCA) study showed that a mix of H2S and Oxygen played as important roles in the damage, where in common systems, the presence of H2S and O2 are eliminating each others and very rare they are exist as one in a close loop systems. This paper pointing about Root Cause Analysis and understanding of Failure Mechanism through some detail damage study and integrated reservoir - process review analysis are able to achieve the objective to secure long term facility integrity and steam supply. After doing a comprehensive surveillance program and applying sophisticated XRF/XRD techniques, showed predominantly solids are Iron products, such as Iron Oxide and Sulfide. Both SRB and GAB Bacteria as the sources of H2S growth from the water supply wells, while the Oxygen are heavily ingress inside the RO Plant and soft water tank facilities. Finally, after injecting a proper biocide and oxygen scavenger and optimize the dosage, the problems have been mitigated successfully.