bluuebunny/crossref_metadata_2025_split huggingface dataset:
Hybrid Bit Technology Expands Application Range in Harsh Rock Environments
Authors: Garcia Alexis , Barocio Hector , John Denise , Avila Eduardo Antonio 
Published: October 2013

Abstract
When drilling in extreme environments, the integration of the latest advancements in materials engineering and cutter technology are crucial to maximizing drilling efficiency and reducing trips. Recent advances in hybrid bit technology have expanded the application range into lithology intervals that feature high compressive strength, high abrasivity and low drillability. By fusing existing technologies such as PDC and diamond impregnated cutting structures, designers have improved existing designs so they feature both optimized cutting element placement for extending bit durability and an engineered mix of diamond impregnated material strategically placed in critical wear-prone areas of the bit to increase exposure on hard and abrasive lithologies. These design changes also take into account the effects of a progressive combination of shearing and grinding rock failure mechanisms to maximize drilling efficiency.
After initial applications in the Sub-Saharan region of the Congo, this bit technology has been featured in several applications across the world. These cases include runs onshore Jordan with highly interbedded lithologies; foothills area of Colombia drilling in rocks exceeding 25ksi UCS and offshore runs in Mexico within the middle and lower cretaceous areas with lithologies containing up to 10% Chert.
In these case studies, the use of hybrid drill bit technology has reduced costs and NPT in situations where it would typically take a number of impregnated, PDC and tungsten carbide insert bits, many using different drive systems, to reach total depth. These cases also describe the different characteristics and drillability of the rock types, as each demands specific bit design features and parameters to be failed in the most effective manner.
During the evolution of the hybrid design, the importance of PDC cutter selection played a crucial role in the design's success. Cutter technology was adapted to provide superior abrasion and thermal resistance, better suited to combat the high abrasivity of the formations. Additionally, the cutting edge geometry was modified to provide increased toughness, avoiding premature cutter edge overload to maximize the length of the bit run.
Long Term Wellbore Isolation In a Corrosive Environment
Authors: Ilesanmi Oluwagbemiga R. , Hilal Bashar , Gill Steve , Brandl Andreas , Abdullah Ali 
Published: October 2013

Abstract
The paper reviews two case histories about successful wellbore isolation with a suitable cementing system for a recent enhanced oil recovery / CO2 project targeting the Thamama B formation of the Bab Far North reservoir in the UAE. The first two wells were vertical observers with zonal isolation required between the Thamama A and B. These wells were expected to exhibit a naturally corrosive environment (e.g. 56,000 ppm of CO2). To address these challenges, a fit-for-purpose cementing system, suitable for CO2 and other corrosive fluids, was developed and successfully applied. The system was designed to isolate and protect specific Thamama zones and wellbore areas that contained gaseous or liquid corrosive CO2. This cement slurry was developed with a density of 16.7 ppg exhibiting expanding properties after setting to compensate potential shrinkage issues and to improve cement bond. Laboratory test results for the developed cementing system, such as compressive strength development, thickening time, expanding properties after setting, and integrity after long term exposure towards wet CO2, are presented and discussed. Performance requirements for cementing sytems to qualify for CO2 tolerance are elucidated. Finally, the execution in the field and the quality of the cement job was evaluated. All of the special designs exhibited excellent bond log results. The favorable lab test results and the positive case history conclude that the developed cementing system can be a viable solution to provide long term zonal isolation in a wellbore with a corrosive environment.
New Generation Drill Pipe to Increase Drilling Performance in ERD Wells
Authors: Van Puymbroeck Luc , El Bachiri Kamal 
Published: October 2013

Abstract
Complex and Extended Reach Drilling (ERD) well profiles are continuously pushing the limits of the drill string. Drill pipe with high-torque connections and increased tensile strength-to-weight ratios are required to overcome frictional drag forces, achieve improved hydraulic performance, control well trajectory and provide higher rates of penetration with optimal hole cleaning. While hole cleaning is generally considered to be well understood when drilling deviated and horizontal wells, many drillers still have difficulty properly managing the entire process.
Experience reveals that less-than optimal hole cleaning can lead to nonproductive time, poor bore-hole quality, and loss of the drill string or even the well. Large boreholes drilled at high ROPs will usually require additional rig time for essential cleanup. An in-depth analysis supported by key performance indicators (KPI) shows that using Mechanical Hole Cleaning Devices (MCD) in certain directional wells can achieve drilling efficiency gains with cost savings.
This paper addresses a new drill pipe design integrating hydro-mechanical features in the tool joint to address annular pressure issues prevalent in ERD wells. This innovative approach to drill pipe design aims at drilling with safer ECD (Equivalent Circulating Density) margins, reducing time spent on hole cleaning, improving hole quality and reducing Nonproductive Time (NPT). Short of a case history, performance improvements similar to efficiency gains achieved with the Hydroclean™ tool in highly deviated well can be expected.
Smart Calliper for Measurement While Drilling
Authors: Rasheed Wajid , Zhou Shaohua , Al-Khanferi Nasser M. 
Published: October 2013

Abstract
This paper outlines the R&D methodology, accelerated testing and successful results of an innovative Smart Reamer Calliper for measurement while drilling. The concept was progressed from design to prototype with long hours downhole drilling qualification tests completed in 3 years. Limitations often exist with ultrasonic calliper measurement technology due to bottom-hole assembly (BHA) placement and changes in fluid density. The Smart Calliper prototype tool overcame these limitations by building onboard proper calibration and multiple sensors that allow 360 ° mapping of the wellbore shape. Further optional Measurement While Drilling (MWD), vibration, magnetic and underreamer position sensors can be added.
An R&D project was established with incremental tests identifying root-cause failure/design issues before moving to the next stage. This iterative process ensured proper prototype manufacturing and minimized risk at critical test points. At the same time parallel activities enabled the project to reduce overall time associated with common project tasks. The whole R&D consisted of four stages: design and finite element analysis (FEA), small scale testing, full scale testing and long hours of field test drilling. The prototype tool was first tested in sliding, rotating and underreaming BHAs for drilling a total of 900 m in chalk, clay and sands. Small scale lab tests — including high pressure and temperature at 13,053 psi and 150°C for 100 hours — were conducted in England. Full scale under-reaming testing occurred in Norway with a wireline calliper for cross-check of the wellbore diameter measurement, and finally another qualification test in England comprising 59 hours on bottom drilling.
Last, a real-time data display was performed via an integration with a standard mud pulse telemetry. In conclusion, the new Smart Calliper tool accurately measures and can provide both memory and real-time data of the 3D wellbore, allowing the drilling team at the rig-site to: Pinpoint narrow or under-gauge wellbore sections, verifying underreamer performance and measuring wellbore diameter above the reamer, allowing for a corrective reaming trip to be performed while drilling BHA is still in hole.Offer better cement volume estimate to minimize excess.Eliminate wireline calliper deployment.Eliminate a wiper trip typically carried out prior to running long casing or liner string.Offer monitoring of downhole tool vibration and separate directional survey if required.
A Milestone in Production Optimization in the Niger Delta Using Intelligent Completions
Authors: Chinwe Uchendu , Nnanna Erasmus , Okpokpor Obaro , Yahaya Ibrahim , Friday Otutu , Erumwunse Courage , Agbonaye Cardinal 
Published: October 2013

Abstract
With increasing energy demand, cost optimization and environmental challenges; using smart techniques to produce multiple reservoirs in a single well is a much welcomed concept. Intelligent completions have been proven to be an efficient reservoir management tool and Shell Nigeria (SPDC) has tapped on this innovative technology to optimize production enhancement in one of its fields.
In this paper an overview of the deployment of the first onshore intelligent well technology in one of the largest field in the Western Swamp area in Nigeria will be reviewed. The well is a part of the Nembe Creek Phase-1 campaign and serves as a pilot for the Phase-2 Smart Well campaign planned for 2013. This paper in detail describes the innovative techniques deployed and benefits of this smart completion are discussed with particular reference to Well A-1
SPDC's 1st smart completion was completed in May 2012. It consists of three (3) intervals - having one of the longest intervals perforated in SPDC (374ft cum length) which was perforated in a single trip system. This well also sets a trend worth replicating as it recorded the best completions installation time amongst competition in Nigeria. This was achieved by effective team work & thorough upfront planning.
The paper will highlight details of the well design, installation/surface equipment hook up in addition to the well clean up and performance monitoring strategy. The paper also highlights lessons learned at each phase of the well project and describes how those lessons will be applied to ensure the next phase of intelligent completion system planned in the field will be implemented to ensure sustained success in smart well technology in Shell Nigeria.
World's First Successful Deployment of an Advanced 11-3/4" Expandable Liner Hanger in a Deepwater Exploration Well
Authors: Adewuya Opeyemi , Tiwari Shrikant , Balhareth Mahdi , Mohamed Abdullah O. , Solano Maurilio 
Published: October 2013

Abstract
Rank wild cat deepwater exploration wells present an escalated set of challenges beyond even those encountered in the most complex offshore well construction. The presence of salt diapirs and well documented stressed pre- and post-salt formation layers produce greater distortion and unpredictability to geopressure and temperature gradients. It is customary to approach these challenges with casing design configurations that afford deployment of contingency casing strings without compromise to mechanical strength, well integrity and reaching the bottom-hole depth objective with the right casing bore size for production testing.
The use of expandable liners have become a panacea for extending hole sections — that may otherwise have truncated and narrowed the final depth — and terminating the hole size of deep reservoir targets respectively. Significant compromise in casing mechanical strength accompanies the application of expandable liners and their application must be carefully considered, alongside an array of qualified alternatives, especially above and across high pressured reservoir intervals.
The Expandable Hanger and Packer Liner (EHPL) System offers the preservation of the maximum bore size for subsequent hole and casing size, while allowing deployment in the tightest annuli that otherwise will have prevented the pass through and space for a conventional hanger deployment to achieve liner design and effective hang-off capacity. In the account presented in this paper, the technical evaluation process, deployment planning and challenges, and successful application industry-wide of the first liner with an expandable hanger and packer system is enumerated.
Inflow Control Device in Thin-Layer Bottom Water Drive Reservoir Enhances Oil Recovery in China South Sea
Authors: Cui Esther , Hay Bill , Garcia Gonzalo A. 
Published: October 2013

Abstract
Horizontal wells can increase a reservoir's drainage area and hydrocarbon recovery, but they pose challenges such as early water breakthrough, high water cut and low oil recovery. Water production continues to increase until the economic limit of the well is reached. In a thin-layer water drive reservoir, in particular, the key factors are controlling water coning, extending the water-free production period and controlling water production post breakthrough.
This paper details the challenges faced working in horizontal wells, an optimized reservoir Passive Inflow Control Devices (PICDs, called ICD in this paper) mechanism to address such challenges and reservoir simulation analysis in the application of ICDs in China South Sea.
Two dynamic reservoir models were built with the same reservoir property inputs but with two well completion types: standalone screen (SAS) completion and ICDs completion. Through the daily oil and water production, cumulative oil and water production, 3D water movement, the performance of an ICD completion were evaluated. The simulation results demonstrate the added value of the ICD completion system compared to a standalone screen completion production and increased oil in a thin-layer bottom water driver reservoir.
Effective Well Management in Sabriyah Intelligent Digital Oilfield
Authors: Jamal Mariam Abdul-Raheem , Al-Mufarej Mishal , Al-mutawa Majdi , Anthony Elred , Hom Chetri , Singh Siddharth , Moricca Giuseppe , Kain Jeff , Saputelli Luigi 
Published: October 2013

Abstract
Oil production from North Kuwait carbonate reservoirs are challenging because of factors, such as high permeability streaks, poor microscopic sweep efficiency, and low mobility ratios, all of which can dramatically impair production rates and oil recoveries. Despite tremendous efforts related to waterflood research, oil recovery in carbonates typically remains low. New technology and approaches are required to increase and sustain oil production to access and drain immense amounts of remaining oil-in-place.
This paper presents the results of collaborative work procedures applied to a selective number of wells to increase production performance in the Sabriyah Mauddud field pilot under the Kuwait Integrated Digital Field (KwIDF) project umbrella. KwIDF is part of a comprehensive strategy undertaken by an operator to enhance overall oil production by the application of digital oilfield (DOF) concepts, which involves (1) well instrumentation to provide enhanced real-time data availability, (2) upgraded power and communications infrastructure to support field instrumentation and control real-time data, (3), creating collaborative decision centers to enhance asset team processes across physically separate locations, and (4) providing a platform to increase effectiveness through automating work processes and to shorten observation-to-action cycle time.
The Sabriyah KwIDF pilot involves 44 producer and five injector wells producing about 7% of total Sabriyah field production. The main objective of this effort was to maximize and sustain oil rates and reduce well decline while honoring safe well operating envelope constraints. As a result of this effort, production gains have been certified in 10 wells of the pilot area to date. This success has been achieved by carefully analyzing past performance and adjusting well settings to real- time production conditions using the operator's digital infrastructure.
This paper describes how this optimization methodology provides improvements to short-term production rates while honoring safe well operating envelope and presents case histories illustrating the benefits from the automated workflows and collaborative decision approach. The average sustained oil gain was 395 BOPD, or 37%. The total sustained oil gain reached 3,949 BOPD (34%), with a cumulative production gain of 756 thousand barrels for the evaluation period.
Real Time Online Energy Management at KNPC Refineries
Authors: Ershaid Mohammad , Al-Tarkeet Ahmad , Al-Mutairi Jamilah , Al-Anezi Salwa , Ruiz Carlos , Ruiz Diego , Santollani Oscar , Cuneo Sebastian , Periyasamy Dhanasekar 
Published: October 2013

Abstract
Kuwait National Petroleum Company (KNPC) is a wholly owned subsidiary of Kuwait Petroleum Corporation (KPC). KNPC operates three (3) refineries viz., Mina Al-Ahmadi (MAA), Shuaiba (SHU) and Mina Abdulla (MAB). KPC internal directives required the implementation of a management process to optimize energy consumption through the formation of energy management cells (EMCs), which implemented an energy management program based on best international practices.
This paper describes the tasks performed to develop and implement real time, online models, to help with the three KNPC refineries energy cost minimization and energy management, which are scheduled to perform it automatically. They allow to clearly identify the different economic trade-offs that challenges the operation of the site wide energy systems at minimum cost while reducing the energy waste and, therefore, CO2 footprint. Recommendations given by the optimizers are taken into account by operations on a daily basis.
The same models used for the online, real time optimization, are also used in standalone mode, populated either with current or historical data, allowing to perform case studies for planning or to evaluate alternatives for a better and most economical operation of the energy systems.
As a result of the project, the information of each refinery energy system has been organized into models and reports to which everyone has access.
Next Generation of Workflows for Multilevel Assisted History Matching and Production Forecasting: Concept, Implementation and Visualization
Authors: Maucec M.. , Singh A. P. , Carvajal G. A. , Mirzadeh S.. , Knabe S. P. , Mahajan A.. , Dhar J.. , Al-Jasmi A. K. , El Din I. H. 
Published: October 2013

AbstractTraditional reconciliation of geomodels with production data is one of the most laborious tasks in reservoir engineering. The uncertainty associated with the great majority of model variables only adds to the overall complexity. This paper describes the conceptualization, implementation, and visualization characteristics of the multilevel assisted history matching (AHM) technique that captures inherent model uncertainty and allows for better quantification of production forecasts.The workflow is applied to history matching of the pilot area in a major, structurally complex Middle East (ME) carbonate reservoir. The simulation model combines 49 wells in five waterflood patterns to match 50 years of oil production and 12 years of water injection and to predict eight years of production. Initially, the reservoir model was calibrated to match oil production by modifying permeability and/or porosity at well locations and by fine-tuning rock-type properties and water saturation. The second level history match implemented two-stage Markov chain Monte Carlo (McMC) stochastic optimization to minimize the misfit in water cut on a well-by-well basis. The inversion process is dramatically accelerated by the efficient parameterization of permeability, constraining the proxy model using streamline-based sensitivities and using parallel and cluster computing. The optimal number of representative history-matched models was identified to capture the uncertainty in reservoir spatial connectivity using rigorous optimization and dynamic model ranking based on forecasted oil recovery factors (ORFs). The reduced set of models minimized the computational load for forecast-based analysis, while retaining the knowledge of the uncertainty in the recovery factor.The comprehensive probabilistic AHM workflow was implemented at the operator's North Kuwait Integrated Digital Oilfield (KwIDF) collaboration center. It delivers an optimized reservoir model for waterflood management and automatically updates the model quarterly with geological, production, and completion information. This allows engineers to improve the reservoir characterization and identify the areas that require more data capture.
Desalting of Heavy Crude Oil by using Centrifugal Technology
Authors: Perschke Thomas 
Published: October 2013

Abstract
The development of new and above all complete and efficient yield from the crude oil and natural gas fields already accessed on all the continents and in all the oceans. Today's challenge is that most of the conventional oil reservoirs are declining and that the importance of the unconventional Heavy Crude Oil reservoirs is becoming bigger and bigger. Hence the world has over 3 trillion bbl Heavy Crude Oil reserves; it covers the world energy needs for the next 100 years. Such unconventional crude oils cannot be handled in the traditional way.
The INDUSTRY works by known mostly with static dewatering and desalting systems using electrostatic fields, chemicals, temperature and the g-force for separation of oil and water. These systems have their limitations when it comes to lower API grades and higher viscosities in capacity and quality. A reliable alternative to the traditional desalting process is the usage of high-speed centrifuges. The system can handle low-API grades and high viscous oils and provide in the same time an excellent quality crude oil even by one stage process. Because of the high g- forces and separation efficiency the overall cost per barrel crude oil can be decreased as temperature, using of chemicals, wash water and electrical consumption can be reduced. The design of the disk-stack centrifuge with the direct-drive concept ensures a minimalized foot print of the installation.
High-speed centrifuges are used successfully in the exploration, delivery and treatment of crude oils and oily water applications. They combine efficiency, reliability and environmental conservation in a broad spectrum of highly specialized applications.