bluuebunny/crossref_metadata_2025_split huggingface dataset:
Study of the PVT Behavior of Methane and Ester-Based Drilling Fluid Mixtures
Authors: Kim N. R. 
Published: June 2014

Abstract
Brazilian oil and gas reserves are primarily located in offshore fields, in deep and ultradeep water depths, where well construction is specially complex. Continuous development of drilling technology leads to the increasing application of synthetic-based drilling fluids, which have adequate characteristics such as lubricity, shale inhibition and low toxicity. In offshore conditions a gas kick is of major concern, as formation gas will dissolve in the organic compound of the synthetic-based drilling fluid. The better understanding of gas solubility is very important in operational and environmental safety of well control procedures, to avoid a blowout situation. In the present work methane was chosen because it is the principal component of natural gas, while ester was used in the formulation of drilling fluids. Knowledge of phase equilibrium of these mixtures, at high pressures and high temperatures, demands experimental tests, which are specific, expensive and time consuming. This work presents experimental data, obtained from PVT analysis of methane and ester-based emulsion mixtures. Laboratory tests were performed with last generation equipment, where a complete visualization of the sample fluid was possible. The mixture was loaded into a PVT cell and the equilibrium was reached at the pressure and temperature conditions expected at bottomhole. At constant temperature, the volume in the cell was monitored as a function of the pressure. An original gas enrichment experimental procedure was devised in order to cover the temperature, pressure and methane concentration range with a long term, single liquid amount test. Measured data enabled the estimation of the bubble pressure, solubility, density and formation volume factor of the mixtures, developing new correlations for pressures up to 15,000 psi and temperatures up to 266 °F. A thermodynamic modeling based on Peng-Robinson equation of state was applied to predict the experimental bubble point. The present work enlarges the limited thermodynamic properties database about methane – ester systems that is available in the literature and furnish scientific answers to the well control problems encountered when drilling with ester based emulsions.
Design of Cone-Launcher System for SET Applications in Well Drilling
Authors: Al-Abri Omar S. 
Published: June 2014

Abstract
Due to the continued forecast of increasing energy demand, oil in particular, it is expected that oil companies will intensify their efforts in meeting the global demand. Drilling deep and accessing difficult reservoirs are already posing serious challenges to local, regional and international players in this business. A part from this, there is a continuous push on performance improvement, cost reduction and innovating new techniques/tools/ procedures to push toward realizing the dream of having mono-bore diameter well. Solid Expandable Tubular (SET) Technology has already made significant inroads in resolving these challenges. Various operators around the world are already using the technology towards zonal isolation, repairing ageing wells to have profitable production, etc. Numerous experimental, numerical and analytical works have been reported in literature related to solid expandable tubular. The recently designed and commissioned expandable tubular test-rig in Sultan Qaboos University - Oman - has helped local operators to use the technology with confidence as well as to search for low cost expandable solutions. Still many issues are either not understood at all or have very little understanding about it. These include post expansion mechanical characterization, lowering the cost of expandable tubular, simplify the expansion operation and cost either through the design of optimal tools or reducing the number of steps needed in an expansion process.
The students at Sultan Qaboos University were actively involved in many expansion related works in Engineering Research Laboratory. However, the students have never made an attempet to complete the question of having own indigenously design cone and launcher system. The task of designing a new cone and launcher system which can be effectively and efficiently used in down-hole applications was initiated last year. In Oman, there is no such in-house developed design to deliver this work. It will be nice to have one's own design, which with time can be improved. In view of this, the objective of this work was set to design a Cone and Launcher System for SET applications. A design was proposed to expand the tubular in a stroke of 2-ft length. Multiple strokes can be done in one cycle of operation. 7⅝" tubular system was selected for this specific task. The design work was done from component to sub-system to product level either analytically or numerically using finite element method. The constraints of cost and ease of manufacturing locally were prime concern during the design work. The working of proposed system has been simulated in SolidWorks software to demonstrate its operation.
An Easy to Use Well Design Software Package for Educational Training
Authors: Dalamarinis Panagiotis 
Published: June 2014

Abstract
One of the biggest challenges in teaching well and drilling design to undergraduate and graduate students is availability of easy to use and understand software simulator programs. Hence a design package is needed for educational use which will not only introduce well design principles but also could be a support package for more advanced drilling programs (like for e.g. Payzone, Petris).
In this paper such a program is presented which has six major parts:
Hydraulics calculations for flow of non-Newtonian fluids in pipe and annuli, pressure losses in drill pipe and annulus, at the bit, considering well geometry, eccentricity and pipe rotation. Bit optimization, specific maximum pump pressure for maximum bit hydraulic horsepower or maximum jet impact force. Mud Cap technique design, with analytic design for parts of the well bore, aiming to introduce the Managed Pressure Design for a well. Pipe design, offering a stress design analysis for the selection of drill pipes. Casing design, making a stress design for the casing at each part of the well Directional drilling calculations for the support of Payzone drilling program.
We present the components and the interface, developed in Matlab environment, together with instructions for use.
The results of this work is a well and drilling design software package for training undergraduate and graduate students, easy to understand, while allowing fairly complex computations.
Technical Contributions: Easy to use, not heavy, yet fairly accurate simulator built in Matlab environment, allowing teaching important drilling concepts such as hydraulic calculations along the wellbore, bit optimization, pipe and casing design, introduction of mud cap drilling technique, and ability to perform computations for directional drilling.
Relevant Applications: The developed program can be used in undergraduate and graduate classes and in not-very-technical training programs, for teaching important aspects of drilling engineering.
The Past, Present and Future of Aphron Based Drilling Fluids
Authors: He Xiaoqing 
Published: June 2014

Abstract
Aphron based drilling fluid is an advanced technology which has been successfully developed for ten years in petroleum drilling industry. This paper firstly summarizes the field applications and laboratory study of aphron based drilling fluid of the past ten years. Then it describes undergoing researches in China, which include the foundation of aphron's structure model, explanation of special properties of aphron based drilling fluid and its sealing mechanism, agents selection method, the way of making typical useful formulas, and field applications in China. At last, the author predicts the potential and expanded use of aphron in petroleum industry in the future.
Characterization of the Horizontal Intermittent Air-Water Flow Using Ultrasound Technique Aided by High-Speed Filming
Authors: Grangeiro Fernando Antonio 
Published: June 2014

Abstract
Two-phase flow is very common in petroleum industry. During off-shore production, liquid and gas phases travel long distances through flow-lines and risers before being separated at different flow patterns. In the present work, air-water horizontal slug flow hydrodynamic parameters are investigated using ultrasound technology aided by high speed filming. The test rig is composed by a 54mm inner diameter acrylic pipe where two stations composed of four ultrasonic transducers each were placed. The parameters obtained were: elongated bubble velocity; elongated bubble, liquid slug and unit cell lengths, and unit cell frequency. These parameters made it possible to calculate flow rates of both phases using the ultrasound technique. Results shown by both techniques agreed against each other.
Appraisal Strategy for a Tight Gas Discovery
Authors: Al Kindi Suleiman , Weissenback Markus , Mahruqi Sultan , Curtino Joe , Al Siyabi Hisham 
Published: June 2014

Abstract
Exploring and developing tight gas accumulations are both technically & commercially challenging due to the large subsurface uncertainty and low expected ultimate recovery (EUR) per well. In this paper, the appraisal phase of a tight gas discovery is described in three parts.
The first part highlights the main geological uncertainties associated with rock properties for tight sands with porosity as low as 5% and permeability of few tens to hundreds of microDarcy. As a consequence, free fluid contracts for such accumulations are difficult to pinpoint using conventional petrophysical analysis of open logs and due to the lack of reliable fluid pressure data. Tight gas accumulations are known to be associated with large gas-to-water transition zones, leading to much broader and uncertain estimates of the gas resources. This in turn adds to the complexity in identifying and planning development options for such discoveries.
The second part describes some new technologies adapted to narrow down the subsurface uncertainties and to speed up the appraisal phase of a tight gas accumulation. Such technologies include: under-balanced drilling (UBD), high resolution gas chromatography measured at drilling site, special core analysis and dedicated petrophysical evaluation for tight sands. In addition, new technologies related to seismic imaging and fracc optimisation are also considered with the ultimate aim of improving gas production rates and EUR per well.
The last part of the paper describes the underlying strategy in maturing a tight gas discovery into field development. The strategy in principle has three main elements: 1) narrowing down the subsurface uncertainty; 2) reducing well cost; and 3) improving expected ultimate recovery per well. The campaign takes advantage of the ongoing development of nearby gas fields that provides the opportunity for hooking up appraisal wells at an early stage for extended well test. This appraisal plan is managed and executed by a dedicated and well-integrated multi-disciplinary team.
Integrated Drilling-Maximize Land Well Drilling Efficiency
Authors: Farooqui Shoaib , Hafeez Iftikhar , Ahmed Sumair , Ahmed Faizan , Siddiqui Ibad , Attaullah Hammad 
Published: June 2014

Abstract
In conventional drilling scenario, the Drilling Manager has to deal with similar drilling problems several times during field development phase. In addition to this he has to manage several service providers which results in increased workload. This increased workload prevents him to focus on the solutions of drilling problem & drilling optimization.
Integrated Drilling Services is a new concept in which all services and equipments are integrated under one contract. It is a contractual model which is technically and economically feasible with efficient risk management. This model reduces non productive time and non conformances with efficient project management and Technology Advancements in order to encourage Drilling Managers “Doing Right Things” rather than “Doing Things Right”.
This paper describes an engineering approach towards well optimization and efficient project management. Moreover, economic benefits are also the part of study.
Kick Detection and Well Control in a Closed Wellbore
Authors: Nas Steve 
Published: June 2014

Abstract
Closing the wellbore at the top with a Rotating Control Device (RCD) for some kind of Managed Pressure Drilling (MPD) operations raises a number of issues with regards to well control and kick detection. The wellbore is closed and the standard flow check of looking into the well is no longer possible. The use of a rotating control device provides drillers with an additional level of comfort because it is a pressure management device, but it doesn’t eliminate the need to have well control as a primary objective. In recent MPD operations, it was observed that well control procedures were relaxed as a result of managed pressure drilling. The installation of an MPD system provides the sense that well control is now taken care of by the MPD provider. This raises the question "Is Managed Pressure Drilling the same as primary well control?", and how do we deal with kicks in Managed Pressure Drilling operations? At what point in a well control process do we change the well from Managed Pressure Drilling to well control and who is responsible?
This paper will present some of the issues that need to be considered when planning and conducting MPD operations. arly kick detection and annular pressure control are promoted as an essential part of managed pressure drilling operations, but there can be confusion as to where the responsibility for well control lies. Does this remain with the drilling contractor and Operator or is this now shifted to the provider of the MPD services. The paper provides some case stu ies where MPD and well control conflicted, causing a number of issues that in some cases led to the loss of the well.
Comprehensive Study of Asphaltene Precipitation due to Gas Injection: Experimental Investigation and modeling
Authors: Zadeh Gholam Abbas , Moradi Siyamak , Dabir Bahram , Emadi Mohammad Ali , Rashtchian Davood 
Published: June 2014

Abstract
Asphaltene precipitation during natural depletion and miscible gas injection is a common problem in oilfields throughout the world. In this work, static precipitation tests are conducted to investigate effect of pressure, temperature and gas type and concentration on asphaltene instability. Three different oil samples are studied under reservoir conditions with/without nitrogen and methane injection. Besides applying common thermodynamic models, a new scaling equation is presented to predict asphaltene precipitation under HPHT gas injection. Published data from literature are also used in model development. The scaling approach is attractive because it is simple and complex asphaltene properties are not involved in the calculations. Moreover, the proposed model provides universal parameters for different fluid samples in a wide range of pressure and temperature that makes it novel for evaluation of future gas injection projects when simple PVT data are available.
i-field™ Programs Enable Operational Excellence in a Challenging Environment—Pushing the Limits of Large Data Transfer for Real-Time Monitoring and Surveillance Operations in the San Joaquin Valley
Authors: Popa Andrei , Cassidy Steve 
Published: June 2014

Summary
Chevron's San Joaquin Valley (SJV) Business Unit (BU) is a mature, heavy-oil, thermally enhanced asset consisting of large fields that have been producing for more than a century. To ensure continuing technology transformation, in 2003 SJV started its own i-field program, being among the first BUs to pursue Chevron's enterprisewide effort in building the Digital Oil Field of the Future. From its initiation, the program has been focusing on creating solutions to manage and optimize operations and enhance recovery.
This paper showcases one of the most technologically advanced i-field heavy-oil solutions implemented in SJV thermal assets, involving a high-accuracy-tiltmeter program implemented by a partner service company to advance the understanding of diatomite operations and monitor the surface ground movement.
In 2008, Chevron's SJV i-field team partnered with its Information Technology (IT) department to develop a state-of-the-art application called Integrated Diatomite Operations Tool (i-DOT). The product incorporated current field workflows for mapping the grid deformation with business data (well locations and status, steam volumes and dates) in relevant time. This was accomplished by establishing a live connection between Chevron and partner-service-company servers whereby terabytes of grid data would flow seamlessly into Chevron's SJV servers. Data-acquisition, data-processing, and data-storage efforts were accomplished through an integrated effort between IT, geographical information system (GIS), and PetroWeb development teams. Workflows were built through close collaboration between i-field engineers, petroleum engineers, earth scientists, IT professionals, and the operations group.
The i-DOT solution has become the single point of operation monitoring and activity scheduling for multiple groups such as Operations, Asset Development, and the Drilling team. The benefits of implementing i-DOT solutions are significant and transformed our decision-making process in diatomite fields. This paper includes not only value creation but also lessons learned during development, deployment, and end-user acceptance.
Implementing i-field-Integrated Solutions for Reservoir Management: A San Joaquin Valley Case Study
Authors: Popa A.. , Cassidy S.. 
Published: June 2014

Summary
To achieve more-efficient business processes by exploiting data and knowledge management, real-time systems, and advanced analytical tools, most major integrated and service companies have developed, or are in the process of developing, intelligent programs also known as "Digital Oil Field of the Future" (CERA 2002). The i-field™ program represents Chevron's efforts to integrate people, processes, technology, and information to achieve its vision of upstream transformation. Ultimately, this vision translates to higher-quality decision making and changes the method in which assets are operated.
A new multiyear i-field™ program, Integrated Reservoir Management (i-RM), was initiated in the San Joaquin Valley (SJV) to enable efficient reservoir management (RM) and quality decision making for heavy-oil assests operating under steamflood enhanced-oil-recovery (EOR) technologies.
The paper describes the journey undertaken by the project team to build a proprietary steamflood-integrated RM tool that answers the basic never-ending engineering requirements: instant access to clean data, single source of information for everyone, and seamless data-tools linkage. The ultimate benefit is not only increased time spent by engineers and earth scientists to analyze data, but also consistent project design workflows and decision-making processes across fields. In addition to the previously described documented benefits, the manuscript includes the operator's experience with project framing, development, deployment, and user acceptance.
Innovative Use of Open-Hole Wireline Formation Pressure Testing in Waterflood Optimization of an Ultra-Tight, Light Oil Reservoir, Belridge Field
Authors: Zannitto P. J. , Rahman M. , Allan M. E. 
Published: June 2014

Abstract
There are not many oil reservoirs in the world with permeabilities less than 1 md that are under waterflood. Aera Energy's Diatomite reservoir at Belridge field in California is one of the few: a massively thick reservoir, with very low permeability, very high porosity, and high rock compressibility that has been undergoing water injection for pressure maintenance for over 20 years.
Optimizing subsurface injection conformance, or injection profile, is the key to operating a successful waterflood in the Diatomite. However, because of wellbore obstructions, the majority of Diatomite injectors are not accessible to conventional radioactive tracer tools for monitoring injection profile. Without a good understanding of vertical profile, it is difficult to balance voidage on a layer by layer basis. Failure to maintain good zonal pressure support can result in poor vertical sweep, as well as reservoir compaction that can lead to irreversible permeability reduction and productivity impairment.
Due to reservoir compaction and elevated rate of well failures, sustaining Diatomite production requires continuous drilling of replacement and infill wells at very close well spacing (20–50 ft). Aggressive replacement drilling programs (300 wells per year) have made it possible to run open-hole Wireline Formation Tests (WFT) in sufficient density over time to effectively monitor vertical and areal pressure profiles. As a result, reservoir intervals lacking injection support have been identified for optimization.
Between 2003 and 2008, Aera ran over 300 open-hole WFT surveys in the South Grande area at Belridge field, vertically covering the Opal-A and upper Opal-CT reservoirs. Large-scale pressure testing has aided in pressure maintenance operations by improving completion strategy in new injection strings, targeting differentially depleted zones. This has improved overall layer voidage profiles, as evidenced by lower producing GOR and greatly reduced occurrence of producer-failures. WFT surveys continue to serve in a feedback loop to optimize injection target setting, voidage management, and strategy for completing replacement wells.
This paper reports on the innovative use of wireline formation testing to optimize water injection pressure maintenance in a major onshore waterflood, with the unique challenge of not being able to monitor injection profile in a majority of wells. The learning may apply to other tight, light oil waterfloods.