bluuebunny/crossref_metadata_2025_split huggingface dataset:
Gerotor Pump Performance in Artificial Lift for Single-Phase and Multiphase Conditions
Authors: Ejim C. E. , Oshinowo L. , Xiao J. 
Published: November 2016

Abstract
Gerotors are positive displacement pumps and candidates for artificial lift in the oil and gas industry. This study evaluates the performance of a unique gerotor pump design under single and multiphase conditions in a downhole configuration. The gerotor pump performance is modeled with computational fluid dynamics (CFD) to develop a virtual prototype of the multiphase performance behavior prior to physical testing.
A prototype 3D model of a 400 series gerotor pump suitable for application in a 5½-in. casing was developed. The pump volume displacement is consistent between the initial laboratory experimental tests and future field testing. A transient 3D CFD was used to simulate the gerotor pump performance under single-phase and multiphase flow conditions. The complex gerotor motion was modeled in CFD using a dynamic meshing technique. Pump rotor speeds applicable to the range of testing conditions were applied. The gas and liquid phase properties correspond to mineral oil and air at the prototype test conditions.
The results of the gerotor pump performance are presented for single-phase and multiphase conditions over a range of gas volume fractions (GVFs) from zero to 0.75. The CFD results show that the flow rate decreases approximately linearly with discharge pressure, which is typical of positive displacement pumps. Pump performance and efficiency curves are developed relating the delivery pressure and flow rate. The CFD model methodology is presented with consideration to appropriate selection of the numerical methods, multiphase model, mesh design, dynamic mesh motion, and other aspects to improve the reliability of the numerical simulations. For the same delivery pressure, increasing the GVF decreases the gerotor pumping rates. Recommendations are proposed for improving the multiphase pumping capacity through pump geometry modifications. The modifications effectively tailor the gerotor to improving gas-liquid pumping in specific oil field operating conditions.
This study highlights the potential for gerotors as an alternative artificial lift technology for multiphase pumping. This technology with the inherent mechanical simplicity and compactness provides cost-effective surface and downhole multiphase pressure boosting for production in the oil and gas industry.
Introduction of 25mm-PDC Cutters in the Latest Drill Bit Technology Leads to Multiple Drilling Performance Records and Reduces Days to Production in Oman
Authors: Al-Hinaai Ahmed , Al Esry Saleh , Scott Dan E. , Fuselier Danielle , Lee Roger , Boisvenue Graham 
Published: November 2016

Abstract
Suppressed oil prices amid a call for increased returns from shareholders has created opportunities for operators and service companies to work closely in developing and deploying new technology in well construction efforts. Under extreme pressure, operators are seeking innovations to reduce drilling time and shorten the time to production. An operator in Oman has tripled output over the last ten years using enhanced oil recovery (EOR) methods, making it the largest independent oil producer in the Sultanate.
The development of polycrystalline diamond compacts (PDC) is one of the fastest-evolving technologies for fixed cutter drill bits. The application of PDC bits continues to expand performance by increasing rates of penetration (ROP) to lower drilling costs. The most recent developments in synthetic diamond cutters have been in 25mm-diameter cutters. Although 25mm-PDCs were developed in the mid-1990s, they lacked the necessary durability for demanding drilling applications. Only recently has the technology become available to meet these needs in this size.
Several recent tests in Oman have shown the new 25mm-cutter technology drastically improved performance with shoe-to-shoe runs at increased ROP. With the new cutters came the need for paired frame improvements with special considerations for aggressiveness and mechanical limitations for torque, both for the drilling rigs and use with positive displacement motors. During vertical drilling through carbonates and shales in the Diba field, the technology established a new field record ROP of 217 feet per hour—an 80% improvement over the field average ROP. In the Jalal field, 275 feet per hour was achieved—29% higher than the previous best record. The technology was also introduced on a steerable motor in a directional well, delivering improved penetration rates and excellent stability in slide mode. An additional lesson learned was the smooth torque generated by the large cutters. The smooth drilling torque enabled improved directional tool face control.
This operator has implemented an aggressive drilling and development program to drill faster and reduce cost per foot in heavy oil sands and fractured carbonates. The authors will present case studies to demonstrate how the latest technology 25mm-cutters and new frame technology helped lowered drilling costs for this operator's drilling program in Oman.
Nanotechnology Improves Wellbore Strengthening and Minimizes Differential Sticking Problems in Highly Depleted Formations
Authors: Al-Ajmi Abdullah M. , Al-Rushoud Abdulaziz S. , Gohain Ashis K. , Al-Haj Hussien A. , Khatib Faiz I. , Al-Mutawa Faisal M. , Al-Gharib Majed A. , Soliman Ahmed H. , Ibrahim Ahmed S. , Al-Mujalhem Manayer Q. 
Published: November 2016

Abstract
It is a challenge to drill in highly deviated or horizontal holes with high differential pressures. Wellbore instability, differential sticking and mud loss are frequently encountered problems while drilling slanted wells in Kuwait across shale and sand series. Drilling became more challenging with considerable non-productive time. Therefore, it is necessary to identify a fluids solution when other options with casing zone isolation are not viable. Traditionally, oil-based mud (OBM) was used while drilling these formations with limited success.
A customized fluid system was designed to overcome the issue of high overburden pressure in shale and sand series formations targeting effective bridging, minimizing pore pressure transmission, and strengthening the wellbore. A nano-size deformable synthetic polymer, along with sized calcium carbonate and graphite, was identified to effectively plug the pore throats and minimize fluid invasion, which was confirmed by particle plugging tests.
A well section was identified to comingle the highly depleted and pressurized formations. This was the first attempt on a high-angle well with development drilling operations in Kuwait and was performed to facilitate the successful drilling of the reservoir. Traditional OBM was converted to a customized fluid system using a nano-size polymer and sized bridging additives based on proprietary software selection and a series of laboratory tests. Drilling and logging were successfully performed for the first time in the commingled section without incident. There was no wellbore instability or differential sticking tendencies, less torque and drag, as well as enhanced wellbore cleaning in the high-angle sections.
This paper also presents some successful applications of the nano-size deformable polymer in OBM to drill highly depleted formations in HTHP wells managing up to 3500 psi overbalance across highly permeable formations.
Technological Improvements in OCTG Premium Casing Connections and Advancements in Design Paradigms to Address the Challenges Present During the Exploitation of Unconventional Hydrocarbon Resources: A Critical Review
Authors: Meza O. Grijalva , Berdasco J. Holzmann , Baptista N. Perozo , Carvajal C. Paz , Oppelt J. 
Published: November 2016

Abstract
Well Integrity is one of the most critical topics concerning the E&P sector nowadays, especially during the development of unconventional hydrocarbon resources. Among them, the exploitation of natural gas from shale and hydrocarbons from deepwater reservoirs pose considerable challenges to the entire well system, specifically in one of its more critical elements: the threaded connection. In the current state of the art, Premium Connections are the best option for ensuring wellbore integrity and mechanical reliability. Despite of its proven improved capabilities compared with standard API Casing connectors, Premium Connections are still relegated to "special applications".
In the case of offshore drilling, and in the light of new drilling techniques to develop deepwater resources, the use of Premium Connections to drill with casing tubulars offshore Australia has demonstrated the great opportunity this type of connection has for deepwater developments. In this work, a brief historical overview will be given addressing the technological highlights that contributed to the current market offer of OCTG specialty connectors for unconventional oil and gas applications. By means of a comparative, however, detailed analysis of available geometric profiles on the market in the last 15 years (ie. improved dovetail thread, coupling bevel, toroidal sealing surfaces, etc.) and the current state of the art of applicable norms, standards and their validation levels (Connection Application Level (CAL)) it was concluded that an additional improvement on the mechanical reliability of the connection still can be achieved. This would be noticeable in form of gas-tighter connections as per ISO 13679 and bigger torque capabilities (e.g. for casing drilling) during make and break operations.
Parallel to this, a new definition for "well integrity" is provided considering the role threaded connections play as critical innate safety barriers within the wellbore system; an extensive discussion on historical development of Premium Connections is provided, focusing in the innovations that took place in the last 15 years in OCTG for Shale Gas applications and Deepwater Drilling, at the same time the current state of the art of norms and standards for OCTG is critically cited.
Maximizing Completion Efficiency Using Remotely Operated Barrier Valves
Authors: Thomson Barry , Arackakudiyil Zac Suresh , Todd James 
Published: November 2016

Abstract
The paper introduces an application of intelligent completions that uses remotely operated barrier valves to improve completion efficiency. The case study outlines the completion of a well in the UK North Sea. The valves were used to set the packer and to test tubing; later, they functioned as shallow and deep-set barriers for the removal of the blowout preventer (BOP) and the installation of the christmas tree.
The well was completed with two barrier valves deployed in the open position; one was installed for use as a shallow-set barrier above the safety valve and the other as a deep-set barrier below the production packer. The valves used onboard decision-making electronics that monitor well conditions and that are programmed to open or close in response to the detection of a specified condition (known as a trigger). This configuration enabled the operator to communicate with the tool remotely from the surface by using applied-pressure commands. The use of remotely operated barrier valves made it possible to open and close the barriers multiple times.
The deep-set valve was initially closed to set the packer and test the tubing string. It was later opened to test the packer on the annular side, and it was closed to act as a deep-set barrier. The shallow-set valve was later closed to act as a second barrier to enable the removal of the BOP and the installation of the christmas tree. Both valves were then remotely opened to begin production.
The use of remotely operated barrier valves helped the operator to successfully eliminate eight wireline runs, which resulted in the elimination of approximately 59 hours of rig time. The health, safety, and environment (HSE) risks associated with rigging up and running wireline were also eliminated in this case.
The industry is striving to perform completions and intervention activities in a safer and more economic manner. This case study demonstrates the new use of remotely operated barrier valves will provide a timely addition to existing completion solutions.
Utilizing Pulsed Eddy Current to Inspect Insulated Piping
Authors: Sayed Talal Al , Hammadi Hassan Al , Yaarubi Ameer Al , Harmi Faisal Al 
Published: November 2016

Abstract
A wide range of Oil & Gas plants is subjected to periodic inservice inspection in order to ensure continued safe and economic operation. The catastrophic failure of a component in a process plant may result in costly business interruption and also it endangers plant personnel. If an explosion or fire occurs, or a hazardous chemical is released widespread fatalities or undesirable environmental consequencies may result. Premature failure of plants can hapeen as a result of variety of different causes, and these include design deficiencies, manufacturing defects, fabrication or erection defects, service related deterioration and operating deficiencies. In order to prevent the sudden upset and resultant catastrophic failures, regular inspections most suitable for the anticipatory failures has to be identified and executed. The inspections are often performed by traditional NDT methods such as Radiographic testing and ultrasonic testing. These can be highly sensitive, but the rate of coverage is relatively very low and extensive preparation for inspection often required, eg. Like insulation removal or composite wraping removal often required for the inspection of substrate. There are also many situations where access or geometry prevents the use of conventional inspection methods.
Over recent years a wide range of advanced NDT technques has evolved. These techniques provide large area screening of a component for significant degradation. Some of the techniques can be rapidly applied and they also provide means of inspecting areas which would be uninspectable. PEC or pulsed eddy current is one among this and this inspection technique is most suitable and best approach for insulated and composite wrapping applied section of piping.
ZK site have many critical piping components applied with pressure / non pressure containment composite wrapping and the recent survey on these piping concluded many affected by corrosion under wrapping. PEC inspection is a solution for the inspection and condition monitoring of substrate under the wrapping, and which has proven and established.
Mitigating Water Injectivity Decline in Tight Carbonates due to Suspended Particles
Authors: Alyan Mohand , Al Tamimi Mohamed , Al Zinati Osama , Calarasu Dan , Martin John , Irwin Drew 
Published: November 2016

Abstract
This paper is a comprehensive analytic driven study on the use and sizing of membrane filters to improve the injected water quality for maintaining injectivity in tight carbonate reservoirs. Out of the different mechanisms of formation damage, the pore plugging with the migration of particles within the injectant fluids by bridging at the pore throat junctions and/or by pore filling can lead to the buildup of an internal filter cake away from the wellbore that limits the well’s injectivity and can affect the vertical and lateral sweep.
This type of formation damage is very difficult to treat with any kind of stimulation and the impact will be manifested especially in tight formations with interbedded stylolites layers with a total range of permeabilities from 2 to less than 1 milli-Darcy and a median pore throat size ranging from 2.5 to 0.3 micron meters. The study comprises several parts starting with a geological analysis that was conducted to identify areas and layers most prone to formation pore plugging by analyzing thin-sections and MICP data. Second, in the lack of core flood tests, a reservoir and well study analyzed existing water injectors situated in similar or slightly higher quality rock areas through the analysis of injectivity index behavior to estimate the impact of damage and the expected injector’s half-life.
As a result, through the application of an analytical mathematical model for defining deep bed filtration parameter, a correlation was established based on average injected particle size and reservoir rock quality to aid in selecting the proper water injection filter size. In order to confirm that, a dedicated injectivity test in a horizontal well utilizing membrane filters was carried out to assess eventual formation damage and the filters efficiency by conducting a series of multiple pressure fall-off tests coupled with injection profile logging to monitor any induced damage within the wellbore region.
Finally, the operational aspects and the integration within field development plans were addressed, especially with the recommended well placement and completion. This culminated in a field development strategy for formation damage mitigation in tight carbonate reservoirs during production and injection phase that can be used in other similar fields.
Achieving Predictable Outcomes for Modular Construction in Megaprojects
Authors: Jeffers John 
Published: November 2016

Abstract
Megaproject definition: A capital investment project with a total installed cost in excess of $1 billion USD with complex stakeholder arrangements.
Rystad Energy estimates that global capital expenditure in oil and gasfields dropped $215bn between 2014 and 2015, shaving almost 0.3% off the size of the global economy. That trend continues in this low oil price environment. The effects of volatile and low oil prices vary along the value chain and are most acutely felt upstream with all national oil companies (NOCs) and international oil companies (IOCs) revising their capital investment schemes downwards.
As the number and size of megaprojects continues to increase across all sectors of the capital projects industry, one fact stands out: megaprojects tend to underperform more often than not. More specifically, megaprojects fail to keep within their approved budgets, fail to meet their approved schedules, or fail to achieve their promised business objectives. To provide substance to this assertion, independent and empirical studies (by Ernst & Young and the I.P.A.) point out that the sector record in executing major oil and gas projects is far from palatable. Approximately 64% exceed their control budget and over 70% experience schedule delays. It is therefore necessary for the oil and gas industry to examine the underlying reasons for this disappointing failure in order to achieve predictable outcomes on investments.
Acoustic Downhole Three-Phase Separation Method in Oil Field Applications
Authors: Abdel-Fattah Amr I. 
Published: November 2016

Abstract
The need for downhole oil-water separation systems increases with the rising water cuts in producing wells worldwide. This need is driven by the urge to reduce costs and environmental risks associated with managing and treating the expected large volumes of produced water. Available technologies utilize hydrodynamic, gravitational, or membrane separation techniques to separate oil from water downhole. They suffer from a number of systemic problems, including flow intervention and possible subsequent pressure drop in the well and failure of mechanical parts. They require a specific range of flow rates and water cut percentages in order to function properly. If well conditions deviate from these operational ranges, partial or complete failure of function is the result, unless some system parts are replaced, which in turn may require costly workover and temporary shutdown. Existing technologies are also incapable of separating fine solids from the fluid stream downhole, and thus run the risk of clogging the formation zones in which the water is reinjected. Acoustic separation techniques provide a viable solution to these limitations and add a number of advantageous functions. In this article, a concept for an Acoustic Downhole Oil Water Separation (ADOWS) tool and its field implementation is introduced. ADOWS is a three-phase separation concept in which both oil droplets and solid fine particles are separated downhole simultaneously from water. Oil is directed to the surface and water is allowed to enter a cavity equipped with a membrane to remove the already-separated particles before reinjecting the water back into the formation. ADOWS thus has the potential of not only increasing oil-to-water ratio and reducing produced water pumped to the surface, but also removing fine particles from the water so it can be reinjected into the formation without the risk of pore clogging. ADOWS is versatile, does not intervene the flow, and does not require narrow ranges of flow rates or water cuts to function properly. The underlying acoustic separation forces can be tuned instantaneously via surface controls to accommodate changes in flow rates and water cuts. Direct microscopic visualization experiments in a microfluidic channel demonstrate the key phenomena underlying ADOWS. The experiments show simultaneous separation of micron-sized oil droplets and solid particles from water by exciting the proper acoustic standing wave patterns in the flow channel.
A Multiscale Pore Network Modelling of Gas Flow in the Nano-Porous Structure of Shale
Authors: Yuan Yudong , Wang Yuzhu , Rahman Sheik S. 
Published: November 2016

Abstract
Flow simulation in shale is challenging due to its multiscale porous structure and multi-physics gas flow in these pores. Because network of pores is capable of characterizing the three dimensional (3D) distribution of pores and throats, it is widely used to estimate the apparent gas permeability of porous media, such as shale. Pores residing in shale have a broad spectrum of size ranging from a few nanometers to micrometers, therefore, multiple flow regimes, including the continuum flow, slip flow, transition flow and sometimes Knudsen diffusion are controlling the flow in the porous structure of shale. In addition, surface diffusion occurs on the adsorption layer of organic matters also contributes to the total flow rate. For the network modelling in the literature, the employed equaitons fail to account for these flow mechanisms. In view of this, Beskok and Karniadakis (1999)’s equation and Fick’s equation are employed to describe the non-continuum flow and surface diffusion, respectively, in a reconstructed network of shale. The simulation results provide an improved understanding of gas flow behaviour in shale matrix. It has been observed that the apparent gas permeability increases by a factor of 2.4, with 21% contribution arising from surface diffusion when the downstream pressure depletes from 9 MPa to 2 MPa. Sensitivity analyses imply that the apparent gas permeability is dependent on the size and shape of throats, compressibility factor and type of gas, Langmuir adsorption parameters and reservoir conditions.