bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Comprehensive Real-Time Data Analysis Tool for Fluid Gains and Losses
Authors: Andia P. , Sant R. V. , Whiteley N. 
Published: February 2018

Abstract
This paper describes a comprehensive approach to aid the monitoring and trending of wellbore fluid gains and losses during well construction drilling and completion operations. A software tool was built that is able to integrate real-time data with algorithms to provide early warning indicators for potential well control and lost circulation events. The focus is primarily on amalgamating relevant formation evaluation data, drilling and circulating parameters as well as pre-drill or real-time pore pressure and fracture gradient analyses.
In order to build a comprehensive real-time data analysis tool for managing the fluid in the well, three groups of parameters were identified as essential for monitoring: surface fluid flows and volumes, surface and downhole drilling parameters and formation properties, and gas events in the wellbore and at the surface. Eight capabilities were created to aid the monitoring of the identified key parameters. These capabilities depend on a number of integrated algorithms and displays that operate within a realtime data platform and were designed to utilize measurements in real-time as well as relevant well construction information. The primary aim is to provide a medium for visualization of events and informative trends, along with alerts when parameters fall outside specified thresholds. Presenting this collated information in real-time provides shared awareness of fluid gain/loss risks and events to personnel that work in a real-time monitoring center as well as to offshore and onshore operation teams. The software tool was developed and tested over three years and trialed in two wells with offshore and onshore operations personnel. It is now being deployed and used by technical specialists that work in a real-time monitoring center and operation support teams in the office.
Nanocellulose and Biopolymer Blends for High-Performance Water-Based Drilling Fluids
Authors: Hall Lee J. , Deville Jay P. , Santos Catherine M. , Rojas Orlando J. , Araujo Carlos Salas 
Published: February 2018

Abstract
Water-based drilling fluids are an economical and environmentally appealing option for wellbore construction. Both conventional and high-performance varieties of water-based systems typically use biopolymers to provide viscosity, suspend solids, and control fluid loss in the wellbore. Some examples include both naturally occurring biomaterials produced by plants or bacteria (e.g., starch, guar, xanthan) as well as their chemically modified analogues. However, new materials that could help improve efficiency, rate of penetration (ROP), or high-pressure/high-temperature (HP/HT) performance are necessary to expand the use of economical water-based systems in increasingly demanding conditions. Recently identified nanostructured biomaterials, such as nanocellulose, have been observed to have outstanding mechanical, structuring, and thermal properties and are known to be potent viscosifiers at low concentrations. This paper discusses a study that investigates the performance of water-based fluids by either replacing or augmenting their common oilfield biopolymers with cellulose nanofibrils (CNFs).
In this study, CNFs produced from technical-grade kraft pulp were mixed in aqueous dispersions with commercial biopolymer viscosifiers, such as xanthan and guar gum. Measurements were made of rheology, dispersion stability, CNF/biopolymer interaction, and filtration behavior as they relate to desirable fluid properties. Unexpected synergies were discovered when the CNFs were blended with secondary biopolymers. Increases or decreases observed in system viscosity were dependent upon the type of biopolymer mixed with nanocellulose but independent of the mass balance of the ingredients. In some mixtures, lower biopolymer concentrations increased viscosity within mixed systems while other mixtures decreased viscosity with increased concentrations.
The implications of these unusual findings suggest that performance efficiency can be tailored simply by mixing CNFs with biopolymers that are already used extensively in water-based fluids, allowing an operation to use less material. This discovery can enable a new method to maintain drilling fluid properties during drilling operations with the added benefit of increased temperature stability.
By modifying the surface of CNFs with secondary biopolymers, a wide range of fluid behaviors were achieved through changes in surface chemistry, surface morphology, and gel-network formation. Such nanocellulose fluid systems could serve as a renewable, nontoxic, and potentially cheaper alternative to synthetic polymers in high-performance, water-based fluids with the added benefit of controlling and helping to improve fluid properties using a mixture with common oilfield biopolymers.
Active Mud Line Pumping, Design, Testing and Future Possibilities in Rig Design
Authors: Hong Young Wan , van Kuilenburg Robert 
Published: February 2018

Abstract
The drilling industry is continuously improving drilling efficiency and safety. Precise control of the downhole pressures and knowledge of fluid flows is an essential element in any drilling improvement project. To obtain real time fluid flow data in drilling operations Coriolis flow meters are more and more used. However Coriolis flow meters are expensive, prone to be blocked by cuttings and handle multiphase and gas entrained fluids poorly.
To mitigate the problems associated with Coriolis flow meters, Noble Drilling and selected 3rd party vendors teamed up to design and test a test skid to prove the performance of a surface based active mud line pumping system. Active mud pumping systems could be a key component for future drilling rig designs and improve performance of current rig designs.
The active mud line pumping system is a pumping system to transfer drilling mud laden with cuttings using pumps from the gumbo box to the shakers. This allows detecting well bore problems such as kicks and loss of circulation with minimum time delay. By adding weight sensors, fluid density can be determined and if installed in the active mud tanks full flow-in / flow out data can be obtained. Active mud line pumping systems do not rely on gravity driven flow for moving fluid. This allows more efficient rig designs with improved safety features as well.
A key design feature of the active mud line pumping system is that it uses components that are already used on drilling rigs. This will facilitate efficient operation and maintenance by normal rig crews.
The testing shows that by using Tesla pumps it is possible to transfer heavy cuttings laden drilling fluids accurately without degradation of the cuttings. Valuable insights were gained at start/stop performance and flow measurements. Future testing will focus on improving the kick detection control loops and extending the modeling of the systems for future rig designs.
Perf-and-Wash Cement Placement Technique as a Cost-Effective Solution for Permanent Abandonment of a Well with Multiple Permeable Zones: A Case Study from North Sea, UK
Authors: Joneja Galen , Nafikova Svetlana , Reid James , Rublevskyi Anton , Salazar Jose 
Published: February 2018

Abstract
The job objective in a UK North Sea field was to permanently abandon a well that had poor cement bonding behind the casing across the intended isolation intervals. The challenge was to provide lateral isolation across two separate intervals in the most efficient way possible. Two "perf-and-wash" operations were executed successfully during the well abandonment. The deeper barrier envelope was validated by tagging and pressure testing the plug. The shallower section had been logged prior to the operation and, on completion of the perf-and-wash job, the plug was drilled out to allow for relogging, which indicated more than 76% of the perforated interval had circumferential coverage. After the bond log results were confirmed, a further cement plug was set across the shallow interval by conventional methods and verified by tagging and pressure testing. This paper outlines the detailed design preparations and presents both case histories where these steps were implemented successfully.
A New Workflow for Estimating Bit Wear and Monitoring Drilling Efficiency in Real Time During Drilling Operations
Authors: Millan Ekaterina , Ringer Maurice 
Published: February 2018

Abstract
This paper presents a new workflow for monitoring drilling efficiency in real time during drilling operations. Based on a bit-rock interaction model, the new workflow provides parameter estimations, such as bit wear and in-situ rock strength, obtained from typical real-time drilling measurements. The model can be used to predict rate of penetration (ROP) ahead of the bit, optimize drilling operating parameters, and determine the potential benefits of tripping out to change the bit.
The new approach presented here was initially tested in a laboratory-based drilling rig. Once these tests confirmed the theory, the technique was then validated on several operations to monitor and optimize drilling efficiency.
The workflow presented in this paper is a powerful method for monitoring real-time drilling efficiency through estimating bit wear, in-situ rock strength, and future ROP. This new method uses a novel approach that combines time-based and depth-based drilling data and innovative data processing algorithms to further constrain and enhance these estimated parameters. The new method is totally automatic and has been shown to facilitate optimizing drilling efficiency in real time.
Drilling Analysis Using Big Data has been Misused and Abused
Authors: Maidla Eric , Maidla William , Rigg John , Crumrine Michael , Wolf-Zoellner Philipp 
Published: February 2018

Abstract
The authors have been contacted by many people in the industry lately that are incorrectly utilizing big data to produce correlations that attempt to identify operational "sweet spots". This paper will show examples and address the need to add several steps to big data before any meaningful correlation results can be obtained, mainly understanding (and this is not a comprehensive list):
- The sensors involved and their limitations;
- The errors in the placement of these sensors (e.g. hook load sensor on the deadline);
- The frequency of the data and how this impacts the analysis (some companies provide 10-second data);
- The quality of the data itself;
- The appropriate filtering of data to ensure apples-to-apples comparisons;
- The rig state must be known
- Understanding of the physics involved.
A Practical Method to Monitor Wellbore Strengthening Particle Concentration
Authors: Alberty Mark , Yao Ziheng 
Published: February 2018

Abstract
The StressCage methodology of wellbore strengthening uses sized particles to bridge and seal induced fractures, increasing fracture resistance in permeable formations. The size distribution of the particles, or fracture prevention material (FPM), that are added to the mud is engineered to ensure correctly sized particles enter and bridge the induced fracture before it grows beyond its designed width and length. A minimum concentration of FPM is determined through a physics-based numerical calculation to derive a mud formulation based on the particle size distribution (PSD) and density of the selected mud additives. This minimum concentration and particle size distribution of FPM must be maintained at all times that the wellbore pressure exceeds the fracture gradient or previously generated fracture resistance of the formation in order to prevent the failure of the StressCage and the subsequent loss of wellbore integrity.
A number of methods have been used to monitor FPM concentration in the mud. Most methods sample the mud returning from the well before arriving at the mud shakers, pass the collected mud sample through stacked sieves, remove the liquid mud coating the particulates using either centrifuges or drying ovens, and weigh the resulting residue to determine the return concentration. These methods can be inadequate and difficult to implement due to the requirement of specialized equipment on the rig (ovens, laser PSD, centrifuges, etc.), the need for additional personnel to conduct the mud monitoring activities on the rig, and the significant delay in obtaining the results. The lag time for results in deepwater wells can be 5 to 10 hours, depending on the time required to circulate the mud up the well and dry the samples. This delay can prevent operators from detecting when FPM concentration decreases to below the minimum required for drilling depleted sands.
A simple and fast method has been developed that requires minimal special equipment. A reference sample is collected from a reserve mud pit carefully prepared with the target minimum FPM concentration. The mud is then run though a set of selected stacked sieves. The reference tare weights of the wet FPM collected in each sieve are used as a reference for monitoring the active system. The reference wet FPM weight is compared to mud samples collected from the suction pit of the active system as the well progresses. The difference in the weight observations is then used to determine appropriate additions to maintain or exceed the minimum requirements.
Flexible, Self-Healing Cement Eliminates Sustained Casing Pressure in Denver-Julesburg Basin Unconventional Wells
Authors: Langley M. , Cleveland M. , Eulberg J. , Hudson M. 
Published: February 2018

Abstract
The oil and gas industry has operated in Denver Julesburg (DJ) basin for many decades. Currently in the basin, increasing population density and wellbore complexity have resulted in a heightened visibility of long-term well integrity. Failure can lead to future liabilities, loss of public trust, and a revoked right to operate. Operators must demonstrate commitment to well integrity to continue operating in the basin, yet many still report sustained casing pressure (SCP) on a significant portion of wells. Because SCP corresponds to the open communication of fluids to surface, it is a direct metric of well integrity failure. Regulations require operators to report and remediate instances of SCP on all wells. On average, clients experience one well with SCP for every five drilled.
As a primary well barrier element, the cement sheath is vital to well integrity improvement. Enhanced placement techniques of conventional cements failed to prevent SCP, confirming that failure is derived from post-placement dynamic conditions. The solution must account for pressure and temperature stresses, preventing and mitigating mechanical failures throughout the well life cycle. A flexible and self-healing cement design provides a twofold response that is ideal for wells in areas, such as the DJ basin, with SCP risk.
Mechanical properties are optimized based on the results of a mathematical stress model. Although Portland-based cement systems can be optimized to sustain higher levels of dynamic stresses, it is impossible to avoid a mechanical failure entirely. Therefore, a self-healing function is a critical secondary feature. The self-healing mechanism is designed to activate upon contact with an invading hydrocarbon and can be formulated for any type of hydrocarbon, from high gravity oil to dry gas.
Flexible and self-healing cement has been successfully designed and implemented on approximately 250 wells in the DJ basin with a reduction to 2% instances of SCP. Elimination of SCP provides confidence in long-term well integrity, which is essential to continued operation in the basin.
Breaking the Performance/Cost Paradigm in Drill Pipe Connections in Extended Reach Drilling
Authors: Plessis Guillaume , Muradov Andrei , Wright Chuck , Morgan Dan , Dugas Jeremy , White Brennan , Daley Dallas 
Published: February 2018

Abstract
Various generations of double-shouldered drill pipe connections have been developed in the past 30 to 40 years with performance as a primary driver. The objective was to bring improvements in torque and hydraulics to satisfy drillers' needs. The record extended reach drilling (ERD) wells could not have been delivered without these technological advancements. The driver for these developments was solely on improved performances, with limited focus on cost, as these technologies were so enabling that the associated costs were deemed acceptable.
When these same connections started to be used on land rigs to deliver wells in a factory drilling fashion, where cost control is of higher importance, the cost of maintaining these premium connections started to become more apparent. It, therefore, became obvious that a different approach was needed to meet the combined need for performance, as well as a lower cost of ownership post acquisition.
A comprehensive two-year research and development (R&D) program was carried out to evaluate various design options. After the research was conducted, a design was chosen that allows better control of stress inside the connection. This allows users to benefit from other design features besides the torque and hydraulics of a streamlined connection. The R&D program included numeric simulation and mechanical lab testing. More specific elements of the design allowed more tolerance related to field damage of the connection, less material loss on repairs, and more importantly, a ruggedness so that the connection can remain in the field longer rather than needing to be repaired so often.
The final stage of qualification was a field trial at the manufacturer's test rig facility. A post field trial inspection confirmed the improved serviceability and ruggedness, qualifying the connection for commercial release.
The 4th generation double-shouldered connection was first put to task in the Permian basin. A rental string was dispatched to a land rig and used to drill the longest and fastest lateral in the area. The tapered 5½ in. by 5 in. drill pipe string, which comes with tool joints of a similar size (this of 5 in. drill pipe), drilled the well and saved two days off the estimated drilling plan. Subsequently, more strings have been deployed, and more data shall be gathered in this paper to demonstrate the low repair rate.
A new approach has been used to design a connection that performs at high torque levels but also demonstrates improved serviceability and a ruggedness approaching that of an API rotary shoulder connection.
Rapid Development of Real-Time Drilling Analytics System
Authors: Cao Dingzhou , Loesel Chad , Paranji Sanjay 
Published: February 2018

Abstract
This paper serves to provide a technical overview of the Real-Time Drilling (RTD) analytics system currently developed and deployed. It also serves to share practices used in managing the RTD analytics project which have resulted in the efficient delivery of work products. By employing the novel and agile development approach on the RTD project, the design to production time has been faster and has cost much less compared to a more traditional multi-year effort and cost intensive RTD development project. Within three months, for proof of concept (PoC) purpose, an RTD analytics system with two analytics modules was built from scratch and placed online in production. This real-time decision-support tool has been fully accepted by the operations team and has become a powerful tool for daily well operations. After eleven months as this paper was drafted, this system has four analytic modules online for production and three analytic modules under development; it is expected that more new modules will be added to the system on a regular basis.
A New Approach to Characterize Dynamic Drilling Fluids Invasion Profiles in Application to Near-Wellbore Strengthening Effect
Authors: Ezeakacha Chinedum Peter , Salehi Saeed , Bi Hongfeng 
Published: February 2018

Abstract
Mud cake evolution and plastering have been identified as important wellbore strengthening mechanisms. They serve to reduce losses through pore throats and fractures, while impeding the growth of induced fractures. Recent experimental and analytical studies have also revealed the complexities in drilling fluids’ invasion profiles and mud cake buildup. These complexities arise from the changing wellbore conditions observed in an actual field scenario. It is important to investigate the effects of these conditions on drilling fluid invasion for near-wellbore strengthening application.
To achieve this goal, some dynamic wellbore conditions which are close-to-real field conditions were simulated in a controlled laboratory setup. The following conditions were investigated: rotary speed, temperature, type of lost circulation material (LCM), concentration of LCM, differential pressure, eccentricity, rock permeability, and fracture width. In the experimental setup, the geometry of the shaft that simulates drill pipe rotation allowed for mud cake evolution and plastering around the inner diameter of the thick-walled cylindrical porous media. Water-based mud (WBM) recipes were formulated for different porous media types. The rheological profile for each mud recipe was investigated for operating temperature limit. Dynamic drilling fluid invasion experiments were conducted with thick-walled cylindrical Buff Berea sandstone, Upper Grey sandstone, and fracture slots with varying widths.
The results indicate that temperature, rock permeability, fracture width, and LCM type and concentration are the most influential factors that control dynamic fluid invasion profiles. Increase in granular LCM concentration at elevated temperature is not completely effective in reducing pore-scale fluid invasion. Spurt invasion, rock porosity, permeability, and fracture width are important determinants of mud cake evolution. Increase in fiber LCM concentration showed effective mud cake evolution in the fracture slots. The results from testing mud cake stability revealed mud cake rupturing on three experiments out of the nine that were performed. The novelty in this approach is the use of thick-walled cylindrical cores and fracture slots to profile dynamic fluid invasion of different fluid recipes. Pressure, temperature, and pipe rotation were combined to simulate wellbore conditions under which fluid loss, cake growth, and plastering occur. This approach can be used in drilling fluid design for minimizing fluid loss, cost, and selection of operating conditions.