bluuebunny/crossref_metadata_2025_split huggingface dataset:
Advancements in Remedial Sand Control Solutions - Successful Deployment in Three Well Campaign
Authors: McKay Eilidh , Wigg Nicola , Parrott Keith , Iqlima Baida 
Published: March 2023

Abstract
Regaining sand control integrity in existing completions has been become an increasing challenge to overcome in recent years. Sand control challenges can occur over the life of the well, in the initial completion design, failure of existing downhole equipment or due to increased water production in later life. All of which need to be addressed using a technology which does not succumb to the same fate as any existing technology. Conventional remedial sand control methods vary in complexity, cost, risk, longevity and have associated weaknesses often resulting in reduced production. A novel thru tubing remedial sand control solution has recently been deployed for an operator in Indonesia which can be run on coil tubing or slickline. It is designed to transit tight restrictions within the upper completion and still set and conform to larger casing/screen IDs where control of sand has been lost. The key to the technology is the use of a unique conformable open cell matrix polymer (OCMP) as the sand retention layer which enables the tool to be fully compressed during deployment but will enlarge when at depth, filling the annular gap. The OCMP creates a tortuous flow path and the polymeric nature of the filter removes the energy out of any sand grain impingement reducing erosional effects. We present a review of three recent well interventions in both oil and gas wells that utilized this technology.
Towards Real-Time Bad Hole Cleaning Problem Detection Through Adaptive Deep Learning Models
Authors: Nivlet Philippe , Bjorkevoll Knut Steinar , Tabib Mandar , Skogestad Jan Ole , Lund Bjornar , Nybo Roar , Rasheed Adil 
Published: March 2023

Abstract
Monitoring of Equivalent Circulating Density (ECD) may improve assessment of potential bad hole cleaning conditions if calculated and measured sufficiently accurately. Machine learning (ML) models can be used for predicting ECD integrating both along-string and surface drilling measurements and physics-based model (PBM) results, even though their generalization is often challenging. To remediate this generalizability issue, we present an adaptative predictive deep-learning model that is retrained with new measurements in real-time, conditionally that the new measurements are not detected as anomalies. Past ECD measurements, corresponding values predicted by a 1D PBM and other drilling measurements are used as input to a deep learning model, which is pretrained on historical drilling data without any hole cleaning problem. This model has two components: an anomaly detector, and a predictor. In this paper, both components are based on combinations of Long Short-Term Memory (LSTM) cells that allow (1) to account for data correlations between the different time series and between the different time stamps, and (2) generate future data conditioned to past observations. As drilling progresses, new data is proposed to the anomaly detector: if the network fails to reconstruct them correctly, an alarm is raised. Otherwise, the new data is used to retrain the models. We show the benefits of such an approach on two real examples from offshore Norway with increasing complexity: For the first one, with no major drilling issue, we simply use ECD from the PBM to predict ECD ahead of the bit. The second example had multiple issues linked with mud loss and poor hole cleaning. For this latter case, we used additional topside measurements to better constrain the ECD prediction.
The Evolution of Hard Rock Drilling in Norway: How New Technology Solved an Old Challenge
Authors: Baruffati Paul Pasquale , Ngueguim Marcel Emile 
Published: March 2023

Abstract
The Åsgard field in the Norwegian sea contains hard, abrasive, and high temperature formations and the reservoir had never been successfully drilled in a single slimhole run over 10 years. Thorough engineering analysis, the application of lessons learned, and the introduction of new generation technology produced a series of improvements. These advances define a sustainable and systematic approach to efficient, cost-effective hard rock drilling in the Norwegian Sea and elsewhere. The method was to define the limitations of the existing approach and then iterate improvements to the system to increase performance. The first step was to define the existing operating envelope: offset data – drilling, downhole, and post-well analysis – was reviewed and weak points were identified. Then, using the most appropriate lessons from hard rock environments worldwide, initial design changes were made to the drilling approach and procedures. These changes delivered the first failure-free well in the field. New technology was then introduced to expand the drilling envelope further and this culminated in the first single run slimhole section in the field. Flat time was drastically reduced, while ROP and borehole quality were improved. Through scrutiny of drilling dynamics, high frequency torsional resonance (HFTO) was revealed to be driving system mechanical inefficiencies. Log analysis enabled the correlation of the onset of HFTO to lithology type, and new drilling parameter limitations – principally management of Weight On Bit (WOB) – were then defined. Real-time drilling optimization engineers were enlisted to support this approach. Rock strength analysis and post-run equipment inspection determined the need for more durable bit and Bottom Hole Assembly (BHA) designs. A custom drill bit was designed and a ruggedized, new generation Rotary Steerable System (RSS) and Measurement and Logging While Drilling (MWD/LWD) suite introduced. Within the established operating framework, this new technology enabled enhanced drilling parameters to be applied and resulted in a 53% improvement in penetration rate. High density survey data from the new MWD/LWD platform showed that the new generation drilling technology delivered an extremely high quality wellbore, where the cumulative tortuosity was within 5% of the theoretical well plan. This allowed the installation of the completion string in a new record time, reducing the technical limit. Overall, flat time was reduced by 56% and then 76% versus the offset average. Robust, new generation technology and a rigid adherence to system limits as defined by advanced engineering analysis provided a framework for rapid continuous improvement and a blueprint for repeatable, efficient performance. This can be used to drive efficiency improvements in similar offshore hard rock environments elsewhere.
Sidetrack Trajectory Success Indicator
Authors: Hitchcock Graham , Watson Andrew , Alshalan Meshari 
Published: March 2023

Abstract
The drilling of a secondary wellbore departing from a primary wellbore, known as a sidetrack, is used for many reasons during wellbore construction. Sidetrack techniques and procedures are well established with all the major service companies. A typical sidetrack operation would consist of setting a deflector (whipstock), cutting a hole in the existing casing (window), and then drilling into the formation at the desired exit angle and direction (kick off) to produce a starting hole (rathole) for subsequent drilling. The sidetrack milling assembly would then be Pulled Out of Hole and the drilling bottom hole assembly (BHA) run in hole to continue drilling the secondary wellbore trajectory. If for some reason, the casing exit and desired departure of the sidetrack is not obtained, this will remain unknown until the subsequent drilling operation with Logging While Drilling (LWD) tools are run in hole and have extended the rathole. The failure to obtain and recognize the desired kickoff departure prior subsequent drilling operations can lead to significant Non Productive Time (NPT) and subsequent rectification costs.
This paper describes the development and successful testing of a compact sensor package located near the front of the sidetrack milling assembly. The sensor package is activated at surface and records inclination data during the sidetrack operation. When the sidetrack milling assembly is pulled out of hole the sensor is read wirelessly using a handheld reader once the milling assembly is at surface. The reader gives the operator a visual confirmation, or otherwise, that the desired sidetrack kick off departure has been achieved allowing informed decisions to be made on the next operational stage.
Water Management Challenges in Greater Burgan Field
Authors: Alkandari Shaikha , Al-Zankawi Omran , Alsaleh Zainab , Jaafar Dunya , Jasem Mariam , Mudvakkat Anandan , Khan Junaid , Alaassar Ahmad , Perez Godo , Rjabli Nuran 
Published: March 2023

Abstract
As oil fields mature, producing more oil out of maturing reservoirs entails more water production. It is essential to have a successful water management process to be introduce, one that can handle substantial volumes of water produced in order to sustain crude oil production.
At the early stage of the Greater Burgan Field water management was not a major concern. Most of its crude oil was dry and easy production with little water from Burgan & Wara reservoirs in Greater Burgan Field. With maturing of the field, South & East Kuwait Asset has started experiencing an increase in water production from its maturing reservoirs. Also starting water flooding in Wara reservoir to increase oil recovery increased water cut with oil production as expected. These changes made the production facilities to become constrained that cannot fully handle produced water volume and result in production deferral.
To mitigate the high water cut challenges, South East Kuwait set up a multidisciplinary team to review and come up with actions to tackle the produced water handling challenge.
The team looked at an operational initiative to maintain the long-term disposal option of disposing produced water into Shuaiba formation. Shuaiba formation is below Burgan reservoir. During drilling the drilling team encountered heavy fluid losses in Shuaiba. This experience led the study team to support the option of disposing effluent water into fractured Shuaiba carbonate.
Shuaiba formation is classify as carbonate formation, full of vugs and fractures resulted from dissolution due to ancient underground water movement, the dissolution led to collapse And creation of large vugs and fractures around the collapsed area. The collapsed area and fractures are the main mechanism for storage of effluent water and increasing disposal capacity for the production facility. The plan is to drill Horizontal disposal wells targeting the Karst to intercept those vugs and fractures. The team saw a promising option to drill in Shuaiba, to increase the chance of loss fluid circulation and enhance facility capacity.
After drilling few wells and encountering total loss in the horizontal fractured section, along the edge of the karst, and performing injectivity disposing test, the wells showed ability to take up high water rates more than (50,000 BWPD). Based on the success of these disposal wells, Production operations bottlenecks are resolved in disposal well capacity and increasing it to more than (500,000 BWPD). Disposing in Shuaiba, formation will not require any treatment facilities and is an environmentally friendly long-term option
Coiled Tubing Drilling Advancement with Smallest Shaped Diamond Cutting Element
Authors: Siddik Syed M. , Rojas Pablo , Barrera Jonathan Lee Quintero , Alraheb Mahmoud 
Published: March 2023

Abstract
This paper describes an innovative concept for the smallest polycrystalline diamond compact (PDC) cutter size with non-planar diamond table used on a fixed cutter drill bit. This unique PDC cutter significantly increases durability, enhancing the bit life to drill more footage in multi-lateral applications driven by motor or turbine in two different challenging formations. Collaboration between a national oil company and a drill bits provider resulted in achieving consistent records in footage while maintaining good rate of penetration (ROP).
This 8.2 mm diameter PDC cutter equipped with unique geometry was used on a 3.625 in. fixed cutter (PDC) drill bit design. Main objective of the unique geometry on this non-planar diamond table is to improve cooling efficiency compared to the standard diamond table of a PDC cutter. Traditionally, PDC cutter technology relies on the cutter's thermal stability and abrasion resistance. Often, those two properties may not provide sufficient durability in abrasive formations. Initially, this unique geometry was used on bigger PDC cutters including 13 mm and 16 mm where a performance improvement was achieved, leading to the decision to scale-down to the smallest PDC cutter size.
Two different 3.625 in. fixed-cutter drill bit designs were used with non-planar diamond table PDC cutters and successfully passed the client requirement and trial testing criteria. Based on the field deployment results, drilling performance in the field was monitored and compared to standard diamond table PDC drill bit designs also used in the past as the benchmark. Shaped non-planar diamond table bit designs surpassed the footage of standard diamond table PDC cutter bit designs by 12% and 36% respectively with two different bit designs. Other performance aspect including dull condition were also monitored and showed similar wear progression as seen with other bit designs used in the application.
This innovative concept demonstrates that the non-planar diamond table PDC cutter successfully delivers more footage per bit run. This led to increase overall performance with deployments on coiled tubing drilling rigs across this difficult drilling environment in the challenging wells drilled in the Middle East. The novel technology achieves all drilling objectives with fewer drill bits and fewer trips, delivering the target footage at improved ROP.
Cementing Methods When Encountering Wells with High Background Gases
Authors: Khuwayr Asim Al , Jezany Mahdy , Shine Joe , Kagongo Eliud 
Published: March 2023

Abstract
Drilling exploration wells can present challenges to well delivery with the more notable including unpredictable formation (in-situ) pressures. The unpredictable pressures, such as wells experiencing high background gases while drilling the openhole, place more emphasis on the ability to provide isolation successfully to ensure well integrity. In addition, the unpredictable pressures can affect the casing design as well as the wellbore stability, which can have logistical restraints associated with a remote location's response time. As a result, a method or series of practices led to cementing success providing the isolation required to ensure well integrity and deliver the well objectives safely.
Understanding the Key Factors Affecting Well Integrity in Horizontal Well Multistage Hydraulic Fracturing
Authors: Arshad Waheed , Khan Khaqan 
Published: March 2023

Abstract
With the significant increase in multistage hydraulic fracturing in the last two decades, occurrence of casing failures has also become noticeable, raising wellbore integrity concerns among operators worldwide. The consequences of casing failures can be varied, but in many cases they affect well production, wellbore accessibility, and, in some rare instances, present well control and associated risks.
In fact, tubular damage during fracturing is not caused by a single, consistent reason. Rather, it varies greatly across the industry. Investigators have identified several different factors that come into play when identifying tubular fatigue failure when exposed to high stress loads during pressure and temperature cycles in a multistage fracturing operation. Other contributing factors are well trajectory and borehole inclination with respect to the fracture plane, the quality of the cement bond, the development of "trapped pressures," or change in in-situ stresses that could initiate formation movement.
A parametric study was conducted using worldwide data to evaluate and determine the main factors controlling overall well integrity. Casing failure was defined as a reduction in the internal diameter of the pipe from its initial completion state before hydraulic fracturing. The failure events were studied and compared with the same factors in successful wells.
This paper provides an insight into the relationship between borehole condition (primarily hole size), well deviation, well azimuth, dogleg severity, pipe centralization, the type of hydraulic fracturing treatment performed (i.e., proppant frac or acid frac) and the risk of pipe deformation. By understanding the primary factors that affect well integrity, the likelihood of casing failure can be predicted and avoided ahead of time, save fracturing costs across high-risk areas, and not jeopardize production from multimillion dollar completions. Managing well integrity is essential for development of oil and gas resources while preserving the environment and assuring safety of personnel.
Well Monitoring New Concept Based on Artificial Lift Power Indicators, Identifying Failures and Minimizing Energy Consumption Costs Due to System Inefficiency
Authors: Coria Pablo , Devincenti Victor , Orozco Maivy 
Published: March 2023

Abstract
The search for energy efficiency and the reduction of operating costs in medium and high flow artificial lift systems is becoming increasingly relevant due to the incipient energy crises. Therefore, the need of developing methodologies and algorithms that allow a rapid, early and effective power consumption deviation identification in huge electro submersible system fields has become a priority need.
Using statistical tools and innovative calculation methods can generate energy deviations zones of analysis that are divided by ESP pumps models and types of producing wells; according to this identification, the required strategies for adjustment -based on the reference efficiency frameworks- are addressed. This process allows to quickly identify and visualize the inefficiencies of the system (Well - ESP) together with the result of the taken actions. Online monitoring can be performed daily, weekly or monthly.
This methodology for monitoring and identifying energy deviations allows -in an agile and dynamic way-, to identify and prioritize energy deviations of large ESP fields, referencing them to pre-established statistical standards, taking action by being able to detect and react early, making the exploitation of producing wells more efficient and increasing the run life of the system. Additionally, it allows detecting viable possibilities for adjustments and optimizations, such as a Green Pulling, reducing downtime and higher costs in ESP repairs, obtaining at the same time, competitive failure rates for complex exploitation oil fields. The time reduction, with the power deviation early notice, allows concentrating the analysis effort on management and improvement actions, which can be complemented with the influence of other relevant variables (motor temperature, % motor load, etc.) that affect the system.
Monitoring energy variables allows summing an economical impact in each operating point, directing the taking of actions towards an economic, ecological and sustainable strategy.
This paper brings the implementation results and the follow up of a methodology focused on algorithms based on energy indicators from flow rates, linked to the characteristics of ESP pumps. This monitoring process integrates production, electrical, economic and equipment positioning variables in fields with more than 1,200 ESP running.
Setting ESP Packer at High Inclination Intervals Using a Creative Completion Design Achieving 30% Completion Time Savings in a Middle East Oil Field
Authors: Almuallim Mustafa , Agarwal Rohit Kumar , Silva Paul , Shaikh Jaffar Al , Al-Herz Mohammad 
Published: March 2023

Abstract
After years of oil production, conventional ESP placement at shallow depth ~ inclination of 45° is no longer capable for production and thus the need to push the ESP deeper and closer to the reservoir at 55°-85° deviation is deemed necessary, which negatively impacts the ability to set packers using conventional slickline systems. A novel approach of setting ESP packers is presented in this paper, featuring a modified completion design that allows the packer to be set at any inclination without the use of conventional methods like coil tubing, wirelines, or slick lines.
To begin with, the paper provides an overview of technologies that are currently being used to overcome the challenges associated with setting production packers at an incline exceeding 45°. It introduces an alternative approach to set packer using a simple, yet an innovative modification in the design of completion assembly despite historical challenges associated with packer placement at highly deviated intervals. The Optimized system creatively integrates application of multiple fit to purpose technologies and valves assembly across the completion string. This assembly can be operated to allow string self-filling and holding pressure from above which provides a simple method of hydraulically setting ESP packer. Additionally, other technologies were used to ensure hydraulic cables and lines are safe and away from any potential pinch point especially while running through deviated intervals. Finally, study concludes with detailed design criteria and description, execution road map and contingencies.
This system was successfully implemented across 5 extended reach wells (ERD) with packer planed at an inclination range of 64° to 86°. Revised approaches enabled time reduction of over 30% compared to other wells across which packer was set with conventional, time consuming and risky operation like coiled tubing and wireline tractor. Optimized completion design is currently adopted by operator as standard practice to set ESP packer across highly deviated trajectories for both multi and single lateral extended reach oil producers in a particular field in the middle east.
The document provides a novel approach to set production packer at high inclination by utilization of optimized and simple completion design compared to expensive and time-consuming alternative approaches. This can easily be duplicated worldwide to optimize production packer setting especially at high inclination and thereby saving tremendous time and cost.