bluuebunny/crossref_metadata_2025_split huggingface dataset:
Transforming Production Phase WIMS to a Game Changer Smart Well Integrity Monitoring System with Real Time Automated Engineering Analytics
Authors: Jasem Mohammed , Fabian Oka , Dawson Graeme , Silari Madhukar , Al Junaibi Bader , Challagundla Srinvisa , Noble Steven , Al Sawadi Obadah , Rodriguez Jose , Mylnikov Pavel , Ge Haoyou 
Published: October 2022

Abstract
First implementation of a new well integrity management solution with integrated and automated workflows, the Well Integrity Management solution (WIMS) that helps company to minimize risks and production loss by the real-time monitoring of the operating limits of sour gas wells. Leveraging digital twin technology, the new software enables engineers to rapidly identify high-risk wells, take corrective actions faster, and mitigate issues to maximize well availability.
Previously, the process of monitoring well integrity was based on the multiple software applications which is time-consuming. To address the challenge, we developed a WIMS coupled with the well engineering analysis approach. The system achieves the following: Representative and accurate well barrier equipment inventory for the entire asset.Safely operate critical HPHT wells to their maximum potential,Eliminate critical and costly barrier failures while minimizing production interruption through automated workflows and alert triggers,Free SMEs to perform critical well integrity management tasks, including technical reviews of sensitivity analysis that determine more accurate MAASP/MAWOP values,Track corporate KPIs and report regulatory requirements effectively.
WIMS integrates source system for the well engineering applications. A first-of-its kind, WIMS uses Real Time engineering analytics and artificial intelligence to run as a Digital Twin for well's Operating Limits and diagnoses potential failures. It also measures, reports and displays most realistic well integrity status for the wells, based on company well integrity standards, processes and best practices. This paper details how we were able to successfully address these challenges which encouraged us mutually to work towards further integration with engineering tools and more automation of WIMS processes.
Important Note: All well data, engineering analysis, operating limits and well information etc., displayed or referred to in this publication, are not necessarily actual and only used for illustration purposes.
Technical Feasibility of a Through Tubing Circumferential Zonal Isolation Gamma Scanner for Plug and Abandonment Implementations
Authors: Inanc Feyzi , Jones Allan , Yuan Peng , Anniyev Toyli , Kverneland Johan , Chuilon Pierre 
Published: October 2022

Abstract
This paper presents a feasibility study of a novel nuclear sensor design toward finding volumetric flaws in cement behind two or more tubulars in a wellbore. The sensor concept targets plug and abandonment activities and the presented results include experimental test setups built for the purpose, results of simulations and experiments conducted for determining the range of applicability.
The measurement is based on a gamma-gamma measurement concept that incorporates a rotating interrogating beam illuminating the wellbore for an azimuthal scan while the tool is in motion in the borehole. The radiation source is a conventional Cs-137 radioisotope emitting 662 keV gamma rays that can penetrate through two metallic tubulars to reach the cement. The detector is a gamma detector that is collimated to accept gamma rays from the volume illuminated with the gamma rays and centrally positioned in the tool body. The detector collimator rotates in synchronization with the rotating interrogating beam providing an azimuthal scanning capability.
The feasibility of the concept was initially tested through simulations that provided encouraging results for detection of volumetric flaws in the cement between the outer casing and the formation. This was followed by experiments that were conducted using synthetic test formations embedded with various volumetric cement flaws. The rock sizes were representative of infinite rocks encountered in typical logging runs. The experimental setup provided not only different flaw sizes but also different tubing positions inside the casing annulus. A generic gamma-gamma tool was run vertically in the synthetic rocks without a tubing and with a tubing in place. The vertical runs were repeated around the borehole and images were formed. Another mode of experiment was conducted by rotating the tool around its axis. The motivation behind this was to study the azimuthal response of the gamma-gamma scanner in an eccentered position. The results from the experiments were in line with the simulation results confirming that it is possible to detect volumetric flaws in the cement between the outer casing and the formation.
This paper demonstrates a method for detecting cement flaws that is pivotal in plug and abandonment activities. Different measurement techniques are usually sensitive to different flaw morphologies. While nuclear methods cannot detect micro-channeling, they can be very efficient in detecting volumetric flaws in cement. In contrast, such flaws cannot be efficiently detected by other measurement techniques. The results presented here show how a gamma-gamma measurement can be used to detect and characterize volumetric cement flaws that can be encountered in multi-annular completions.
Development of a New Reservoir Drilling Fluid to Achieve Matrix Injection
Authors: Morrison Alexandra , Biyani Mahesh , Kadam Sunita , Bose Sohini , Zhou Bill 
Published: October 2022

Abstract
Injector wells comprise a small portion of the wells drilled globally; however, they pose unique drilling fluid challenges. Required for pressure support and production maximization, these wells can be costly if the desired level of injectivity cannot be achieved without first flowing them back. Traditional drill-in fluids (DIFs) contain starch and xanthan, the latter is known to impair injectivity due to its poor acid solubility. This paper describes the development of an aqueous reservoir drilling fluid targeted for injector wells.
A brine-based reservoir drilling fluid was designed and developed utilizing a novel dual-functional xanthan-free additive to provide the necessary rheological and fluid loss properties without impairing injectivity. A thorough qualification was undertaken to evaluate fluid performance under a variety of conditions. Properties investigated included rheology, static-age stability, fluid loss, lubricant compatibility, and contamination susceptibility. A delayed-action filter cake breaker fluid was also designed and tested for suitability with the new reservoir drilling fluid. Return injectivity measurements were performed on both aloxite discs and core plugs to simulate the ability to achieve matrix injection without flowback.
The novel additive provided excellent rheology, suspension, fluid loss control in the reservoir drilling fluid tested in the laboratory. Return injectivity testing demonstrated that the new DIF significantly outperformed existing fluids that contain xanthan or diutan without adjusting the delayed-action breaker formulation. The rheological performance of the new fluid was found to be stable and can be adjusted either though the novel additive concentration itself or through particle size optimization. Evaluation of the spent filter cake breaker effluent demonstrated that the novel additive was fully degraded, as compared to the traditional DIF in which an iodine test indicated the presence of whole starch persisting after several days contact with low-pH breaker.
Existing DIF solutions function adequately for oil and gas producing wells given the low lift-off pressure resulting in minimal impairment to productivity. When considering injection wells, superior performance was achieved using this newly developed DIF which provides the potential to reduce well construction costs by eliminating the requirement to flow reservoir fluids back to a production facility before injecting.
The Sensor Ball Revolutionizes Wireline Operations
Authors: Al-Hajri Nasser M , Ureiga Sulaiman T , Javed Muhammad Imran , Alqarni Hassan S 
Published: October 2022

Abstract
This paper will share production engineering perspectives on the deployment of the sensor ball technology. The sensor ball is a new integrated production logging platform that was developed to measure primarily wellbore downhole pressure and temperature. The reduction in size of the innovative tool sensors has enabled packing of the tool in an attractive wireless manner. The sensor ball records wellbore data and stores collected data on electronic memory chips. The scope of this paper is to explain the working mechanism of the technology and outline the proper methodology for deployment by recapping the operational events of a successful sensor ball field trials on two water wells.
The sensor ball is deployed and collected from the wellhead tree cap in a carefully designed sequence of operational steps to ensure no damage to the tool or tree valves can take place. The sensor ball has dissolvable weight element that allows for the tool to descend to the target measurement depth. The tool is made from material, with a specific density, that allows for buoyancy floating in water after the release of dissolvable weight. Conventional wireline gradient pressure and temperature surveys preceded the sensor ball runs during the trial phase. The objective of the wireline surveys is to provide a basis that qualifies the sensor ball data and quantifies its accuracy with respect to gauge measurements. The developed field trial test success criteria were: Successful mechanical deployment/retrieval of the sensor ball within programmed timeComplete data recovery from the sensor ball upon retrievalAccuracy of recovered data compared to wireline surveys below 5% average absolute error
The comparison results of the sensor ball and wireline data at both water wells showed consistency and accuracy. The average absolute error was less than 3 % for pressure and temperature data. Further, the field trial has met all developed success criteria. The deployment of the sensor ball technology by oilfield operators will enable realization of several tangible benefits such as reducing acquisition time of downhole data compared to wireline and reducing manpower requirements for pressure and temperature surveys. The sensor ball enhancement to manpower requirement can allow for simultaneous data acquisition operations that were not possible with wireline surveys. Oilfield operators can avoid direct costs related to wireline units and associated equipment and its maintenance. Further, the typical mechanical risks associated with well intervention can be eliminated by deploying the sensor ball technology.
An Innovative Wellbore Cleanup Solution for Non-Cemented Lower Completions Saves 27 Million$ in ADNOC Onshore
Authors: Varma Esha Narendra , Mwansa Peter Levison , Husien Mohammad , Bin Bahrom Abdul Raman , Saragi Raymond , BinSumaida Ali Sulaiman Ahmed , Al Samahi Musabbeh Khamis , El Moumni El Walid Ben Mohamed , Al Shamsi Juma Sulaiman , Alshaigy Ahmad Othman , Gaurav Anchit , Abdelhalim Khaled 
Published: October 2022

Abstract
The long-term development of any mature field requires a fresh perspective of long MRC (Maximum reservoir contact) wells and increased well accessibility. To improve well accessibility the deployment of lower completion has been a mandate. Onshore UAE Field demands drilling Slim hole (6″ /6-1/8″ ) laterals and Slim Hole ERD (Extended reach drilling) wells with 4.5″ Uncemented Lower Completion. This paper highlights the innovative wellbore cleanout procedure prior installation of Lower Completions.
Conventionally, using Water Based Mud (WBM) with high friction factors in 6″ Horizontal Hole (HH), two trips were required to reduce the friction factor prior running the Lower Completion. The optimized solution allowed wellbore clean-up and displacement of brine in one trip with drilling assembly (BHA). This innovative technique eliminated one dedicated trip for wellbore cleanout and thus saved millions in CAPEX and Business Plan days.
The T&D data for 5 wells with dedicated cleanout trip were compared to clean-out with 6″ drilling BHA with viscous-lubricated brine. The 6″ BHA was optimized to fit with innovative dormant drilling scrapper and lubricated viscous brine was displaced in the Open Hole. A thorough hole cleaning procedure was formulated and was applied to all the wells.
After analyzing over 5 wells, it was observed that in both runs, the one with 6″ BHA compared to dedicated cleanout-trip, the torque and drag values were similar and the effective reduction in friction factor was similar. This supported the elimination of planned dedicated cleanout trip and saved average 2 days/well and 27MM$ for year 2022.
This optimized BHA design with enhanced hole cleaning procedure was a keystone in deploying slim 4-1/2″ lower completion in WBM system. This practice led to successful deployment of First Slim Hole ERD in UAE with 15000ft of 4-1/2″ lower completion with WBM system. This was a one-of-a-kind achievement in UAE.
Successful First Rigless Fully Retrievable ESP System Installation with Coiled Tubing in West Kuwait: Case study
Authors: Al-Matar Mohammad Ahmed , Al-Haddad Mohammed , Najaf Abdulaziz , Al-Obaidly Mubarak , Slama Hedi , Badrawy Kareem , Mahmoud Wael , Baidas Abdullah 
Published: October 2022

Abstract
As hydrocarbon reservoirs deplete and lose their natural energy to flow, artificial lift techniques become unavoidable to keep wells development plan and sustain hydrocarbon production.
In several cases, Electric Submersible Pumps (ESPs) have become a reliable and important tool in today's global oilfield and inevitably the preferred artificial lift method to keep these wells alive and achieve a high hydrocarbon recovery however, since these pumps incur heavy workover rig interventions, the increased operating cost and the unwelcome disruption to the production operations often lead to an unfavorable profitability contrast for oil and gas operators
With the oil and gas economics nowadays managing the operating cost and decreasing the deferred production is the key elements of sustaining a positive business across.
In Kuwait, nearly 67% of the producing wells are equipped with artificial lift systems as several filed are producing from depleted or sub hydrostatic reservoirs that requires an electric submersible pump to help sustaining the life cycle of reservoir development
In an attempt to slash down the overall operating cost related to maintaining and lowering those Electric Submersible Pumps (ESPs), an alternative deployment option was assessed riglessly with Smart Coiled Tubing thus eliminating cost the heavy rig intervention and operational disruption
A team of engineers were assigned to design and meet the challenges of such an application. The team conducted a detailed and comprehensive analysis of all the risk aiming to deliver an optimal intervention design and procedure to ensure minimum cost.
The intervention was designed to use real time downhole telemetry on coiled tubing through fiber optics to monitor and manage the loads exerted on the Electric Submersible Pumps (ESPs), downhole.
After retrieving the ESP, Coiled Tubing clean out run using high rotating jetting nozzle was carried out on the docking sub of the ESP for the deployment and eventually, the ESP was lastly run and placed at the required setting depth.
This paper describes the successful installation of the first Rigless Fully Retrievable ESP System Installation with Coiled Tubing in West Kuwait.
A New Rigless Approach for Fishing a Stuck and Parted Coiled Tubing in a Live Well
Authors: Allegretti Gianluca , Lerose Marco , Mangione Alessandro , Di Vincenzo Stefano , Luppinan Salvatore , Cervantes Julio , Tarchi Mohamed Lamine , Cerri Paolo , Abid Mohamed Lakhdar , Boyce Robert , Mahmoudi Hadjer , Mebarki Safa , Ahmim Nacer Ridha 
Published: October 2022

Abstract
Usually, the preferred way to restore production in wells with accessibility heavily compromised is by rig workover activity. However, a preliminary approach in rigless mode followed by rig activity can be even more effective in the presence of several critical issues. Here we illustrate the methodology and technical solutions adopted to perform a challenging rigless fishing job to make the subsequent rig workover operation quicker, cheaper, and safer.
A workflow was developed for a course of actions to perform a complex fishing intervention while fully respecting the well control requirements. Considering the well status—1½-in. coiled tubing (CT) stuck in 4½-in. tubing at 7582 ft due to scale buildup, parted in two segments side by side, top of fish at 1345 ft and with no injectivity in the well—it was decided to adopt a fit-for-purpose rigless strategy by combining conventional fishing tools (flow release overshot, continuous cutting overshot) with a CT anchor, which guided the electrical line (EL) cutting tools inside the pipe while keeping it in tension. To accomplish the target, a robust design, with multiple contingency plans was properly defined and successfully implemented. In addition to the main constraint of having a CT pipe parted and stuck in the tubing, the scale deposit prohibited killing the well by bullheading. Consequently, the overall fishing operations were planned and managed as if the well was alive.
The alternate use of CT fishing tools, CT anchor, and EL cutting operations allowed recovering approximately 6958 ft over a total length of 7398 ft, leaving just 440 ft of CT pipe stuck in hole inside the scale deposit (with the new top of fish at 7142 ft). As a result, a complex well situation, which could have led to a long and expensive rig operation, was successfully approached in rigless mode, leaving the well ready for a simpler workover activity.
The use of Continuous Cutting Overshot (CCO), through a standard "cut & drop" approach, was limited by the CT lubricator height. An innovative fishing approach was then deployed: a proper CT anchor BHA, to latch and hang the CT pipe in the tubing wall, was run. The beveled shape of the CT anchor allowed EL tools to enter inside the CT pipe and cut the same above the free point, so recovering longer sections of pipe.
Single-Trip Completion Technology Development for ERD Wells
Authors: Murray Fraser , Wee Keith , Kouadio Yao Fernand , Parihar Shardul , Wills John Andrew 
Published: October 2022

Abstract
A well operator wanted to maximize operational efficiency for extended-reach drilling (ERD) wells of more than 45,000 ft measured depth (MD) by converting from a two-trip to a single-trip completion solution. A safety valve, field-adjustable polished bore assembly (PBA), and production packer were developed for the single-trip completion design used in both the producer and injector well environments. Strong collaboration between the well operator and completion technology supplier resulted in a tailored technology development and validation program that reduced operational risk as much as reasonably practical. The technology developer achieved several significant technical milestones during the process, which are discussed in more detail. A pre-run computational modelling strategy was developed to manage deployment risks and ensure the technology operated as designed. The analysis performed using this strategy, along with details on how this data is used to configure the technology is also discussed. Track record details are provided to demonstrate successful deployment of the new technology in a live well environment. To date, the operator has successfully deployed three systems in wells between 30,000 and 45,700 ft MD. The well operator and technology supplier continue to collaborate on ongoing and future wells, where the developed system adds significant value.
Well Completion Design Integrity Evaluation Including Thermal and Stress Analysis for Multi-Zone & Multilateral Well Completions
Authors: Shahreyar Noman , Butler Benjamin , Al-Sheyrey Hussain 
Published: October 2022

Abstract
This paper provides an overview of an analytical method to assess tubing loads, design integrity, and buckling behavior under complex mechanical, pressure, and thermal-loading conditions. The methodology uses a proven tubular design and stress analysis software, applied to a multi-zone intelligent completion and a dual string TAML level 5 multilateral well. Tubing load scenarios are evaluated in separate phases of the completion installation and operating phases. Simultaneous production and injection scenarios are also examined for a dual string multilateral well.
Full well models are created and evaluated, analyzing stress-loading for both well types. Thermal simulation is first performed, followed by tubular stress modeling to guide tubular selection and completion design. Analysis covers completion operations during installation such as packer setting and testing, well operation scenarios such as well stimulation, simultaneous production / injection for the dual string multilateral, and production scenarios for the multi-zone intelligent completion with multi-position Interval Control Valves (ICVs) in various positions.
Results presented show temperature/pressure changes for each simulated scenario and the corresponding load state cases in the modeled wells. Tubular axial loading, burst and collapse limitations, pipe movement and buckling potential are modeled. The resultant forces on completion packers are modeled for the well with the multi-zone intelligent completion. These results are evaluated to select and optimize the well completion design and also identify well operating limits with respect to a set of combined ICV positions during commingled well operations. Results on estimated annular pressure buildup during well operations are also presented with some guidelines on minimizing annular pressure buildup in annuli through mechanical control or well completion landing practices.
This paper provides workflow outlines and results for tubing stress analysis in complex multi-zone intelligent completion and dual completion multilateral wells. Variations in operating temperatures and pressures in such scenarios can place completions in conditions that can exceed design margins that are already limited due to production-casing diameter constraints. The methods and results presented are useful for balancing design-versus-risk for the completion. They can also provide savings by optimizing well design to meet design integrity standards without being overdesigned.