bluuebunny/crossref_metadata_2025 huggingface dataset:
A Novel Cement Additive to Prevent Gas Migration in Producing and Abandoned Oil and Gas Wells
Authors: Mohamed Abdelmjeed , Giovannetti Bruno , Salehi Saeed , Muhammed Farag
Published: October 2022

Gas leakages from producing and abandoned oil and gas wells are considered a threat to the environment and increase greenhouse gas emissions. They are also a cause of sustained casing pressure and other wellbore integrity problems, which are significant operational and safety issues. Cement integrity in oil and gas wells is crucial to ensure excellent zonal isolation and prevent gas migration to the surface over a long production time. Therefore, cement slurry should be carefully designed to yield better performance in sealing the annulus between the casing and drilled formations. This study introduces a novel additive to improve the cement slurry properties and mitigate the gas migration problem.

The new cement formulation consists of water, dispersant, retarder, cement (class G), and a novel polymeric anti-gas migration additive. To evaluate the performance of the new additive, several formulations were prepared by varying the additive concentrations from 0 to 6.0% by weight of cement (BWOC). The mixing process was first optimized to fulfill better slurry performance. The effect of the new additive on static gel strength (SGS), gas migration, slurry rheology, fluid loss, consistency, thickening time, and unconfined compressive strength (UCS) was studied at 70°C and 90°C. Static gel strength was the primary indicator of cement slurry's ability to resist gas migration; therefore, it was initially used to optimize the additive concentration. Eventually, the optimized formulation was tested on a new experimental pipe setup to simulate the actual well conditions.

The SGS results showed that the new additive could effectively reduce the gas transition time to 15-25 minutes for the optimum concentration, compared to around 50 min for the base cement. The optimum concentration was found in the range of 1.5-3% BWOC. Adding more than this concentration would increase the cementing operation cost without further improving the performance. Consistency and rheological measurements confirmed the excellent stability and pumpability of the new cement slurry with this concentration range. The new additive performed better with increasing temperature up to the maximum testing temperature, 90°C. A high reduction in the fluid loss was also observed with the introduced additive compared to base cement slurry and other commercial additives. Pipe test results showed that the new additive completely stopped gas migration, and no gas leakage was observed for more than 24 hrs. In contrast, a high leakage rate was observed with the base cement after only 4-6 hrs.

The findings of this study are promising. Adding 1.5-3.0% BWOC of the new additive was adequate to maintain cement slurry expansion and develop enough static gel strength in a short time. Using the introduced cement formulation with more optimization to the cementing operation would significantly improve wellbore integrity for short-term and long-term operations.
Hollow Bit: The First Worldwide Campaign Result of a Breakthrough Technology of Slot Recovery Technique in Offshore Abu Dhabi Field
Authors: Fukuda Kengo , Biyanni Hanifan Mayo , Toma Motohiro , Moslim Samaawi Moslim , Toki Takahiro , Al Zaabi Ali Yousef , Najjar Abdelrahman , Chammout Omar
Published: October 2022

Demands for reutilizing existing slots on the offshore platform are expected to rise to maintain oil and gas productivity by drilling and completing the well to different targets, whereas most of the slots are occupied in mature fields. Slot recovery operations are one of the solutions to recover occupied slots. Different slot recovery techniques have been executed in the Offshore Abu Dhabi field, which include cut & pull, milling, Casing Pulling Tool, and Conductor Deflector Tool techniques which are time-consuming and require high overpull to release the casings. The hollow bit is a slot recovery technique that enables the user to recover casing by the standard fishing tool (i.e., casing spear and overshot) without excessive overpull which inherits a risk of surface equipment damage and safety issues on the rig floor. Moreover, overcoming the strong cement bonding between a 30" conductor and 13-3/8" casing is difficult and is dependent on the cement condition. The casing is cut into short intervals to be pulled out which results in a long operation duration. Hollow bit removes the annulus cement between 30" conductor pipe and 13-3/8" casing by washing over the cement. Casing cuts can be minimized since the removal of cement from the annulus overcomes the cement condition uncertainties which results in a shorter slot recovery duration.

This paper presents the 3 hollow bit field trials conducted in 2021-2022 in Offshore Abu Dhabi. Lessons learned accumulated from each trial were implemented in subsequent wells to improve the performance. Performance was increased by 60% compared to other slot recovery methods by reducing the operation duration from 20.8 days to 12.5 days. Best practices that can be implemented to similar application by hollow bit are also presented.
Latest Generation Flat Rheology Fluid Enables Successful Drilling at High Overbalance Conditions Utilizing Multi-Functional Nanoscale Additive
Authors: Olivares Tulio , Pino Rafael , Rojas Juan Carlos , Cascone Alessandro
Published: October 2022

Drilling for Oil & Gas is never an easy task. In order to reach to the hydrocarbon source, several layers of drilling formations with different characteristics need to be drilled through. This leads to a challenge of needing various well designs, tools and fluids to drill these wells. An ideal case would a fluid design that is flexible enough to be applicable for most of the fields; yet providing consistent properties across a wide range of temperatures and pressures. A uniquely customizable flat rheology fluid was developed to meet a variety of conditions in terms of pressures from low density to high density to maintain well control and temperatures from 60 °F at surface to 150 °F - 400 °F range downhole. The fluid constituents were carefully selected to exhibit a flat rheology profile to aid in trouble-free drilling of the well. The fluid also used a novel nanoscale additive to aid in filtration control to enhance filter cake properties in high overbalance situations and minimize the risk of differential sticking which is a large contributor of NPT in drilling operations. The fluid properties were then optimized with typical drilling parameters and well conditions in a robust physics-based hydraulics simulator to ensure successful execution and anticipation of various scenarios. After vetting various formulations in a laboratory setting designed to mimic downhole conditions including contaminants like acid gases; the fluid was ready to be utilized to drill a well in onshore. A holistic plan was utilized to manage all project aspects from resources, logistics, procedures and what if scenarios to allow for a successful implementation of the fluid.

The two intervals were drilled ahead of schedule with no NPT or unscheduled events, such as losses or differential sticking despite the fact that one of the intervals had high overbalance of 5,700 psi over the pore pressure. The fluid’s properties were tracked across various temperatures to understand the fluid behavior at different sections of the well where it showed consistently flat rheological profile.

The hydraulics simulations showed superior hole cleaning conditions as well as the ability to stay within the narrow drilling window which was confirmed by the trip conditions with no back-reaming and not inducing fractures or experiencing any downhole losses. The fluid performance and consistent fluid properties including rheology, filtration control and suspension of cuttings and weight material with no sag occurrences were enabled by using novel emulsifier chemistry, customized polymeric additives and a novel multi-functional nanoscale additive for high overbalance conditions.
A New Application of Pressure Transient Analysis to Calculate Completion Efficiency in Long Horizontal Wells with Limited Entries: Flow Restrictions and Well Architecture
Authors: Al Qahtani Abdullah M. , Al Qahtan Bader A.
Published: October 2022

This paper presents a novel application of pressure transient analysis to calculate completion efficiency in long horizontal wells with limited entries to calculate completion efficiency in long horizontal wells, using pressure transient analysis to unleash flow efficiency restrictions and maximize well productivity. This calculation scheme could be done prior to well drilling using reservoir data and calculating unsteady flow pressure perturbation around flow ingresses, using Green's functions, or during production modes at any time using downhole pressure transient behavior at each flow restriction. The total flow efficiency is impacted by the configuration of well architecture and the distribution of flow entries along horizontal sections and laterals. The unsteady flow pressure perturbation could be augmented into the wellbore flow hydraulics to determine the overall performance of wells, especially in finite-conductivity horizontal and multilateral wells. The use of pressure transient analysis showed a very instrumental tool to calculate the overall efficiency of completion in horizontal wells. It can explain why some horizontal wells didn't produce to the design capacity and help salvage well completion design. This advanced calculation scheme has never been used as a tool to calculate a completion efficiency factor by which the overall all performance of horizontal wells are measured. The scheme is an innovative way to design and maximize well completion to decide on the configuration of well architecture and placement of flow entries/restrictions in horizontal sections. This is best applied during production mode to continuously monitoring completion efficiencies in cases where multiphase flow occurs, with real-time data acquisition of pressure transient downhole.
Maximizing Reserves Value Using Multilateral Wells - A Decision Support Tool and Key Applications
Authors: Yanez Eglier , Saputelli Luigi , Al Hosani Fahad
Published: October 2022

As global energy market conditions demand more reliable energy sources, fields with lower productivity reservoirs struggle to provide cost-effective production options. Multilateral technology (MLT) has been used to improve per-well deliverability and economics, i.e., by increasing the drainage area with less surface footprint.

The objective of this work is to review the state-of-the-art of selected completions to provide insights for adoption of MLT technologies including lessons learnt, experiences and some recommendations. Six globally selected demonstrative applications were reviewed to validate the technical assumptions for selecting a particular MLT concept.

The first step was to review earlier applications in similar formations to identify the degree of success of these wells and to research possible better candidate reservoirs. Secondly, a screening tool analyzes specific reservoir production conditions where the application of MLT would be compelling. The research was focused on reservoirs with noticeable high-economic potential interest in the application of such technologies.

We propose a workflow combining both technical and economic criteria to guide the selection of MLT vs single lateral wells, providing a cost-effective and lower risk decision support tool. We introduced a process to identify the MLT applicability window based on the Activation Index (AI) and the mother to Lateral cost ratio. Our proposed method is likely to be beneficial for operators which struggle to make smart decisions on MLT well concept selection.

We show that MLT completions can reduce between 10 and 30% the D&C cost requirements while enhancing field development NPV in the range of 1-21%, and with the potential of promoting fields that were otherwise uneconomic. We discuss here the success factors to make this possible. In addition, one key advantage of MLT is the acceleration of production since multiple zones are available for production much earlier compared to the single zone wells. Furthermore, the implementation of MLT completions is enabling the recovery of reserves on fields where the surface space is constrained due to either a high number of wells or a geographic limitation or even a combination of both.
DST in Deep Offshore Exploration: Pushing the Limits
Authors: Arnold Sebastien , Jaffrezic Vincent , Dubes Gregory
Published: October 2022

Objectives / Scope

Reservoir connectivity has a strong impact on the number of wells that are required to produce a hydrocarbon accumulation and, ultimately, on the associated economics of the development. Appraisal well tests are commonly conducted to confirm that wells are able to drain sufficient reserves. In a deep-water environment however, the test durations are constrained by high rig costs which consequently limit the investigated volumes to only a portion of the reservoir. This paper describes two cases where close collaboration between reservoir and drilling teams allowed to achieve long radius of investigation while minimizing rig time and risk exposure.

Methods, Procedures, Process

In the first case, a ball valve located below the production packer was acoustically activated during the final build-up to isolate the lower part of the DST string. The upper part was then pulled out of hole to carry out well abandonment. Using an electromagnetic telemetry (EM) system, it was possible to communicate with the downhole gauges installed below the ball valve to continue the monitoring of the pressure build-up during the abandonment operations.

In the second case, the rig remained on location but in a harsh environment with high risks of well disconnection. Few years ago, such operation was still considered as technically challenging with important financial exposure in case of disconnection during the DST operations. To face that challenge, the drilling team performed a careful selection and qualification of the DST string and surface equipment using the results of high angle acceptance tests and computerized finite element analysis. The DST acquisition program was optimized by the reservoir team both before and during the operations to minimize the time spent on location while collecting sufficient information. Specific forecast methods were also developed to anticipate any degradations of the weather conditions.

Results, Observations, Conclusions

In the first case, it was possible to record over 600 hours of undisturbed build-up data while minimizing the time spent on location. An investigated distance of 9.5km from the well was achieved saving additional appraisal wells. In the second case, over 200 hours of pressure data were collected in perfectly safe conditions. This provided key insight on the dynamic behavior of the field and should greatly help to assess the development of this deep offshore discovery.

Novel / Additive information

This paper illustrates how the combination of innovative techniques and close collaboration between drilling and reservoir teams can maximize the value of information during DSTs. This can help to reduce the number of appraisal wells and to de-risk the development of deep offshore discoveries.
A New Generation, Multi-Sensor MLWD Device for Optimized Drilling Performance and Reservoir Insight: A Case Study, Offshore Abu Dhabi
Authors: Fares Wael , Abbas Nashat , Al Nokhatha Jamal , Parker Tim , Montasser Ahmed , Mubeen Muhammad
Published: October 2022

Acquisition of reservoir properties measurements, high-resolution borehole images, and continuous directional surveys has historically required the deployment of multiple discrete tools. This paper details the first-time deployment of a new, integrated, multi-sensor tool, in one of the largest oil-producing reservoirs in Abu Dhabi. Deployment of the new technology helped to achieve a new record for the longest bit run with the new system.

The new measurement-and-logging-while-drilling (MLWD) platform incorporates multiple sensors with significantly reduced footprint, delivering critical, high-definition measurements closer to the bit than previous technologies with modular designs. In this case study, the existing MLWD technologies were included in the drilling assembly for measurement validation and benchmarking. The new tool provided borehole size and shape measurements, and high-resolution radius and acoustic reflection-amplitude images with an axial resolution of 0.1 inches. In addition, the tool provided vibration, weight, torque, and pressure-while-drilling measurements, to help optimize the drilling parameters, and an azimuthal gamma ray sensor for formation evaluation.

The new design also includes a compact directional module to provide static surveys and high-resolution continuous inclination and azimuth while drilling, facilitating wellbore placement and safe and efficient drilling by minimizing the tortuosity. The bottomhole assembly included LWD gamma ray, propagation resistivity, formation density, and neutron porosity sensors from the legacy system, along with a point-the-bit rotary steerable system and a new-generation resistivity sensor. The new system was deployed in an 8½-in. horizontal section of 14,318 ft, reaching a total depth of 25,500 ft. MD. It was the longest run of the new MLWD system globally to date.

The real-time MLWD data included gamma ray and ultrasonic borehole size. Furthermore, the high-resolution radius and reflection-amplitude images captured geological features that often control the reservoir properties such as vugs, fractures, and minor faults. The radius measurements provided details of the borehole size and shape, with a three-dimensional (3D) visualization of the wellbore helping to identify borehole enlargement and breakout.

In addition, the new and legacy propagation resistivity measurements matched closely. The continuous, high-definition surveys helped the drilling team to ensure smooth hole and avoid any collision risk with nearby wells.

The forward plan is to continue to deploy the new generation of tools in a wider range of conditions and locations, and to add additional next-generation sensors, including higher resolution density, neutron porosity, and deep multilayer reservoir mapping sensors.
Optimizing Wireline Formation and Evaluation Operations in Deep Horizontal Wells: Case Study
Authors: Franco Nata , Corona Mauricio , AlMahroos Mohamed , Kestring Thiago
Published: October 2022

The evaluation of horizontal gas wells using routine logging tools is more challenging, when compared to vertical holes. The standard practice is to deploy logging tools on a drill pipe, typically known as Pipe Conveyed Logging (PCL), however, this standard conveyance method is risky and time-consuming. Therefore, this paper focuses on the optimization project to convert all PCL runs, including formation testing, into time-efficient operations by using groundbreaking wireline conveyance techniques.

Assessing fit-for-purpose alternative options is necessary to de-risk open hole logging operations. Firstly, a thorough review of the logging requirements was performed for reservoir section in each hole size, namely 8-3/8″ and 5-7/8″. Concurrently, the wireline conveyance techniques present within the services provider's portfolio, were evaluated against the normal borehole conditions, open-hole risk profile and potential saving opportunities. Thus, the tailored risk-based workflow created suitable conveyance methods for each application. It ensured that the newly initiated solutions matched with operational needs. Considerations were also made to upgrade the existing technologies to meet the logging objectives.

An extended-reach wireline deployed tractor system was implemented to pull the tools for over 2,800 ft of open hole of up to 87 degrees inclination, across highly depleted carbonates in the 8-3/8″ deviated section. This technology combines the use of an electric-driven tractor with low-friction taxi wheels. It provides better data quality due to enhanced tool stand-off and saves more than a day of rig time compared to a conventional PCL run.

In addition, in the 8-3/8″ section, formation testing runs were conducted using high-tension cables with up to 60 dg inclination, and maximum overbalance of 3,920 psi. Up to 14 pressure points per run were taken down to 13,700 ft without deploring any differential sticking incidents or tool obstructions.

PCL runs were replaced with through-the-bit logging services across the 5-7/8″ horizontal reservoir, typically stretching across 5,000 ft. This unique conveyance platform is designed for long laterals, and it consists of a suite of logging tools which is integrated to the drill string, allowing the combining of logging operations and reaming trips. Prior to running the stage-frac lower completion, the reservoir was successfully logged.

This innovative engineered approach was implemented across large scale, multiple rigs, in one of the most prolific gas fields, accelerating the learning curve of logging operations optimizations. It has helped to decrease risk and lower well construction costs, by saving more than one day of rig operation time. Thus, alternative conveyance methods will enable operators and service companies to work tightly together, driving logging efficiency in the Middle East and other basins.
Using the Properties of Carbon Composite Rod to Decrease the Uncertainty of Along Hole Depth Measurement, Leading to Increased Confidence in Field Wide Geological Models and Well Placement.
Authors: Troup Duncan John
Published: October 2022

Depth is probably the most important measurement that can be made in the petroleum industry because it is the reference for all other measurements that may be recorded. The discrepancies between drillpipe depth and wireline depth are well documented and both suffer from limitations. The properties of carbon composite rod, including low stretch coefficient and negligible thermal expansion, when combined with advanced well entry modelling allow very precise determination of absolute depth.

Carbon composite rod is an enabling technology for intervening in extended reach wells, and part of the qualification process has been the evolution and verification of the predictive simulation software, which has proven to be very accurate and reliable. Part of the output of the simulation model is the calculation of a tension/compression profile along the entire length of the rod with the BHA at any position along the wellbore, which allows the extremely accurate calculation of the total cumulative stretch at any point along the wellbore, and hence the absolute position of any measurement devices.

Carbon composite rod does not behave like drillpipe, wireline or coiled tubing so traditional modelling software cannot be used to simulate well entry. A bespoke mathematical technique was developed to fully describe the behaviour of the rod in a downhole environment and was initially used to predict well entry parameters, assisting in planning. Following each intervention, predictions were compared with actual performance for both surface weight and downhole cable head tension. The software's facility to assign individual friction factors to the rod and individual BHA components, and also to any area of the completion, was used to build extremely detailed well models in order to overlay calculated and measured parameters. With the model built, cumulative stretch with the measurement BHA at any point can be calculated with great accuracy. The results showed that the trajectory of the well bore and any areas of isolated high friction can have a very large effect on stretch and can render traditional stretch corrections liable to extreme errors. Further modelling in a variety of different well trajectories was undertaken to build further understanding of localised stretch effects and showed that even in complex wells stretch may be described by fourth order relationships with depth.

The paper will demonstrate that the physical properties of carbon composite rods allow very precise modelling of cumulative stretch along the entire wellbore even in complex trajectories. This raises the prospect of being able to record a reference log of absolute depth which can then be used correct any previous data. Should the reference log be a continuous gyro survey, the absolute position of the well bore in 3 dimensions may be derived.
Utilization of a Building Blocks Concept to Develop a Joint Technical Scope of Work of Electric Line Logging Services for All Abu Dhabi Onshore and Offshore Operations
Authors: Elyossef Bassem S. , Nasr Karim , Al Mazrooei Abdulaziz S. , Fitzpatrick Sam G. , Abu Safieh Ashraf R. , Farooq Assad , Al Marzouqi Muna S.
Published: October 2022

As part of the ADNOC's strategic approach to maximize the value of procurement, a Group Category Management initiative was launched for Electric wireline logging services with a primary objective to leverage the spending and volume of ADNOC Group Companies. In support of this direction, ADNOC sets the following goals; ADNOC to become the regional operator of choice, securing Gulf Countries Council (GCC) Wireline service capacity to ensure tool and personnel availability, implementation of log output-based scope design, promoting operational delivery through the introduction of performance-based work incentives, reducing operational delays and Non-Productive Time (NPT) through improved supplier performance management, increasing access to new technology, promoting In-Country Value (ICV), and increasing Emirate employment in Wireline Logging.

ADNOC Upstream operating units execute oil and gas drilling and production operations that spread over onshore and offshore Abu Dhabi and handle various reservoir types and conditions such as shallow/deep reservoirs, sweet/sour, and ultra-sour gas reservoirs. Under such circumstances, a critical success factor of this initiative was underpinned by a unified scope of work that accommodates Onshore/Offshore, sweet, and harsh operating environments to come up with a scope that balances the work environment requirement, service quality, and cost. This paper describes the detailed journey to build a joint scope of work that can serve all ADNOC operating units in a cost-effective and flexible model based on the building blocks concept. To compartmentalize, ADNOC technical team built the scope package and respective cost model based on service type that includes Open Hole, Cased Hole and Explosives logging services. The proposed scope of work model was tested by designing different types of jobs. Later, a technical group verified the proposed model by comparing the model outcome with the current discrete models for Onshore, Offshore, harsh, and extended reach well environment. It was concluded that integrated scope of work is a safe, robust, and cost-effective model that assures the same level of service quality is provided all over Group companies considering the differences in operation environment and requirements.

Following the scope and strategic option review, a group level procurement event was determined as the best course of action to achieve the set objectives. As such, a market capability assessment and demand analysis were conducted to initiate the sourcing event.
Optimizing Future Drilling Center Location Using Advanced Analytics and Machine Learning Algorithms in Offshore Abu Dhabi
Authors: Salimov Rail , Jaffres Benoit , Alblooshi Jamal , Sarsekov Arlen , Chirkov Maxim , Al Kuwaiti Humaid
Published: October 2022

Long term development planning requires infill drilling. Due to limited number of slots in offshore environment new drillings centers (Well Head Towers) are required. Optimized location of drilling center can have big impact on reducing drilling expenses. Two main challenges related to WHT placement are tackled in the paper. Firstly, where to place future drilling center based on subsurface coordinates and drilling constraints. Secondly, how to allocate dozens of subsurface targets to multiple drilling centers.

Developed drilling center placement optimization algorithm is based on multiple optimization parameters related to well cost. Main driver of total well cost is well length. Hence, it will be used as primary optimization criteria. It requires solving complex 3D well trajectory analytically and screening thousands of iterations for various WHT locations. Secondary optimization criteria are type of mud used in main section of the well, seabed depth etc. All parameters are summarized in total well cost map helping to choose global best location of WHT. Wells allocation per WHT are performed with constrained K-means clustering algorithm.

Proposed methodology was developed in house using open-source programming language. Generated well trajectories are identical to the outputs of commercial drilling software proofing the robustness of the solution. Screening hundreds of drilling center location requires thousands of well trajectories generation which can be computed and analyzed within seconds.

Proposed methodology was applied in optimizing WHT locations on several Long-Term Development projects across various offshore fields. Drilling center's location are generally chosen based on simplistic approach such as arithmetic average of landing points. Proposed approach can save in average ∼3-5 percent of total drillex as final trajectories will be shorter and mud type in main section can be simplified.

Restricted K-means clustering approach is proven to be quick and efficient approach to allocate all subsurface targets to chosen number of wellhead towers respecting maximum number of wells per wellhead tower. Once subsurface targets are allocated per WHT, main optimization algorithm is applied. The novelty of developed approach is ability to screen drilling center locations for any complexity long term development plans in-house within minutes and it does not require any external resources/licenses since it's developed in open-source programming languages.
Sustainable Treatment of Wastewater Generated by Oil & Gas Drilling Rig Camps
Authors: Alexandersen Dennis Kronborg , Headley Tom R. , Prigent Stephane , Schmuelling Marcus
Published: October 2022

Oil & gas exploration and production activities often takes place in remote areas with no immediate wastewater treatment access. It is industry practice to establish own treatment facilities or to tanker wastewater long distance to municipal treatment facilities outside the concession areas. The remote setting and harsh operating conditions makes it challenging for mechanical treatment systems to comply to national effluent discharge standards. This paper explores if a nature-based portable solution can help overcome this challenge while promoting sustainability. By deploying a Test Unit (ReedBox®) to Khalifa Industrial Zone Abu Dhabi in the United Arab Emirates, the treatment performance is tested for compliance. Following a 26-week test period, a third-party performance verification confirmed that the Test Unit satisfactorily treated the wastewater producing an effluent in full compliance with the Abu Dhabi Recycled Water and Biosolids Regulations for P1 Unrestricted Reuse. As a result, the portable nature-based wastewater treatment system offers a green alternative to operators and contractors willing to uptake innovation that helps protect the environment.
15KPSI MSF System with Metal Expandable Open-Hole Packers; Making a Difference in Delivering Required Capabilities to Challenging Wells
Authors: Al Haji Ahmed M. , Ufondu Kenechukwu O. , Arias Urbina Rommel Ernesto , Nazri Mohammad Noor
Published: October 2022

This paper describes the design, implementation details, and the added value of deploying a 15 kpsi Multi-Stage Fracking (MSF) system with an open hole (OH) metal expandable packer. The system would be an additional enabler for successful OH MSF system deployment, especially for wells with concerns over wellbore stability (pack off and/or washouts), getting stuck while running with the completion string to the deployment depth and in Extended Reach Drilling (ERD) wells.

The system used four (4) stages deployed in a 5-7/8″ open hole with a length of 3,000 ft. The completion equipment was successfully deployed. Rigless activities commenced by fully expanding the packers (with 12,400 psi), before the multistage fracturing was conducted successfully. The slim Outer Diameter (OD), the ability of drill pipe rotation, the 15 kpsi fracturing capabilities in hole size up to 6.5 inches and the lack of internal moving parts like sleeves or mandrels; enabled the system to deliver the fracking capabilities required with challenging OH conditions.

The system provided reservoir compartmentalization with 15 kpsi capabilities between different stages, 15 kpsi fracturing capabilities in hole size up to 6.5 inches and slim outer diameter to enable the deployment of the completion string into challenging open hole conditions. Furthermore, the system has the ability of drill pipe rotation to enable the deployment of the completion equipment to overcome any obstruction while running in hole and no internal moving parts, which lessen the mechanical failure risks.

The 15 kpsi MSF with metal expandable frac packer system has the following novel features in wells with wellbore stability (washouts) concerns, where the 15kpsi fracturing capabilities in hole size up to 6.5 inches, as well as long seal length.

As for wells with wellbore stability (pack-off) concerns, the system provides relatively slim OD, for smoother running and, that, can be helpful in wells with differentially stuck concerns. Also, it provides better reliability and robustness, as there are no internal moving parts.
Application of Computer Vision in Diagnosing Water Production Mechanisms in Oil Wells
Authors: Abdelaziem Osama Elsayed , Gawish Ahmed Ahmed , Farrag Sayed Fadel
Published: October 2022

Diagnostic plots, introduced by K.S. Chan, are widely used to determine excessive water production mechanisms. In this paper, we introduce a computer vision model that is capable of segmenting and identifying multiple Chan signatures per plot, for the sake of surveillance and early screening, given that wells could exhibit diverse mechanisms throughout their lifecycle.

As deep learning demands a vast amount of information, we start our workflow by building a dataset of 10,000 publicly available oil wells that have experienced varying water production mechanisms and annotating them. Next, we perform pre-processing and remove anomalies from production data, which could be misleading in analysis. Then, we visualize Chan plots as images, split the dataset, carry out augmentation, and have the data ready to be used as input for a CNN (Convolutional Neural Network) layer. Eventually, we utilize YOLO, a one-stage object detector, tune hyper-parameters and evaluate the model performance using mAP (mean average precision).

The collected data from fields in Alaska and North Dakota represent oil wells that have been producing for decades. When working with some wells that possess noisy production data, we identified challenge, bias, and tedium in human interpretation of Chan plots. Subsequently, we observed the inevitability of cleaning well production data prior to constructing the plots, and thoroughly revealed its effect on enhancing the potentiality to get a satisfactory score. In addition, we concluded that following a simple approach of active learning, a technique that allows the user to analyze mistakes of prediction and label the data incrementally in order to achieve a greater score with fewer training labels, accomplished a significant boost in model performance especially with under-represented classes. The newly proposed model employs automatic feature extraction, expresses data in much more detail and is confirmed to be robust as it successfully predicted multiple mechanisms of excessive water production, with confidence scores higher than 80%, in wells that exhibit different production conditions such as horizontal trajectories, artificial lift, water flooding, stimulation, and other well intervention events.

In this work, we introduce a novel computer-vision model, which combines image processing and deep learning techniques to identify multiple water production signatures that a well can undergo, and eliminate the subjectivity of human interpretation. This approach has the potential to be effective, as a part of workflow automation, in expeditious surveillance of large oilfields.
Wells Operations Data Visualization Through GIS Mapping Software
Authors: Aufi Saif Al , Ismail Asif , Mamari Maadh Al , Ruwaishdi Mahra Al , Cruz Rafael , Haddabi Ishaq , Bulushi Khamis Al , Khatri Fahad Al , Manhi Hamed Al , Kalbani Abdallah Al , Yaroubi Saif Al , Hashmi Jawad , Mashrafi Abdullah
Published: October 2022

PDO has grown rapidly over the past few years and is seen as an innovative organisation and a leading company within the Middle East when it comes to applying best practice, adding value to the economical and societal development of the Sultanate of Oman

In the highly volatile oil business market, it is very crucial to having information on fingertip, making informed decisions, visualization of the area where the task is been carried out, to know who owns and operates, liable route network adhering to the HSE policies and safety, availability of assets and resources thus helping the workforce to connect, collaborate and deli ver the business KPIs seamlessly.

Current ways of operating was the field resources have to navigate to different standalone systems, offline data or maps, excels and data sources to sketch out the needed information which was time consuming, indecorous infor mation, non availabilty of SME to validate and authenticate the data, information is especially valuable for PDO business.

As PDO understand the value of data decided to embark the journey through which allows PDO personnel's to connect data of different forms like Products, Assets, Devices, Location, Resources and to use the same in rationalized useful value to reveal the benefit of data value in PDO Business.
Unveiling the Value of Data - An End-to-End Data Analytics System at Scale for Logging Operations
Authors: Torlov Vladislav S , Kanfar Majed F , Saumya Sachit , Gill Oscar
Published: October 2022

This paper presents a summary of a Wireline Logging Operations Analytics System and a patented workflow that has brought a paradigm shift to a logging operations assessment. The aim was to provide a holistic insight into logging operations and enable optimization of time, operational capability, resources, and reduction in carbon footprint. The described digital transformation initiative led to the design and implementation of an end-to-end data analytics system at scale.

The process started in 2020 with the implementation of events tracking software that enabled Logging Engineers to create a comprehensive dataset containing detailed labelled wireline logging activities record with an extensive set of job metadata. The records comprise temporal depth, surface, and downhole tension data, drilling parameters log, detailed job parameters, downhole instrumentation, and time-mapped activities which constitutes a comprehensive hierarchical events tree. The operational events are either tracked during the job or identified based on a stack of raw log signatures and are captured through an interactive graphical process using a dedicated interface.

To leverage the big data, sets of immersive analytics dashboards was designed to address different parties’ inquiries. The system integrates data from multiple sources and includes extensive ETL (extract, transform & load) routines. Multiple queries and further computations were applied to unveil the full value of data within the Well Logging domain including operating efficiency, incidents records, hole conditions tracking, sustainability etc. Domain knowledge paired with statistical and machine learning analyses allowed ranking performance affecting factors and establishing the variable operational performance metrics. Using the established baselines, activities duration is compared to a calculated reference, and is summarized over the attribute of interest, e.g. logging company or a crew, area, rig, conveyance, category or distinct activity, job type, time etc. Periodic summary review allows tracking the performance of Logging company in respect to established metrics by a variety of parameters. Some Logging companies have introduced Engineer's scorecard that provides performance insights and input to a competency assessment. The implemented approach moves away from a rudimentary efficiency assessment (binary productive vs non-productive time). The implemented system is a pioneer in data analytics driven solution at scale for logging operations. According to the Logging companies, it is the first exhaustive recording of logging activities in the world, that can be used to evaluate operational performance, identify, prescribe, and track the improvements.
Computer Vision Based Smart CCTV Solution
Authors: Alam Fahad , Alraeesi Ammar
Published: October 2022

With the assessment of the latest technology safeguarding humanity for their safety and security round the clock is an immense challenge. Deep learning algorithms are being developed to provide greater performance, accurate classification, and the extraction of useful information. Numerous deep learning architecture techniques have been put forth in recent years. Massive security camera deployments have been made, together with additional sensors, to monitor important infrastructure, including Oil & Gas industries, military bases, airports, power plants, banks, etc. As human resources are expensive and have a finite skill set, manual monitoring by human operators is an ineffective solution in modern world. The goal of AI technology used in CCTV system is to automatically monitor infrastructure or the environment with little to no human involvement. These monitoring activities involve automatically locating and tracking objects (such as people or vehicles), followed by additional analysis and action. Techniques for artificial intelligence (machine learning), signal processing, and image processing are key components in the development of such intelligent systems.

The most popular modality (device) for a surveillance system is a visible camera like a CCTV. It has been used for a very long time to keep an eye on people and events. To automatically evaluate data (image or video) from surveillance cameras, extensive research has been done. Numerous specialized review papers on background-foreground segmentation, objects detection and classification, tracking, and behavioral analysis have covered a large portion of these investigations. Other than visible cameras, many sensor modalities have been investigated for surveillance systems, including thermal and infrared cameras, radar, and audio sensor.

This paper will present the case study of a comprehensive overview of computer vision base CCTV surveillance system and to review the current approaches to each of its processing steps.
The potential diagnostic use of clinical characteristics and mitochondrial DNA copy numbers of peripheral blood and ovarian tissue in polycystic ovary syndrome (PCOS) patient
Authors: Song Yi , Deng Yan , Chung Jacqueline , Li Tin Chiu , Wang Chi Chiu , Li Hu , Yang Tao , Sui Yi , Tang Tao
Published: October 2022

Polycystic ovary syndrome (PCOS) is a complex, heterogeneous syndrome of uncertain etiology characterized by hyperandrogenemia, hyperinsulinemia, chronic anovulation, and polycystic ovaries. Recent studies showed that the abnormalities of mitochondrial metabolism are related to PCOS. We hypothesized that mtDNA copy number is an important marker that can reflect mitochondrial function. In this study, 135 PCOS patients and 57 age-matched healthy participants were studied. Mitochondrial DNA copy number in peripheral blood and PCOS ovarian tissues, and some clinical parameters were assessed. From the single factor analysis, we can find some clinical parameters are different between PCOS and healthy women and the mitochondrial DNA copy numbers in peripheral blood in PCOS women were significantly lower than in healthy women. We also found that there was no correlation between mtDNA copy numbers in peripheral blood and in ovarian tissue. After multiple logistic regressions, we identified the occurrence of PCOS was significantly positively correlated with BMI and pulse, and negatively correlated with mitochondrial DNA copy numbers in peripheral blood. We also found the decreased mtDNA copy numbers in PCOS patients are independent of these clinical parameters. We constructed the ROC curve based on these risk factors and found if they have potential to predict the patient’s outcome. In conclusion, the changes in mtDNA copy number and some clinical parameters may provide new ideas for PCOS diagnosis. More studies are necessary for further validation of their use in PCOS diagnosis.
Known risk factors of the developmental dysplasia of the hip predicting more severe clinical presentation and failure of Pavlik harness treatment
Authors: Lankinen Vilma , Bakti Karim , Helminen Mika , Välipakka Jarmo , Laivuori Hannele , Hyvärinen Anna
Published: October 2022

Purpose. Developmental dysplasia of the hip (DDH) varies from mild instability of the hip to subluxation or total dislocation of the joint. Well-known risk factors of DDH include pre-natal breech position, female sex, positive family history, hip side, primiparity and the mode of delivery. Aim of the present study was to further evaluate known risk-factors of DDH, find associations with more severe dysplasia (characterized with Ortolani positivity) and find risk factors of failure of the Pavlik harness treatment.
Material and methods. All children with the diagnosis of DDH treated in Tampere University hospital in the years 1998-2018 were retrospectively identified for the study and the data was collected from the medical records. Total of 948 patients were included.
Results. Breech presentation was strongly associated with Ortolani positivity (p<0.001). Among breech born infants C-section was strongly associated with Ortolani positivity (p<0.001) (OR 1.833, CI95% 1.332-2.524), whereas vaginal delivery was not (p=0.420). Breech presentation was not associated with ending up for spica casting and/or operative treatment (p=0.849) despite the association with Ortolani positivity.
Ortolani positivity (p=0.002), positive family history (p=0.013) and primiparity (p=0.048) were associated with ending up for spica casting and/or operative treatment.
Conclusion. Breech presentation seems to increase the risk of Ortolani positive DDH. However, these infants are likely to recover with initially started Pavlik harness treatment, as it was not associated with elevated risk for undergoing more robust treatments. Positive family history is associated with the most severe cases of developmental dysplasia of the hip, and it may predispose to the failure of the Pavlik harness treatment.