bluuebunny/crossref_metadata_2025_split huggingface dataset:
DST in Deep Offshore Exploration: Pushing the Limits
Authors: Arnold Sebastien , Jaffrezic Vincent , Dubes Gregory 
Published: October 2022

Abstract

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

Abstract
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

AbstractThe 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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

AbstractThis 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

Abstract
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.