bluuebunny/crossref_metadata_2025_split huggingface dataset:
Innovative Performance Models for Integrated Projects in Offshore Deepwater Operations
Authors: Nunez Davila Andres Felipe 
Published: March 2023

Abstract
Integration in offshore drilling environments was traditionally limited to bundled services and managed by a project manager. The success of the integration model was mainly related to equipment logistics and quality assurance. The objective of this paper is to describe how the traditional model has evolved from a bundled long-term service commercial relationship to the innovative performance award model that has been implemented in an integrated project in the Gulf of Mexico.
The offshore and deepwater drilling environment is characterized by its high operating cost; thus, risk management is one of the key aspects for the project's success. The oil and gas industry has continuously evolved during the last decades, moving toward digital and automation technologies and applications. The new performance model is based on a time definition and further estimation of budget required. Factors are linked to specific rewards in case the predefined objectives are achieved. The associated risks definition becomes critical to ensure the predefined estimates are achievable. To support the risk management process, the application of digital solutions support the planning and execution stages.
The multiwell performance analysis and benchmarking tool enables us to evaluate the historical results and comparison between rigs, including and not limited to determining the project baseline, identifying the historical invisible lost time, and defining the main areas of improvement.
This tool supports the definition of the risks factors and provides the inputs to determine the most accurate project budget.
For the execution, one of the historical associated risks was related to the drilling fluids and well integrity. It is commonly found in the area for wells to be drilled under narrow operating windows and having extended sections. The increase of frequency and accuracy of drilling fluid properties verification is fundamental to ensure the system is under the required parameters and properties limits previously determined. The automated rheometer has been developed to increase the frequency and accuracy of rheological drilling fluid properties, thus minimizing the impact of one of the most relevant risks across the area.
Finally, the focus to optimize the schedule and logistics was based on synergies developed across the different services involved. This included activities that are carried out from a single point of contact, eliminating the duplication in tasks and minimizing the resources required.
Real-Time Autoregressive Deep Learning Framework for In-Line Automatic Surface Logging
Authors: AlShehri Abdallah , Katterbauer Klemens , Yousef Ali 
Published: March 2023

Abstract4th Industrial Revolution (4IR) technologies have assumed critical importance in the oil and gas industry, enabling data analysis and automation at unprecedented levels. Formation evaluation and reservoir monitoring are crucial areas for optimizing reservoir production, maximizing sweep efficiency and characterizing the reservoirs. Automation, robotics and artificial intelligence (AI) have led to tremendous transformations in these areas. From AI inspired well logging data interpretation to real-time reservoir monitoring, technologies have led to cost savings, increase in efficiencies and infrastructure centralization. In this work we provide an overview of how autoregressive deep learning methodologies can lead to major advances in the field of formation evaluation and reservoir characterization, providing a comprehensive overview of the technologies developed and utilized in this domain. Furthermore, we provide a future outlook for smart technologies in formation evaluation, and how these sensor-derived data can be integrated. This also describes the challenges ahead. Future developments will experience a growing penetration of 4IR technology for enhancing formation evaluation in subsurface reservoirs.
Interactive Analysis (IRA) Determining Focal Reservoir Parameters Dominating Estimated Ultimate Recovery (EUR)
Authors: Shan Youngbin , Wu Yaoguang , Hu Aiguo , Li Fanlei 
Published: March 2023

AbstractInteractive Analysis (IRA) is a new reservoir study method which applies to both condensate oil & gas reservoir and conventional oil & gas reservoir.IRA establishes the correspondence between stage EUR equivalents and reservoir parameters.Often, reservoir parameters include but not limited to porosity, permeability, burst pressure, Poisson rate, Oil saturation or Gas content, Free gas content and adsorption gas content, pay zone thickness, resistivity, mud content, etc.In a specific compartmentalization, it is important to decide which parameter is the focal parameter dominating the productivity. If the focal parameters can be decided, operators can use this evidence to decide which zone and which sub-zone drilling must fully penetrate through. Additional, when well is designed for hydraulic fracturing, engineers can use this data to design stages and clusters. Designing of higher focal parameter quality in stage and cluster is certainly a contribution to better frac efficiency and EUR.IRA is expressed that the Normalized Correlated Coefficient (NCC) Vector is equal to the Moore-Penrose inverse of the Normalized Reservoir Parameter Quality Factors (NRPQF) matrix multiplying the Normalized EUR equivalent (NEE) vector. NCC deriving from the IRA represents the weight of productivity contribution to EUR.Analyzing IRA equation, the focal parameters dominating the well EUR can be determined. With focal parameters available, operators can optimize the drilling criteria and optimize frac design.For a specific compartmentalization, the focal parameters derived from IRA shall give consistent focal parameters which dominate the higher productivity and lower productivity. When a well is hydraulic fractured, the NEE can be tested and analyzed. To input the NEE into IRA equation, the frac efficiency is also reflected by NEE.Three shale gas wells in a compartmentalization are analyzed via IRA analysis. The positive focal parameters, irrelevant parameters and negative focal parameters in each well and overall averaging give good convergence.Two wells in condensate oil pay zone in a compartmentalization are also analyzed via IRA analysis. The positive focal parameters, irrelevant parameters and negative focal parameters in each well and overall averaging give some convergence.If a NCC is bigger, it dominates EUR. If it is small or very small, the contribution to EUR is less or measily. On the other hand, if a NCC is positive, it increases the productivity when the parameter quality is higher. If a NCC is negative, it decreases the productivity when the parameter quality is higher.No focal parameter dominating EUR can be understood until IRA is proposed.Rather than reservoir mechanics analysis, IRA gives explicit linear mathematical expression which makes engineers easier to calculate by aid of Matlab coding.IRA analysis is a breakthrough to understand the intrinsic structure between reservoir parameters and EUR.
A Review: Progress of Diverter Technology for Oil and Gas Production Applications in the Past Decade
Authors: Li Wengang , Sahu Qasim 
Published: March 2023

AbstractDiversion technologies is becoming widely used as part of multistage fracturing operation and acid stimulation especially in carbonate formations completed with extended reach or multilateral wells. Further importance is gained during the development of unconventional resources where large number of stages are required with enhanced stimulated reservoir volume (SRV) per fracture. This is achieved by improving the fracture network and complexity using far field or deep diversion techniques. Diversion gained more value since it was an enabler for more efficient refracturing jobs since it can divert treatment from existing fractures. One of the main functions of diverters is to direct the stimulation fluid toward the desired treatment interval to increase the efficiency of productivity enhancement process.A diverter could be either mechanical or chemical. Mechanical diverters include packers, ball sealers, coil tubing, and particulate diverting agents such as benzoic acid flakes, rock salts, wax beads and fiber. Chemical diverter is mostly used as temporary barrier of fluid during treatments, and will get converted back afterwards by chemical means. Chemical diverter can be divided into two main types: polymer-based diverter and surfactant-based diverter. In the past decade, biodegradable diverter has been developed according to the concern of both environmental protection and less formation damage. Relative permeability modifier (RPM) can also be used as diverter in some cases. All the above diversion techniques will either divert the fluid in the wellbore or deep inside the formation based on the objective of the treatment and type of fluid used.This paper covers diverters in both injectors and producers with the applications of matrix acidizing, acid fracturing and hydraulic fracturing. In matrix acidizing, polymer-based acid gel is one of the most applied diverters. Adding N2/CO2 to form foamed acid, the treatment efficiency could be further enhanced with less formation damage. Viscoelastic surfactant (VES) improved acidizing was also applied in many cases. Fiber based acidizing fluid proposed to be effective in carbonate formation. Multi-stage acid frac jobs were done in 2011 in tight gas carbonate formations. A new trend of acid frac is to use CO2 energized fracturing fluid for tight, sour gas formations. Far-field fracturing mechanism was studied by means of solid particulate diverting agents. Eco-friendly and biodegradable diverters were applied for zonal isolation. Nanoparticles, as new generation of diverters, have been used for EOR as foaming agents since beginning of this decade, especially at HTHP conditions; nanoparticle stabilizers were applied in polymeric gel and VES system to enhance the stability for diversion fluid.To make the best performance of diverters, limitation on working conditions of each type of diverter would be identified, such as cost, temperature range, pH range, size distribution, and compatibility with fluid additives.
Successful Analysis of Acoustic Sand Monitoring in Tandem with Online Sand Sampling to Safeguard and Optimize Production in a Mature Oil Field
Authors: Chin Alvin Zhi Siang , Roh Cheol Hwan , Noordin Fuad , Zainul Zaimi , Ho Dylan Zhe Xin , Basri Hakim , Chandrakant Ashvin Avalani , Zin Zulkifli , Rosland Eadie Azahar , Ambrose Jonathan , Taha Adam 
Published: March 2023

AbstractThis paper serves to share the findings and best practices of sustaining production for a mature field with high sand production with analysis from Acoustic Sand Monitoring (ASM) paired with Online Sand Sampling (OSS). Field B, located in the East Malaysia Region, is a high oil producer for over 40 years under a strong water drive mechanism. Water production has significantly increased over the past 5 years, which has led to significant sand production impacting surface facilities and well integrity. Hence, the need for a reliable and efficient sand management surveillance in field B.As the first application for oil fields in the region, ASM and OSS was conducted with the objective to determine the maximum sand free production rate from over 80 active strings in Field B over the span of 4 months to safeguard production rates of 10 kbopd. With ASM and OSS, a reduced data surveillance duration can be achieved within 2 hours compared to conventional well sand sampling per well which requires a minimum of 24 hours before sand production rate is determined. ASM sensors are clamped on the well flowline to detect and record the noise vibrations produced by the sand while OSS is conducted concurrently by diverting parts of the same flow from the flowline through a sand filter to have a quantitative representation of sand produced for a predetermined duration.During the campaign, choke sizing was manipulated to control reservoir drawdown. For most wells, a lower drawdown resulted in lower amplitude readings from ASM and less sand observed from OSS. However, there are several wells that had higher sand production at a smaller drawdown due to a change in flow regime (steady flow to intermittent flow) resulted from inefficient gas lift production (multi-pointing). As ASM provided the raw velocity signal which is heavily influenced by the liquid flow regime, gas oil ratio and sand production, OSS results (from physical sand produced and weight of sand particles) established a baseline for ASM signals which indicate a sand free production. Overall, ASM and OSS analysis provided a baseline for determining the optimum rate of production with minimum sand to avoid well integrity issues and protecting the surface facilities, thus allowing continuous field production of 10 kbopd.A presentation and discussion of the successful results, limitations, best practices, and lessons learnt of the ASM and OSS campaign aspires to be additive to the production surveillance sand management in the oil and gas industry by providing a fast and reliable means of identifying optimum sand free production rates for a high number of wells in a mature field.
Practical Imaging Applications of Wettability Contact Angles on Kuwaiti Tight Carbonate Reservoir with Different Rock Types
Authors: Al-Sayegh Saleh , Flori Ralph , Al-Bazzaz Waleed , Kholosy Sohaib , Al-Saedi Hasan , Abbas Abdulaziz , Qubian Ali 
Published: March 2023

AbstractThis study focuses on a tight carbonate reservoir which is located in Northern Kuwait and is classified as an unconventional reservoir. A practical imaging technique of wettability contact angle (θ°) presents "big data" as well as relative-permeability (Krw and Kro) measurements. Also, modeling, through rock image technology, the vast well-documented grain/pore boundary morphology available inside fresh rock fragments have achieved good results. Conventional laboratory relative-permeability experiments are expensive and time-consuming. This study introduces a novel method to measure/calculate relative permeability through fast, less expensive, non-destructive, and environmentally friendly techniques of imaging technology. One tight carbonate reservoir is selected, imaged, processed, analyzed, and then modeled using several pore diameter morphological models. The images are captured using a backscattered electron microscopy BSE-SEM technology analyses.In this study, two-dimensional images are used to characterize the morphology of selected samples grains and pores, using a two-step technique. In the first step, the image is captured using a backscattered electron detector (BSE), digital electron microscopy imaging, and pore-counting processing technology. All of the sample grain/pore features captured in the image are reported in micrometer units. In the second step, the pore area of such features is scanned using image analysis software that can accurately measure several morphological parameters of pore and grain spaces.A robust technique of visual estimate is used, which has the advantage of speeding the image analysis process. The visual analysis software tool counts different pores and counts grains and also measures their shapes and sizes which are crucial for relative permeability calculations. Several pore morphological models have been considered for optimum accuracy comparisons, including pore/grain relationships (area/perimeter), pore contact angle (θ), and pore count. Relative permeability is calculated based on the area of the pore/grain features measured from two-dimensional images.The study objectives are to accurately measure the wettability contact angle of huge pore geometries using 2D image technology to understand the nature of the pore network in the candidate reservoir. To study the relative permeability of internal influences of pore and grain morphology needed for enhanced oil recovery/improved oil recovery (EOR/ IOR) future programs. And, finally, to measure relative permeability faster and more accurately.
Accelerating the Host Country National (HCN) Technical Competencies Towards Sustainable and Safe Operation (Control # 23GOTS-P-434-SPE)
Authors: Yusof Yushafidi Bin , Mohamad Nor Mohamad Hafiz Bin , Hussain Ruslizan Bin 
Published: March 2023

Abstract
The paper aims to describe the methodology and processes that PETRONAS Upstream International Operation has established via the Local Talent capability Development Acceleration Framework which accelerate talent competency and progression that provides assurance on the talents technical capabilities operating the facilities around the world. It is imperative that the Local Talents are given the right and ample opportunities to develop themselves as the oil and gas industry demands capable people to operate the business efficiently in an extremely risky & complex environment.
The framework was designed as a structured competency acceleration program with rigorous monitoring aims to produce a robust and competent local workforce that can operate the plant independently. The program is phased out for up to seven (7) years with each year having specific indicators identified and determined to be achieved based on the requirements of the respective position. Local candidates are assigned to a technical coach and are tracked and monitored religiously on a bi-weekly basis to ensure they are always on track to meet the target. There are two (2) stages being set with each stage having a different target.
Stage 1 focuses on equipping the talents with minimum critical skills to perform operation critical position task in the plant with minimal guidance and supervision from the expert. Stage 2 focuses on upskilling the candidates to the "skill level" which makes them ready to execute critical position task without requirement of direct supervision.
In developing the local talent, understanding the ground rules and regulations such as the limitation on employing staff within a certain province where the plant is operated lead to a limited pools of experienced and quality talents e.g. fresh graduates. It has been observed an improvement of 35% of talents meeting the target indicators within 2 years of program implementation. A few enhancements were made along the way based on the analysis to further improve the outcome.
This paper provides some insights on the best practices/lesson learnt that can be replicated by other O&G Operators across the world in accelerating the capabilities development towards sustainable talents pool from the local talent's resources.
Comprehensive Approach for Tracing Back Potential Sources of Organic Chloride in Crude Oil
Authors: El Sayed Mohamed , Khammo Michel , Al Amri Mohamed , Al Hebshi Mona , Mousa Hisham , Elwan Mahmoud , Koriesh Mahmoud 
Published: March 2023

AbstractOrganic Chloride is organic compound that have chlorine atoms as part of its chemical composition. Over the last four years, there has been continuous increase of number of research papers addressing the corrosion impact of organic chlorides in processes that includes high temperature like distillation towers. Where chlorine atoms start to detach and form free radicals in moisture wetting metal surfaces and result in severe corrosion of distillation towers. The Fact that led regulatory agencies to set a threshold number for maximum allowable content of organic chloride in crude beyond which crude is either not accepted or depreciated. That puts pressure on oil producers to maintain acceptable levels of organic chloride content.Companies working in Refineries are more familiar with organic chlorides than upstream operators are. Having the regulatory agencies pushing on setting limits on maximum allowable content of organic chlorides in crude. Now many operators are looking for a way to keep monitoring OC within limits and to define potential sources.Organic Chlorides rarely naturally exist in crude oil. That means there should be external source to contaminate crude such as chemicals used during the extensive operations in the oil field from drilling chemicals, stimulation, production, process, ETC.A leading example from Gulf of Suez, late 2021 a concern was raised on organic chlorides levels in crude of one of the prolific fields and the risk was to have negative impact on crude oil pricing. The risk would be dramatic on the large scale since all crude from different fields gather at the processing facilities then goes to same storage tank.An integrated Multidisciplinary in house task force team was formed to investigate the root causes for OC levels. The team reviewed MSDS of all chemicals consumed in all operations, qualified a Lab from Local Market for testing OC in crude Following ASTM D4929. Developed a comprehensive sampling and tracing strategy to be able to trace back to root causes.Over 5 Months of Monitoring, tracing and correlation between ongoing daily operations and OC levels. In addition to testing chemicals for OC. It was concluded that batches of organic solvent from one supplier are contaminated by OC. Contaminated Batches were quarantined and not used for daily operations. Another supplier was qualified for temporary supply of this type of solvent.As a result of the deep investigation a set of lessons learnt and recommended practices were generated and communicated with different disciplines for awareness and compliance to maintain OC levels manageable. Which in return saved operator company from the risk of depreciation of Crude oil price.Testing Chemicals with organic components are key for eliminating OC in crude and this should be done in Batch basis.