bluuebunny/crossref_metadata_2025 huggingface dataset:
A Novel Modeling Enhancement of Emulsion in Condensate with High Aromatic
Authors: Sagar S. F. S. W. , Halim N. H. , Amir M. I. M. , Hendraningrat L.
Published: October 2023

At surface facilities, a gas field with condensate and a severe oil in water/reverse emulsion problem was observed. Due to the emulsify-prone nature of liquid production, this field suffers from Oil in Water content. Current modeling prediction tool cannot be used to predict the severity of the condensate emulsion problem because its application is restricted to black oil. This paper describes enhancements to the modeling of condensate with high aromatic mixtures.

The process flow for testing the enhancements to the modeling is as follows: At first, a large number of laboratory experiments were carried out. These experiments included the measurement and characterization of the mixture's composition, as well as the formation of an emulsion despite variations in the process's parameters, such as shear rate, temperature, pH, and solid content. To develop correlations in order to enhance the applicability of inhouse Emulsion Stability Tool by changing fluid and process parameters in preparation for future emulsion monitoring and the optimization of process facilities at condensate field. The generation of output data of Turbiscan Index (TSI) and Turbidity were accomplished through the development of a multi-equation model of data sets. The following parameters have been agreed upon and will serve as the Key Performance Indicator (KPI): > 80% of measurements in the laboratory should correspond to the model's predictions, and these predictions should be validated with data from the field.

Through the multi-correlation method, an improved modeling has been developed for condensate emulsion. During the validation process between the measurements taken in the laboratory and the predictions made by the model, the accuracy of the model reached 94% using 396 sets of trained data. During validation with actual field data, it achieved a perfect score of 8 out of 8 trained data points. It concluded that KPI has been achieved based on those parameters.

This modeling enhancement is a novel tool that can predict emulsion in condensate with a high aromatic composition to an exceptionally high degree of accuracy. It can provide early detection of emulsion issues for corrective measurement, also known as the optimization of de-oiler dosage. It has the potential to generate added value by lowering the cost of sampling, reducing the number of laboratory tests required for bottle testing, and preventing improper facility design.
A Holistic System Optimization Method to Maximize Energy Savings Within Existing Pump-Systems
Authors: Teesink P. J. , Hurst R. , Bastiaansen T. , Thomas T. , White B. , Carrillo J. Lopez , Butz V.
Published: October 2023

The increasing urgency to act on decarbonization and energy reduction targets has many Oil and Gas operators looking to emerging technologies: Green Hydrogen, Electrification of combustion processes and Carbon Capture and Storage (CCS). The timeline to effectively implement these technologies and the required infrastructure is significant. Starting from licensing, engineering, and procurement to commissioning their impact on carbon and energy can be considered part of a long-term strategy. To meet short term objectives, these initiatives need to be combined with improving the energy efficiency and associated reduction of scope 2 emissions of existing assets. This pursuit is competing for resource and capital priority with the range of asks an operational process plant pose: reliability programs, de-bottlenecking, and margin improvement projects. In a refinery, 50-60% of all electricity is consumed by pumping systems [1] with significant opportunities to improve [2]. Because of the scattered nature of this energy consumption (an average sized refinery process requires over 1000 centrifugal pumps), the key to unlocking this potential is a programmatic, data-driven approach that covers all aspects of energy efficiency: process needs, conversions and control. This paper presents a novel approach to that query.
Personal Protective Equipment Detection Using Computer Vision Techniques
Authors: Aldossary R. S. , Almutairi M. N. , Alotaibi N. M. , Serkan D.
Published: October 2023

The intensive use of chemicals, machines and electrical assets introduced unsafe conditions to the workplace. An unsafe condition is a physical condition that can cause an incident, such as operating without training, defective supplies and poor housekeeping. Such conditions might cause serious injury or even death. As well as the human impact, unsafe conditions have a significant impact on operational excellence and the financial state of a company. Companies are committed to ensure a safe environment by setting safety polices, conducting safety training, fire prevention systems, safety manuals and signboards and providing safety gears. Personal protective equipment (PPE) is safety equipment that can maintain the safety of employees in hazardous conditions, such as hot surfaces and toxic chemicals that can cause serious injuries and illness. PPE is sometimes referred to as the last line of defense. Some workers might not comply with safety policies or refuse to wear the PPE. To overcome the manual safety checks and compliance of employees, in this paper we propose an AI-powered computer vision automation solution leveraging the state of the object detection model. Computer vision is the field that mimics human vision to extract purposeful information from videos and images. Computer vision brings about various functionalities to perform tasks such as object detection, object classification, object identification and object verification. The proposed solution is developed by using a computer vision technique that detects various types of PPEs in real time. The main purpose of this project is to detect a presence of eight classes (person, helmet color: Red, Yellow, Blue and White, head, vest, glasses). The best results were achieved by applying the tunned YOLOv5 on a set of construction site images with corresponding annotations in YOLO format. The proposed solution automates the process of detection and monitoring PPE and employee behavior in operation fields in real-time. Automating the detection can reflect the business value by reducing the timeframe for tracking, creating a safe environment that in turn can increase the productivity and safety of the workers and reduce the costs of operations. The proposed solution includes all the components of data ingestion, data processing, object detection model and deployment on the edge device or server to improve safety.
Cost-Effective Solution for Highly Deviated Wells in Egypt: The Optimal: Artificial Lift System (ALS) Combination Using Continuous Rod with RRP
Authors: Tharwat M. A. , Ariza Gonzalez G. A. , Naguib A. H. , Connally D. R. , Mohammadain A. , Awadallah M. , Farouk E. M. , Halawa I. , Ghareeb M. , Salem A.
Published: October 2023

The oil and gas (O&G) industry has long believed that rod-driven artificial lift systems (ALS) are only suitable for vertical wells. Therefore, Electrical Submersible Pumping (ESP) has been the preferred option for highly deviated wells due to the risks associated with tubing and sucker rod wear. Nonetheless, ESPs are expensive and require high power consumption. When ESP Operational Expenditure (OPEX) becomes too elevated over time, operating the well is no longer economically feasible. This paper proposes an optimal ALS combination for an oil application with challenging wellbore geometry in Egypt, using a cost-effective ALS resulting in lower power consumption and fewer workover intervention expenses to improve lifting costs in highly deviated wells.

The Fadl-3 well is a highly deviated well in Egypt with a dogleg severity (DLS) value of 11.70°/100 ft and 300 pounds-force (lbf) side load. Initially, the well was completed with an ESP as the primary ALS, but over time, the production started declining, and the energy consumption required by the ESP was high, making it unsustainable to operate with this expensive ALS. The operator sought a more cost-effective solution, and in Egypt, rod-driven ALS such as Reciprocating Rod Pumping (RRP) and Progressing Cavity Pumping (PCP) have always been considered too risky for highly deviated wells. However, by combining RRP or PCP with continuous rod, the side load has been decreased to 9 lbf, minimizing the risk of failure due to tubing wear, rod parted, or any other intervention resulting from aggressive wellbore geometry. Continuous rod works with a minimum of two coupling connections, one at each end of the rod string, making it a valuable alternative for deviated or horizontal wells by distributing the contact load throughout the entire rod string length, eliminating high contact load value sections.

This paper demonstrates how the combination of RRP with continuous rods can be an optimum solution to overcome the challenges of using a rod-driven artificial lift in aggressive wellbore geometries. The results of this application in Egypt, where RRP was combined with continuous sucker rod string in a highly deviated well, prove how to make the transition from an expensive ESP technology feasible to a more cost-effective solution to accelerate the return on investment. The ALS solution provided 40% OPEX related to power consumption and 25% cost savings compared to the previous lift systems deployed in this well. The Fadl-3 well has been in operation using RRP and continuous rod since May 2022, producing 100 barrels of fluid per day (BFPD), 38 °API, 50% Water Cut (WC).
Estimating Relative Permeability and Capillary Pressure Functions from Unsteady-state Core Flooding Data Using Dynamic Optimization Techniques
Authors: Kalule Ramanzani , Alfazazi Umar , Ahmed Shehzad , Abderrahmane Hamid Ait , Alameri Waleed , Sassi Mohamed
Published: October 2023

Accurate estimation of the relative permeability and capillary pressure functions is necessary for effectively managing oil and gas reservoirs. Various methods for estimating these properties exist, but mathematical modelling-based strategies have shown promise for accurate estimates. We propose a Pyomo-based mathematical modelling dynamic optimization approach for estimating relative permeability and capillary pressure functions from unsteady-state core flooding experimental data. The approach solves the inverse problem to estimate the unknown function parameters that characterize the evolution of relative permeability in the porous medium and the forward problem to verify the accuracy of the estimated parameters and estimate the capillary pressure function trend. Our results demonstrate the effectiveness of the proposed method in estimating relative permeability and capillary pressure functions from unsteady-state core flooding data and highlight the potential for this approach to enhance reservoir management strategies.
Ground Robotics: A Comprehensive Journey Towards Remote Operations
Authors: Munoz Jean Michel , Bartoli Eric , Collin Gildas , Grenier Philippe
Published: October 2023

Normally Unattended Facilities have a significant cost reduction potential. They represent substantial technical challenges both for their design and for their operability. In our vision, operability is based on a new concept of operations with the presence of resident robots on site. However, this technology is emerging for Oil & Gas applications. This paper presents a methodology applied at TotalEnergies to qualify these solutions and accelerate their deployment on site.

Preparing to deploy a completely new technology in a context of a traditional industry and where all the technological bricks are not yet mature or even not yet well identified is far from obvious. Moreover, waiting for everything to be ready and tested before considering using the technology could take a while and delay the anticipated benefits. In order to be ready to deploy this new operating mode as soon as possible, TotalEnergies has embarked on a progressive qualification program with a succession of on-site pilots of increasing complexity and more and more integrated into the field operations organization.

This progressive approach with the definition of predefined areas of progress has allowed a sequence of successive pilots taking into account, little by little, all the components of the robotic ecosystem that goes well beyond the simple robot. The paper will present through the history of our previous pilots in North Sea, Europe and Middle East, the preparation of our last pilot on an FPSO in Africa with all the technological bricks developed for a complete integration and adoption of this new operating philosophy in our operations in order to ensure scalability to any type of site. Among these bricks, the emphasis will be placed on the field operation operator experience from the definition of missions with the customization of the existing maintenance engineering tools, to the management of a fleet of autonomous robots, the analysis of data and the necessary evolution of the field operations methods.

The paper proposes an evaluation scale to progress in the adoption of an on-site robotic solution and presents the main characteristics and first feedbacks of the latest and most complex robotic pilot of TotalEnergies.
Successful Increase of Clean in-House Power Generation Through Collaborative Inter-Disciplinary Steam Feed Study
Authors: Alkhoujah K. , Al Qaydi J.
Published: October 2023

This paper will present the successful enhancement of In-house power generation in a sour gas plant through overcoming the limitations and constraints of increasing the steam feed into the main steam turbine generators. The study included multi-disciplinary design reviews and various adequacy checks resulting in exploring a new increased safe and sustainable steam feed in the steam turbine generators and hence, increasing in-house power generation. The results of the test showed that the steam feed can be increased safely given that all structure reinforcement is done as per the recommendation of the piping experts. The steam increase has resulted in cost savings of over 70,000,000 USD for the lifetime of the plant (approximated of additional 20 years) and it will ensure reduction of greenhouse gases emissions of 35,478 tons per year.
Calculating Invisible Loss Time (ILT) Index Values & Predictive Analysis Using Bayesian Approach to Improve Drilling Operational Efficiency: Adopting Best Practices
Authors: Dubey Pranav , Garg Rachit , Kumar Prateek , Tyagi Akash , Jain Aditi , Chakraborty Pramit , Chabbra Sameer
Published: October 2023

Contribution in reducing Invisible Loss Time (ILT) towards operational efficiency has been a significant approach towards adopting best practices in drilling operations but predicting ILT using mathematical models accurately has been an additional challenge due to multiple factors contributing towards ILT. This paper sketches an algorithm for calculating the ILT Index value and then uses the Bayesian approach for predicting the invisible loss time (ILT) index value over other existing statistical methods. Digital Oilfield architecture processes along with data management systems have worked in synchrony for streaming data for analytics in real-time well engineering solutions. Defined KPIs of Invisible Loss Time (ILT) were evaluated in small sets of datasets with a Bayesian Optimisation approach using a probability model for the likeness of event occurrence. The performance of this model is evaluated based on a comparison of actual vs predicted ILT index values. Benchmarked (BM) values were calculated based on the best performance for the quarter, month, and week to understand the randomness of values. Real-time data generated were packeted for small sets as per KPIs defined for probability analysis. Sets of data made available for calculation were used to feed in the probability model for forecasting the values. Results from the predictive models showcased that batch drilling activities had a significant reduction in variance amongst the ILT values. Reduced ILT while operational activity due to adaptive learning can be calculated to quantify that cost component. Weighted percentages of KPIs in decreasing order of their significance were calculated.
Moving Towards Automation and Artificial Intelligence in Managing HSE Risks and Incidents
Authors: Go C. H. , Agusalim F. , Wan Hussin W. , Chang E. J. T. , Gonasergar V. , Abd Kahar N. S. , Syd Hamdan S. I. , Sazali O. R.
Published: October 2023

As society and the economy gravitates toward cleaner and renewable energy, the energy sector continues to diversify and increase in complexity, leading to a ‘never normal’ business portfolio and project delivery. On top of safeguarding On Time, On Budget, and On Scope delivery, this constant state of change also warrants new ways of managing Health, Safety and Environment (HSE). At PETRONAS, new ways of working is synonymous with digital transformation. Hence, this paper will outline how PETRONAS leverages digital technologies in managing HSE risks in project delivery. Since 2019, the project delivery arm of PETRONAS has invested in developing an artificial intelligence (AI) predictive model to predict future HSE risks and incidents based on historical HSE incident big data. Coupled with real-time data visualization and prescription of control measures, this digital solution has greatly enabled the organization to rationalize resources and implement informed, risk-based interventions. Considerable efforts have been made to operationalize the predictive tool, which includes stakeholder management, change management, as well as work process enhancement to incorporate automation and have end-to-end oversight on risk mitigation and intervention. This provides a HSE management framework that focuses on data-driven decision-making, which translates to targeted intervention with pace. As a result, PETRONAS project delivery arm has seen incident reduction of more than 55% for both injurious and non-injurious incidents in 2022 in comparison to the preceding three-year average. In addition, the implementation of the digital solution has enabled an improved process cycle efficiency of HSE risk management from 32% to 97%, with a reduction of total mantime of 143 hours.
Insights into CH4/CO2 Adsorption and Mechanisms Enhanced CH4 Recovery in Kerogen Slit Nanopores by Innovative Molecular Dynamics
Authors: Li Jiawei , Wang Rui , Dai Xu , Rahman Sheikh S
Published: October 2023

CO2 injection into shale reservoirs to enhance methane (CH4) production is treated as a better way to promote gas recovery efficiency as well as easing carbon emission by CO2 sequestration and storage. Most CH4 is adsorbed inside the organic micropores and mesopores (≤ 50 nm), which hold large surface areas and enormous adsorption sites. And another key structure characteristic in shale reservoir is the slit, which is usually treated as a significant sequestration medium. To better understand the microscopic mechanism of enhanced CH4 recovery by CO2 in nanopores and slit becomes necessary in shale reservoirs owing to the geological and physical properties. Laboratory experiments show challenges in observation of molecular adsorption and displacement processes inside the nanoscale pores, and also present restrains in achieving high temperature and high pressure simultaneously. Thereby, Molecular Dynamics simulation (MD) method supports a solid foundation for constructing the nanosized kerogen frameworks to investigate the gas adsorption behavior on the kerogen-accessible surface. This study innovatively introduced a new method of constructing kerogen slit nanopores, making the model more practical and approaching real underground environments. The grand canonical Monte Carlo (GCMC) method is employed to reveal the gas adsorption and sequestration in the kerogen nanopores and slit at various subsurface conditions. According to our results, the slit overlooked by previous studies particularly impacts gas adsorption process and CH4 recovery efficiency, owing to the space facilities the free gas resides. This study also examines the widespread water encroachment phenomenon, which includes various water contents and saline concentrations to mimic the real subsurface environment. Pure water has an overall negative influence on gas adsorption and sequestration, whereas, promoting the recovery efficiency of CH4 by CO2 injection. Moreover, saline has a further enhanced negative influence on gas adsorption due to the presence of ions, whereas, encourages the displacement process by CO2 injection. Ethane (C2H6) impacts the CH4 adsorption negatively but favors the recovery process. This work shows significant importance in underlining the kerogen slit nanopores structure and develops the knowledge of the comprehensive underground conditions effects on gas adsorption and recovery mechanisms at a thorough level to enhance CH4 extraction and CO2 utilization and sequestration, and provides a solid background for gas industrial production.
Pilot Deployment of IIoT-SCADA by Leveraging Low Power Communication Technologies, Sensors, and Legacy Scada Controllers
Authors: Ahmed Muhammad Shahzad , Al Bloushi Mahdi Abdula , Ali Asad , Yousef Ahmed Alhammadi , Mistry Kalpit Jayendrabhai , Henson Hushish Hernandez , Shar Aijaz Ahmed
Published: October 2023

Remote monitoring and operation are a key aspect in oil and gas facilities due to remoteness of producing and gathering facilities. Traditionally, SCADA system based on wired Fiber Optics or wireless radio communication is used to gather this remote data and perform supervisory actions. During last decade IoT (Internet of things) solutions are being adopted in oil and gas industries because of their cost efficiency and ease in deployment.

Most of industrial internet of things solutions (IIoT) available in market are utilizing LPWAN (Low Power Wide Area Network) wireless technologies e.g., LoRaWAN, SigFox, NB-IOT with backbone network infrastructures based on GSM/Satellite/ public cellular network and cloud-based application/network servers. Such solutions, due to the involvement of 3rd party/public networks pose a concern related to data security and complete network ownership.

This paper explains the deployment of a pilot project executed in Giant Oil and Gas Production Field (X Field) in ADNOC Onshore with following features,

Deployment private LPWAN based on existing telecom backhaul consisting of FoC and WiMAX network. Data was taken from exiting active instrumentation and converted to Modbus RTU routed over LoRa wireless modulation as Physical Layer by adding LoRa Slave Modules. Data from slave modules was wirelessly communicated through LoRa Master Gateways to SCADA Master Controller (MTU). This solution embeds IIoT technologies i.e. Low Power Wireless Gateways to industry proven SCADA controllers for remote monitoring as well as some operational commands such as oil well closure.

At present, in ADNOC Onshore there are multiple remote facilities e.g., oil wells, water injection wells, CP system solar stations etc. which are without centralized remote monitoring; at the same instance, the field has a widespread SCADA network based on WiMAX and FoC. This situation is equally applicable for most of oil and gas brownfield facilities. Private LPWA networks built upon these existing SCADA networks are cost effective solutions to cover the gap for remote monitoring of the facilities where near real-time data monitoring is required.

In this deployment ADNOC onshore has successfully achieved the flexibility and cost effectiveness offered by LPWAN along with the hardened centralized SCADA controller to eliminate the cyber security concerns related to Application and Hardware Security.

Below LPWA technology was primarily utilized as an added function for this development IIoT SCADA

Private Lora (Modbus RTU over physical layer of Lora)
Energy Storage Study for Water Electrolysis Based Green Ammonia Plant
Authors: Choudhury Soumya Jyoti , Singhal Sunil Kumar
Published: October 2023

As the world is battling to reduce CO2 emissions to combat climate change, green H2 and ammonia as green energy carrier are new buzz words in the industry. The biggest attraction of green H2 is as alternate fuel to gasoline and diesel. In fact, many believe that green H2 will play a bigger role in heavy vehicle industry as an alternate to diesel since it has been found uneconomical to run battery driven heavy vehicles. For long haul transport of green H2, either it must be liquified or H2 can be converted to green Ammonia (NH3). There is no established infrastructure for long haul or large quantity transport of liquid hydrogen. On the contrary, the world is quite familiar with handling of liquid NH3 and transport infrastructure is well in place for long haul and /or large quantity ammonia transport. Ships with different capacities are already in use for long haul transport NH3 with adequate facility at many ports for unloading and loading of NH3. Many counties also have infrastructure in place for inland transport of NH3 via rail route. One of the ways to produce green ammonia is electrolysis of water using renewable power followed by Ammonia Synthesis process.

Continuous Supply of renewable power is required for continuous production of green NH3 from water electrolysis. But there are some challenges. On average solar and wind energies are available for ~25% and ~35% hours respectively in a year. Though they are somewhat complimentary, together they can at best provide renewable power for 50-60% hours. This still leaves a gap of 40-50%. When only solar or wind power is a source of energy, then hours when renewable power is unavailable increase significantly. Hydro power is a continuous source of energy, but it is heavily geography dependent, capital intensive and in most parts of the world hydro power has been nearly maximized just to meet regular power demands. Upcoming and developing sources of renewable power like Geothermal, tidal, ocean wave etc. are at nascent stage of development and has only been explored at limited small-scale installations. Another continuous source renewable energy that is slowly gaining interest and is witnessing scaling up is generation of electricity from waste material. However, this paper does not include evaluation of energy generation from waste.
Fully Automated Land Rig Pipe Handling: Learnings from the First Year in Operation
Authors: Craig C. , Gupta A. , Yenzer D. , Hasler D. , Towns J.
Published: October 2023

Objectives/Scope

A look at learnings from the first year of operations on a fully automated rig floor package retrofitted to a 2000hp Permian Basin rig. Technical issues and optimization efforts will be reviewed as the factors driving next-generation pipe handling system that improves safety while meeting well delivery metrics.

Methods, Procedures, Process

The retrofittable automation system controls several tools and technologies automating pipe handling for drilling, tripping, casing running, offline stand building and routine BHA handling. Keeping the focus on this area provides a drilling environment where risk due to man / machine interactions are substantially reduced or eliminated. During this proof period, improvements have continued in casing handling and running that are being optimized based on the learnings from the current pipe handling system. These improvements are being flowed through engineering and will support the next generation automated rig floor improvements.

Results, Observations, Conclusions

While the industry continues to focus on improvements in crew safety and consistency, applications of automated drilling systems often cannot justify the expense of a next generation drilling rig. Automation systems specifically designed to be retrofitted to existing rig designs provide these capabilities for a fraction of the cost of a new rig. This means the next evolution in safety can be affordable and installed on current drilling rigs with only short windows of down time. Existing technologies like robotics, modern control systems, closed-loop feedback, and zone management for both machines and crew all combined to focus on getting the job done safely are no longer exercises in what could be, rather what is available. Within the contractor fleet several rigs of the same design are working in the same field drilling the same wells which allows for direct comparison of key performance indicators for the automation system. Learnings from the first year will be reviewed and discussed.

Novel/Additive Information

Versions of pipe handling have been with the industry since the advent of harsh environment floaters. Today's automated functionality brings a new level of crew-less operations. Keeping crew separated from hazards is the next step in rig floor operations. This improved level of safety can now be achieved through more economical, retrofittable upgrades while maintaining similar rig performance metrics.
Offline Stimulation Through a TAML Level 5 Multilateral Junction: Operational Success Within a Carbonate Formation Through Design Collaboration and Joint Planning
Authors: Bjørnseth Fabian , Tjensvoll Anna Vigrestad , Lande Hans Petter , Sastre Johanna , Barron Angus , Falnes Morten , Kogsbøll Hans-Henrik , Jakobsen Erik
Published: October 2023

Multilateral well construction is generally accepted as a beneficial method of field development within the Norwegian Sector, however methods of production enhancement in combination with multilateral technology are less common and have produced varied results. Specific to carbonate formations within the region, low complexity multilateral junctions – such as open hole laterals – in which offline stimulations have been performed, have resulted in limited production uplift or issues with junction integrity resulting in a short well lifetime. These latter issues become more apparent in weak reservoir rock, where high stress effects from reservoir compaction can result in collapse even in cased intervals.

Considering the case history and the expected stresses applied at any in-reservoir junction, a high strength Technology Advancement for Multi Laterals (TAML) level 5 junction was required to provide mechanical and hydraulic integrity. Unlike previous attempts at multilateral technology (MLT) evaluation of the field, where the focus was on the functional requirements of the equipment, an alternative approach was made whereby the operator and MLT vendor collaborated to identify suitable reservoir targets and make specific business cases for different multilateral designs. This resulted in the development of a 7-5/8 in. TAML level 5 multilateral stimulation system over an 18-month period.

The system was successfully deployed in a dual lateral application in March of 2022, acid stimulated by bullheading in June 2022 and subsequently put on production. Production data indicates flow contribution from both production legs, with a productivity in line with expectation. This paper covers an overview of the junction design, key points in the job planning process and challenges with the execution.
Field Application and Performance Evaluation of a Cost-Effective Matrix Acidizing Technique in Naturally Fractured Carbonates - Case Studies from Gulf of Suez
Authors: Hegazy Amr , Hakim Emad Abdel , Ramadan Ahmed , El-Shiekh Kareem , Saleh Khaled
Published: October 2023

Improving production in offshore brownfields presents significant challenges, particularly in extracting additional oil from layers unaffected by water breakthroughs, especially in commingled completions. Conventional matrix stimulation treatments in commingled completions often require straddle packers to achieve effective zonal coverage and selective treatment. However, the complexity escalates when mechanical isolation methods are more expensive than chemical diverters.

This research paper introduces a comprehensive approach encompassing several vital factors to enhance production in these challenging scenarios. The approach includes understanding the inflow productivity of wells, addressing water breakthrough and low specific productivity index in commingled layers, formulating appropriate acid chemical recipes, selecting suitable chemical diversion methods, identifying optimal well candidates, and optimizing job execution to improve success rates. To illustrate the application of this approach, three candidates from the Gulf of Suez basin, a complex and heterogeneous basin located in the Eastern Desert of Egypt, produced from carbonate reservoirs, are examined as case studies.

Extensive laboratory tests were conducted to develop a chemical diversion technique that simultaneously serves as a water conformance agent and a diverter. A viscous pill was prepared to temporarily isolate fractures or fissure networks while diverting the treatment away from water zones before proceeding with the complete acid treatment. The results of this innovative diversion technique demonstrate a significant four-fold increase in well productivity while reducing water cuts.

This paper presents our approach and showcases the laboratory test results of this unique recipe and cost-effective diversion technique designed explicitly for fractured and watered-out carbonate reservoirs. Additionally, it highlights the valuable lessons learned while applying these methods, offering insights and practical knowledge for future similar projects.
A Novel Approach to Delayed Survey for Stuck-Pipe Prevention Practices and Drilling Performance
Authors: Khader C. , Soh A. , Lawati Al. A. , Humaidi H. A. , Harrasi F. A. , Elanbiya M. , Bahri S. A. , Hinai A. A. , Habsi Y. A. , Belushi M. A. , Noumani A. A.
Published: October 2023

In onshore Oman, difficulties are encountered where required dogleg for horizontal wells exceeded 8 degrees and execution put it above 10 degrees due to the added geological factor. Optimized landing in thin targets needed real time adjustments, which increased the stress on the trajectory, and increased the risk of hole instability due to limitation on hole cleaning capabilities, while running high tech tools in a high Dog-Leg Severity (DLS) area, where fishing comes with a low success rate. A precise well trajectory is crucial and the way to ensure the integrity of the well path is by surveying the borehole at an acceptable frequency as per the well surveying program. Which in accordance with world wide industry practices. Such acquired data is utilized in the drilling campaign starting from the planning phase throughout execution all the way to post drilling activities.

The 8.5in section is executed with a high dogleg severity (DLS) application. As such, a flexible-designed BHA (bottom hole assembly) is utilized to deliver the high deviation required to accurately land the well 0.5m true vertical depth (TVD) into the desired zone of interest. The current survey procedure of this BHA takes approximately 5-7 minutes of stationary time, not inclusive of connection time, leading to higher stuck-pipe risk such as solids-induced pack-off and differential sticking. Therefore, an optimized mud weight is planned to support the borehole with its Nahr Umr (shale) and Shuaiba (Limestone) formations exposed. With such high mud wight, differential sticking risk becomes high in the limestone, and drill string stationary time becomes crucial to stuck-pipe prevention measures. Delayed survey was trialed in the past to be an option to overcome low efficiency pumps on some rigs, and also for under-balanced or foam drilling. In this case study, it was decided to adopt such practices to eliminate any possible survey stationary time while drilling.

The trial proved successful and reduced stationary time after connection, from 7 minutes per stand to 0 minutes per stand (100% survey time reduction). As an additional benefit, drilling performance improved and saved approximately 4.5% of well AFE time due to reduction of survey time. This experiment helped to redesign the stuck-pipe prevention practices, deploy it on all wells, and start implementation on the 12.25in hole also to save another 6% of AFE time. As a result of the trial, such practice is adopted in all rigs by the operator, and this contributed to the increased performance and reduction of stuck risk in this drilling campaign.
A Thermodynamic Approach to the Enhancement of Reliability and the Optimization of Energy Efficiency of Centrifugal Compressors
Authors: Al-Mamari Ahmed , Al-Azri Nasser , Al-Rawahi Nabeel
Published: October 2023

The Aerothermodynamic performance of centrifugal compressors is substantially influenced by the variation in suction parameters and distortion in the internal clearances or the gas flow profile. Furthermore, deposits buildup can also affect the rotordynamic response of the system which can result in excessive vibration amplitudes due to the change in the synchronous dynamic forces acting on the rotor-bearing system. Therefore, thermodynamic performance analysis is an effective diagnostic tool for optimizing energy consumption and the reliability of the compressor through early prediction of machine failure and efficiency deterioration. This work introduces an approach to modeling and monitoring of the thermodynamic performance of centrifugal compressors. The approach relies on GERG-2008 equation of state for calculating gas properties at suction and discharge states. Additionally, Huntington 4-point method is used for evaluating the polytropic efficiency and polytropic head. A computer algorithm has been developed to Calculate the thermal and caloric properties of the gas at the compressor suction and discharge using GERG-2008 equation of state. In addition, it evaluates the polytropic head and efficiency using Huntington 4-Point Method. The program was also designed to Generate corrected performance maps based on the existing suction conditions and the manufacturer as-tested maps. The code can be run on historical data and produce trend plots for polytropic efficiency with temperature, pressure, flow rate, and speed. The calculated gas properties and polytropic efficiency were validated against literature results. Moreover, the developed algorithm was tested on several machines to assess their efficiency and energy consumption over different periods of time. The generated trends can be utilized to diagnose the root cause of efficiency degradation. Overall, the developed approach provides accurate and instantaneous results that can assist the compressor end-users in making critical decisions regarding the optimum time to halt operation of the highly demanding machines for carrying out major maintenance activities.
A Novel Integrated Approach to Characterize Transition Zone in a Low Relief Marginal Field
Authors: Kobenko Igor , Farmer Russell George , Mohamed Alyazia
Published: October 2023

Marginal Field developments require robust understanding of reservoir lateral and vertical extension, facies distribution, saturation profiles and uncertainty.

This paper highlights a reservoir study of a Lower Cretaceous unit of the Thamama Group, located within the Eastern UAE, close to existing major oil producing fields. The results of an integrated petrophysical approach in modelling a low structural relief, complex carbonate reservoir, complicated by the presence of transition zone and post-sedimentary imbibition effects will be showcased.

Static (core, logs) and dynamic data (pressure, sampling, well tests, PLT) from wells in the study area and nearby fields helped build a robust rock classification and saturation model. Saturations below present day FWL were evaluated as residual due to post-sedimentary regional reservoir tilting which is supported by the presence of both tar and bitumen in the core.

NMR was used to derive an independent dataset to define petrophysical groups, reservoir saturation modelling, irreducible water saturation and identification of transition zone intervals for well perforation planning. These predictions were complemented by MICP saturation models using paleo-FWL and tested with fluid sampling in new wells.

NMR capillary pressure-based saturation profiles showed excellent agreement with log derived (Archie) saturation and drainage SHF model results, supporting the rock typing and reservoir properties evaluation. MICP saturation models, representing drainage cycles, were not used directly but as complementary support to identify transition zones using paleo-FWL depth.

Predictions of irreducible Sw and transition zone heights were directly confirmed with fluid sampling stations, demonstrating the additional value of NMR derived capillary pressure data for saturation modelling and alternative rock typing.

Saturations below present day FWL were evaluated as trapped residual hydrocarbon due to post-sedimentary reservoir tilting, which occurred regionally. The presence of tar and bitumen on core supported the concept of the reservoir undergoing imbibition. Sampling showed water.
An Innovative Automatic Alarm System for Early Kick or Influx Events by a Machine Learning Based Abnormal Flowback Detection
Authors: Chao MU , Paterson Graeme , Jian Zhao , Tao Yu
Published: October 2023

During drilling operations, kick or influx events are threatening the safety of operating personnel and the environment; thus, early and accurate detection of the potential kick or influx becomes essential. Kicks frequently happen while making connections because when the pumps are turned off, the circulating flow rate decreases to zero, and the pressure exerted on the formations moderates to the hydrostatic pressure. Flowback fingerprinting, an analysis method for interpreting and comparing flowback patterns, has been widely used in the industry recently for early kick and loss detection during connection operations. However, the flowback fingerprinting, usually conducted manually by skilled engineers, lacks timeliness and accuracy in some scenarios. This paper presents an innovative solution to enable detecting abnormal flowbacks automatically by leveraging data-driven and machine learning based algorithm, including smart safe envelope, mud transfer filter and trip tank change detection.

The new system automatically monitors the flowback volume vs. time data and compares them with a safe envelope in real time. The safe envelope is formed by a machine learning process, which performs clustering and curve-fitting based on historical normal flowbacks in the current well. Uncertainty is also included in the process to determine the upper and lower bound of the envelope. During each connection period, if the flowback curve deviates from the safe envelope, it will be identified as abnormal flowback and alarms will notify the users. During the operation, the safe envelope is automatic updated adaptively based on the characteristics of current flowback, e.g., the hole depth and the flow rate before turning off the pumps. This fully automated system greatly improves the accuracy and timeliness of abnormal flowback detection while minimizing the frequency of false alarms. Besides, the smart alarms could be sent to users by mails or mobile app which makes the reaction and decision-making more in time and convenient.

The new system has been evaluated on previously drilled wells. In this paper, the capability of the new system is presented in one case studies by means of streaming actual well data, in which alarms were successfully triggered before the influx events occurred. The case studies demonstrate the capability and benefits for the entire workflow and how they can significantly reduce operation risks and non-productive time.
Advanced 3D Geomechanical Modelling of Seismic Fault Pattern Above the Crest Structure in a Giant Oilfield, Offshore Abu Dhabi
Authors: Tsusaka K. , Hussein A. M.
Published: October 2023

Prediction of fault and fracture distribution is a key to incorporate enhancement of matrix permeability in reservoir modelling and to avoid excessive mud loss or kick in drilling engineering. The current study sought to model the fault pattern induced by updoming and regional tectonic activities in a giant oil field, offshore Abu Dhabi. The study applied finite element analysis to reproduce the present-day crest structure. The boundary conditions were applied by following updoming and regional tectonic lateral extension that the studied field has experienced simultaneously. The analysis calculated accumulation of rock strain and produced a discrete fracture network which corresponded with the magnitude of the rock strain. Mechanical anisotropy of rock mass due to the development of fractures was incorporated in subsequent numerical steps. The distribution of the rock strain was compared with location and pattern of fractures modelled by a clay-based analogue model at laboratory, seismic fault system and fractures acquired in the field. The distribution of rock strain by the numerical simulation showed good agreement with the major fracture pattern of the analogue model and seismic faults distribution which represent the northwest to southeast in the crest and the west-northwest to east southeast in the flank. In terms of the distribution of sub-seismic faults, the orientation of the fractures was evaluated by considering mechanism of shear-slip and tensile opening based on the stress tensor in each of the grid cells in the simulation. Shear fractures develop at oblique angle to the direction of the principal stresses based on the Mohr Coulomb criterion. Tensile fractures are orientated normal to the least principal stress. The orientation of the fractures estimated in the simulation also showed reasonable agreement with that of the fractures interpreted in the locations except for the near-top of the crest. The three-dimensional geomechanical numerical simulation presented in this study significantly aids the evaluation of the distribution of sub-seismic faults by combining the results of analogue model and seismic interpretation. The simulation technology presented has already been applied by combining with seismic interpretation for the purpose of prediction of the areas where fractures highly develop in the overburden intervals in the studied field.