bluuebunny/crossref_metadata_2025_split huggingface dataset:
Mitigation of Injectivity Loss in Polymer Injector Wells at North Kadi Field of Mehsana
Authors: Gupta Nayan , Chanchlani Kuldeep Laxmanbhai , Jain Pramod Kumar 
Published: February 2022

Abstract
The north sector of the North Kadi field at Mehsana is a brownfield with a primary recovery of only ~20% despite good permeability and active aquifer support due to high mobility contrast, with oil viscosity between ~50 to ~120 cP. Polymer flooding is formulated through 8 injector wells in an inverted spot pattern with 21 producers. The key risk involved is the loss of injectivity in polymer injector wells. A case study of two injector wells demonstrates successful mitigation measures employed for the injectivity improvement.
The partially hydrolyzed polyacrylamide polymer solution is injected into the polymer injector wells. Injector wells lose injectivity over time, making it hard to keep injection pressure below the designed maximum operating pressure. Critical analysis of the trend of injectivity decline is carried to identify the root causes. A structured mechanism for various mitigation options like solvent treatment, oxidizer treatment, acidization, backwash and technical water squeezing, artificial pressure drawdown, and formation bottom cleaning near the wellbore is discussed.
The quality of raw water used for the polymer preparation based on parameters like TSS, turbidity, TDS, and hardness is a key factor in the injectivity loss in the injection wells. In case of rapid decline in injectivity due to poor quality of water with high TSS, turbidity, TDS, and hardness content, solvent squeezing followed by acid stimulation proved optimal. During a gradual rise in injection pressure, while maintaining satisfactory water quality, acid stimulation in combination with oxidizer treatment such as Ammonium Persulphate (APS) proved beneficial. Injectivity maintenance in polymer injector wells has resulted in production gain of approximately 172 tons/day, reducing operational expenses significantly. Monitoring of polymer injector wells is critical, and diagnostic examinations are conducted regularly to assess the severity of the decline.
No More Inefficient Crude Desalting - Breaking Bottleneck with Dual Frequency Technology Lowering Total Cost of Ownership
Authors: Elumalai Prabhu , Sams Gary , Subramani Umanath , Sanghani Pinkesh 
Published: February 2022

Abstract
Historically, the engineering and operations teams in refineries have been constantly challenged to deploy efficient solutions for their crude desalting processes as part of the crude distillation unit (CDU). Inefficient crude oil desalting employing AC technology leads to higher utility consumption and corrosion-related issues with downstream equipment that create multiple bottlenecks while processing opportunity crudes. In addition, these challenges lead to a significant increase in operating expenses due to processing upsets and subsequent downtime.
A major independent crude oil refinery in Asia is processing crude oil in two CDUs utilizing an AC technology desalting system. The total design capacity for the CDU is 206,000 BPD. The first CDU desalting equipment is designed for 150,000 BPD, and the second CDU is designed for 56,000 BPD. Both CDUs were operated in a range of 10 to 30 PTB inlet salinity. However, due to inefficient desalting, less than 60% desalting efficiency was achieved for each train with subsequent low dehydration efficiency. This led to a considerable bottleneck with the processing capacity and much higher chemical consumption, accompanied by frequent upsets and operational issues on downstream equipment.
After a review of the entire desalting operations, the CDU 1 desalter vessel was upgraded to dual frequency technology, and a new dual frequency desalter was installed at the second stage of CDU 2. This change provided a paradigm shift in handling opportunity crude blends in the range of crude density 21 to 28° API with the flexibility of 20 to 100 PTB inlet salinity. After the upgrade, the CDUs achieved a desalting efficiency of more than 90% on each stage and more than 99% on two stages.
This paper examines the project from early engagement through conceptual technology selection phase, engineering design, and project execution leading to a successful startup backed by operational history. Furthermore, the adoption of dual frequency technology over legacy AC technology demonstrates the twin goals of positive economic and environmental stewardship, thereby lowering the total cost of ownership to the customer.
The CDU 1 dual frequency technology retrofit has been in continuous operation since 2019 and performing well within the PTB outlet specifications. The system is running with 40 to 50 % lower utility consumption, both chemical and power savings with reduced downstream corrosion and an increase in uptime reliability.
State of the Art Membrane Nitrogen Technology Enables Remote and Large-Volume Pipeline Leak Testing
Authors: Hella Abdullah , Al-Ajmi Mohamed , Abdelrahman Sherif 
Published: February 2022

Abstract
The paper presents a case study of applying Membrane Nitrogen technology in purging a 600 km long pipeline in Saudi Arabia for pressure testing purposes. The paper will cover the operational advantages and superiority that comes with using Membrane Nitrogen Technology compared to using Cryogenic Liquid Nitrogen. Besides that, potential applications for the technology in remote projects requiring large volumes of Nitrogen will be covered in the paper.
The paper will explain in full detail the Membrane Nitrogen technology along with elaborating how the process works at remote sites. In addition, comprehensive elaboration of several aspects of the technology are discussed; including but not limited to quality of Nitrogen generated, injection rate capacity, injection pressure and the process flow diagram. The paper also examines how this technology eliminates the logistical challenges and ensures maximum efficiency at the job site.
Exploring the Barriers to Implementation of Carbon Capture, Utilisation and Storage in Nigeria
Authors: Betiku Adedola , Okon Bassey Bassey 
Published: February 2022

AbstractThe global economy has increased CCUS technology development programmes to attain its commercial deployment, which is expected to be beneficial for developing countries such as Nigeria. This paper aims to examine the barriers to CCUS implementation in Nigeria by investigating the differences between global CCUS and Nigerian status, evaluating the perspectives of industry and government practitioners on the economic barriers to CCUS implementation, and identifying policy and industry strategies to deepen the adoption of CCUS. Study participants were selected using a purposive sampling technique to explore the opinions of personnel working in three oil-related agencies: Nigerian National Petroleum Corporation, Ministry of Petroleum Resources and Nigerian Liquefied Natural Gas. Information collected from existing literature and related reports on CCUS were critically analysed, whereas data from semi-structured interviews were generated by audio-recording of participants’ responses. These responses were transcribed from audio recordings for each participant and quality controlled by ensuring that transcripts matched the respective responses. Transcripts were analysed using thematic analysis, exploring the research theme using both theory and practice. The theoretical framework utilised PESTEL and SWOT analyses to evaluate the macro environment and the internal and external environment of CCUS implementation in Nigeria. PESTEL analysis showed that CCUS implementation in Nigeria is driven by various regulatory and policy frameworks, lack of adequate capital, public acceptance and infrastructure. Similarly, the SWOT analysis showed that Nigeria has enough coal reserves that could serve as a potential for CCUS implementation. However, Nigeria’s weaknesses include lack of expertise in CCUS technology, inadequate capital for CCUS investment and policy summersaults by successive governments. Nigeria should thus consider the introduction of subsidies to mitigate various barriers and challenges that hinder CCUS implementation, e.g., low tax rate for enterprises involved in CCUS implementation. There is also urgent need to improve funding of CCUS implementation through foreign direct investment or by the equity market. Furthermore, the importance for an enhanced technology to deepen the adoption of CCUS in Nigeria can not be overemphasized as the world moves towards decarbonisation and Net Zero.
Autonomous Well Performance Troubleshooting; A Promising Data-Driven Application
Authors: Abdelrahman Sherif , Al-Ajmi Mohamed , Essam Tarek 
Published: February 2022

Abstract
Well Performance can deteriorate due to several reasons, for example: formation damage, scale buildup, back pressure from other wells, artificial lift issue etc. In this paper we present an application of utilizing machine learning to build a model to articulate and flag deterioration and reason behind it. The model was used to flag problems such as salt and scale build up in the tubing as well as backpressure due to emulsions in the tubing or in topside pipes. The model was capable of monitoring well performance using only the well head parameters
Selection and Evaluation of Ejectors for Flare Gas Recovery and Upstream/Midstream Gas Compression Applications
Authors: Ainge Peter , Al-Khateeb Eyad 
Published: February 2022

Abstract
Historically, Ejectors have been regarded as novel but inefficient devices. For projects requiring a dedicated motive liquid stream (where one was not already freely available), the high liquid flow rate requirements (and therefore high pump power requirements) were prohibitive when compared to equivalent rotating compressors.
In recent years, through its ongoing long-term Product Development Project, Ejector specialists, Transvac, have significantly increased the efficiency of its liquid-driven Ejectors. In some cases, over 50% reduction in pump power requirements has been achieved. Importantly, these improvements mean the new Ejector designs often require less power than traditional compressors.
This paper will explore the latest advancements in Ejector technology and how this has altered the landscape for the selection process of various compressor types for highly challenging duties, such as Flare Gas Recovery and midstream gas compression. In particular, we will see how improvements in liquid-driven Ejectors (Liquid Jet Compressors or LJC's) can offer significant power savings compared to other compressor types.
We will use recent case study/project examples demonstrate how Operators such as Saudi Aramco have already successfully implemented Ejector technology for Flare Gas Recovery and other gas compression applications. The selected projects will demonstrate how Ejectors can be driven by ‘waste energy’, how they can be controlled and other operational considerations. We will also look at how Ejector solutions can operate efficiently using dedicated high-pressure pumps as part of a complete packaged solution.
Pre-Intervention for Multistage Frac Operation: Abrasive Perforation Challenges and Lessons Learnt
Authors: Mezabia Othmane , Belkacemi Ahmed Amir 
Published: February 2022

Abstract
The Plug and Perf technique is the most common application used in completions or horizontal wells that require multistage hydraulic fracturing.
Once the horizontal well is drilled, cased, cemented and isolated - two runs of coiled tubing will be required. The first coil tubing run will be to clean up residual cement and the second run to convey the first set of perforating guns to the end of the well or toe. Once the perforating guns are initiated and perforated holes through the casing and cement into the formation, fluids can now be pumped into the formation. This injected fluid is required to push the WireLine bottom hole assembly (BHA), containing a frac plug to the target depth.
The use of pressure-activated toe valves or Toe Injection Valve (TIV) in a completion string is yet another innovative approach to completing a horizontal well. This technology eliminates the need for perforating guns prior to a multi-stage hydraulic fracturing (frac) operation. Subsequently, the operator can greatly reduce costs when the need for coiled tubing (CT), wireline (WL), or workover rig (WOR) is no longer needed on location to convey perforating guns.
However, if the completion is not equipped with Toe Injection Valve TIV or when injection rate through it is not adequate for wireline pump-down operations, or the toe valve (TIV) fails to open, in this cases the operator must rely on the conventional methods of perforating in order to achieve injection into the well and begin the frac operation.
The conventional method will negate any cost savings that the TIV was designed to provide.
In this paper will review cost effective solution using a motor BHA and abrasive perforator in tandem to clean-out, perforate make another clean out, test the infectivity and Pump acid if needed all in one run using by-pass abrasive tool.
High Gain, Low-Cost Production Optimization of Brownfield in Sarawak Offshore
Authors: Dasuki Nurul Ain , Chaw Kit Teng , Zamdy Siti Nurdyana , Polycarp Maurice 
Published: February 2022

Abstract
In the quest to unlock extra barrels in this challenging oil and gas environment, operator had decided to pursue low-cost oil gain via surface facilities optimization. It is becoming more important than ever to ensure the production system is managed optimally. This initiative was rolled out to all its brownfield asset located at offshore Sarawak. To achieve this objective, Integrated Network Modelling (INM) was conducted to identify facilities bottleneck and optimization opportunities. A structured workflow was utilized to ensure a thorough assessment prior going into full field implementation. All well models were updated to ensure they are representative of the latest field performance. Upon integrating the subsurface and surface system, the model was calibrated with the latest field parameters. Sensitivities run were carried out to identify production constraints and optimization options which include choke size optimization, well bean-up opportunities, separator pressure optimization and system backpressure evaluation. The options were then prioritized based on implementation cost and economic value. Outcome of this study concludes a total potential gain of 5.81 KBOPD from eight fields. This paper presents the overall strategy in finding opportunities from surface facilities optimization via INM.
Integrated Approach to Solving Sand Issues at Onshore Terminal
Authors: M. Johar Juhaida , Myo Thant Maung Maung , Tuan Mahmud Tuan M. Yusoff , T. Aziz Tengku Zulfadzly , Che Daud M. Faizal 
Published: February 2022

Abstract
Lately, one of the terminals in Peninsular Malaysia receives hydrocarbon with fine sand content from multiple offshore feeders. Majority of the sand particles size is below 16 µm with the presence of mercury and TENORM. Sand accumulates, causes erosion, and clogs the equipment and instrumentation devices installed. It has also impacted gas and condensate export specifications. The paper presents a techno-economic evaluation of sand management solution for the terminal to meet an export specification of maximum 5 µm sand particle size both in gas and condensate stream.
The evaluation started with sand data establishment such as sand particle size distribution and sand concentration via online sand sampling. Sand Transport and Erosion Modelling Study was conducted using combination of PETRONAS owned Sand Suite Technology and commercial software for quantitative evaluation of sand mapping, deposition, and erosion within the facility. A total of eleven (11) proven sand technologies at various locations were screened and four (4) technologies were selected as a basis to develop solution options. Via Concept Select Methodology, the evaluations conducted based on Risk Ranking Criteria, CAPEX, OPEX and Schedule. The estimated performance for the selected option was quantified and sand disposal strategy was determined.
An In-Vessel Cyclonic Device is proposed in the existing Condensate Separators and Cartridge Filter at upstream of the Condensate Metering. Gas System will be provided with new Cartridge Filters. These technologies are commercially proven to meet an export specification of 5µm. The proven technology for this application does not differ much for the last few years. New technologies are recommended to be deployed in the terminal and the performance of these technologies are quantified and compared. As the terminal was not originally designed to receive sand, sampling improvement is also proposed to collect more sand data prior to next engineering phase and to measure performance of the proposed technologies.
The results from this study show that current technology could provide a solution to manage fine sand both in gas and condensate. PETRONAS in-house technologies are compared and could be a better option in reducing OPEX and operators’ exposure to hazardous components thus minimizing the impact of transported fine sand on surface equipment in general.
Digital Solution to Extend the Life of Wells with Continuous Corrosion Monitoring Based on Machine Learning Algorithms
Authors: Dallag Mohammed , Bawazir Mustafa , Al-Ali Ali 
Published: February 2022

Abstract
Well integrity in the oilfield is one of the challenges that petroleum engineers face, as they seek to monitor well corrosion in the field to optimize well performance. Most of these fields can be categorized as brownfields, with some of the wells considered aged and have expected integrity issues. To achieve sustainable production targets with cost-effective and safe operations from these fields requires a close monitoring of the integrity of all elements involved in the production chain. Addressing these challenges requires the engineers to coordinate and analyze several data elements, including casedhole, openhole, reservoir, well, and production data from multiple sources. Another challenge is to create and automate a corrosion workflow that saves the engineers’ time and improves efficiency.
In this paper, we introduce an innovative workflow that uses the historical corrosion data while integrating the multiple production and reservoir variables. The innovative approach uses machine learning (ML) algorithms to provide a powerful tool for workover (W/O) candidate selection and for optimizing the corrosion evaluation frequency, which are required in different areas of the fields. Different ML methods (random forest classification and neural net) were applied on training data. Different models were created, and the best model will be used. This offered key insights on the rate of corrosion and corrosion patterns. Further, the developed workflow was designed to be self-sustaining and acting as a surveillance tool for monitoring the integrity of the wells.
The first step of the workflow was to start with organizing and auditing the available corrosion data, followed by a review and analysis of existing openhole, casedhole, production, and reservoir engineering data. This approach led us to understand the extent and severity of corrosion in terms of the corrosion rate and the corrosion index. The corrosion logs were digitally interpreted depth-wise in order to explore the maximum metal loss for each interval. New animated conformance corrosion maps were created.
The successful diagnosis through data analytics in a modern integrated software platform will assist in corrosion monitoring and decision-making. The multiple corrosion maps can be animated to visualize the current corrosion profile and predict the corrosion over time, in addition to ranking the wells for W/O candidate selection.
Optimizing Carbonate Acid Stimulation by Minimizing Acid Injection Volume with Selective Treatment Placement
Authors: Sidaoui Ziad , Abbad Mustapha 
Published: February 2022

Abstract
In carbonate acidizing, highly conductive wormholes are created. The process of wormhole formation comprises two major periods: induction and wormholing. The induction period is the time from the first injection of the stimulation fluid to wormhole initiation. The volume of stimulation fluid injected during the induction phase can be more than 30% of the total volume required for the stimulation operation. Minimizing the induction period can significantly reduce the cost and time of matrix acidizing operations.
Several series of core-flow experiments are conducted under the same experimental conditions, namely temperature, pressure and flow rate to investigate the effects of changes made to the geometry of the injection face of the core during acid injection. Induced holes, sometimes called notches, of various depths and locations were created into the injection face of Indiana limestone cores to evaluate their impact on the wormholing with 15% wt. HCl. The pore volume to breakthrough (PVBT) of injected acid is obtained with the notched cores are compared with ones recorded with a regular plain core (baseline).
The experimental results show that inducing hole in the core can significantly reduce the PVBT of injected acid compared to regular cores. The depth and location of the notch both affect the volume of injected acid as well as the optimal flow rate at which the breackthrough in achived. Shallower notches induced in an optimal location can save about 25% volume of the injected acid while deeper ones can help to reduce the injected acid up to 50%.
Moreover, notches can localize the wormhole initiation point. Based on several repeated experimental results, the creation of notch prior to acid injection can optimize a matrix acidizing treatment by reducing the wornmhole induction period and therefore reducing the volume of acid required to achieve equivalent stimulation performance. It also enables more selective treatment placement.
The creation of notches in the formation method has been applied to hydraulic fracturing because it generates weak points and reduces the pressure required to fracture the formation, Kayamov et al. 2019, Aidagulov et al. 2016, and 2015. However, this proposed method is the first application in matrix acidizing treatments that demonstrates the impact of face geometry on wormhole generation.