bluuebunny/crossref_metadata_2025_split huggingface dataset:
Successful Testing and Sampling the Desired Formation Fluids Despite the Challenging Environment in the Middle East
Authors: Espinoza Irina Baca , Perdigon Rony , Osunluk Halil , Mushir Khan Kashif 
Published: March 2023

Abstract
Most of the time a brownfield's formation producibility is no surprise to petrophysicists and reservoir engineers, however, the downhole conditions change continuously in the oil and gas production and injection. Therefore, it is critical to acquire high-quality representative testing and sampling data in real-time despite formation uncertainties and operation constraints.
There are several challenges when acquiring the wireline formation testing (WFT) and sampling services in Middle East. The downhole real time fluid properties must be representative of reservoir conditions and provide fluid fractions, water salinity, contamination, etc. At the same time, there is a big constraint on the operational time limit per station due to the substantial risk of getting stuck. In complex lithologies, it is critical to understand the fluid's connectivity between layers and rock compressive strengths as the expectations may not match reality. To meet the abovementioned challenges the WFT technologies must be equipped operationally and provide a valid instantaneous interpretation.
Current research covered cases across several countries in the Middle East. In low-mobility formation the challenge was on operational ability to continuously pump-out for extended hours. The record-breaking results were achieved with 36 hours of pumping-out, with bubble point as close as 50 psi below formation pressure. Some advanced features were implemented including FT pre-job modeling and real-time support vertical interference tests, which helped to complete the injector well as planned. Many challenges comes in differentiation between formation and filtrate water in real-time. It was solved using the only resistivity sensors available in current WFT setup. For deep tight gas reservoirs, the sampling in tight environment were an issue, nevertheless, getting a single sweet spot allowed to collect representative gas samples. Dealing with retrograde condensate field might be tricky when the condensate precipitation and gas appearance are not known. In presented cases the two scenarios shows the appearance of gas across the zone and appearance of condensate. The results were compared to production logging (PLT) to clarify the unusual multi-phase changes in phase behavior.
Innovative Workflow for Wellbore Stability Evaluation Using Logging-While-Drilling Technologies
Authors: Fouda Mohamed , Taher Ahmed , Al-Hassan Mohammed 
Published: March 2023

Abstract
Logging-while-drilling (LWD) technologies have long been used for real-time formation evaluation and geosteering. Several optimization techniques for drilling and completions have been developed, based on data acquired from emerging and existing LWD technologies. In this paper, methods and techniques are presented where LWD measurements were utilized for the purpose of safely planning, drilling, and completing vertical and horizontal boreholes.
Optimizing drilling and completions can be achieved by continuously monitoring for signs of deteriorating borehole conditions in data coming from different LWD sensors like density, resistivity, or ultrasonic imagers. In addition to resistivity tools known to provide shallow and deep readings, density tools provide azimuthal borehole images from two detectors of different source-detector spacings, allowing their data to have different depths of investigation (DOI). Comparison between the responses of sensors having different DOI over multiple logging passes can be used to assess wellbore deterioration over time. Emerging tools like ultrasonic LWD imagers provide high-resolution, azimuthal hole-size measurements allowing advanced evaluation of wellbore conditions.
Analysis of LWD data showed the potential to identify, mitigate or eliminate existing and potential wellbore stability risks. Integrating multiple sensors of different DOI in the logging suite, and comparing their individual responses, gives more insight into the borehole conditions than analysis of single-sensor data alone.
Customized workflows were established where available data from LWD was integrated with surface-data-logging (SDL) data to provide full analysis of wellbore conditions in real time. Time-lapse analysis using data acquired while tripping out of the hole revealed deterioration that was not observed in the first logging passes while drilling. Interventions were made to mitigate wellbore instability and lessons have been captured to prevent hole deterioration in subsequent wells drilled in the area.
Workflows have been developed to utilize existing and emerging LWD technologies for wellbore stability monitoring. Procedures have been established to mitigate borehole deterioration, thereby optimizing operations for drilling and completions.
Achieving Well Cleanup and Zero Routine Flaring Utilizing Existing Flowline and Ecxtended RTP
Authors: Aldughaither Abdulmajeed , Marri Saleh , Albuali Muhammed 
Published: March 2023

Abstract
As part of Zero Routine Flaring initiatives, advanced steps have been taken to align with goals of minimizing carbon footprint. Therefore, several important technologies have been widely exploited for usage in oil and water wells. Additionally, restrictive regulations were implemented including the prohibition of oil and water wells flaring. This paper outlines the combination of technology and existing facilities to ensure zero flaring while cleaning a well.
The well is a disposal well for a hydrocarbon facility. During normal surveillance, the well was identified with losing its injection capability and having a high pressure. Therefore, the well required cleanup and acid stimulation to restore its injection capability. However, the well can't flow to the hydrocarbon facility due to one-way valves on its flowline in addition to the inability to flare. Accordingly, a procedure was developed to flow the well to the facility through a temporary installed 6.5km HT Reinforced Thermoplastic Pipe (RTP) in an uneven landscape to connect the well to the nearest existing producer carbon steel flowline.
The developed procedure enabled the successful achievement of maintaining zero routine flaring. Also, the cleanup operation was safely and successfully conducted by flowing the well continuously for 48 hours through the installed RTP line. The successful cleanup helped to conduct an acid stimulation using a 2-3/8″ HPCT to restore its injectivity and aid the facility to dispose its processed water in the well to meet its production target. Following the acid stimulation, nitrogen purging of the RTP line was required to ensure the presence of no liquids in the line to avoid environmental pollution when disconnecting the line
This paper highlights a comprehensive procedure to overcome a challenging case of a well located in a remote area and uneven landscape in which a group of solutions were combined to restore a well's injectivity while maintaining zero routine flaring.
Modeling of Multi-Component and Thermal Flow for Geologic Carbon Sequestration Using Operator-Based Linearization Approach
Authors: Kumar Ajitabh 
Published: March 2023

Abstract
Multi-component and thermal flow modeling has been applied in oil and gas industry for last few decades. But its application is challenging due to growing size of simulation models and need to handle multi-physics. In this study, operator based linearization (OBL) approach is used to model multi-component and thermal flow with application to geologic carbon sequestration.
Geologic carbon sequestration studies require different approach as compared to conventional oilfield as the size of aquifer and time-scale of simulation are relatively large. Also, sparse data availability necessitates systematic simulation study with hundreds, if not thousands, of simulation runs to capture underlying uncertainty. With this in mind, operator based linearization is used to model nonlinear flow in carbon-dioxide storage in subsurface. Compute expensive fluid model is handled using operator table, and state values are interpolated using multi-linear interpolation.
Approach is applied to carbon-dioxide injection modeling in first multi-component, iso-thermal setting and then in multi-component, thermal setting. Implementation of OBL formulation in the open-source GEOSX simulation tool is used in this study. A static operator table is included at the start of simulation in which state-dependent operators are parameterized using mesh in parameter space. OBL approach accelerates time required for simulation by replacing compute-expensive calculations with multi-linear interpolation, while also introducing some approximation errors. This approach would be applicable in simulation workflow where hundreds of simulation runs are required to make decision.
Effective Method for Decontamination of Compromised Slug Catcher: Case Study
Authors: Braganza Giselle , Gomes Joel 
Published: March 2023

Abstract
This paper describes a vapour phase method for cleaning and decontamination of a slug catcher in a gas processing plant. Corrosion and heavy metal losses required the slug catchers to be replaced. Safe decommissioning demanded the elimination of H2S, LEL and pyrophoric iron. Compromised integrity made traditional cleaning methods like circulation or pressure jetting unfeasible. The proposed method significantly reduced decontamination times and the associated effluent.
The vapour phase method using degassing chemicals entrained in steam lowered H2S and LEL levels to substantially zero and also neutralized the pyrophoric material. The entire cleaning process was conducted with a temporary H2S scrubber due to unavailability of the process flare. This method did not require the system to be liquid filled or subject to high jetting pressure, making it possible to limit the treatment pressure to below 2 barg, thus minimizing the stress on the structural integrity of the slug catcher. In addition, the slug catcher weak zones were fortified externally in preparation for decontamination.
This technique of using steam as a medium to distribute and apply the degassing chemicals throughout the slug catcher has proven to overcome the limitations of conventional cleaning methods. It further provided a viable solution to reducing the time and resources required to achieve substantially zero H2S, LEL and pyrophoric content by half.
With traditional cleaning methods, the effluent generated would be substantial, necessitating additional logistical support for transporting the waste from the offshore location. Decontamination in a steam saturated vapour phase reduced the amount of effluent generated significantly, to only one third in comparison. This resulted in a solution that was more economical and environmentally friendly. Effective decontamination eliminated the risk associated with the presence of hydrogen sulfide (H2S) gas and pyrophoric materials, ensuring the slug catcher was decommissioned safely and successfully.
For heavily compromised systems and for locations with water supply, waste management or schedule constraints, the vapour phase decontamination process has distinct advantages over conventional methods.
The resultant savings in time and resources makes this an attractive option for mainstream oil and gas processing facilities as well.
Enhancing CO2-Foam Stability and Rheology Using Surfactants Mixture
Authors: AlYousef Zuhair , AlMajid Muhammad , Alabdulwahab Amin , Swaie Othman 
Published: March 2023

Abstract
Generating in-situ foam is regarded as one of the most promising techniques to overcome gas mobility challenges and, accordingly, improve sweep and sequestration efficiency in CO2 injection processes. Foam generation and stabilization at harsh reservoir conditions as well as surfactant-rock interactions are the major limiting factors that can impair the efficiency of foam flood. Surfactants mixtures offer the solutions necessary for the generation and stabilization of foams at harsh reservoir conditions.
In this study, mixtures of anionic and amphoteric surfactants have been evaluated in comparison to using each surfactant individually to determine the overall effect on producing stable foams. Using bottle foam tests, dynamic foam analyzer, and foam rheology apparatus, the foam stabilization factors were analyzed and quantified. The bulk foams for each surfactant and the mixture of the two surfactants at different mixing ratio were analyzed by measuring the foam-life over time, the foam bubble sizes, and the foam rheological properties at high pressure, high temperature (HPHT) and using high salinity water.
The experimental results clearly demonstrated that the use of surfactant mixtures improved the stability of produced foam. The results revealed that the mixing ratio of each surfactant significantly impacts the foam stabilization. The surfactant mixture solutions produced more stable foams as evidenced by a longer foam-life. The foam-life increased by almost 1.5-2 times depending on the mixing ratio. The results also revealed that there are ranges of concentrations at which the most stable foams can be produced. The foam rheology results showed that the produced foams using the surfactant mixtures are of higher apparent viscosity when compared to those obtained with the anionic surfactant. The addition of the amphoteric surfactant to the anionic surfactant solution enhanced the foam stability, and accordingly, the foam rheological properties. The measured foam apparent viscosity increased as the concentration of the amphoteric surfactant increased. Longer foam-life and greater apparent viscosity are indicative of better, stronger and more stable foams.
Towards Online Natural Gas Composition Analysis by Low-Field NMR Spectroscopy
Authors: Mohnke Oliver , Thern Holger , Ortiz Sergio , Swiatek Anna , Ohligschläger Andreas , Duchowny Anton , Dupuy Pablo Matias , Widerøe Hege Christin , Leknes Øyvind , Küppers Markus , Adams Alina 
Published: March 2023

Abstract
The most common NMR methods in the oil and gas industry are NMR relaxometry and diffusometry. Relaxation times T1 and T2 as well as diffusivity D are determined for characterizing fluids and their surrounding pores in logging applications or laboratory analyses. NMR spectroscopy is rarely used for petrophysical investigations but primarily in medical, food, and material applications. In a joint operator-academia-service company project, we explore opportunities for gas component quantification by low-field NMR spectroscopy with the prospect of rig-site, production-plant, and sea-floor deployment. Using an affordable benchtop device in a production-like environment, we gained a fundamental understanding for a commercially viable application of low-field NMR spectroscopy and translated this knowledge into a practical workflow for online natural gas composition analysis.
We measured typical natural gas components (all isomers from methane to n-hexane) with a portable desktop NMR spectrometer working at a proton resonance frequency of 60 MHz A hardware setup was manufactured for mimicking a gas production environment up to 200 bar. A database was populated by NMR signatures of pure gas components, derived from measurements on pure components and binary mixtures. Additional efforts were dedicated to understanding and quantifying systematic effects on the hydrocarbon NMR spectra connected to sample composition and pressure. Pre- and post-processing data procedures were developed and applied for substantially increasing robustness of the method and further improving the gas composition analyses results. Using an indirect hard modeling (IHM) analysis, the constituting pure components in binary, ternary, and more complex gas mixtures were identified and quantified. IHM automatically accounts for small variations and uncertainties in the NMR spectra. The results from the NMR spectrum analysis are in very good agreement with vendor certificates of gas composition obtained from gravimetrics and gas chromatography.
Wellhead Protective Measures During Well Stimulation Operations; Current Limitations and New Horizons
Authors: Mukhlifi Mohammed , Al-Aamer Mansour , Wirawan Pandu , Muqri Mohammed , Saeed Mohammad 
Published: March 2023

Abstract
Wellhead and production trees are the primary safety barriers on any gas, oil and water wells. Such wells may require flowing corrosive or abrasive fluids through the permanent wellhead components as part of well stimulation to restore well productivity. This paper describes the limitations of the available methods to protect wellhead equipment during acid stimulation jobs and proposes a new solution that will provide the required protection and field operation optimization.
Current wellhead protection solutions during well stimulation activities fall under two methods; utilizing sacrificial equipment during well stimulation or utilizing tree savers on permanent wellhead equipment. Both approaches have their drawbacks. The former involves additional operational cost to install and remove the sacrificial equipment. Furthermore, well securement involves killing the well which will diminish the effectiveness of the stimulation job. The latter utilizes proprietary technology that is limited by well completion size and does not offer protection for all production tree sizes.
The proposed solution involves setting an isolation sleeve across the permanent wellhead equipment. A sacrificial set-up is installed on top of the permanent production tree to facilitate isolation sleeve installation, well stimulation activities and maintain well control requirements. The sleeve will be retrieved and the sacrificial set-up removed once the stimulation operations are concluded.
This technology bypasses the limitations of the available methods. It provides full protection from the production tree to the tubing hanger from abrasive fluids pumped and pressure during well stimulation jobs. Furthermore, it does not require killing the well to remove the sacrificial set-up resulting in optimizing rig operations and maximizing the benefit of well stimulations. Finally, it has no limitations to production tree size unlike the existing solutions.
The methodology presented in this paper provides a novel solution to ensure complete protection to the wellhead equipment during well stimulation, minimize operation cost and bypass the current limitations from the available solutions in the market.
New Insights for the Use of Lactic Acid in Carbonate Acidizing
Authors: Alhamad Luai , Caliskan Sinan , Alfakher Basil , Ibrahim Hussain 
Published: March 2023

Abstract
Utilizing HCl on deep high-temperature formations is associated with corrosion and reactivity concerns. Organic acids are a common choice for conducting matrix acidizing on carbonate formations where the use of HCl is limited or unfavorable. An organic acid can stimulate as a standalone formulation, mixed with another type of organic acid, or mixed with HCl. One commonly used organic acid is Lactic acid, which has a dissociation constant similar to formic acid, which is approximately 10 times larger than acetic acid. The objective of this work is to show experimental results conducted using lactic acid for matrix acidizing.
Solubility tests using a HPHT autoclave were done to evaluate acid-carbonate reaction and produced by-product salts. Coreflood tests were performed on Indiana limestone core plugs to mimic a matrix acidizing procedure and to investigate the amount of pore volumes required to breakthrough. These tests were monitored by using inductively coupled plasma (ICP), X-ray diffraction (XRD), and computed tomography (CT) scans to measure different ion concentrations in solution, to identify precipitated solids, and to evaluate dissolution patterns generated in the coreflood test, respectively.
The reaction of lactic acid with carbonate rocks was associated with production of calcium lactate which found to be soluble above 150°F. Lactate-based precipitation was avoided by incorporating gluconic acid along with lactic acid. In addition, lactate-based precipitation was avoided by mixing low concentration lactic acid with HCl. Adding HCl to lactic acid solution allowed for the reduction of lactic acid concentration to a precipitation-free level where lactate ions would be at a minimum. Coreflood results established more understanding of lactic acid utilization in matrix acidizing in terms of minimum pore volumes to breakthrough and generated wormholes. The results highlighted the correlation between acid-core reactivity, injection rate, and dissolution pattern. Coreflood tests showed that the lactic acid blends at optimum injection rate penetrated tested core plugs with minimal acid pore volume without any face dissolution or salt precipitation on the plug faces. Coreflood tests showed that the lactic/gluconic acid blend can stimulate carbonate cores and generate an optimum wormhole. A lactic/HCl blend was more reactive than a formic/HCl or lactic/gluconic acid blends as more pore volumes were needed to breakthrough Indiana core plugs. Thereby, a higher injection rate is required to obtain an optimum pore volume to breakthrough despite the high reactivity.
The detailed experimental work shown in this study shows major advantages that can be achieved by using different lactic acid-based blends. Among these advantages are favorable dissolution pattern due to lactic acid retardation, and less corrosion rates that can reduce allocated costs for maintenance and replacements.
Rotating Equipment Switchover Optimization to Enhance Equipment Reliability and Minimize Emissions
Authors: Gohel Kinnjalkumar 
Published: March 2023

Abstract
The association of rotating equipment switchover strategy with machinery health and reliability is discussed. The paper includes the design considerations for spare equipment in processing facilities, need for a switchover strategy, factors affecting the equipment switchover and the benefits of optimizing the switchover strategy in terms of equipment reliability and HSE.