bluuebunny/crossref_metadata_2025_split huggingface dataset:
Two-Phase Interference Well Testing Interpretation Method for Polymer Flooding Multilayer Reservoir
Authors: Li Peng , Zeng Yang , Tang Engao , Wei Zhijie , Cheng Shiqing 
Published: March 2022

Abstract
The current research on interference well test technology is based on water flooding reservoir, but the analysis method of interference well test in polymer flooding reservoir has not been reported, which leads to unclear understanding of the physical property changes between wells in polymer flooding reservoir. Considering the characteristics of polymer flow, a two-phase interference well test model of polymer flooding multi-layer reservoir is established. The pressure, water saturation and polymer concentration are all implicitly solved to improve the stability of the numerical solution, and the typical curve is drawn. The results show that: the water phase viscosity is greater during the polymer flooding process, the pressure fluctuation of the active well is later, which affects the observation well, and the pressure fluctuation received by the observation well is greater. The results show that the interference well test curve of polymer flooding is farther to the right than that of water flooding in the early stage and higher than that of water flooding in the middle and late stage. The application example shows that coincidence rate with commercial software well test interpretation is over 90% when the model is degenerated to conventional water flooding, which proves the accuracy of polymer flooding interference well test model, and provides technical support for the improvement of well test method of polymer flooding reservoir.
Bolted Flange Joint Integrity Digitalization Programme for Sustainable Flange Leak Free Operation
Authors: Saad Safari , Ekhwan Alzakri , Al-Idrus Syed M Hafiz 
Published: March 2022

Abstract
Loss Of Primary Containment (LOPC) due to hydrocarbon leakage from bolted flange joint has always been one of the main issues that leads to catastrophic fire and explosion in operating platforms and plants. Oil and gas companies have been putting many efforts to reduce Health, Safety and Environment (HSE) incidences due to the flange joint integrity issues. PETRONAS, which operates many oil and gas platforms, has also made series of improvement in lesson learnt and enhanced best practices to find a wholesome solution to achieve sustainable zero hydrocarbon leak from bolted flange joint. Loss Of Primary Containment (LOPC) due to hydrocarbon leakage from bolted flange joint is one of major concerns in oil and gas industry, which may cause catastrophic fire and explosion at platforms and plants. Bolted Flange Joint Integrity (BFJI) digitalization program is designed to emphasize on end-to-end digital solution addressing three main important aspects towards sustainable flange leak free operation that included correct design and specification, good quality flange joint components and correct work execution.
Towards a Multidisciplinary Approach in Play Characterisation: An Integrated Case Study from Browse Basin, NW Shelf, Australia
Authors: Ben Habel Wael , Dubey Siddharth 
Published: March 2022

Abstract
Stratigraphic forward modeling (SFM) is an innovative approach to subsurface facies prediction at the basin scale that augments and overcomes some of the limitations of conventional seismic, well, and analog data. As a multidisciplinary approach to play characterization, SFM improves the efficiency of current workflows, which is important given the current downward pressure on capex in oil and gas companies.
A 2D SFM study on data from Browse basin, NW Australia, was conducted to enhance the prediction of facies distribution and improve play characterization by integrating SFM with other disciplines. The work started with seismic interpretation and depth conversion. Then, a third to fourth-order sequence stratigraphy interpretation was performed to determine the main sequence boundaries, maximum flooding surfaces, and a relative sea-level curve. The sequence stratigraphy results were later used to infer some of the inputs and parameters of the SFM model. The model simulates the deposition of clastic and carbonates from the Turonian (Late Cretaceous) to the present day.
The results from the model were used to validate some of the geological concepts and the seismic interpretation. In addition, the approach enabled the prediction of reservoir quality, reservoir distribution, the presence of the seal, and the quantification of erosion. A 2D petroleum system model (PSM) covering the area from the Yampi shelf to the Seringapatam sub-basin was built using seismic interpretation, regional tectonic information, source rock geochemistry, and paleo heat flow. The results from SFM were integrated into a 2D PSM by resampling facies and erosion properties for each of the finely subdivided layers. The high-resolution 2D PSM with refined facies was simulated in geological time to model the basin evolution and its impact on all elements and processes of the petroleum system of Browse basin, which have been validated with nearby fields.
As a result of this integrated approach, the risk of charge and entrapment in prospective stratigraphic traps was better understood and quantified. In addition, this approach helped to increase yet-to-find (YTF) hydrocarbon resources by accurately predicting reservoir distribution and extent. The generation of a 2D SFM and its integration within a multidisciplinary approach to predict facies represents a novel addition to exploration workflows. Adopting such an approach can improve significantly on the understanding of hydrocarbon entrapment and further reduce exploration risks.
Nanofluids Development to Improve Oil Recovery: A Synergistic Effect Investigation
Authors: Hendraningrat Luky , Razali Norzafira , Chien Chee Sheau 
Published: March 2022

Abstract
Various type of nanoparticles has been studied in last decade for improve oil recovery purpose and observed its mechanisms of displacing oil concluded as disjoining pressure that involved wettability alteration, log-jamming, and viscosity effect. This paper focus on the investigation of new potential mechanism of nanoparticles to improve oil recovery with study case in an offshore Malaysian oilfield.
The silica-based nanoparticles were used in this study, and additives of polymer and surfactant were involved to improve stability of fluid and observe any potential of novel mechanism. The nanoparticles were characterized under electron microscope, dispersed, and sonicated in saline water as replicated of injected water to be nanofluids for particular concentrations. A degassed crude oil from Malaysian field was used with viscosity of 3 cP. All fluids measured their rheology and fluid properties. A polymer additive was used to improve particles stability dispersed in saline water. Meanwhile, a surfactant additive was added into the formulation to observe any synergetic effect of displacing oil. The interfacial tension (IFT), optical contact angle (OCA), and relative permeability measurement using native cores at reservoir condition to observe potential novel mechanism.
The additive showed better performance in term of stability and wettability alteration through IFT reduction and reducing contact angle to render more water-wet through dynamic OCA measurement. The synergistic effect was observed when surfactant added into the nanofluids, and classified as fragmentation. The IFT reduced significantly when nanofluids contact with crude oil from field after 10-20 minutes and oil drop started disintegration. This phenomenon was identified consistently through OCA measurement. It altered surface of rock from medium water-wet to strong water-wet. The relative permeability measurement showed consistent wettability alteration that the curve shifted from water-wet to be stronger water-wet.
This observation not only showcases the great potential of nanoparticles but also providing a new reference for synthesizing and formulating nanoparticles as a technique to improve oil recovery.
Investigation of Intermittent Loss of Electrical Integrity in Subsea Control System
Authors: Tanna Mohit Bharatbhai , Rayner Wayne 
Published: March 2022

AbstractObjective/ScopeThe project under consideration witnesses IR (Insulation Resistance) degradation on reconnecting the subsea system to the FPSO (Floating Production Storage and Offloading) after a prolonged period of disconnection. The IR of the system eventually regains its expected value after some time interval. The present research investigates the causes of IR degradation and the possible mechanisms behind IR recovery after system startup. The prime focus of this work is on the umbilical utilized in the field.
A Case Study of LWD and Wireline Formation Pressure Tester on Depleted Reservoir of Offshore Development Sequential Wells, Kutai Basin, East Kalimantan, Indonesia
Authors: Manurung Vinda Berlianta , Himawan Glen Ricky , Warkhaida Laila , Zulharman Ahmad , Citajaya Novrianto , Laksono Setiadi 
Published: March 2022

Abstract
The Kutai Basin, has been under production for more than 40 years and many wells have been drilled to develop the area. This has resulted in reservoir-induced drilling problems, like kicks and lost circulation due to depletion, while some high-pressure zones still exist. This complexity makes pore-pressure and stress analysis difficult. To address this problem, a comprehensive reservoir-evaluation program was developed by adding formation pressure testing to the planned quad-combo logging-while-drilling (LWD) program. Pressure measurements in this development stage were planned to aid the operator's understanding of the field's current hydraulic communication pathways, to relate reservoir characterization to the geological model. Emphasis was on the insight of static reservoir pressures, which are important for confirming fluid contacts and fluid density gradients.
Methods of formation pressure testing have evolved over many years. Through this paper's case study, recent LWD and wireline pressure-testing technology are elaborated in depth, in relation to two sequential wells drilled offshore in the Kutai Basin. LWD pressure-testing operations were conducted in well XX-5 in a dedicated run after completion of drilling the section. The wireline test was conducted in well XX-4 as an open-hole logging run, along with the acquisition of fluid analysis data.
Both systems were successfully utilized in the 6-inch hole sections of the subject wells, in a depleted reservoir, with the pressure overbalance expected to reach around 3100 psi in the pre-job planning stage. The average mobility was low in both sets of pressure test results, as also align with the reservoir's current depletion state. Challenges related to tight tests and lost seals in this mature field were experienced with both systems. The drilling environment and the formation's exposure conditions may have presented varying challenges; nevertheless, the same relatable quality has been achieved with both types of testing (LWD and wireline).
This paper describes in detail the planning, design, and performance of pressure testing using LWD and wireline in the Kutai Basin. Comparisons between results are displayed to highlight the current character of the subject offshore field. This study aims to enhance future drilling and logging operations, by reviewing solutions from formation pressure testing technologies and to add value to mature and depleted field planning.
Technical Categories: Geotechnical, Geoscience & Geophysics; Drilling Technology
Verticalized Sonic Measurements in Deviated Wellbore for Accurate Velocity Modelling and Seismic Well Tie in Offshore Malaysia
Authors: How Elijah Lip Heng , Donald Adam , Bettinelli Pierre , Chongrueanglap Pongsit , Hooi Woi Loon , Soh Anniza Ai Mei 
Published: March 2022

Abstract
Vertical seismic profile (VSP) or checkshot surveys are useful measurements to obtain accurate time-depth pairs for time-depth conversion in seismic exploration. However, in deviated wells, the standard geometry correction for rig-source VSPs will not provide reliable time-depth profiles because of ray bending, anisotropy, and lateral velocity variation effects. The accuracy of the time-depth profile can be improved by using model-based correction or vertical incidence VSP simulation with transversely isotropic (TI) data from an advanced sonic measurement. Elastic anisotropy parameters derived from sonic combined with VSP time-depth information are shown to accurately place a deviated wellbore within the reservoir to improve the drainage and productivity of a reservoir in offshore Malaysia.
For rig-source VSP in a deviated well, the source-receiver travel path is not a vertical straight line, but an oblique, refracted path. The seismic waves from the source travel along straight paths within a layer of constant velocity. On entering another layer, they undergo refraction and the direction of travel changes. The pseudo-vertical incidence VSP is simulated with a velocity model to accurately calculate the vertical traveltime.
This deviated well passes through various layers of overburden before reaching the target reservoirs. Observations from the dipole shear anisotropy, formation dip, and using dispersion analysis, indicate that these shales can be considered transversely isotropic with a vertical axis of symmetry. A single well probabilistic inversion was used to solve for the five anisotropic constants by combining the sonic measurements and prior elastic anisotropy relationships. This advanced model-based correction was the optimal solution to improve the accuracy of checkshot time-depth velocity data in combination with the anisotropic velocity model.
Isotropic model-based correction showed a 6-ms time difference compared with standard VSP geometry correction. However, the sonic data in the overburden formations showed a significant amount of layering that gave rise to significant uncertainty in the existing velocity model and thus the position of the top reservoir. The anisotropic parameters were determined at sonic scale for the shale directly overlaying the reservoir. The upscaled anisotropic velocity model showed that an 18-ms time difference with standard VSP geometry correction changed the depth of the reservoir up to 45 m. The new model now placed the reservoir at the correct position and can be used with more confidence for development purposes.
The FEL-Agile Hybrid Approach to Selecting the ‘Right’ Oil & Gas project
Authors: Nesan Ashvin 
Published: March 2022

Abstract
The front-end loading (FEL) project management process is a method that is trusted and ingrained into most Exploration and Production oil and gas companies worldwide. The entire FEL is modeled after the Waterfall model which is sequential in nature. The waterfall model can be construed to be too slow in adapting to changes resulting in a significant number of oil and gas projects having a high tendency of cost overruns, schedule delays and not meeting stakeholder objectives. On the other hand, the agile model employed by IT, software and technology companies offers a refreshing view to achieving the desired result in projects. However, these two industries have substantial differences between them, for example in project value and regulation. This explains the reluctance by major oil and gas companies to implement agile as part of their project management approach. Nevertheless, as the environmental and organizational factors in project management in all sectors are changing at a rapid pace, seeking alternative and workable approach is vital. The paper seeks to evaluate the concept of adapting the agile methodology for FEL in oil and gas field development projects. The paper identifies areas for integrating agile such as in FEL selection criteria and further suggests to seek a balance between the two contrasting methods. Overall, the results from a case study in the oil and gas industry indicates that by adapting agile approach into the current FEL practice, it's more likely that the right project would be sanctioned, therefore, increasing the chances of project success.
A New Insight into Smart Water Assisted Foam SWAF Technology in Carbonate Rocks using Artificial Neural Networks ANNs
Authors: Hassan Anas M. , Ayoub Mohammed A. , Mohyadinn Mysara E. , Al-Shalabi Emad W. , Alakbari Fahd S. 
Published: March 2022

AbstractThe smart water-assisted foam (SWAF) technology is a novel enhanced oil recovery (EOR) technique, which combines the synergistic effect of both smart water and foam-flooding methods. The smart water enables multilevel improvements, namely, stabilization of foam-lamella and wettability alteration of the carbonate rock, which leads to desirable oil relative-permeability behavior. Contact angle tests are the common approach for measurement of the preferential affinity of reservoir rocks to fluids. However, the laboratory methods for contact angle measurement are costly and time-consuming. Therefore, in this study, we propose a new approach to predict contact angle based on a machine learning technique. A model based on artificial neural network (ANN) algorithm was developed using 1615 datasets acquired from diverse published resources. The developed ANN-based model to predict contact angle was further evaluated by applying the trend analysis approach, which verify the correct relationships between the inputs and output parameters. The collected datasets were trifurcated into training, validation, and testing segments, so that the over-fitting and under-fitting issues are evaded. Furthermore, some statistical error analyses, namely, the average absolute percentage relative error (AAPRE), and the correlation coefficient (R) were performed to present the robustness and accuracy of the proposed model.The findings from the trend analysis showed the sound relationships between the inputs and output parameters. The statistical error analyses proved that the developed ANN-based model does not have any under-fitting or overfitting anomalies, and correctly determines the contact angle with high accuracy, substantiated by the R values of 0.9988, 0.9985, 0.9967, and AAPRE values of 1.68, 1.62, 1.81, for training, validation, and testing datasets, respectively. The proposed ANN-based model for contact angle prediction has many advantages including speed, reliability, and ease of usage. This work highlights the potential of machine learning algorithms in oil and gas applications, particularly in contact angle prediction from SWAF technology. The findings from this study are expected to add valuable insights into identifying the optimal conditions (i.e., optimum smart water and surfactant aqueous solution) for the operation sequence of SWAF technology, leading to successful field applications.
The Versatile and Tunable Metal-Organic Framework MOF for Condensate Decontamination
Authors: Arayachukiat Sunatda , Pironchart Taradon , Kongpatpanich Kanokwan 
Published: March 2022

Abstract
Contamination of heavy metals especially for Mercury (Hg) and Arsenic (As) in condensates becomes one of major concerns in Natural Gas production due to theirs high toxicity and carcinogenicity. The key challenge to develop adsorbents for Hg/As removal is to find suitable porous materials with high adsorption capacity, long-term stability and easy to handle the toxic wastes after the adsorption process. Metal-organic frameworks (MOFs) are one of promising porous materials constructed from metal clusters and organic linkers to create the 3D framework structures. MOFs are one of the promising adsorbents for removal of Hg/As from condensates owning to their versatile structures, tunable porosity, and tailorable chemical functionalities. In this work, Zr-based MOFs have been developed for dual removal of Hg and As species owning to their chemical stability in moisture conditions, which is highly desirable for industrial processes. Zr-based MOFs with different topology and pore size distribution have been synthesized for Hg/As adsorption to understand the contribution of porous structure on the removal of Hg/As species in condensates. The performance of Zr-based MOFs results showed Hg and As removal up to 99.5% in condensates from several petroleum sources. The removal efficiencies were found to be influenced by topology of MOF adsorbents and the speciation of Hg/As in different petroleum sources. In addition, Zr-based MOFs have proposed some future trends and challenges of porous material that can be used as an alternative to the conventional metal oxides and zeolites.
Experimental Investigation, Porosity-Permeability Modelling, and Artificial Neural Network Prediction of CO2 Injectivity Change for Sequestration
Authors: Md Yusof Muhammad Aslam , Mohammad Fuad Iqmal Irsyad , Md Akhir Nur Asyraf , Ibrahim Mohamad Arif , Mohamed Muhammad Azfar , Maharsi Dara Ayuda 
Published: March 2022

Abstract
CO2 sequestration in saline aquifer is a promising approach to effectively secure the anthropogenic CO2 gas. Complex fluid-rock interaction processes take place during the injection of CO2 would disrupt the thermodynamic equilibrium of CO2 injectivity at near wellbore. In this study, a comprehensive investigation on the CO2 injectivity change of different injection flow rates and brine salinity was performed using core flooding experiments, permeability change prediction using (Kozeny-Carman and Hagen-Poiseuille models) and artificial neural network model (ANN). Core flooding experiments revealed CO2 injectivity impairment increased with increasing brine salinity, with Hagen-Poiseuille being the most fitted model with R2 of 0.935. However, all porosity-permeability models failed to give a good prediction at changing injection flow rate with R2 is well below 0.4. The adopted ANN model showed good agreement with the experimental data at varying brine salinity and injection flow rates. The utilization of ANN for such prediction procedure can reduce the number of experiment, operating cost and provide reasonable predictions compared to existing analytical models.
Edge Optimization Analytics and Control: A Integrated Device of Intelligent Intermittent Pumping for Tight Oil Wells
Authors: Wang Cai , Zhang Xishun , Zhao Ruidong , Shi Junfeng , Zhao Hanjun , Sun Yizhen , Xiong Chunming , Deng Feng 
Published: March 2022

Abstract
Intermittent pumping is an effective measure to reduce energy consumption and improve production time rate for tight oil wells with extremely low oil production. However, the intermittent pumping scheme is mainly controlled by manual timing or RTU remote timing in the cloud. The design of intermittent pumping interval lacks reasonable theoretical basis and the control efficiency is relatively low. Therefore, an integrated intelligent intermittent pumping device combining edge optimization analytic and edge control is developed.
A closed-loop integrated device containing real-time data acquisition and transmitting module, optimization module and edge control module is realized. The optimization module embeds the pump fullness calculation model and intermittent pumping scheme optimization model. Instead of using dynamometer cards, a deep learning model of transferring power curves to dynamometer cards named PTD (Power to Dynamometer) is established through deep learning in order to lower the oilfield IoT cost. The average single well area error of predicted dynamometer card is less than 3%. To transfer the PTD to untrained new wells, a parallel model is established by parallel connection of PTD and transferring learning model. The parallel model is embedded into the edge computing device to realize the dynamometer card real-time prediction and pump fullness calculation. The calculated data is transmitted to scheme optimization model where a reasonable intermittent pumping scheme can be optimized. Then the optimized pumping scheme is transmitted back to the edge control device to adjust the pumping scheme to realize loop control.
This technology was applied to 100 wells in the oilfield, the monthly energy consumption reduced by 30%, and the average pump efficiency increased by about 17%. The application of this technology is insightful to promote the IoT and intelligence of oilfield artificial lifting system.