bluuebunny/crossref_metadata_2025_split huggingface dataset:
Multilateral Fishbone Wells Utilization to Unlock the Production Potential and Analyze the Interference Phenomena of Marginal Field with Depletion Drive Mechanism
Authors: Magomadov Ismail , Balhasan Saad Abdallah , Elsayed Mohamed , Abbas Hafsat Abdullahi 
Published: October 2022

Abstract
Technical and economic optimization of marginal mature fields currently becomes a major industry concern: such fields contain considerable amounts of hydrocarbon reserves that could be produced using current technology simplifying lack of pressure support and interference phenomena issues. The total oil recovery factor of depletion drive reservoirs varies from 5 to 30%. This type of reservoir does not initially have a source to maintain pressure: energy is mainly supplied by the release of dissolved gas due to the rapid continuous decrease in pressure and the low compressibility of fluids. Multilateral wells technology accomplished with ESPs is used in our study to mitigate the interference phenomena and provide the strong pressure support to the system- a theoretical marginal reservoir. The major objectives of this work are to design various multilateral alternatives, analyze technical standards and specifications, observe production performance, and judge the designs technically, economically, and based on ethical and environmental codes compliance. Design alternatives of this study contain 2, 4 or 6 fishbone type laterals under 45 or 90 degrees inclination angles. The main horizontal bore is fully cased and cemented, and the branches are fully cased and perforated. All alternatives were accomplished with Electrical Submersible Pumps (ESP) technology. Based on technical performance (Recovery Factors and Cumulative oil production) one design alternative was selected as the best one (2 laterals from 45 degrees group): RF was enhanced from initial 2.6 to 22.6 %. Based on the results of economic evaluation and risk analysis, alternative with dual 2 laterals under 45 degrees inclination demonstrated the best performance. Production performance of marginal field was optimized increasing the RF from primary recovery 2.55 % to 22.63 % after utilization of multilateral well technology combined with ESP-s.
Digitalization of Corrosion Management – Use Cases for Oil and Gas 4.0
Authors: Sharma Prafull , Oskuie Aliakbar , Ennaceur Chiraz , Silatani Mehrdad 
Published: October 2022

Abstract
This paper describes the applications of digitalization technologies specifically Industrial Internet of Things (IIOT) to predictive Corrosion Management with an attractive use case of corrosion under insulation. The available technologies and case studies of field use cases will be presented.
Hidden corrosion such as corrosion under insulation (CUI) can be better managed with digital data harvesting and with predictive tools using data of the assets such as knowledge of moisture locations and temperature etc. This method involves use of this data set to manage the assets holistically, prioritizing the risky locations and scheduling their inspection and maintenance. A predictive method is described which can help the asset owners not only manage the assets in a cost-effective way but in a safer way too if the risks are pre-identified and acted upon.
In this article the predictive CUI monitoring technology is introduced. The technology includes sensing conditions under the insulation and predictive modeling to estimate risks in a very rapid manner. In this paper, use-cases and applications will be explained and shown.
The new method of using sensing and industrial IOT to detect and predict corrosion in the field will be a huge impact for the asset integrity struggling with the threat of hidden corrosion such as corrosion under insulation. The paper will reveal the latest case studies from the field usage of monitoring thereby building confidence in it and advancing the knowledge base in corrosion industry.
Dynamic Optimization of Demulsifier Injection and Water Separation Crude Oil Through Data Analytics
Authors: White Ramsey James , Lopez Andreu Miguel Angel , Alhamoud Abdullah Abdulrahman 
Published: October 2022

Abstract
This paper describes a sophisticated control method (known as "Smart Demulsifier Control") for automatic adjustment of optimum demulsifier chemical injection, which was adopted at several Gas Oil Separation Plants in Saudi Aramco. Demulsifier chemical is a key additive used for oil and water separation. Excessive dosing would lead to increased operational costs while demulsifier under-dosing will impact crude quality due to separation upsets such as desalter grid overload. The system utilizes models that were developed using data analytical tools to optimize demulsifier chemical injection in real time.
In a Gas Oil Separation Plant, formation water is first separated in a horizontal three phase separator. The rest of water is removed in electrostatic coalescers to achieve the required crude specification. The amount of demulsifier added can balance the separation within certain limits. There are several operational parameters that affect the separation. Most are not controlled (disturbances) such as crude type, emulsion tightness and temperature. The method uses basic instrumentation measurements to measure the online separation balance, compares the actual data to expected data based on a process model and adjusts demulsifier concentration within an adequate dynamic window using a combination of PID algorithm control loops.
The implementation of Smart Demulsifier Control scheme at several GOSPs was proven to be a reliable and robust method to fully automate the addition of this important chemical. The online separation measurement provides a clear visualization of the overall separation balance and it is used to adjust dosages accordingly with PID loops. PID algorithm can be easily adjusted at each plant to ensure the speed of response is adequate. Usual plant disturbances that can affect separation balance such as well alignment changes, feed rate and water cut variations are tackled by the control scheme through live separation monitoring. Operators can also influence the separation with some margin parameters provided in the scheme. The dynamic operating window ensures that the amount of demulsifier is within reasonable limits at all times. The design is parametrized to allow for easy modifications in case of new crude feeds, demulsifier effectiveness formula changes or seasonal changes (summer/winter). This novel scheme has been implemented at nine Gas Oil Separation plants processing Arab Light crude. Based on a complete year of evaluation, a very significant reduction in electrostatic coalescer upsets related to inadequate water separation in the three-phase separator has been achieved along with an average reduction of demulsifier consumption of 15%.
A patent for the control scheme has been granted by the United States Patent and Trademark Office. It is unique in its simple approach to optimizing demulsifier dosage while ensuring a smooth process of crude oil emulsion treatment and separation.
Detection and Monitoring of Corrosive Oilfield Microorganisms via Novel Biomarker Technologies
Authors: Lahme Sven , Mand Jaspreet , Oparaodu Kingsley , Enning Dennis 
Published: October 2022

Abstract
Petroleum-transporting infrastructure can experience severe corrosion in the presence of microbial biofilms, a process termed microbially-influenced corrosion (MIC). However, not all microorganisms are corrosive and distinguishing corrosive from benign biofilms remains challenging with current technologies. In recent laboratory tests we identified two biomarkers suitable to discriminate corrosive methanogenic archaea (micH) and sulfate-reducing bacteria (micC) from their noncorrosive counterparts. In this study, we demonstrate suitability of newly developed qPCR assays, that target the specific microbial enzymes micH and micC, for field application.
Water samples and pig debris were obtained from various oil-transporting pipelines that with high likelihood experienced MIC at the time of sampling as well as from pipelines without a perceived threat of MIC. Samples were analyzed with existing methods including 16S rRNA gene sequencing to identify the whole microbial community present in the samples and qPCR assays designed to enumerate total bacterial and archaeal populations. These results were compared to those obtained from the use of newly developed targeted qPCR assays for micH and micC.
First we tested the novel assays on pig debris samples obtained from a North American pipeline in which active corrosion was suspected from recent in-line inspection (ILI) date. The results showed 5.6·104 gene copies of micH and 7.9·104 gene copies of micC per g of pig debris. In comparison, the micH and micC biomarker were not detected in a pipeline from the same field that did not show active corrosion. Subsequently, we tested the novel biomarker assays on more readily available produced water collected from an African oilfield. On average, 2.4·102 gene copies of micH/ml were measured in MIC-affected pipelines. The MIC biomarker micC, on the other hand, was detected at about 1.2·102 gene copies/ml in only one of the tested pipelines that experienced MIC. Intriguingly, neither micH nor micC were detected in wellhead fluids or other areas where MIC was not suspected. The correlation of micH and micC with active corrosion in oil field settings demonstrated the merit of these novel biomarker to serve as indicators of active MIC. Detection of the MIC biomarkers in water samples from affected pipelines would also allow efficient microbial monitoring independent of biofilm samples. This would allow easier implementation of this new biomarker technologies in the field. Furthermore, the detection of both biomarkers in samples from geographically distinct oil field operations points to global significance of these assays.
MIC is notoriously difficult to detect and monitor with current technologies. The development of these novel MIC biomarker technologies enables, for the first time, the targeted detection of highly corrosive microbial communities to develop truly diagnostic and actionable data for MIC detection and mitigation.
A Study on Reliability-Based Assessment of Ageing Fixed Offshore Platforms Located in the Arabian Gulf
Authors: Thomas Abin Pulivelil , Nekstad Ole Jan 
Published: October 2022

Abstract
Offshore platforms and tubular structures are examples of lightweight supporting structures for oil and gas and wind energy production units. However, their reduced weight is obtained at the expense of increased susceptibility to fatigue failure because of their tubular welded joints or connections. Hence extra consideration must be given to the fatigue design of the hot spots. The objective of the proposed shell fatigue design methodology for critical jacket joints is to calibrate the fatigue reliability for inspection planning studies. This study summarises research on the development and use of reliability-based jacket joints inspection planning approaches for offshore structures. The main objective of the study is to reduce the uncertainty introduced by SCF calculations on crucial joints by modelling such joints as an FEM shell model. The study also provides an application process and workflow for a standard Arabian Gulf jacket for fatigue reliability assessment. First Order Reliability Method (FORM) is used to determine the reliability index. The study also provides insights into methods for planning in-service inspections of ageing offshore platforms.
Erosion Prediction in FCC Unit of Refinery Through Computational Fluid Dynamics Simulation
Authors: Abdul Quiyoom , Rakshit Pranab Kumar , Voolapalli Ravi Kumar , George Prince , VN Dileep Kumar , Thota Raviteja 
Published: October 2022

Abstract
In the Fluid Catalytic Cracking unit of refinery, erosion due to catalyst impact on wall refractories is a serious issue that affects the plant performance. In the present study, Computational Fluid Dynamics (CFD) coupled with Discrete Element Model (DEM) method is used to characterize gas-solid flow dynamics and erosion in regenerated catalyst slide pipe (RCSP). Catalyst particles size in the range of 1-180 µm were considered for the simulations. The predicted erosion profile was verified by comparing with thermography experiments and were found in a good agreement.
The predicted results revealed that due to partial opening and orientation of regenerated catalyst slide valve, the rapid alterations of flow direction of catalyst particles take place. Particles recirculate in the rear end of the pipe and continuously impinges at the 12 o'clock position upstream of the valve. This led to erosion in the pipe. The experimentally validated CFD model was used to characterize the erosion profile under different relative openings of regenerated catalyst slide valve (RSCV). It was observed that with increasing the valve opening the erosion profile was reduced due to decreases catalyst recirculation velocity and vice-versa. Further, effect of valve opening orientation was also studied and it was found that by changing the valve opening orientation from parallel to ground surface to down towards, erosion was not observed due to small recirculatory flow of catalyst with low velocity. The results presented in this work will help refiners to understand the catalyst flow dynamics inside the regenerated catalyst slide pipe, root cause of erosion in pipes, and to achieve further improvements in the performance of plant.
Impact of Diagenesis on the Reservoir Properties of the Cretaceous Kharaib Formation, Sajaa Field, Sharjah, United Arab Emirates
Authors: Phukan Madhujya L , Siddiqi Saad A , Almunaifi Asma , Robert Matthew J 
Published: October 2022

Abstract
The Early Cretaceous Kharaib Formation is one of the most prolific hydrocarbon bearing reservoirs in the Middle East. Based on sedimentary characteristics, the Kharaib Formation is divided into three main intervals/zones: the lower, middle and upper Kharaib. Interpretation of the depositional fabrics and prediction of reservoir parameters is often difficult due to the Kharaib Formation's diverse array of sedimentary characteristics. To address the considerable heterogeneity of the Kharaib Formation, this study investigates depositional characteristics and the diagenetic impact on reservoir quality within the Sajaa Field.
The Kharaib Formation sediments were characterized using a Dunham/Embry & Klovan (1971) defined classification scheme. Analytical techniques via thin section analysis, scanning electron microscopy (SEM) and capillary pressure data were used to qualitatively and semi-quantitatively assess porosity and the diagenetic processes involved in its evolution. Key reservoir quality parameters for Kharaib intervals were defined by combining petrographic analysis and conventional core methods.
The sedimentological characterization of the Kharaib sediments in the Sajaa Field showed a range of Orbitolina-bearing carbonate textures, which were interpreted as inner-ramp deposits. The stacking pattern of the depositional facies showed intermediate-order trends. The conventional core analysis measurements showed poor to good reservoir properties with porosity values of 0.7 – 23.2% and permeability values from negligible to 2 – 3 md. The pore system is dominated by grains and matrix-hosted micropores, which are primarily generated via diagenesis. Qualitative thin section analysis identified grain-hosted micropores as the most significant microporosity type, highlighting that grain-rich textures are relatively more porous compared to mud-rich textures.
Diagenesis transformed both the matrix and various grain types (e.g., micritized grains, foraminifera etc.), generating considerable micropore volume. High resolution SEM imaging, along with semi-quantitative assessment, highlighted that diagenetic modification of the micritic sediments led to an abundance of sub-rounded to polyhedral crystals exhibiting primarily sub-punctic to punctic intercrystalline contacts that generated a porous fabric. Mercury injected capillary pressure (MICP) data, confirmed the abundance of micropores within the pore size distributions of studied samples.
This study demonstrates the importance of considering textural variation within the Kharaib Formation when assessing the reservoir coupled with the fractured nature of the unit. The established microporosity-depositional relationships when combined with the updated core descriptions now allow for the integration of textural trend information in the field that can be applied to refine reservoir property and abundance distributions.
Proactive Management of H2S Levels in a Mildly Sour Gas Field Through Production System Optimization: Case Study From Central Luconia Province, Malaysia
Authors: Mohd Ali Haneff , Omar Siti Ili Fatimah , Langat Adrian , Mohamad Shah Samsul 
Published: October 2022

Abstract
High H2S issue was investigated in Field B shortly after production, with quite a variation on the measured H2S readings. The initial opinion was it might be related to the measuring methodology, as no evidence to suggest that the H2S level would increase over time from the reservoir point of view. To verify this, a full sampling program was conducted, consisting of onsite sampling and laboratory analysis. This includes stain tubes measurement, online gas chromatograph, H2S analyzer and UOP method. The H2S isotope analysis was also conducted to determine the H2S source and its future behavior in the reservoir. This paper serves as lesson learnt and best practices in H2S management from subsurface to facilities unified approach, highlighting the importance of proper data acquisition, with focus on contaminants. Indeed, H2S is a contaminant found widely in oil and gas industry and can be a limiting factor to development or hinder production if it is not appropriately characterized during exploration, appraisal and early stage of production.
Addressing the Challenges of Simulating EOR and CO2 Storage Projects at Reservoir Scale: Accurate Estimation of Trapped Gas Saturation
Authors: Aghabozorgi Shokoufeh , Sohrabi Mehran 
Published: October 2022

Abstract
One of the first and foremost steps in the feasibility analysis and site selection of geological CO2 storage projects is estimating the storage capacity of the appointed aquifer or depleted reservoir. It has been established that the volume of CO2 stored due to capillary trapping is significantly higher than other active mechanisms. Therefore, an accurate method is required to determine the trapped gas saturation in the system. This method is also of significant importance for simulating any other process involving cyclic injection of fluids in subsurface reservoirs as the hysteresis in relative permeability is a direct function of trapped gas saturation. Examples of the cyclic process in subsurface reservoir engineering are gas storage projects and reservoirs undergoing Enhanced Oil Recovery (EOR) injections. In this study, we present a detailed study of the reservoir scale simulation results using commercial software, and we discuss the challenges observed in calculating the trapped gas saturation.
The first challenge is that Land's formulation relates the initial and residual non-wetting saturations measured during an imbibition cycle. However, in many reservoir blocks, the volume and rate of displacing fluid are insufficient to ensure reaching the residual values. Accurate determination of saturation histories in various reservoir grid blocks is also challenging as small oscillations make it hard to identify the flow reversal points. A significant amount of error is introduced in compositional simulations when the composition of trapped gas saturation enters mass transfer calculations, and the trapped gas is dissolved again in the oil phase. Whereas physically, it should be isolated and shielded by the water phase. Finally, an inaccurate definition of saturation-dependent functions can increase the error associated with calculating relative permeability data using trapped gas saturation.
In this study, we present a new workflow for calculating the trapped gas saturation, addressing all the abovementioned issues. The backbone of this workflow is an efficient algorithm which removes any oscillation misidentified as a flow reversal point. The results discussed in this paper indicate that the available formulation in the literature should be deployed carefully (considering the active mechanism in the system) to decrease the uncertainties. As a result, the feasibility of EOR methods, the site selection for CO2 storage projects and the decision-making process can be based on more reliable data.
The Accurate and Efficient Simulation of a Fractured Tight Gas Condensate Reservoir Using Embedded Discrete Fracture Model
Authors: Yuan Chengwu , Yu Wei , Ghanbarzadeh Soheil , Liu Chuxi , Miao Jijun 
Published: October 2022

AbstractThe hydraulic fracture modeling is critical for the well dynamic performance and development optimization in the fractured condensate reservoir. The conventional approach based on LGR (Local Grid Refinement) is widely used but with low computational efficiency, and sometimes with artificial fracture orientation and geometry. In this study, a new workflow to model the hydraulic fractures using EDFM (Embedded Discrete Fracture Model) is developed to couple with the Nexus reservoir simulator for the first time. Borrowed from the dual continuum concept, the main idea of EDFM is the non-intrusive embedding of the fracture medium physical properties (such as transmissibility, pore volumes, etc.) into the pre-existing matrix cell blocks. Using the EDFM, tedious work such as model re-gridding and refinements can be avoided, and realistic fracture geometry and geological structures can be honored with only a fraction of the total computational cost.We validate the EDFM approach firstly with a simple mechanistic model and then a sector model with 18 hydraulic fractures in Cartesian grids. The results from the traditional LGR method are compared with those from EDFM to demonstrate its robustness. For the same fracture geometry and reservoir model configurations, the LGR-based and EDFM-based approach gives almost identical results for production simulations. We then applied this workflow to a more realistic sector model with 18 vertical wells in a tight gas condensate reservoir with corner points geometry. We demonstrated that the EDFM approach enables more realistic hydraulic fracture modeling, including the flexibility to incorporate geomechanics-consistent fracture orientation, gridding-independent fracture height, fracture half-length, and straight-forward modifications of fracture properties. Additionally, the speed of the EDFM is much superior to the LGR-based one. The speed-up factor reaches about 50 when appropriately decomposing the domain in this sector model, reducing the computational time from about 8 hours to about 9 minutes. This EDFM-Nexus workflow enables a much faster and more robust fracture modeling, model calibration, development optimization, and business decision-making in the tight gas condensate reservoirs.