bluuebunny/crossref_metadata_2025_split huggingface dataset:
Investigation of Critical Requirements for Enhanced Oil Recovery using Lateral Wells in a Layered Reservoir
Authors: Adewole Ezizanami Stephen , Arukhe James Ohioma , Azagbaesuweli Gregory Azuka , Akeredolu Kolawole Peter 
Published: March 2023

AbstractEnhanced oil recovery from a vertically-stacked layered reservoir with lateral wells completed in the layers is often challenging due to inadequate understanding of the complex dynamics of the displacement process. A mobility ratio, which considers reservoir layers, well design and fluid properties, is derived to search for stability condition in the displacement process. Fluid displacement in real time is considered.Displacement stability is monitored using mobility ratio derived from pressure distribution for each lateral well completed in each layer of the reservoir, and the enlarged single reservoir. Any well can be used for injection, depending on displacement and injection fluid type. Crossflow interface is assumed as responsible for communication between the layers. A computer program is written to compute mobility ratios in real injection time. Fluid injection time at which mobility ratio is greater than unity and as high as 10 is identified for any well design, layers, and injection fluid properties.Complete individual layers dimensionless pressure characterization, using layers interface conditions, gives an expression for mobility ratio of interlayer displacement process involving lateral wells. Depending on the nature of injected fluid and overall recovery objectives, any of the layers can be selected for injection or production. Basal waterflooding and gas cycling and crestal gas injection can be studied directly using the expression derived for mobility ratio. The ratio derived gives indication of the duration of optimum clean oil production for any combination of fluid injected. The mobility ratio is affected by individual layer well design, layers fluids and injected fluid breakthrough time. Ratios of well lengths affect length of time of oil production. Longer oil production is possible if the wells have unequal lengths. If the top layer permeability is larger than the bottom layer permeability, waterflooding yields prolonged oil production. Viscosity ratios only slightly affect stability. However, if the bottom layer is used for injection, gas injection for gas cycling, gives appreciable results. Water-free oil production increases as the spacing between the layer wells increases. But well spacing beyond a certain limit does not contribute to further increment in oil production.
Innovative Integrated Workflow to Reduce Uncertainties and Improve Hydrocarbon Recovery
Authors: Boudiba Younes , Pisharat Maneesh , Kelkouli Mohamed , Nettari Ferhat , Meddour Nordin , Seddar Bilal , Babbouchi Reda, Adam , Berbra Abdelhakim 
Published: March 2023

AbstractIn producing fields, remapping reservoir fluid content and new contacts are some of the most important objectives in pursuit of optimized well productivity. Wireline logs and formation testing (FT) data are widely used for this purpose. Continuous fluid data from advanced mud gas (AMG) analysis with downhole logs can be used to generate a comprehensive data set for reservoir evaluation. Each method has its limitation and advantage. Combining and interpreting the output from the fundamentally different data sets require an experienced petrotechnical expert with specific skill sets.To calculate hydrocarbon volume, and estimate and forecast reserves, formation fluid evaluation has primarily relied on a traditional method that depends heavily on formation pressure measurements. This was achieved through the analysis of gradients and local fluid contacts. This approach can be misleading for brownfields, where a sizable amount of producible hydrocarbon is left in the reservoir.For characterizing formation fluid, a novel approach using complimentary technologies was adopted. For early hydrocarbon detection and FT program optimization, AMG data were first gathered while drilling. Post-drilling openhole (OH) logs, formation pressure, and fluid data were acquired not only to verify the AMG findings, but also to fill in the gaps regarding water-swept zones, reservoir pressure and depletion, exact fluid contacts, and fluid characteristics to reduce uncertainties.During the job execution, AMG data were effectively used to provide early formation fluid identification and contacts. This information was used to optimize the wireline advanced fluid analysis stations. AMG analysis identified multiple fluids (wet gas, gas condensate, oil, and water) and revealed a much greater complexity of the reservoir, which could not be achieved with standard formation evaluation or other fluid contact identification techniques based on regional gradient analysis. The fluid types and contacts identified by AMG were then confirmed by the wireline downhole fluid analysis. Using this workflow, a high potential recoverable hydrocarbon oil was identified over a reservoir that was classified as a water zone based on initial evaluation and knowledge.In this field, an innovative method was adopted for reservoir fluid characterization. This approach, based on digital integration and a unified workflow, was used successfully for fluid contact identification, targeted fluid sampling, and identifying and recovering more hydrocarbon from the swept zones.
How to Achieve Operational Excellence through Digital Transformation
Authors: Hegazy Mahmoud Ibrahim , Alsawi Kamel Abdelhamid , Atwa Mohamed Said , Sayed Mahmoud Sayed , Bakeer Mohebat Mady , Rezk Ramy Sayed , Fouda Ahmed Mohamed 
Published: March 2023

Abstract
Achieving operational excellence in oil and gas industry has a great importance due to their high impact on operational efficiency and effectiveness by proper use of human resources, process, innovation and technology which will positively support the quick decision making, eliminate wastes, maximize the system capacities, optimizing the expenditures and resources.

Methods, Procedures, Process
Operation Management System is an inhouse customized cost-effective software to collect, organize, calculate, allocate and analyze big data from different disciplines which helps oil and gas company operations in many ways to overcome business challenges, data management, enhance workflow efficiency, integrate between different disciplines, save time and cost. Each discipline in each company uses its own workflow and data processing technique which may leave gaps in the interconnections between them. These gaps require work duplication to cover overlap areas.

Results, Observations, Conclusions
Using Operations Management system achieves Generate Global database for all company assets production for better management for asset, well performance, target achievements and automatic notifications for targets over dues DFL, well tests, etc. also, allocate all wells in GIS Map for easy and quick access to well data.
It provides cost control tool over the contract by real-time allocation for actual costs and invoices. Digitalizing all the contracts data and track contract administrative. It provides a smart notifications tool for contracts list that will be expired after 6 months.
Real-time allocation for expenditures over the budget accounts directly from invoices and warehouse modules. it shows budget inception to date, Variance and forecast with option to display cost breakdown just by one click.
Smart Tool for Tracking Invoices process as per Company Cycle to make use of early payment discounts. Automatic review for invoices as per cost reference (Contract or purchase orders) and allocate actual cost directly to both budget accounts and contract.
Manages the process of administering receiving, issuing and approving the tenders of the business. It also provides access to all the tender archived data.

Novel/Additive Information
It helps to detect problems sooner, boost collaboration and improve responses, for safer, more reliable, and more efficient operations.
Optimization Design of CO2 Pre-Pad Energized Fracturing for Horizontal Wells in Shale Oil Reservoirs: A Case Study of the Ordos Basin
Authors: Zang Yuxi , Wang Haizhu , Abderrahmane Hamid Ait , Wang Bin , Wang Tianyu , Tian Shouceng , Stanchits Sergey , Cheremisin Alexey 
Published: March 2023

AbstractAn improved recovery technique using carbon dioxide (CO2) pre-pad energized fracturing is presented to address the issue of low recovery in depleted development of shale reservoirs in the Ordos Basin. This study quantitatively evaluates the effect of CO2 pre-pad energized fracturing under different engineering and geological parameters. The geological model of the target block was created in GOHFER using field logging data from the Ordos Basin oilfield. By coupling the reservoir simulator CMG, a three-dimensional wellsite-scale long horizontal mechanism model was established, considering the artificial hydraulic fracture model. The influence of engineering parameters and geological parameters on CO2 distribution was quantitatively evaluated.According to the outcomes of the simulation, the production potential of shale oil reservoirs can be significantly increased by using the CO2 pre-pad energized fracturing development method. Important engineering factors affecting the stimulation include the CO2 injection volume and soaking time, and the geological factors include the porosity, permeability, and layering. When the injection amount reaches a certain level, the growth of CO2 sweep area decreases. With the increase of immersion time, the CO2 sweep range gradually increases. Reservoir porosity and permeability affect CO2 sweep in the lateral direction. Considering the front slick water fracturing fractures, the impact on the CO2 sweep range is not apparent.Combined with GOHFER and CMG numerical simulation software, this study can realize the refined description of reservoirs considering artificial hydraulic fracture networks. According to the CO2 injection range, the effect of CO2 pre-pad energized fracturing under different engineering and geological conditions can be quantitatively evaluated. This study can be used as a reference CO2 pre-pad energized fracturing of shale oil reservoirs in the Ordos basin.
Breaking New Ground. Enhancing Polycrystalline Diamond Compact (PDC) Bit Performance in Chert Formations through Use of Shaped Cutter Technology
Authors: Abdelrazik Mohamed , Ismail Ahmed , Suleiman Ahmed , Hanafy Hatem 
Published: March 2023

AbstractCherty formations are notoriously challenging for fixed cutter drill bits and present a costly challenge for operators who routinely experience short intervals and numerous trips. The predominant limitation is short bit life due to mechanical failure of the cutters. This paper details how an inter-company collaboration led to the development of a design philosophy and a novel shaped cutter technology that resulted in a step change in drilling efficiency and drilling consistency in chert formations.A collaboration between companies was initiated that commenced with a comprehensive study into the cutter-rock interaction to identify the failure mechanism of chert. The results of the research were then used to determine the critical design levers required to overcome these challenges, extended bit life and maximize drilling efficiency. Two fixed cutter drill bits in the 6-in. and 8.5-in. hole sizes that incorporated the new design philosophy and shaped cutter technology were designed. These bits were then field tested in the Egypt Gulf of Suez interbedded carbonates application characterized with the presence of dark brown chert.The new 6-in. and 8.5-in. designs were tested twelve times across four different fields. The runs were then evaluated against durability, rate of penetration (ROP) and cost per foot (CPF) compared to field offsets. In the 6 in. section, the new design drilled the entire section of 3,369-ft that includes 381-ft cherty formation with one bit compared to three bits previously required to drill the same interval. For the same offsets, an improvement of between 50-85% in ROP was achieved. The CPF assessment demonstrated drilling cost reduction between 24-75% across the fields tested. In the 8½ in. section, the new design drilled the entire section of 6,141 ft that includes 296-ft cherty formation with one bit compared to four bits previously required to drill the same interval. ROP wise, an improvement between 59-178% was achieved which corresponded to a CPF reduction of between 41-69% across the fields tested. These field tests demonstrate ground-breaking results in the durability, ROP and CPF performance metrics measured. Furthermore, the number of runs and diverse nature of the fields tested demonstrate the consistency of this new approach to drill cherty formations with full directional control and mitigating downhole vibration severity.A re-examination of the failure mechanism of chert drilling and the root cause behind drilling deficiencies in cherty applications conducted in a collaborative environment has paved the way for a step change in drilling performance. Novel design philosophies were created, laboratory tested, and field validated for consistency of the trials. As the drilling industry continues to explore unchartered applications to ensures cost efficient solutions is paramount to success
Data Science Techniques for Unbiased & Efficient Production Analysis
Authors: Jordan Colin Lyle , Koochak Roozbeh , Roberts Martin 
Published: March 2023

AbstractAnalyses have been widely applied in production forecasting of oil and gas production in both conventional and unconventional reservoirs. In order to forecast production, to estimate reservoir properties, or to evaluate resources, various statistical and machine learning approaches have been applied to various reservoir analysis methods. Nevertheless, many of these methods are suboptimal in detecting production trends in different wells due to data artifacts (noise, data scatter and outliers, inadequate SCADA systems, production allocation problems) that obscure unit reservoir signals, production trends, and more leading to large forecast error, or fail due to lack of data access (inadequate SCADA systems, missing or abhorrent data, and production allocation problems). This work outlines a method that is currently being used in a commercial setting which combines advanced analytics and machine learning with a modern cloud architecture, provide rapid, repeatable, unbiased estimates of original hydrocarbon -in-place (OHIP), estimated ultimate recovery (EUR), and remaining recoverable (RR), and even deliverability forecasts - all in the presence of abhorrent data.
Development of Emulsified Acid System using Organoclays
Authors: Mahmoud Ali Adel , AL-Dogail Ala Shafeq , Gajbhiye Rahul Narayanrao , AlSultan Abdullah Saad 
Published: March 2023

AbstractMatrix acidizing technique is used to enhance the production of hydrocarbons from a reservoir, especially in low permeable reservoirs and in the case of formation damage. In carbonate reservoirs, acid stimulation jobs are challenging due to the acid's strong reactivity with the formation. Thus, the ability to create wormholes will be limited. Wormholes allow hydrocarbons to be produced by flowing into the wellbore. Emulsified acids system helps to overcome this challenge by reducing face dissolution. Recently, Pickering emulsions have attracted attention due to their easy preparation and enhanced stability features. In Pickering emulsions, solid microparticles that localize at the interface between liquids are used as stabilizers instead of surfactants.The preparation of emulsified acid system (EAS) is a complex process sensitive to several parameters governing the properties/feature of the emulsified system. The parameter includes mixing the aqueous and oleic phase, the rotational speed, the time of mixing, and the quantity of emulsifying agent (organology). It requires performing several experiments to identify the proper procedure and optimum range of the parameters affecting the emulsified acid preparation of desired properties.In this study, several experiments were performed using three types of organoclays (OC) namely Claytone-SF (strong), Claytone-EM (medium), and Laponite-EP (weak). Thermal stability tests were carried out at room temperature, 80ºC, and 120ºC. Rheology tests were performed for the most stable emulsions. This study investigated the potential of using special nanoparticles as emulsion stabilizers instead of surfactants. A proper sequence of the component mixing and optimum range of the factors affecting the emulsion preparation and properties were identified. This work aims to study the parameters involved in the emulsified acid preparation and optimize them to obtain a stable EAS.
Numerical Investigation of Hybrid Carbonated Smart Water Injection (CSWI) in Carbonate Cores
Authors: Hassan Anas Mohammed , Al-Shalabi Emad W. , Ghosh Bisweswar , Tackie-Otoo Bennet N. , Ayoub Mohammed Abdalla , Adel Imad A. 
Published: March 2023

AbstractCarbonated smart water injection (CSWI) is a potential hybrid EOR technology under development. The process involves dissolving CO2 in smart water ripping the benefits of the synergic effect of CO2 injection and smart water. Based on the experimental laboratory data, including core flood experiments, this paper presents numerical investigations of the combined impact of dissolving carbon dioxide (CO2) in smart water (SW) on oil recovery in carbonate cores. An advanced processes reservoir simulator was utilized to build a core-scale model. Both the physics of smart water flooding as well as CO2-gas injection were captured. The generated model was validated against the coreflooding experimental data on hybrid CSWI, including cumulative oil production (cc) and oil recovery factor (%). The Corey's correlation relative permeability model was used for capturing the multiphase flow. The numerical model was used to understand the underlying recovery mechanisms and crude oil-brine-rock interactions during CSWI. The model was further utilized to perform sensitivity analysis of different parameters and to optimize the CSWI design.Based on the numerical results, the experimental coreflooding data were accurately history-matched using the proposed model with a minimal error of 8.79% applying the PSO-based optimization method. Moreover, this history-matched model was further used for sensitivity analysis and optimization of the CSWI process. The objective functions for sensitivity analysis and optimization are based on minimizing the history-matching global error and maximizing oil recovery. The optimized design was achieved by performing a sensitivity analysis of various input parameters such as oil and water saturations (Soi and Swi), DTRAP (i.e., relative permeability interpolation parameter). On the other hand, in terms of maximizing the oil recovery while minimizing the usage of injected CSW solutions during CSWI, the optimal solution via the PSO-based approach achieved a cumulative oil recovery of 55.5%. The main mechanism behind additional oil recovery with CSW is due mainly to wettability alteration and ion exchange between rock and brine. Additionally, CSWI was found to be more efficient in releasing trapped oil compared to waterflooding, indicating the synergic effect of dissolved CO2 in SW solutions. Based on this research, the envelope of CSWI application in carbonates for CO2-storage is expected to expand. This study presents one of the few works on numerical modeling of the CSWI process and capturing its effects on oil recovery. The optimized core-scale model can be further used as a base to build a field-scale model. This promising hybrid CSWI process under optimum conditions is expected to be economical and environmentally acceptable, which promotes future field projects.
Impact of Temperature Cross in Feed Bottom Exchanger
Authors: Albert Eliot Robin Bruce 
Published: March 2023

Abstract
The feed bottom exchanger is normally applied to improve the heat recovery, thereby reducing the external heat addition by means of live steam, re-boiler duty, or fired heater duty. A typical approach to heat integration to maximize the heat recovery using feed bottom exchangers would require overcoming the temperature cross in the exchangers. Thermodynamically, heat exchange beyond the cross temperature in a heat exchanger which is not truly countercurrent, is actually not possible. Hence penalty by means of excess area (extra shell) is required to overcome the cross temperature. Conventionally E-shells in series are applied to facilitate the heat exchange beyond the temperature cross. The F-shell exchanger, which is truly countercurrent, can also be used to achieve the same, but constrains such as physical and thermal leakage limit the usage. Recent advancement by the use of twisted tubes in F shell, avoids the physical leakage, because twisted tube bundle is a baffle free design. For the case under study, the heat exchange beyond the temperature cross is not likely to benefit. Hence the use of F shell exchanger will not be attractive. To overcome the temperature cross, the exchanger design is tuned by increasing number of passes or by increasing the number of exchangers in series, enabling more area requirement. An alternative proposal of heat exchange up to the temperature cross is delineated. The parameters that affect/impact the scenario are discussed. The feed bottom exchanger commonly used in units is hydro-treater reactor, amine regenerator and sour water stripper. In the present investigation Sour Water Stripper (SWS) is considered for the case studies.